bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Study Design for Follow-Up of Cancer Incidence and Mortality among Norwegian Offshore Oil Workers
Authors: Andersen A. 
Published: December 2007

Abstract
More than 30 years have elapsed since oil and gas were discovered under the sea bed around the Norwegian coast, and during these years there has been a rapid escalation of employees to 15-20 thousand. Work pattern and the health hazards vary among the different occupational groups, from drilling operation to canteen personnel. To our knowledge information of occupation linked with data on mortality for such a group of workers does not exist. An exception is the Healthwatch programme in Australia, but this study consists of few offshore workers only.
The purpose of present investigation has three features in relation to risk of cancer and cause of mortality in selected occupational groups. -collection of individual data on job history, chemical exposures, diet, smoking, alcohol consumption and leisure activity.-linkage of individual data with the Cancer Registry including date and cause of death.-analysis of potential risk of cancer and mortality in occupational groups working at offshore.
The study will include all present and past employees. At regular intervals the material will be linked to the Cancer Registry. Standardized incidence and mortality ratios (SIR) and (SMR) will be used in the analysis.
Waste Management Practices in the Gulf of Suez - Egypt
Authors: Ghzaly Sayed Mansour , Binegar James S. 
Published: December 2007

Abstract
The Gulf of Suez Petroleum Company (GUPCO) is the largest offshore oil producing company in Egypt. GUPCO currently produces 4(10,0(10 BOPD from over. 150 wells supported by 87 offshore producing platforms.As a leader of the Egyptian petroleum industry, GUPCO established within its strategies and goals a separate category covering safety, health and protection of the environment. This step was recognized and emphasized the importance of GUPCO’s role in protecting the Egyptian environment while producing oil and natural gas. This paper discusses the existing waste management practiccs of the Gulf of Suez Petroleum Company which were put into place to protect the Egyptian environment in the Gulf of Suez-Egypt and GUPCO’s associated operations
Auditing Environmental, Health and Safety Management Systems in E & P Companies: A Second Generation Auditing Program
Authors: Goldman D. J. , Guckian W. M. , Moore D. W. 
Published: December 2007

ABSTRACT
This paper presents the development of a method of performing Management Systems Audits of Environmental, Health and Safety (EH&S) programs in upstream oil and gas companies. It describes how the results from the compliance auditing system presented in SPE Paper 25955, "Initiating an Audit Program: A Case History" were combined with a system categorizing EH&S activities into several management systems defined by regulations and good operational practices, and used to perform short term "Pareto-style" audits (e.g., 80% of the value from 20% of the time). A comparison is made of this type of audit model with the classic accounting audit model. Examples from Management System Audits of ARCO's foreign and domestic operations are used. Included are discussions of the economic benefit of performing EH&S Audits and the benefit of developing a method of auditing considering the new ISO 14000 standard for environmental auditing and the proposed ISO safety auditing standard.
The conclusions presented are that auditing by experienced personnel using an auditing template developed exclusively for upstream operations provides benefits to the company in the areas of compliance, management systems development and education of first line operations personnel as well as resulting in an overall reduction in the cost of an audit. A further conclusion will be that trends in international standardization appear to be mandating an EH&S auditing program for those companies planning to do business outside the United States.
Public Consultation and Risk Communication: The Brave New World
Authors: Denstedt Shawn , Verchere Bennett Jones 
Published: December 2007

Abstract
The general theme of the paper will be the increasing awareness of the public and ENGOs about environmental issues and perceived impacts of the oil and gas industry. The focus of the paper will be on the public consultation process and how the risks associated with oil and gas development are communicated to the public. The paper will review how the public consultation process has changed and the demands that stakeholders are making on the industry for constructive input into projects and information on the impacts of projects. The paper will consider the types of risk that oil and gas projects present: Impacts on air quality and related quality of life and health impacts;Contamination (soil and groundwater) that impact on environment, land values, and health;Worst case "catastrophe" scenarios and impact on public safety; andPerceived impacts of the public on quality of life.
As part of this section, the paper will consider a number of examples of projects in Alberta.
Finally, the paper will consider how a company should approach public consultation and risk communication. The paper’s conclusion will be that a proponent should consult broadly and present clearly the negative and positive impacts of the proposed project with a goal of creating an informed public, not to convince the public that the project is in its best interest.
The paper will also conclude that today’s public and environmental groups are more sophisticated and more organized than in the past. Regulatory authorities are demanding that accurate and comprehensive information be provided to stakeholders with a result that more and better information will be required upfront which will mean longer timelines for projects to get approved.
An Interactive 3D Fracture Modelling Environment
Authors: Swaby Peter A. , Rawnsley Keith D. 
Published: December 2007

