bluuebunny/crossref_metadata_2025 huggingface dataset:
Chemical Water & Gas Shutoff Technology – An Overview
Authors: Kabir A. H.
Published: December 2007

Numerous chemical options are available for addressing excessive water and gas production problems. The chemistry of most of these options is complicated. A petroleum engineer with an average chemistry background has difficulties understanding these to a level that enables him/her to choose and apply a proper option to the problem at hand. In this paper, we provide a brief overview of all chemical water/gas shutoff (WGSO) options available to date. Monomer systems, polymer gels, relative permeability modifying polymers, inorganic gels, plastics etc. are commonly used chemical options. Less common options include viscous flooding, selective plugging with induced mineral precipitation and other miscellaneous grouting materials. Pros and cons of all these options are also discussed.
A Comparison of Various Laboratory Techniques to Measure Thermodynamic Asphaltene Instability
Authors: Jamaluddin A. K. M. , Creek J. , Kabir C. S. , McFadden J. D. , D'Cruz D. , Joseph M. T. , Joshi N. , Ross B.
Published: December 2007

Asphaltenes are the n-pentane or n-heptane insoluble fractions of crude oil that remain in solution under reservoir temperature and pressure conditions. They are destabilized and start to precipitate when the pressure, temperature and/or composition changes occur during primary production. The precipitated asphaltene particles will then grow in size and may start to deposit onto the production string and/or flowlines, causing operational problems.

In this paper, our emphasis is to identify the first pressure and/or temperature conditions at which the asphaltene will start to precipitate for two reservoir oils. Four different laboratory techniques were independently used to define the onset of the asphaltene precipitation envelope. These methods are 1) gravimetric, 2) acoustic resonance, 3) light scattering, and 4) filtration. The gravimetric method was found to be precise and within the accuracy of the analytical methods. However, the method was time consuming. The acoustic resonance technique (ART) was fast and less subjective, but it did not define the lower asphaltene boundary. The interpretation of the onset pressure from the near-infrared (NIR) light-scattering technique (LST) was subjective to a degree. However, the NIR response defined the upper and lower boundaries of the asphaltene envelope and the bubblepoint pressure, as did the gravimetric technique. In a way similar to those of the gravimetric technique and LST, the filtration technique can also define the upper and lower asphaltene phase boundaries in addition to the bubblepoint pressure. The filtration technique is fast compared to gravimetric technique, but takes more time than the ART and LST methods.
Reservoir Characterization - Integrated Interpretation of Borehole Data and Surface Seismic Data
Authors: Cao H. , Endo T. , Yamamoto H. , Cao D.
Published: December 2007

Precise reservoir characterization is of primary importance to reservoir evaluation and optimization. Effective integration of borehole and surface seismic data is the key to achieve this objective. However, such an integration is well known to be a complex task due to various difficulties, e.g. different resolutions between well data and seismic.

In this paper, we show an integrated workflow in which borehole data and surface seismic data are integrated for reservoir characterization. The workflow consists of three steps as follow: Formation evaluation. Accurate petrophysical evaluation of well logs with other borehole data is carried out to build a petrophysical model that describes formation composition, lithology and fluid type.Fluid substitution and AVO modeling. This establishes the link between the seismic responses and petrophysical parameters. Borehole seismic data provide the calibration for the sonic data, and also the input for the anisotropic and inelastic effects. Fluid substitution investigates the effects of pore fluids on the propagation speeds of waves. AVO modeling generates offset dependent seismic responses for the models of interest with known petrophysical parameters.Seismic classification. Knowledge extrapolation is performed to populate the seismic volumes or sections with the calibrated AVO response obtained at the well location. A geostatistical and neural network analysis establishes the relationship between the seismic attributes and formation properties (lithofacies, porosity, permeability, pore fluids, etc) at the well location. The quantified knowledge between formation parameters and seismic response at the well location is exported to the rest of the seismic data (2D sections and/or 3D seismic volumes).

This workflow will reveal if there is enough acoustic difference between different lithofacies for them to be distinguished from seismic data. When there is sufficient acoustic difference between different lithofacies, the distribution and variation of these lithofacies can be tracked using the seismic data.

