bluuebunny/crossref_metadata_2025_split huggingface dataset:
Protecting Wellheads And Maintaining Platform Integrity During Offshore Well Fires
Authors: Hansen A. Boots , Matthews E.O. Coots 
Published: December 2007

The risk of offshore blowouts and of pressure fires is considerable. and dangerously unpredictable. Such blowouts and fires are so dangerous and so expensive, that owners and operators of offshore structures are well advised to consider expending effort and money to do everything they can in advance that will reduce damage, lost time and the costs of capping the blowouts and extinguishing the pressure fires.
Getting back into production after such an accident on one Gulf Coast platform required several months for one operator. Elsewhere. a platform emergency involved ten wells set on fire after one blow out on a 64 slot platform being worked. Capping such blowouts and cutting off such pressure fires is not at all the same as coping with ordinary hazards and accidents. Nor is it substantially the same as coping with the same emergencies onshore.
Every professional in the oil industry has some knowledge of what equipment should be used and what precautions must be taken to prevent blowouts and pressure fires. This technology has been around for many years. Many professionals also have considerable knowledge about fighting offshore fires knowledge they very likely gained at considerable cost! But both equipment and procedures are different in each field. Fighting offshore fires, capping blowouts in remote and hostile environments, particularly in areas like the North Sea, is still rather new. We believe that the people who are most concerned about avoiding such disasters, and about reducing the damage and cost of any outbreak that does occur, do not have an adequate picture of the best approaches. Much knowledge has become available piecemeal. Only in recent months have those professionals most concerned with it put together a complete perspective and recommendations.
Tecnomare Steel Gravity Platforms For Marginal Fields
Authors: Lalli D. , Vielmo P. 
Published: December 2007

Introduction
The world economic situation characterized by the energy crisis created by the oil shortage and consequent oil price rise, has in the last decade, and more particularly in the last five years, determined the oil particularly in the last five years, determined the oil industry's entry into a more expensive exploitation of offshore oilfields. This trend is being pursued by means of considerable research and development activities in the following areas:Achievement of technologies and exploitation systems suitable for oil/gas production in verydeep waters, in severe meteoceanographic condition seven in arctic environment.Achievement of technologies and systems for the economic extraction of oil/gas from fields of moderate size and production remotely located or not easily linkable to major production complexes.Rationalization of the development programme of the oilfield exploitation systems by means of techniques and components which may require lower investments and quicker recovery.Optimization of design of the exploitation system components implementation of their operating efficiency achievement of high operating safety standards.
A particular interest is being expressed by oil companies in the development of the so called marginal oil/gas fields. That is those fields which due to their expected production, their location and environmental characteristics, were considered not economically exploitable with the conventional systems, mainly based on fixed piled platforms. In the present paper the technical and economical problems posed by the development of marginal fields will problems posed by the development of marginal fields will be considered and the various solutions proposed by Tecnomare in this regard will be presented.
A High Pressure Riser Within An Articulated Column
Authors: Moinard M. , Dupont B. 
Published: December 2007

Abstract
Subsea development schemes for oil and gas Fields require reliable riser systems to control production wells and handle high pressure effluents from the sea bottom to floating processing supports. A permanent high pressure multiline riser has been designed to be installed in articulated structures. The riser is able to sustain the more adverse sea conditions of the North Sea without any need for disconnection. The technology of such a riser has been developed in detail. Fatigue and life endurance tests have been performed on full scale protoeype component parts. Test performed on full scale protoeype component parts. Test results confirm that the design may be applied with confidence to industry. The ability to pass high pressure pipelines through the articulation is the specific feature of a riser connected to a column. The technique is based on deflecting pipes passing through an annular universal joint. These pipes are passing through an annular universal joint. These pipes are arranged in a bundle configuration and extend from top to bottom of the column inside a central stack. Deflecting steel pipes are expected to last several years and can easily be replaced from the top deck of the column. The reliability of this riser design led to comprehensive studies for diverse uses of the column: * The use of an articulated structure as a logistic platform to permit daily control and maintenance of subsea wells. * The use of a column acting as a permanent riser an single mooring point for a floating production vessel with the possible alternative of installing production facilities on an isolated column. Water depths up to 400m can be reached with a single articulated structure.

Introduction
The development of the offshore oil and gas industry now advancing in water depths of 100–350m.
High Accuracy Directional Surveying Of Wells Employing Inertial Techniques
Authors: Morgan D.G. , Howe N. 
Published: December 2007

Drilling of multiple wells from offshore platforms has increased the accuracy requirements for directional surveying. To meet this need a 3-dimensional method of surveying wells to within one foot to 13 3/8 in. casing shoe has been developed. The basis of the equipment is an inertial system which consists of a gyro stabilized instrument cluster with three accelerometers measuring the displacements. The advent of inertial techniques has provided a means to complement monitor and improve provided a means to complement monitor and improve conventional survey techniques.