Abstract
An original three dimensional (3D) fracture modelling environment which is designed to allow users to interactively construct near well fracture models suitable for use as input to fluid flow simulators is described. Data input consists of a surface model of the seismic scale structure, well fracture data, and user defined parameters. Sedimentary discontinuities and faults can be extrapolated from the wells in 3D. Within this near well model tension fractures can be generated using a genetic process which aims to reproduce the initiation, growth and interaction of fractures in order to create realistic fracture systems. Graphs are available for calibrating the fractures to assumed statistical distributions.
Thesis - Keeping the Management System "Live" and Reaching the Workforce
Authors: Primrose M. J. , Bentley P. D. , van der Graaf G. C. 
Published: December 2007

Abstract
Previous papers given to SPE conferences have described the Shell Group approach to Safety Management Systems and to Safety Cases. Their extension to HSE MS and to HSE Cases has also been addressed. Since 1984 the Enhanced Safety Management (ESM) programme within Shell companies has led to a significant improvement in the management of safety but it was only when structured management systems (based upon an understanding of the business processes) were introduced that true integration of HSE as a line responsibility became a reality. This paper describes the THESIS software package and the way that management systems have been made 'live' and how workforce involvemerU can be demonstrated.
The paper starts with the premise that "...work should not start before it is confirmed that essential safety systems are in place and that staff are accountable for this requirement. Where we cannot ensure safety, then operations should be suspended...".Line management needed a way of making this a real part of the job and of providing workplace personnel with an essential understanding of the risks that they face.
In Jakarta we stated that "Many of the early Safety Cases reviewed failed to provide a clear message that the operation's safety management system has benefited from the assessments made in preparing a Safety Case. They were regarded as paper exercises and a sterile documentation of what had been done, often by engineers or consultants. Without some form of 'energising' the system becomes just another book on the shelf. Since Jakarta we have been completing wotk on relational database software aimed at changing the Safety Case from being a paper document to a software based 'System' from which on-line reports can be extracted that add value to those managing the risk of the business. Changes to the electronic document can be readily undertaken and whilst still not painless the development and updating of a Safety or HSE Case is now much reduced in terms of time and effort enabling it to remain alive.
With the critical HSE activities and tasks specified and related hazards and effects identified and linked via a relational database, it is possible and realistic to provide to the workplace clear reports that describe the necessary controls in terms of the tasks that actually provide those controls.
Developing Health, Safety & Environmental Management Systems for Well Service Operations in the North Sea
Authors: Sealy I. 
Published: December 2007

Abstract
A health, safety and environmental management system has been developed to meet die business demands in the North Sea area. After reviewing published best-practice solutions a model that allowed the incorporation of existing programmes was adopted. Particular emphasis was placed on the need to implement a system that would promote continuous improvement, meet customer audit requirements and meet both current and projected future business requirements. In addition to formalising and documenting a number of existing programmes the system introduced two new programmes; competence assurance of ail operational personnel and internal auditing and benchmarking of management system performance. The system and its associated management tools are now being implemented in three countries in the North Sea area. Plans for future development of the system, particularly with respect to the integration of quality management programmes are also described.
Certification – The Same as Fitness for Purpose?
Authors: Montgomery M. E. 
Published: December 2007

Summary
Classification and certification are not the same, and fitness for purpose may or may not be determined by either. This paper compares and contrasts classification, certification, and fitness for purpose. Included are not only the general policies and definitions used by the major classification societies, but also how these services fit into the various quality certification schemes like ISO and API. As a result, when you have a need for third party verification of "quality", you will know what you should specify and the correct terminology used by those in this industiy.
Unique Gauge Structure and Other Bit Modifications Improve Drilling Efficiency of Baram, Baronia Fields
Authors: Ngieng J.Nk. , Khalid M.Z. , Edmondson M. , Skari D. , Robinson R. 
Published: December 2007

Abstract
The introduction of roller cone bits incorporating a unique gauge cutting mechanism, in combination with other gauge and hydraulic modifications, dramatically increased drilling efficiency and lowered the costs of two major development projects offshore Sarawak, Malaysia. The aforementioned technical modifications and other continuous improvement practices, which resulted from close interaction between operator, contractor and bit company, saw drilling costs reduced nearly US$378,000 on the Baram and Baronia development programs.
This paper describes the evolution of operator-driven tool development and operational practices that led to increased footage and penetration rate per bit in the interbedded shale, sandstone and limestone intervals intrinsic of the directional wells drilled offshore Sarawak. The authors will review the two fields (Baram and Baronia), detailing the tool and operational modifications that significantly improved the economics of the development drilling campaign.