It can provide direct hydrocarbon indicators for the optimization of well locations. When the acoustic impedance difference between different fluids in the formation is large enough to be captured by AVO analysis, direct hydrocarbon detection is possible and the well locations can be optimized. This integrated approach adds tremendous value to the existing data and shows what is needed for future data acquisition.
Monte Carlo Simulation on the Effect of Fracture Characteristics on Reduction of Permeability by In-Situ Bacteria Growth
Authors: Han C. , Kang J. M. , Choe J.
Published: December 2007

We have simulated the effects of fracture characteristics on the reduction of effective permeability of fractured rocks due to in-situ bacteria growth. A solute is injected continuously to provide food for the growth of in-situ bacteria. We used a power law for fracture length distribution and a fBm for fracture aperture spatial distribution. The results show that in-situ bacteria growth reduces the permeability hyperbolically, but the porosity of backbone fracture does not change significantly. It shows that the reduction of the permeability proceeds faster for smaller values of length exponent and for larger values of Hurst exponent. The fracture length distribution has a stronger effect on the speed of permeability reduction than the aperture spatial distribution. The time needed to reduce permeability is inversely proportional to the hydraulic gradient.
Geosteering in a Complex Dolomitic Reservoir
Authors: Longis Christian , Ferment Denis Yves , Madjidi Ahmad
Published: December 2007

This paper presents the key of success for the development of a complex prospect, the Sarr dolomitic reservoir in the Kharir field, located onshore Yemen. The drilling of horizontal wells was considered to limit the early water encroachment observed on vertical producers and to improve both the oil production and the final recovery. A careful data acquisition program, a close cooperation between all the parties involved in the drilling process, with the implementation of common decision procedures, allowed geosteering in optimized reservoir targets, while preserving the safety of the horizontal drilling operation. The Kharir Sarr field is a multi-layered oil bearing dolomitic reservoir interbedded with tight limestones. Variable petrophysical properties characterize the dolomite in this field, following the geometry of elementary sedimentary facies, their stacking, their structural position, and finally their diagenetic history. On top of the structure, the reservoir is interpreted as dolomitized patchy biostromes, very difficult to target and to appraise with vertical wells.

Monitoring the data acquired in real-time, referenced to pre-job-modeling, provided the key elements for cautious decision-making on trajectory definition. The expertise developed in geological steering has contributed to boost oil production and add significant field reserves.
In the Driver's Seat with LWD Azimuthal Density Images
Authors: Ballay Gene , Al-Ali Hussein , Amos Scott , Dennis Bob
Published: December 2007

Formation evaluation has been historically done ‘after the fact’, by means of wireline logs run at either an intermediate casing point, or when the well had been TD'ed. While this procedure is clearly inefficient in unexplored areas, there is also significant room for improvement in even relatively developed areas, if only one were able to measure and analyze formation attributes just after drill bit penetration. Ruggedization and miniaturization of the electronics have yielded tools that can be placed just behind the drill bit: increasingly efficient data transmission protocols permit ever more data to be examined, in real time. Saudi Aramco utilizes this technology for both real-time formation evaluation, and well-bore trajectory optimization.

The basic Logged-While-Drilling (LWD) service includes gamma ray (GR), density-neutron porosities (Rhob-NPhi) and resistivities at a variety of depths of investigation, transmitted up-hole at sufficient resolution to allow real-time formation evaluation. With this information one is in a position to quantitatively monitor local reservoir quality, and to make recommendations with regard to wellbore trajectory (deflect up or down, etc) and wellbore length (drill ahead, TD early, etc). One is not, however, able to address reservoir geometry questions (bed dip), which also have a direct bearing on the ‘drill ahead question’.

Modern LWD services include azimuthal gamma ray, density and resistivity measurements, which ‘look’ up, down and to the side. As the wellbore intersects various reservoir features, well-documented sinusoidal patterns present themselves visually in the data, and when coupled with real-time directional survey measurements allow one to deduce the local reservoir geometry. Formation evaluation personnel are literally " in the driver's seat " and can steer the wellbore either through or along (depending upon the circumstances) the feature of interest. One can furthermore extrapolate this local geometry (as opposed to field averages) geometry over to the next drilling location, and therefore compound the value. These capabilities are illustrated with actual data sets, in a development well environment.
Positive Returns from an ISO 14001 Environmental Management System
Authors: Al-Lamki F.
Published: December 2007

