bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Cases of Cost Efficient Slickline Well Interventions
Authors: Larimore David R. , Fehrmann Gary Z. 
Published: October 2008

Abstract
The comparison of today's slickline capabilities with its early usage for routine remedial workovers and maintenance best illustrates the significant advances that have occurred within slickline technology. Today, for example, slickline can be used to I) set and retrieve slickline-retrievable safety valves or plugs, 2) open and close downhole circulating devices, 3)retrieve accurate depthhime data for correlating with memory production surveys for well diagnostics (problem identification) reservoir description, or flow analysis, 4) provide accurate correlation of tubing casing collars, and 5) pull and run multiple flow controls set packers and other downhole equipment without explosives; setting monobore tools; and other perform other well interventions that are dependent upon measurement accuracy. Less than a decade ago, slickline was only considered for mechanical well workovers.
This paper will discuss the newly developed technology that allows slickline to economically provide alternatives to services traditionally reserved for other, more costly options. Case histories will be used to illustrate the enlarged scope of services and how the equipment combines to provide the innovative low cost service options that the industry has been seeking.

Introduction
Economic initiatives are usually the drivers of new technologies, and thus, reacting to the significant decline in the oilfield climate during the last decade, no era has been as momentous in providing stimuli for operational change. Unfortunately, operators who are seeking new methods usually look to new technologies as the potential problem solvers, and in so doing, overlook enhancements to the older, proven technologies that could provide the cost efficient alternatives they want.
This has been the case with slickline. Until the resurgence of investigation into new strategies to meet the oilfield cost constraints of the last decade, slickline service was only considered for routine mechanical workovers. Who would have considered using slickline to set a packer in the early 90's.
The capabilities that have changed the profile of slickline service from one of routine mechanical well work overs to a multi-faceted service technology are derived from the new slickline tools that can be used independently or combined to further enhance the scope of services. The equipment includes an electronic triggering device (ETD) that enables safe detonation of explosive devices, a battery-operated, electro-mechanical tool that sets wellbore devices on slickline and braided line without explosives, an electronic measurement system that automatically corrects measurement inaccuracies resulting from line stretch and environmental stress factors, a slickline collar locator (SLCL) that accurately verifies collar locations in a tubing string, and data job loggers or acquisition software systems that connect to the electronic measurement system to graphically record dynamic wireline information.
A New Concept for Multibranch Technology
Authors: Stracke Mark , Neme Eric , Leismer Dwayne , Buytaert Jean 
Published: October 2008

Abstract
Industry interest for multibranch wells has grown in the past few years thanks primarily to the new capabilities offered by quickly evolving drilling technologies. A wide range of applications. all aiming at improving reservoir production economics, has already been identified.
However, multibranch wells have also created new challenges. Well construction. well control. as well as completion of the branches remain key issues yet to be satisfactorily addressed.
A new concept of multibranch system design has been developed not only to address short term well construction issues (milling, drilling, and completing), but also to answer the needs of reservoir management during the life of the well. Input from over fifty oil companies was gathered to define this system's specifications. It was developed by a multidisciplinary team of specialists from major directional drilling, completion, drilling fluids, and cementing companies.
This system is designed to provide a prefabricated sealed connection between the branches and the main trunk of the well. It will be functionally tested in a workshop prior to installation. Once installed in a well, the system provides ready to use sealed outlets which do not require window milling, nor does it rely on cement for pressure integrity, and it maintains full bore access below each branch. Other features include selective reentry ability in each branch at any stage of the life of the well, with minimal time spent for intervention

Introduction
A multibranch well is a vertical, deviated, or horizontal main conduit with two or more lateral conduits drilled at am depth, in any direction, and either horizontal or slit inclination. The main conduit may be an existing well (reentry) or a new well drilled specifically for the multibranch application. Multibranch wells provide opportunities for increased production rates at lower costs than single bore horizontal wells, and are particularly applicable for high cost and small fields. They will pennit a reduction in the surface construction requirements for wells; wellheads, surface and intermediate casing strings, and their corresponding costs. One of the greatest potential applications for multibranch wells will be in the development of deep water reservoirs where the number of wells and their surface construction items are commonly major driving factors in production system design and costs.
Multibranch well technology is not a new technology. Since the early 1950s oil company operators have experimented with multibranch wells. These early wells were exclusively open hole sidetracked completions. Even today this is the most common example of multibranch well drilling as evidenced by the hundreds of multibranch wells being drilled in such areas as the Texas Austin Chalk and Canada.
Use of Electrical Power in Control of Wax and Hydrates
Authors: Aarseth Finn 
Published: October 2008

Abstract
Electrical heating of subsea flowlines represents an effective method to prevent wax and hydrate formations, especially at long transportation distances and in deep waters with a low seabed temperature.
Such systems are available to be used in conjunction with bundles, pipe-in-pipe and wet thermal insulation systems, enabling an environmental friendly fluid temperature control without use of chemicals and flaring for pipeline depressurizing.
Enhanced production availability is achieved as no time is lost by unnecessary de-pressurizing, pigging, heating medium circulation or removal of hydrate and wax blockages.