Introduction
In early 1994, Baram Delta Operations (BDO) launched an aggressive development drilling program on its Baram and Baronia fields, two of nine structures discovered offshore Lutong, Sarawak, Malaysia. Fig. 1 shows the location of the two fields on the SK15 concession at the mouth of the Baram River.
A total of 61 wells have been drilled in the development program, including 33 on the Baram field - discovered in 1963 with exploration well Baram-1 - and 28 on the Baronia field, which was discovered in 1967.
The two fields are located in the structurally complex Baram Delta Province, where nearly 730 hydrocarbon-bearing reservoirs have been identified. The region features abrasive intervals and extremely depleted reservoirs that possibly overlay severely overpressured formations. Generally, the structures are complexly faulted, comprising interbedded sand and shale with limestone and dolomite intervals. The sands, which are fine and angular, tend to be sharp and highly abrasive. Fig. 2 is a cross-section of the Baram field, highlighting its structural complexity.
The often unpredictable geology of the Baram Delta Province has caused numerous development drilling problems, particularly in the deeper wells. Chief among the drilling problems are stuck pipe, lost circulation and abrasion-induced drillstring washouts.
Owing to its complexity and highly troublesome characteristics, the Baram field was selected as the testing ground for most of the experiments directed at improving efficiencies in the development drilling program. The knowledge gained in the Baram experiments was subsequently implemented in the younger Baronia field.

BDO Drilling Efficiency Program
A typical well in the recently concluded Baram Delta Operations campaign was drilled directionally from either a cantilevered jack-up or from a tender-assisted rig on the "F" platform. On the average, a BDO well was drilled to a total measured depth of 8,000 ft.
P. 367
Water Frac Applications In High Island 384 Field
Authors: Claiborne E.B. , SAUCIER R. , WILKINSON T.W. 
Published: December 2007

Abstract
A frac pack technique using water, herein referred to as a water frac, has been developed for use in wells where the goal is to achieve effective sand control at minimal cost while bypassing wellbore skin thus increasing well productivities. This increased productivity is accomplished by a properly designed, length limited, hydraulic fracture, created and propped with non-damaging fluid/prop that provides a highly conductive flow path through the wellbore damaged zone, in conjunction with a proper gravel packed completion. The process is applicable to intervals comprised of multiple pay zones by using a multi-stage water frac technique. The entire process of creating and packing the fracture(s) and gravel packing is accomplished using a properly defined gel free brine.
The multi-stage water frac process has been applied and evaluated in the High Island 384 Field. Job evaluations herein illustrate the process. The process has also been applied using uncrosslinked gelled fluids in this field as well, with the evaluations to date indicating the water frac results to be superior. Comparisons with larger sized frac packs in a similar area also indicate the water fracs to be equal or superior to the frac packs in well performance.
In the following, the process of a water frac will be described, typical field pumping techniques will be provided and field applications and results will be presented.

Introduction
Bypassing near wellbore damage in relatively high permeability formations using a propped hydraulic fracture is an increasingly well known and commonly applied practice. Wellbore damage is typically relatively close to the wellbore (ie: three times wellbore radius) and hence to bypass wellbore damage requires only a short fracture (+/– 2 ft). More generally, for relatively high permeability formations, the fracture does not have to be long to optimize the production rate, as illustrated by Figure 1. Figure 1 shows that a fracture length of 5-10 ft will deliver virtually all that can be produced from many high permeability formations. The small fractures can be created and propped effectively with brine, as opposed to more viscous, highly complex fluids. These type treatments are herein referred to as Water Fracs (WF). These short conductive fractures that bypass damage, coupled with an effective gravel pack constitute an effective, sand free, high productivity completion. This WF process is not to be confused with high rate water packs that are pumped below fracture pressure.
The following describes the water frac process, and applications on the HI 379B platform. Also included is a brief background and history of the HI 384 area leading to the application of the WF process, as well as typical treatments and pumping techniques. Discussion of results follow and include the evaluation of field data via history matching, post frac buildup analysis (both initially and over time), other observations from the data, results, and conclusions.
P. 419
Hydraulic Fracturing for Control of Sand Production and Asphaltene Deposition in Deep Hot Wells
Authors: Ortega L. , Brito L. , Ben-Naceur K. 
Published: December 2007

