bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Novel Retrofit Solution for Oily Cuttings Slurrying and Re-Injection on the Ula Platform
Authors: Minton R.C. 
Published: December 2007

Abstract
Within the North Sea area there are many platforms nearing the end of their initial drilling phase but with the likelihood of significant, if infrequent, sidetracking operations in the future. For a number of these, oil based drilling fluids still offer a cost effective solution, particularly where tortuous trajectories are proposed. The Ula platform is a case in point, but, as with all operations in the Norwegian sector, unprocessed oily cuttings can not be discharged. Cuttings slurrying and re-injection resolves this problem and has been successfully used by BP Norway on the Gyda platform for the last 5 years. The challenge, therefore, was to design a slurrying system for the Ula platform, recognising both the space limitations and the cost constraints. This paper reports on the novel solution adopted, the costs involved and the subsequent performance of the installation.

Introduction
The Ula field, located in block 7/12 of the Norwegian sector of the North Sea, (Fig. 1), was discovered in 1976 by the semi-submersible drilling rig "Nordskald". It is a jurassic reservoir, at some 3200M vertical depth below sea-bed with total recoverable reserves estimated at 435 million barrels of oil equivalent. The PDQ (Production, Drilling, Quarters) jackets were installed in 1985 and first oil was produced in 1986. In the intervening ten years, over 300 million barrels of oil have been produced. The production rate is presently about 50-55,000 barrels of oil per day, with a water injection rate of about 200,000 bpd. Eighteen slots are available and, at present, there are 11 wells on production, six are water injectors and one is temporarily abandoned.
The first seven wells on the field were drilled using a KCl/Polymer drilling fluid system. However, major problems were encountered in drilling the Tertiary shale interval, so much so, that Low Toxicity Oil Based Muds (LTOBMs) were used for the 12 1/4" and 8 1/2" sections of the latter wells. The resultant fluid costs were reduced by 36%, on a comparable cost per meter basis, the average ROP increased 74% (Table 1) and the drilling problems were significantly reduced.
However, there remained the issue of the oily cuttings. A cuttings cleaning plant was, therefore, installed, and it succeeded in reaching the then specified limit of 10% oil, on a weight by dry weight basis. Efforts were subsequently made to reduce the residual oil on the cuttings further, so as to comply with the interim 6% limit, that was to be introduced.
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Environmental Performance Indicators - the Line and Management Tool
Authors: Jones Murray G. , Hartog Jan J. , Sykes Richard M. 
Published: December 2007

Shell companies have their own separate identities. In this paper the collective expressions 'Shell' and 'Group' and 'Royal Dutch/Shell Group of Companies' may be used for convenience where reference is made to the companies of the Royal Dutch/Shell Group in general. Those expressions are also used where no useful purpose is served by identifying the particular company or companies.

Abstract
The Objective of the presentation is to make the audience aware of the value and approach to Environmental Performance Indicators (EPI) for both internal and external use.
The premise is that EPI are of benefit in a number of ways including:–measuring performance against targets–gaining internal credibility–ensuring what gets measured gets done and reported–providing information to the various stakeholders–meeting external demands for reporting–responsible corporate citizen
A key theme will be the need to report (information, data) at the level where key stakeholders are concerned i.e. this is at the Shell Operating Company level as the companies must work with their neighbours, governments and local NGO's. It is also crucial to note that the report is an internal communication vehicle - you want/need the employees on side.
Recognition that companies must move into EPI as their information base becomes available. This is only just the case in many companies. Concerns with aggregating data will be mentioned (i.e. loss of specific information, different means of accounting, ability to interpret). Reference will be made to move of companies into public environmental reporting as the information base becomes available. This is only just the case in many companies.
Content aspects will include:–the need for quality data–the need to present information that is also used within the Company (e.g. Targets, Objectives) thus of value added not additional work–the use of EPI in external reports
'Good' examples of EPI will be provided from within the Shell EP World including Shell EP Companies from Canada, Netherlands, Norway and Oman. The development of EPI by industry associations will also be addressed.