In 1999, Petroleum Development Oman LLC (PDO) obtained ISO 14001 certification for all its production and service operations. PDO was the first major E&P oil company in the Middle East to achieve the ISO 14001 certification. The certification process helped PDO to develop a culture of environmental awareness at all level, which has started providing positive returns in environmental performance. In addition, the certification re-inforced PDOs already high reputation in the country as a environmentally responsible operator. After the certification, PDO was seen as a pioneer both at local and regional scale, with peer companies consulting PDO on achieving higher standards in environmental management.
Risk Based Assessment of Storage Well Rehabilitation
Authors: Terchek Sean T. , Amick Paul C. , Newman Mark A.
Published: December 2007

Today's competitive environment within the natural gas industry requires gas storage operators to apply various risk management practices to effectively maintain and manage gas storage facilities. One operator's business management strategy includes tracking two key monitoring and maintenance parameters - reservoir integrity and storage well mechanical integrity. Reservoir integrity management consists of applying recognized standard reservoir engineering methods to monitor pressure and volume relationships. A storage well Condition Assessment Program is proposed to provide a consistent means to monitor and assess storage well mechanical condition in order to optimize limited capital resources applied to asset integrity management.

A relative risk assessment methodology is proposed to identify candidates for storage well reconditioning programs. A standard relative risk equation is applied to generate a relative risk profile based on certain probability of failure and consequence of failure parameters. By normalizing the information used in evaluating mechanical condition, wells within a controlled population are examined as possible reconditioning candidates.
Optimizing Drill-in Fluid Composition on Filter Cake Lift-off Pressure for Openhole Completion Offshore Applications
Authors: Queiroz João
Published: December 2007

This paper presents experimental results of a technique for minimizing the lift-off pressure of the mud cake generated by biopolymer/CaCO3 drill-in fluid (PDIF) used in horizontal well drilling.

The first stage of the work comprised the identification of the most influential variables in the lift-off process of the mud cake. Thus, from a group of seven suitable variables, mostly related with the composition of the fluid, the use of the technique of experiments factorial allowed to identify the permeability and the concentrations of the starch and of the calcium carbonate as the most influential in the lift- off process2.

Another group of experiments, this time with the calcium carbonate, showed that the minimization wanted in the lift-off pressure of the mud cake could only be reached through the use of concentrations of calcium carbonate of 50.0 lb/bbl.

Besides, other experiments showed that the use of concentrations of calcium carbonate of 50.0 lb/bbl does not cause disarray in the rheological properties of the PDIP, signaling that under that optics that concentration, the development of its use in the field would not be a difficulty.

Also, results of an experimental work of treatment of the PDIF are presented with concentrations of three surfactants marks, seeking to promote mud cakes of low lift-off as an alternative method to the use of larger concentration of calcium carbonate in the fluid.

The results of those treatments with surfactants were shown to be promising. Samples of the PDIF generated mud cake of low lift-off, of same of magnitude that the mud cakes generated by synthetic fluids.
Zero Shear Viscosity Determination of Fracturing Fluids: An Essential Parameter In Proppant Transport Characterizations
Authors: Asadi Mahmoud , Conway Michael W. , Barree Robert D.
Published: December 2007

This paper details the importance of zero shear viscosity in proppant transport evaluation and presents a methodology to obtain zero shear viscosity of fracturing fluids. Knowledge of zero shear viscosity is a major factor in modeling and predicting proppant transport in hydraulic fractures. The importance of this factor arises from the fact that shear rate in the fracture decreases from its highest value at fracture walls to zero value at the center of the fracture. And since proppants are mostly concentrated at the center of the fracture, it is therefore, essential to know the viscosity of a fluid at that shear rate so that proppant transport capability of a fluid can be realistically evaluated. The developed methodology to measure zero shear viscosity of a fluid involves measurements of viscoelastic parameters such as viscosity and elasticity as a function of oscillatory frequency. A non-linear regression model based on Maxwell's model is then used to calculate fluid's viscosity at various relaxation times and hence zero shear viscosity. Detailed explanations and examples are also presented on the measurements of viscosity, elasticity, and relaxation time as well as the process at which zero shear viscosity is obtained.
Application of Propellant High-Energy Gas Fracturing in Gas-Injector Wells at El Furrial Field in Northern Monagas State - Venezuela
Authors: Salazar Arquimedes , Almanza Edgar , Chira Pedro , Folse Kent
Published: December 2007

The Furrial Field located in the Eastern Basin of Venezuela is characterized by large oil reservoirs with complex geology due to faulting and heterogeneity. To optimize oil production and oil recovery in the field, the operator, PDVSA, implemented a gas-injection project. Several wells were drilled and completed as cased-hole completions using through-tubing and casing-gun technology. However, the results obtained with the conventional perforating techniques yielded less than optimum injectivity indices, non-uniform injection profiles, and higher compression requirements on the gas injectors.