Introduction
The seabed temperature at 100 m water depth and lower may range from 7 °C to -1.5° C, causing a rapid cooling of hot well streams being transported in subsea flowlines, see Fig. 1.
Vulnerable crudes and multiphase compositions will at such super cooling deposit wax and asphalts, and the gas - water phase may freeze solid hydrate particles that can permanently block the pipeline.
A conventional approach to secure a safe subsea transportation has been to use thermal insulated flowlines in combination with the following measures:Continuous injection of chemicals to reduce the hydrate freezing point and the rate of wax deposition.Depressurization of the flowline to enable a further reduction of the hydrate freezing-point.Use of twin parallel flowlines to achieve a more effective depressurizating of potential hydrate plugs, and to perform pig cleaning operations. Further to circulate hot waterloil in order to melt out wax and to pre-warm the flowlines after long lasting shut downs.
It is obvious that these measures do have physical, economical and environmental limitations especially in deeper waters and over very long transportation distances:The pressure head in deep water pipelines may give an insufficient pressure relieve at blow downs.Blow down and pressurisation of pipelines will involve pressure drop expansions and a related Joule-Thomson supercooling of multiphase fluids, that by itself can cause severe wax deposits and hydrate plugs.Heat loss in long twin pipelines that shall be preheated in a serial configuration, will restrict adequate heating above 10-15 km length.Continuous injection of large amounts of hydrate and wax inhibitors will dissolve in the produced water that may have a restricted release to sea.Long twin flowline installations will generate high investment and operational costs.
Thermal insulated and electrically heated flowlines represent an alternative prevention method for wax and hydrates that will not be restricted with the same limitations.
A market review of different designs and functional principles conclude that electrical heating technology is available for flexible risers and flowlines, pipelines, pipe-in-pipe and bundle systems for all practical lengths in subsea transportation. Some of these have been in operation with a satisfactory performance over a period of more than 20 years.
Cased Insulated Pipeline Bundles
Authors: Nock Mendel , Bomba John 
Published: October 2008

Abstract
Bottom tow pipeline bundle installations are gaining acceptance in deepwater developments. This is particularly the case where paraffins and hydrates pose a problem, since insulation and heating lines may easily be added inside the buoyancy casing, with less cost impact than in vessel based methods.
However, barriers to more extensive use of the bottom towed bundle technique are perceived problems of potential leakage into the outer casing and perceived problems related to the pressurization of the casing.
Approaches to mitigation of such problems, such as Bulk heading and foam filling are proposed and evaluated herein.

Introduction
Deepwater developments currently underway are increasingly requiring either insulation or heating to prevent hydrate formation or waxing in flowlines traversing cold ambient waters. Flowlines may be insulated either with directly applied insulation, pipe-in-pipe insulation, or insulation wraps within cased bundles. Heating may be achieved utilizing heating water in separate lines or annular jackets, or electrically, utilizing skin effect current transfer or other means.
Possible installation methods, already in use or imminent, include reeling, J-lay, S-lay or towing of bundled pipelines. In a towed installation, the pipelines and casing are welded into strings on a beach. To date, all Gulf of Mexico bottom towed bundles have been fabricated at Matagorda Peninsula, just down the coast from the mouth of the Colorado River. Thus site accommodates bundles up to 10 miles long. The bundle is then deflected laterally off of the beach and towed to the site. Pipelines may be towed on the sea dace, at mid- depth, or on bottom. All the Gulf of Mexico bundled installations have been by bottom tow.@ The bundled approach to installation of multiple pipelines, is to gather the several pipelines into a single package, and to provide a casing around the entire package which brings the total bundle submerged weight into a desired range. For a bottom towed bundle this submerged weight must be great enough to provide stability during the launch and tow process but low enough to permit towing by available vessels. The casing diameter required for correct submerged weight is normally sufficiently large such that an insulating wrap layer may be added to the flowlines without change in the design of the bundle, and the low density of insulating materials makes only a modest change in the submerged weight.
In shallow water depths the casing may resist hydrostatic collapse through its inherent stiffness, however, as water depths increase the increase in wall thickness required to prevent buckling makes it impossible to achieve a desired submerged weight.
The Development and Use of a Subsea Multiphase Flow Meter on the UK South Scott Field
Authors: Slater S.G. , Paterson A.McK. , Marshall M.F. 
Published: October 2008