Introduction
The increased density of wells being drilled from offshore platforms, particularly in the North Sea has emphasized a need for more accurate directional survey techniques. Safe practice necessitates an increasing loss of production during concurrent drilling and production operations due to the uncertainty of hole position. The need to define bottom hole position is essential to avoid loss of well control. There has existed a source of concern arising from doubts about the accuracy of conventional surveys and the doubt that the position of a deep well could be defined with a horning device.

TECHNOLOGY
Given a doubt about the accuracy of conventional surveys there has been a need to define alternate systems. Inertial navigation systems have been developed for application in all weather combat aircraft and missiles. More recently they have been applied as survey equipment in artillery and topographical surveys. The navigation performance for aircraft is typically one nautical mile per hour - accuracy sufficient to assist transatlantic crossing - the system is, however capable of increased accuracy under different operating conditions.
Offshore Processing Plants A Systematic Approach To Weight Saving
Authors: Loge P.G. , Brekke T. 
Published: December 2007

Abstract
Weight and space requirements of offshore processing facilities can be used as parameters indicating a relative cost level of the installation. Of the two, weight is the easier to quantify. The operating weights of certain such production facilities are presented in this paper. The overall weight is broken down into a limited number of sub-groups, and the results are compared. Based on these results some ways and means of reducing the weights are discussed. All data used in this paper are as-built weights from North Sea installations. The paper further highlights the importance of keeping good control over platform weights, not only by keeping within weight estimates, but by looking at weight minimizing as a worthwhile optimization exercise.

Introduction
The overall function of a primary producing facility whether on land or offshore, is to produce hydrocarbons in a sound and economic way. Offshore, platform size is one important parameter affecting costs of an installation and keeping the size down will generally help projects economics. This size will, by common sense, be dependent on platform function, but often the physical dimensions of a platform bear little relation to the functions of the platform. Indeed, when looking at the weights of some recent North Sea projects, it is difficult to see any sensible relationship between platform capability and the weight of the facilities. Nevertheless, little has been done to carefully investigate why, consequently, certain platforms become too heavy.
In a number of engineering disciplines optimization is common. The object thus being to find, not only one way of doing it, but the best way of doing it. With the cost of the platform in mind, how to do it smallest and lightest, ought to be regarded as an optimization study in itself. Because most certainly, by looking at some past projects, the size varies considerably, and there past projects, the size varies considerably, and there is room for savings in most of them.
Experiences From The Removal Of Platform WE
Authors: Brookes M.A. 
Published: December 2007

Background

Structure description
Platform WE was a small four leg unmanned platform located in BP's West Sole gas field. The jacket carried a deck comprising a helideck with two cellar decks beneath for production equipment and supported a single 30 in. (760 mm) conductor tube together with an 8 in (200 mm) riser. Figure 1 gives a general view of the structure in service. The general arrangement of the jacket is shown in Fig. 2. The jacket was sited in a mean water depth of about 25 m and had plan dimensions of 32 ft (9.8 m) square at the top, tapering to 57 ft (17.4 m) square at seabed level. It was supported on four 30 in. diameter piles driven through the legs into hard boulder clay and welded to the top of the jacket. The annular space between shear capabilities at the nodes.

Service History
The platform was originally designed to support the West Sole discovery well drilled by the ill-fated jack-up 'Sea Gem'. When 'Sea Gem' collapsed in December 1965, the well was lost and the then fabricated platform was stored in Holland. Subsequently the jacket was modified and used at the WE location in July 1966. The platform was designed according to the best standards applicable at the time. These owed much to Gulf of Mexico experience with some necessarily limited local environmental data.
In 1973 a major structural reappraisal of all the West Sole platforms took place and as a result some strengthening of the platforms was carried out. In the case of WE it was estimated that its fatigue life could be of the order of a further 5 years. No strengthening of the platform was undertaken, however, as it was economically difficult to justify.
Review Of Drilling Operations Montrose Field
Authors: Medely E.L. 
Published: December 2007

Medely, E.L., Amoco (UK) Exploration Co., Scotland and Dent, W.F., Amoco (UK) Exploration Co., Scotland

Abstract
This paper reviews the drilling operations on the first 16 wells drilled by Amoco (UK) Exploration Company on the Montrose Alpha platform. Initial wells were plagued by numerous problems associated with bad hole conditions and complicated completion procedures. The average time to drill and complete the first six wells was 67 days at a cost of $3,500.000 each. After the sixth well major changes were made in both the drilling and completion programmes which resulted in substantial savings in time and well costs. The average time to drill and complete the next ten wells was 38 days at a cost of $2,400.000 each.
This paper describes the drilling and completion philosophy and practices adopted by Amoco to reduce philosophy and practices adopted by Amoco to reduce costs by 1.1 million dollars per well.