The primary damage mechanism in these completions was identified as asphaltene deposition, presenting the challenges of being able to identify the damaged zones, and then, to selectively treat them in a safe and economical method under the prevailing conditions. Another problem identified was the emulsion damage caused by the inverted mud system used during drilling operations. After review of the available perforation and stimulation methods, a propellant high-energy gas fracturing technique was selected for field trials to enhance injectivity. The propellant high-energy gas fracturing technique, although not a new technology, was the first application of this process on gas injectors in Venezuela.

This paper emphasizes the methodology used to validate the application of the propellant high-energy gas fracturing technique on gas-injection wells and the use of surfactant during propellant activation to further creating an additional stimulating effect in the formation. A computer simulator was used to design the propellant treatments and analyze the effects of generated pressures on the mechanical well configuration and wireline design. The primary benefit of propellant treatments is its capability to selectively create mild fracturing with minimal formation damage. This benefit was demonstrated with the improvements and changes obtained in the injectivity and productivity profiles.

The case histories from the Furrial field validate this technology and provide operational guidelines and results in the form of injectivity changes. Production log responses to evaluate effectiveness of selective propellant placement will demonstrate the changes in completion efficiency. The propellant high-energy fracturing technique offers a simple, cost effective, and time-saving alternative to more commonly known stimulation techniques for selective treatment of formations. The objectives of this document are to present the experience gained from applying the technique, the results obtained, and why this method was particularly beneficial to the wells included in this paper.
Through-Tubing Gravel Pack With Small Clearance: The Important Factors
Authors: Vickery E. Harold
Published: December 2007

In remedial situations, it is often desirable to place a large diameter screen inside of a liner or failed screen section and place gravel in the small annular space. In some situations, this will allow continued optimum production from the wellbore without the need for a costly sidetrack.

In preparation for some remedial work in the North Sea, a laboratory investigation of important parameters involved with low viscosity gravel packing with small annular clearances was undertaken. Initial laboratory testing had indicated that the extremely tight clearance between the screen and the casing (approximately 0.27 inches radial clearance) caused sufficient change in the flow dynamics for premature bridging to occur even when standard water packing guidelines were followed. To alleviate this problem, further testing was performed to determine how standard practices could be modified to meet the challenge. This study included both circulating gravel packs and gravel packs conducted with no return flow. A variety of wellbore deviations, flow rates, sand concentrations, and washpipe diameters were tried to determine the relative importance of these variables.

The results of these tests, a look at how these results fit with current concepts of through tubing gravel pack completions, and guidelines to assist in the design of through tubing gravel packs are presented.
Pilot Test of Limited-Entry Frac Applications on Extra-Thick-Pay and Vertical-Fracture Wells in the Massive Oil Pool
Authors: Li Yongming , Guo Jianchun , Xu Wei , Zhao Jinzhou
Published: December 2007

LJ oil field is a massive oil pool with vertical fracture propagation, which needs applying fracturing-stimulation treatments for commercial production. The main oil-containing pay S3 is between 150 m and 200 m without obvious barrier layers. To meet the requirement of three layer series of development, fracture height must be controlled. Formation caving test and stress test were done for thirty wells of six well units. Based on the stress profile, pilot test of limited-entry fracturing was done for twenty wells. In addition, we did pre-frac and post-frac temperature log for eight wells. Shown from stress test and temperature log, fracture height was successfully controlled. According to post-frac statistical data of twenty wells, the increasing oil for limited-entry fracturing was 3.5_104 ton.
Effect of Material Type and Size Distribution on Performance of Loss/Seepage Control Material
Authors: Pilehvari Ali A. , Nyshadham Venkata R.
Published: December 2007

Circulation losses have always been a serious and expensive problem to drilling industry. Even with the best drilling practices circulation losses do occur. In order to reduce such losses to acceptable level fluid Loss Control Material (LCM) or Seepage Control Material (SCM) is used.