Introduction
Environmental Performance Indicators (EPIs) are a principal means of measuring and recording environmental achievement over time. The move to the use of EPIs in Shell EP Companies is complimentary with the programme of performance data gathering that has been underway for 3 years and with the needs and requirements of a Health, Safety and Environmental Management System (HSE MS). Currently available environmental data includes air emissions, wastes, effluents, potential liabilities and spills. Smaller amounts of information are emerging on effects. EPIs should be chosen to reflect those areas in which the Company has identified the need for environmental management and control.
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The Lifecycle Approach to Hazard Management
Authors: Dalzell Graham A. 
Published: December 2007

Abstract
The Cullen report into the Piper Alpha disaster recommended a change from prescriptive legislation to a goal setting approach. The new legislative approach is -described in Ref (1). The preparation of the regulations covering fire, explosion and emergency response Ref. (2) which would support the Safety Case coincided with an initiative by UKOOA, the United Kingdom Offshore Operators Association, to develop guidance on hazard based design to protect against fires and explosions. Agreement was reached with the UK Health and Safety Executive and the drilling and design contractors to work together to develop it into the technical guidance to support the new regulations. This set a precedent for UK offshore safety legislation. Previously, the regulators had developed, and had been the custodians of such guidance. It also marked a new era in positive co-operation between the "ruler and the ruled".
The UKOOA Fire and Explosion Hazard Management (FEHM) guide Ref. (3) is the product of that initiative. Initially, the authors set out to prepare guidance for designers of fire and explosion protection systems to encourage them to specify systems to match hazards. It soon became apparent that there was no overall guidance describing an integrated approach for managing hazards. The result was the development of the lifecycle hazard management concept. This paper outlines the lifecycle and highlights the main features of a risk management system which is based upon it. The approach can be applied not only to fires and explosions but to all major accident hazards including these involving toxins or pollution.
Employee Assistance Programs for Expatriate Employees
Authors: O'Donnell William J. , Wilson Dixie B. 
Published: December 2007

Abstract
With the rapid expansion of the global market, there is an increasing need to identify, develop, and support expatriate talent. The literature reveals that 20% of American expatriates fail in their assignments. Each failure can cost a company up to a million dollars. It makes good business sense to find ways to protect these investments. This presentation will focus on the delivery of EAP services to expatriates through a consortium model, as well as recommend a six-step process - a comprehensive HR approach to help insure successful expatriate assignments.
The Pattern of Accidents on Offshore Drilling Rigs in the North Sea
Authors: Forbes M. J. 
Published: December 2007

Abstract
As part of the effort to reduce accidents on drill floors, the pattern of fifteen years of retrospective accident data involving North Sea drill crews was studied. Of the various patterns examined it was found that there was an increase in accidents in the 0000 - 0400 hours period, and also that accidents rose to a peak in the middle of a two-week shift. Possible factors are discussed and suggestions made to decrease the accident peaks.
A New Solution to ILU Preconditioning Parallelization and Its Applications in Reservoir Simulations
Authors: Xing Jian , Ma Yuan Le 
Published: December 2007

Abstract
This paper presents a new parallel ILU preconditioned It is based on the technique of Sequential Staging of Tasks (SST) which overcomes the difficulty of recursiveness arising from ILU factorization. This new parallel ILU preconditioner is easy to reconstruct from the sequential version. The only requirement is to insert the synchronization codes of stages of tasks into the sequential version, and any other modifications to the original serial codes are not needed. The characteristic of matching various ordering schemes is still maintained, and the new merit of handling different numbers of processors is obtained. Numerical results were obtained using a thermal model with different grid system. The parallel speedup is satisfactory.
The Migration of CADE Software for Oilfield Application to Laptop Computers
Authors: Ward V. L. 
Published: December 2007

Abstract
The popularity of Laptop computers has dramatically increased because of their portability, low cost and increasing competitiveness with Workstations and mini-computers’ performance. As a result, many organizations are beginning to migrate their engineering applications to Laptop Computers. In 1994 Schlumberger Dowell started to migrate the full suite of mini-computer based CADE (Computer Aided Design and Evaluation) applications to Laptop computers. This paper chronicles the issues faced and resolved during the successful migration of the software.
Cost Effective Modular Unit for Cleaning Oil and Gas Field Waste Water
Authors: Zinberg M. B. , Nenasheva M. N. , Gafarov N. A. 
Published: December 2007

Abstract
Problems of enviromental control involving conservation of water resources are vital for the development of giant oil and gas condensate fields near Caspian Sea (Russia) characterized by water shortages.
One of the urgent tasks of oil production industry is to use all field waste water consisting of underground, processing and rain water. It was necessary to construct a new highly effective equipment which could be used in local waste water treatment.
Now we have at our disposal a technology and equipment to meet the requirements to the treated water quality. Thus we have installed a modular unit of 100 m3/a day capacity to clean waste water from oil products, suspended matter and other organic pollutants at Orenburg oil and gas condensate field, Russia. The unit provides with a full treatment of produced water and comprises a settling tank with adhesive facility, the number of sorption filters, Trofactor bioreactors and a disinfecting facility. The equipment is fitted into three boxes measuring 9x3.2x2.7 m each. The equipment is simple in design that enables to save money, time and space. Sorption filters, bioreactors as well as the Trofactor process are a part of know-how.
Ecologically Safe Method to Monitor Fluid Filtration in Oil and Gas Bearing Formations and Wells
Authors: Zinberg M. B. , Ivanovskaya I. B. , Mezhebovskaya G. P. , Gafarov N. A. 
Published: December 2007