Introduction
The Montrose field is located 125 miles east of Aberdeen in 300 ft of water. It was discovered in September 1969, and development drilling began in April 1976 from an eight leg steel platform. By October 1978, 16 wells had been drilled from the platform, 14 producers, and 2 water injectors. Drilling and production operations have been conducted simultaneously on the platform since June, 1976. Therefore, each well is completed and placed on production as drilling is finished. The maximum combined producing rate from the 14 wells has been 41,700 bopd. producing rate from the 14 wells has been 41,700 bopd. Oil is transported from the platform by tanker loading through an SMB. Production from the field is from the Palaeocene sand, with the sand top at 8,100 ft subsea. Palaeocene sand, with the sand top at 8,100 ft subsea. All wells from the platform have been directionally drilled with the longest step-out being a well with a displacement of 8,978 ft at 8,961 ft TVD reaching a total measured depth of 13,375 ft. The maximum hole angle was 69 degrees. Penetration rats are generally very fast, with instantaneous rates up to 900 ft/hr.
Reduced Maintenance Costs For Rotating Equipment Through Monitoring: A Rationale Based On North Sea Experience
Authors: Miles A.P. , McGregor I.G. , Melling T.H. 
Published: December 2007

Abstract
The use of electronic aids in monitoring the performance and condition of rotating machinery has performance and condition of rotating machinery has in the past decade taken a considerable upward trend. Widespread use is being made of vibration measuring systems coupled with the monitoring of temperature, pressure, load and speed, all of which are indicative pressure, load and speed, all of which are indicative of the system performance. Other methods such as magnetic chip debris collection and spectrographic oil analysis procedures (SOAP) are being increasingly employed outside of the aerospace industry in which they were conceived. The upward trend in offshore rotating machinery monitoring appears to result from the present high cost of frequent and often unnecessary routine overhauls. Improved techniques in machinery monitoring have in may cases enabled operators to reduce shutdown frequency and operate on a planned for basis rather than a pull it to pieces and lets see approach. Unfortunately, the unsurge of interest in this field has inevitably led to jumping on the bandwagon and a wide range of equipment claimed to give early indication of damage over a wide range of machinery components is now being promoted. This paper seeks to briefly outline the inherent difficulties of relating machinery damage to vibration presents hands on experience from several major presents hands on experience from several major northern North Sea developments and brings to light why many of the available systems are entirely unsuitable as general purpose indicators of damage. Concluding remarks include a section on future trends and developments toward truly universal system.
What Motivates Engineers From A Major Company's Point Of View
Authors: Juge Peter E. 
Published: December 2007

JUGE, PETER E. NO COMPANY
Good afternoon. It is a pleasure to be here this afternoon to participate in this session of your Fall meeting, which focuses on the topic "Engineering People-Motivation, Productivity, Profits". My talk is entitled "What Motivates Engineers from a Major Company's Point of View"
I plan to include some discussion on the retention or engineers in my remarks as well, because I believe the two are closely related. Also I reel it is important first or all to begin by giving you some brief general information about Engineers in Mobil, and how they are recruited, as background for the rest or the discussion.
Out of a workforce of some 10,000 employees in Mobil's Exploration and Producing Division worldwide, engineers number just under 1150. Roughly Producing Division worldwide, engineers number just under 1150. Roughly half of these engineers are located at Mobil units in the United States. The other half are located abroad. Many or the latter are nationals or the countries where we operate. The approximate number or American engineers working abroad for Mobil is 230.
About 30% or Mobil's engineers are in managerial and supervisory positions. The other 70% are in professional ladder positions. I'll have more to say about this later.
Like most of the majors, we "grow our own" engineers. Most are recruited directly out of college. During the past three years we have recruited over 200 engineers from schools in the U. S.
Mobil's record in recruiting on campus is good. We hired 33 out of the total of 360 B.S. PEs and 42 MS PEs who graduated last year or about 8%. Our overall college recruiting acceptance ratio is on the order or 50% as compared with an industry average of 35%. We have a program for just- graduated, young engineers who join the Company to assure proper orientation and training in various engineering fields of specialization. The program is not a formal training program as such but more a series or work assignments within the Company and at outside schools, with tracking to help make certain all bases are covered. The main reason given by young engineers who join us from the college campuses for their decision to choose Mobil is the quality or the engineers and other professionals they meet during the recruiting process. The negative reason most often given by those who turn us down is location. But there doesn't appear to be any real pattern here. Some don't want to work in a city like Houston or New Orleans. While others don't want to go to such garden spots as Freer Texas or Morgan City.
Most of the engineers we recruit from college stay with us, pursuing a wide variety of engineering careers possible within Mobil. Our current turnover rate for engineers is 4%. This I believe is better than the average rate for majors and reflects a downward trend in Mobil over the past few years.
Control of Gas Cap Encroachment in a Thin High Permeability Reservoir
Authors: Al-Emadi Ismail A. Abdulla , McCoy Michael W. , Thomasen Jakob B. 
Published: December 2007