Abstract
In May 1995 a multiphase flow meter (MPFM) was installed in a subsea production manifold on the UK South Scott Field operated by Amerada Hess Limited. This achievement was the culmination of a three year collaborative development programme, the objective of which was to develop and prove a prototype MPFM for a commercial subsea application.
The incorporation of the MPFM in the South Scott production facilities had two main benefits. It reduced the complexity of the infrastructure required to develop the field by eliminating the need for a dedicated test pipeline and riser system, and significantly reduced the project capital expenditure. Additionally the application provided the opportunity to deliver benefits to the production and reservoir engineering community by allowing real time monitoring of well tests.@ Despite the comprehensive testing undertaken during the development programme, the South Scott MPFM experienced an electronic component failure early in its operational service life, which resulted in the recovery of the meter and a subsequent failure investigation. This process uncovered a more complex problem associated with one of the sensor units, which required the development of a new technology for a solution. Through the sustained efforts and commitment of the venture partners, the initial setbacks have been overcome and the meter is planned to be operational on the South Scott field in February 1997.

Introduction
The development of hydrocarbon reserves in the mature province of the United Kingdom Continental Shelf is an increasingly challenging business. As the production from the large pioneering fields gradually declines and the discovery of significant reserves becomes a less frequent occurrence, the development focus has fmly turned to the exploitation of marginal and mini fields. As many of these accumulations are in the proximity of existing platforms, the option to produce the fields through subsea facilities tied back a to host platform is an attractive development concept. The limitations posed by existing infrastructure and the characteristics of some of the new fields has necessitated the advancement of new technology to provide novel equipment and processes for the economic development of these fields.

New Technology Initiative
In recognising the need for new technology and the significant contributions it can make to the core business areas of finding, developing and producing offshore hydrocarbon reserves, Amerada Hess Limited embarked upon an initiative to search out specific emerging technologies which could benefit the business if progressed to the level of commercial availability.
During the course of evaluation studies performed as part of the initiative, the topic of subsea multiphase separation, transportation and measurement was repeatedly identified as being of major importance to the development of future prospects.
Applications of Multiphase Meters at the Gullfaks Field in the North Sea
Authors: Økland O. , Kleppe K. , Berentsen H. , Klemp S. 
Published: October 2008

Abstract
The development of Multiphase Meters (MPM) has been an important R&D project for Statoil during the last decade. Extensive testing of MPM the last 4 years, leading to significant improvement of the accuracy and reliability of the meters, has proved that today the performance of MPMs are within our specifications.
The first large scale tests of MPMs from the vendors Fluenta, Framo and MFI took place at Statoil's Gullfaks B platform during the period from December 1992 to November 1994. The results from these tests have been published earlier [1,2,3]. The Gullfaks B conditions are, however, considered not to be too difficult for multiphase metering. This is due to relatively good mixing of the phases and a low gas volume fraction.
In 1995 the fist testing of commercial multiphase meters over a broad operational domain took place. This qualification test was performed in Norsk Hydro's test facility in Porsgrunn [4]. The test campaign was repeated in 1996. Improved commercial meters from Fluenta, Framo and MFI were tested together with two meters under development (Kvzrner Process Systems and ISA Control). The test was sponsored by 9 different oil companies.
In August 1996 Statoil awarded a contract for the supply of 8 topside MPM for the Gulfaks Satellite project. This was followed by a new award in November 1996 for 18 subsea MPM (with an option for another 9 meters) for the field developments of Asgard and Gullfaks Satellites. Bothcontracts were awarded to the Norwegian company Multi-Fluid Int. (MFI).
For applications of subsea MPM it is of crucial importance that the accuracy, stability and repeatability of the meters are according to the specifications. To be able to learn from practical experiences of operating such meters, Statoil has installed two subsea meters from MFI and Framo for a one year test at the Gullfaks B platform.
At Gullfaks B another MPM has been in operations since November 1996 for allocation metering of the production from a long reach well. The well has been drilled into a nearby reservoir where other tax regulations appliescompared to the main field.
Initial comparisons of the MPM and the test separator shows encouraging results.