Abstract
The North of Monagas giant field in Venezuela has been produced since the late 80-s. Depth ranges from 12000 to 20000 ft (3,600 to 6,000 m). Wells in the field have experienced early in the production cycle both problems of sand production and asphaltene flocculation. A multidisciplinary team was created to define ways to optimize production from the field.
The paper first addresses the methodology used to identify the source of the sanding problem, including extensive mechanical analysis of the formation, with tri-axial testing and sanding critical flow gradient analysis. The effectiveness of the initial strategies of optimization of choke size, and selection of perforated intervals and gun sizes is evaluated. The onset of asphaltene deposition was analyzed, and it was determined that most occurring problems were related to drilling and production practices.
To solve both problems, by modifying pressure drop and flow profiles, a hydraulic fracturing strategy was implemented in the field. Special care was given to the particular well conditions (close-by dual tubing completion, with potential risk of communication, thick and multi-layered geometry), in addition to expected high treating pressures and sensitivity of formation fluids to thermal shocks. A detailed pre- and post-fracturing well testing procedure was adopted which allows for an optimization of the fracture length, and comparison of results with predictions. Prior to the main fracture, calibration treatments were performed; calculated fracture heights were compared to the ones determined from temperature logs. A new technique to determine permeability from mini-fracs using the theory of impulse testing was also applied. Finally, production logging after the frac and a build-up were used to assess the validity of the predictions.

Introduction
The giant North of Monagas field lies in the East of Venezuela, in an area of over 400 km2 (Fig. 1). Its structure is an asymmetric anticline, with the Naricual formation (late Oligocene) being the most important feature, and thickness of over than 1500 ft, at depths between 12000 and 20000 ft (3.6 km to 6 km). The field was discovered in the 1980's. Despite high reservoir pressures, several wells have experienced severe sanding problems, combined with asphaltene deposition in the downhole tubulars. In addition to production losses, the frequency of well intervention to clean up downhole flow obstructions (via workover, snubbing or coiled tubing), and the complexity of working in wells with dual completions has created a major challenge. Another problem has been in the erosion of surface equipment, due to sand flow.
In order to provide viable long-term solutions to both problems (sand production and asphaltene), a work group between Corpoven and external laboratories to identify the cause of the production behaviour, and implement efficiently the techniques, with proper evaluation.
P. 449
Heterogeneous Formation : Assessment of Vertical Permeability Through Pressure Transient Analysis - Field Example
Authors: de la Combe J.-L. Boutaud , Deboaisne R.M. , Thibeau S. 
Published: December 2007

Abstract
In strongly vertically heterogeneous reservoirs, the oil flows to the well through the high permeability layers. Often in this kind of reservoirs, most ofthe original oil in place is stored in the low permeability layers, which are not contributing directly to the well production. This oil can only contribute to production if vertical communication occurs between low permeability layersand high permeability layers. Because the vertical permeability has a major impact on oil recovery, the evaluation of its uncertainty is a key factor for economic evaluation of the field.
This paper demonstrates how uncertainties in vertical permeability were deduced from pressure transient analysis on a field example in the Middle East. The classical multilayer analytical solution which represents crossflow between layers with the pseudo-steady state assumption was used. This paper highlights a practical method to compute the whole range of vertical permeabilities which honor the well test data. The use of these computed vertical permeabilities in reservoir simulation is discussed.

Introduction
Drill-stem tests were performed on three appraisal wells in a highly vertically heterogeneous carbonate formation. In order to evaluate the productivity of the wells, an acidization was performed on each well during the test before the buildup data acquisition.
The geological model has divided the reservoir into high flow capacity layers and low flow capacity layers, sometimes separated by a tight layer that can play the role of a permeability barrier. The permeability of the high flow capacity layer is due to vuggy porosity.
The build-up data were matched using the classical multilayer model. The well test analysis theoretically allows to define the following reservoir parameters : horizontal permeability and skin of each layer, storativity ratios and interlayer crossflow coefficients (lambda). However, the information provided by the derivative signature is not able to characterize such a bignumber of parameters. It is the reason why some of these parameters are fixedbefore the interpretation, thanks to an a priori knowledge of the reservoir. Then, the non fixed parameters are computed from the well test interpretation. They are considered as the results of the analysis. Among this computed parameters appears lambda which characterizes crossflow between layers. However, reservoir engineers prefer to deal with vertical permeability rather than interlayer crossflow coefficient.
This paper states that the solution in terms of vertical permeability is nonunique and shows how to compute its complete range consistent with the test data. Afterwards the impact of layering is discussed.
P. 399