Abstract
Effective production of oil, gas condensate and natural gas depends on the geological structure of oil and gas bearing formation. Having analyzed gas saturated reservoirs of oil and gas bearing formation in Orenburg oil and gas condensate Held, it was concluded that the wells in the sites of high vertical and horizontal fracturing are flooded by underground waters. Direct data and field take-off arc used to determine the reservoir direction, its filtration and capacity characteristics.
Today there are some methods to monitor the direction of stratum fluid movement using radioisotope or sound waves though their application is limited. A radioisotope method is not ecologically safe, others demand a complicated equipment and specially trained personnel.
We have developed and model-tested a biological tracing method to expose the zones of increased fracturing and of vertical and horizontal communication between wells and strata-reservoirs. The method is especially effective for sulfated carbonate reservoirs of heterogeneous fracturing.
Disposal of Nonhazardous Oil Field Wastes into Salt Caverns
Authors: Veil John , Elcock Deborah , Raivel Mary , Caudle Dan , Ayers Robert C. , Grunewald Ben 
Published: December 2007

Abstract
Bedded and doma! salt deposits occur in many states. If salt deposits are thick enough, salt caverns can be formed through solution mining. These caverns are created either incidentally as a result of salt recovery or intentionally to create an underground chamber that can be used for storing hydrocarbon products or disposing of wastes. This paper evaluates the legality, feasibility', and suitability of disposing of nonhazardous oil and gas exploration, development, and production wastes (hereafter referred to as oil field wastes, unless otherwise noted) in salt caverns.
In 1988, the U.S. Environmental Protection Agency (EPA) published a list of those oil field wastes that were exempt from regulation as hazardous wastes under Subtitle C of the Resource Conservation and Recovery Act (RCRA). EPA's Underground Injection Control (UIC) regulations allow most of those oil field wastes to be injected into Class II UIC wells. At the state level, only the Railroad Commission of Texas (TRC) has formally authorized disposal of oil field w astes into salt caverns, although several other states are considering authorizing the practice. The TRC has issued permits for six facilities, but as of May 1995 only three of these were active. In August 1995, the TRC released draft proposed amendments to TRC Rule 9, the regulation that governs underground injection activities in Texas. There are no outright regulatory prohibitions on the use of salt caverns for disposal of oil field wastes at either the federal level or in the eleven states contacted as pan of the study.
The types of oil field wastes that are planned for disposal in salt caverns are those that are most troublesome to dispose of through regular Class II injection wells because they contain excessive levels of solids (i.e., used drilling fluids, drill cuttings, completion and stimulation waste, produced sand, tank bottoms, and soil contaminated by crude oil or produced water.)
Sustaining Global Progress - in Partnership with the Environment
Authors: Smith A. L. 
Published: December 2007

Abstract
A sustainable development strategy for Marine Fabrication and Decommissioning facilities has been developed and implemented, with the application of environmental pro-grammes; by understanding the effect of the facilities operations on the ecosystem and through minimising the environmental impacts on SSSI/SPA/SAC/Ramsar/Natura 2000 sites in a scientifically based, cost effective manner. This paper provides an international perspective for all E & P operations, especially those in the sensitive inter-tidal zone.
Well Testing - Oil Disposal Options
Authors: MacFarlane Timothy 
Published: December 2007

Abstract
This paper discusses and contrasts the use of clean-burning equipment used for flaring with the use of a well-test vessel that captures the hydrocarbon products for sale rather than disposal. Even though new burner technology eliminates much of the black smoke and hydrocarbon fallout, burning is prohibited in some environmentally sensitive areas. Under these circumstances, a properly equipped well-test vessel could be used to capture products for sale. The technology chosen is usually decided based on the technical parameters of the well being tested.
New burners and well-test vessels both represent the "best available technology" (BAT) to minimize environmental impact. Therefore, case histories demonstrating the use of clean burning and the use of a well-test vessel are presented. Technology detailed in this paper further demonstrates how the industry can contribute to improved environmental protection in the North Sea.
The Troll HSE Risk Management System
Authors: Wiig Erik , Berthelsen Inge , Donovan Kevin 
Published: December 2007