Introduction
The large economical potential for applying multiphase meters has been the driving force behind the various development projects supported by the oil industry for the last 10-15 years. Today, several first generation meters are commercially available and the oil industry is now starting to use them in large numbers. Multiphase meters are either used for well testing or for production allocation metering.
France's Forty Years of Experience in Offshore Technology
Authors: Appert O. , Burger J. 
Published: October 2008

Abstract
This paper focuses on some particularly illustrative contributions of oil companies, service and equipment suppliers, research centers from France, to the history of forty years of offshore adventure.
Other advances are still to be expected, and some major trends for the coming decades are discussed.

Introduction
The importance of France's technological input to offshore industry may surprise since France holds very low oil and gas reserves on its territory. Despite this situation, Elf and Total are in the top 20 of the world's oil companies, the French supply and services industry has developed worldwide activity, Institute Francais du Petrole (IFP) and other research institutions are known internationally for their contribution to the progress of the oil and gas industry.
This situation results from the fact that after World War I the security of energy supply has been recognized by the successive governments of France as a major political issue. Therefore, the necessary impetus has been constantly given to encourage the development of the French oil and gas sector. Under the umbrella of this oil policy, a close cooperation between oil companies, suppliers and research centers has been set up in order to develop competences to take up the new technological challenges. This was clearly the case for offshore activities.

A Retrospective View
In the early sixties, the geopolitical situation led France to define a new policy, and it was decided to launch an important programme of development in order to diversify the sources of oil supply (Ref. 1). Offshore was still at the infancy. In fact, the first real offshore discovery had been made on November 14, 1947 in the U.S., 15 km off the coast of Louisiana, in a water depth of 6 m (20ft), with congratulations expressed for having surmounted such a "technical difficulty"; but the exploration activity on the continental shelves really started in 1960. In 1965, gas was discovered by BP in the North Sea: the technological challenge of offshore development effectively deserved to be coped with. When the first oil shock occurred, the French industry had developed the necessary background for taking its share in the development of the promising reserves of the European offshore domain.
In this context, the European Commission launched in 1973 a technological program to promote the development of hydrocarbon resources in Europe. During this period of high oil prices, new technologies were studied and tested at the prototype stage with the aim of overcoming the bottlenecks to exploration and production with regard to hardly accessible offshore reserves. French companies have been strongly involved in this adventure and contributed to major issues, as indicated below, while promising international partnerships were initiated.
Meeting the Challenge Regarding the Quality of Drilling and Production Data Recovered From Offshore Wells
Authors: Debray Benoit , Haines George 
Published: October 2008

Abstract
This paper presents the efforts made by a service company during the past thirty years to participate in the development of offshore activities, by continuously meeting technical challenges in the monitoring of drilling, testing and production of offshore wells. Offshore operators have long recognized the need for a maximum of drilling and production data of the highest possible quality. Today's stringent requirements for increased safety, environmental protection and minimum cost have increased the importance of data quality and are being applied worldwide.
On site real-time data aids offshore development : many case histories have demonstrated how the use of rig site data acquisition computers provides geologists and drillers with valuable data from which rapid and efficient decisions could be made a1 the drill site. Surface data logging is a unique opportunity to obtain direct evidence of oil as well as recording all main well events; offshore constraints have speeded up the development of on-site data storage and offshore-onshore teletransmission.
Technical advances applied to surface and down hole equipment enable efficient appreciation of onshore exploratory wells : once a system is installed to acquire, monitor and transmit data during the drilling phase, it is convenient to also use it during the testing phase. The quality of the monitoring of well testing activity relies on the ability to obtain accurate bottom hole data in real-time, which can be difficult while running a DST. Newly available technical advances help in solving such problems, as well as improving the quality of pressure measurements and optimizing the cost of the test by reducing its overall duration.

Introduction
We present here an overview of advances in information technology and remote sensing by a particular service company that we believe have had a significant impact in offshore drilling, well testing and production. These innovations have been developed over the past 30 years and are being implemented worldwide. The general aim of these technological refinements has been to close the decision loop that is to increase the reliability of data and shorten the time required to make critical decisions.

On Site Real-Time Data Aids Offshore Development
Mud Logging, sometimes referred to by the modern term of Surface Data Logging (SDL) provides the only broad-based method to combine geological and drilling data in real time. This provides a unique opportunity to obtain direct evidence of oil and gas as well as recording all main drilling events. SDL is an evolutionary step beyond basic mud logging services, recovering transient drilling and geologic information to allow better 'tuning' of the well construction process for highest efficiency. A major component of SDL is the effort to simplify, as much as possible, the presentation of ever-more complex operating conditions, while reducing the need for operator intervention to understand the nature of well events.