Abstract
The Nahr Umr sandstone reservoir in the Al Shaheen field offshore Qatar is a thin high permeability oil bearing reservoir with a primary gas cap. Effectively producing the oil reserves has been challenging due to the flat reservoir structure that promotes gas channelling from the gas cap to oil producers. Horizontal water injectors placed at the edge of the gas cap have been used to shield the oil producing regions from the ingress of gas. Water injectors have also been incorporated into radial patterns away from the gas cap to provide pressure support and efficiently sweep the oil bearing areas. Development to date comprises 15 horizontal production and injection wells drilled from three surface locations.
This paper discusses the completion techniques used for injectors and producers, along with the water flood monitoring programme and the interim results of the water flood compared to reservoir simulation predictions. Four years of performance data are presented.
Optimisation of Carbon Steels for Sour Service
Authors: Emenike Cornelius O. , Borouky Fikry F. 
Published: December 2007

Abstract
Failures in sour environments are a major concern to oil producing companies because these failures do not usually involve material loss (wall thinning). These time – dependent failures can release toxic gas (hydrogen sulphide) to the environment. Of major concern is the exposure of facilities designed for sweet service to wet hydrogen. Hence, this paper reviews the theory of HIC. For new production facilities such as Pipelines, free-water knock out ( FWKO) drum and flare stack, material selection using the well-known immersion test NACE TM0177/ NACE TM02 84 is highlighted.
Structure – property relationship is of paramount importance in design, hence regression equations were used to establish the effect of chemistry and microstructure on mechanical properties.
Recommendations were made for repair of equipment / facilities that failed during the transition from sweet to sour services. Eventually, a rule based form of expert (knowledge based) system was used to formalize a number of relationships. These rules are in the form of IF -THEN relationships. A brief explanation of the expert system is given as the basis of rule format.
Use of Sludge for Removal of Heavy Metals from Wastewater
Authors: El-Mahadi Hayat , Chaalal Omar , Zekri Abdulrazag Y. 
Published: December 2007

Abstract
In this paper sludge biomass is used for removal of heavy metals such as Cu, Cd, Pb, and Zn from wastewater and this was introduced in order to develop a comprehensive technique that remove or reduce heavy metal concentration to an acceptable level. Also SEM was used to explore the surface of the sludge and ensure the availability of microorganisms or pores, which may add additional advantages for retention of heavy metals.
New Technique Estimates Drilling Filtrate Invasion
Authors: Hassen Barry R. 
Published: December 2007

ABSTRACT
A technique has been developed which calculates filtration of drilling fluids under actual well conditions. Theoretical and empirical equations were derived from the findings of an extensive literature search. These relationships enable comprehension of the many intricacies of downhole filtration far beyond that enabled by the primitive static fluid loss test. With this understanding, it is possible to modify drilling fluids and drilling practices such that invasion of drilling fluid filtrate is minimized.
The model accuracy was verified through comparison with well log results on 21 Canadian wells. Filtration volumes into a particular zone can now be estimated through use of a programmable calculator under conditions where well log data fails to do the job.
This paper outlines the types of filtration relationships derived, examples of the model results and the potential applications of the system. Armed with the capabilities of this system, it becomes possible to reap the benefits of reduced filtrate invasion.
Bridging Particle Size Distribution: A Key Factor in the Designing of Non-Damaging Completion Fluids
Authors: Mahajan Naresh C. , Barron Bruce M. 
Published: December 2007

ABSTRACT
Great care must be exercised in the formulation and use of completion and workover fluids; otherwise extreme damage can be done by "non-damaging" fluids. Excessive loss of brines, polymers, or bridging solids to a producing strata can result in irreversible formation damage. Rapid formation of an effective filter cake on the formation face with the resultant low filtration rate and minimum solids penetration can significantly reduce the potential for formation damage.
Laboratory data indicates that low filtration rates achieved with the formation of a thin, competent filter film composed of properly sized bridging particles and hydrocolloid polymers will most effectively prevent formation damage. The deposited filter film acts as a downhole filter, screening out unwanted solids from the small volume of filtrate actually entering the formation.