Abstract
The Petroleum Act and Internal Control regulations in Norway lay down requirements for how HSE shall be managed and documented. To comply with the Norwegian legislation the Troll Project has developed an HSE Risk Management System (RMS) structured around Hazards and Effects Management. The resulting quality, technical and operating integrity, and HSE performance are an endorsement of the power of RMS.
Two-Screw Multiphase Pump Behavior In Heavy Crude Oil
Authors: Gonzalez R. 
Published: December 2007

Abstract
Multiphase fluid handling technology has been applied worldwide in its commercial version since 1984, specializing in pumping medium and light crude oil and its associated gas. This technology was applied to Venezuela's heavy/extra-heavy crude oils in 1995 in a field evaluation in Corpoven's Arecuna Field, Hamaca Area in the Orinoco Belt. This was done by installing a multiphase pump with a capacity of 53.5 MSTBD equivalent (5.5 MSTBD of liquid and 48 MSTBD equivalent of gas), an intake pressure of 30 psi, and a maximum discharge pressure of 700 psi (a pressure differential of 670 psi). This equipment was designed to handle the production associated with eight wells, located 5.28 miles from the nearest crude oil separation and treatment facilities.
After 3260 hours of continuous operation, the results obtained from the evaluation of the two-screw multiphase pump show normal behavior, handling a flow of 52 MSTBD equivalent (11 MSTBD of liquid and 41 MSTBD equivalent of gas), an intake pressure of 20 psi, and a discharge pressure of 300 psi (a pressure differential of 280 psi). The average power consumption was 400 kw/hr. Results empowered Corpoven to include multiphase technology as a component of its existing new developments. Multiphase pump low pressure intakes have resulted in lower pressures at well heads (from 140 psi to an average of 80 psi), allowing a 12.5% production increase, equivalent to 220 STBD.
The purpose of this paper is to reveal the results obtained from a field evaluation of a multiphase pump application in Venezuelan heavy/extra-heavy crude oil production areas. Additionally, this paper includes an economic analysis of multiphase versus conventional gathering facilities and operating recommendations based on a commercial pilot test.

Introduction
Corpoven's heavy/extra-heavy crude oil production has traditionally been handled and transported through a flow station-production station arrangement, where produced fluids are collected, separated, measured, and subsequently treated and transported to different destinations (compressor plants for gas and tank farms for crude oil). This conventional scheme has worked efficiently when the processes are continuously optimized, however, the costs of installations and major equipment have increased considerably, in addition to the operational inconveniences represented by the presence of crude oil storage sites scattered around the producing areas. In order to take advantage of new technologies that add value to processes of gathering, handling and transportation of produced fluids to the production stations, and reduced investment and operating costs, beginning in 1995 Corpoven has began to apply multiphase pumping technology on heavy/extra-heavy crude oil production in the Arecuna field within the Orinoco Belt.
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Implementation of a Risk Analysis Method on Fishing Operations Decisions
Authors: Cunha J.C.S. , D&apos;Almeida Albino L. 
Published: December 2007

Abstract
It is very important to determine the economical feasibility of a fishing operation in order to know whether to continue or interrupt the fishing procedure. This decision, when erroneously taken, can often lead to unexpected losses of money and time.
In the past the decisions concerning whether to continue or interrupt a fishing operation were based primarily on the operator's previous experience. This procedure often led to wrong decisions and consequently unnecessary monetary losses.
This paper describes the implementation of a decision-making method based on risk analysis theory and previous operation results from the field under study. The method leads to more accurate decisions on a daily basis allowing the operator to verify each day of the operation if the decision being carried out is the one with the highest probability to conduct to the best economical result.

Introduction
Fishing problems can occur during drilling, completion or production operations in oil and gas wells. These costly and undesirable remedial operations have been resulting in annual losses of US$ 500 million worldwide.
Recently a decision-making method to deal with this problem was developed. Based on risk analysis theory, probability distribution and previous operation results, the method conducts to more accurate decisions allowing the operator to verify if the decision being carried out is the one with the highest probability to conduct to the best economical result.

Theoretical Review
In Ref. 1, the basic concepts of the method were presented. Also derivations of all equations were presented and thoroughly discussed. Following, a review of the mainly concepts and equations.–Economic fishing time (EFT): EFT represents, at a certain moment of the operation, the amount of time within the operation should be concluded in order to produce a satisfactory economic outcome.(1)–Probability of Success: This is the probability that the operation presents to be successfully concluded within the EFT.(2)–Expected cost of the operation: Value calculated using the principles of risk analysis theory. It involves not only the costs but also the operation probabilities of success and failure at a certain moment.(3)–Conditional probability of success at day i of the EFT:(4)–Conditional probability of failure at day i of the EFT:(5)
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