The objectives of this study have been to evaluate and compare the performance of different LCM/SCM and determine the effect of size distribution on their performance. Twenty-four different LCM/SCM samples made of various materials and blends of material having different size distributions were tested with three different types of mud. The three mud types used were water base mud, regular oil base mud, and environmentally safe oil base (Synvert) mud. With each mud three tests were conducted, one with the base mud and two with LCM/SCM concentrations of 5 and 10 lbs/bbl. The experiments were conducted in a Permeability Plugging Apparatus (PPA) at a differential pressure of 2500 psi and 250 °F, using ceramic disks. The performance of each LCM/SCM sample was determined based on the amount of spurt loss and total fluid loss of the mud according to the recommended procedure for PPA. The experiments show that amount of fluid loss depends on the mud type, LCM/SCM material, concentration and size distribution.

This paper presents details of the experiments, the collected data and the analysis and discussion of the results obtained.
Working Together in a Contract Environment: Angsi, Larut and SSE Teluk Ramunia Experience
Authors: Ibrahim Shamsulkamal , Ason Nazri , Jahuri Mohd. Abdul Malik
Published: December 2007

Integration of safety programmes from different stakeholders is often a challenge. However, for Angsi and Larut field development projects' jackets fabrication, this opportunity was chosen up-front by the two operating companies, and later planned and executed in a tripartite HSE arrangement between the two parties and their common fabrication contractor. Despite facing various challenges, all the three parties were willing to work together. In some areas, they were also willing to do things differently such as introducing Safety Greeters programme and applying Safe Performance Self Analysis and Incident Prevention Observations programmes for the first time in their upstream sector of the oil and gas industry. All these gave significant positive impacts on safety during the fabrication phase of the three jackets.
Contractor Management by Integration into the Safety Management System
Authors: Sohani Sunil , Haugnaess Thor
Published: December 2007

As the safety culture evolves in the oil industry, it is becoming evident that long-term business success, as well as the safety performance of an organization, depends on the performance of its contractors and suppliers.

In this paper we discuss the key elements of the contractor management process as applied within the Safety Management System on Schlumberger sites. We detail the step-by-step process flow and the various management tools. We also present results of safety audits, showing the improvement in contractor management.

We conclude that managing contractor safety performance, by integrating contractors into the Safety Management System, is a forward step in the progress of the overall safety culture in the oil industry.
Experience in Integrating Occupational Health into Safety Risk Matrix
Authors: Liew Keng Cheng , Zainuddin Zainal Mubarik , Samad Abu Hasan
Published: December 2007

Traditionally, an occupational health risk assessment is conducted by the occupational health (OH) subject-matter-expert (SME) separately from a safety risk assessment which is often conducted by the safety SME. Occupational health risks are often not assessed in-depth in the safety, health, and environment (SHE) risk assessment, which is normally led by safety SME. One of the reasons could be that the methodology is not well defined to align the OH risks with safety risks on a common basis in the risk assessment. This is understandable as OH risk assessments are based on "what-is" exposure assessment whereas the safety risk assessments are based on "what if" scenario of probability of safety incident occurring. A common risk assessment matrix for assessing both OH and safety risks with prioritized SHE risks will enable the line management to manage these risks better.

This paper describes how the safety risk matrix's methodology is enhanced by integrating occupational health into the matrix. It also describes the experience and challenges in using the proposed SHE risk assessment matrix.
Deep Sea Ecosystems on the Equatorial African Margin: First Results of a Pluridisciplinary Environmental Programme and Discovery of Chemosynthetic Based Ecosystem
Authors: Sibuet M. , Galéron J. , Khripounoff A. , Menot L. , Olu-LeRoy K. , Durrieu J. , Miné J.
Published: December 2007

The environmental study initiated in 1998 by Ifremer and TotalFinaElf, in the framework of oil exploration, on the continental margin off Angola, Congo and Gabon, has been successfully implemented. Under this study, 9 long term moorings were laid out from RV le Suroît in April 2000 on three deep sites, and 38 trawling and box coring were operated from RV Thalassa in August 2000 near well stations. Subsequently in January 2001 cold seep communities were discovered during an in situ exploration using the new ROV Victor 6000 from L' Atalante.

On going studies brought already original results on the general structure of the benthic communities and on chemical characteristics of the sediment near well stations (Block 17 – 1350 m depth). A comparison of the biological and chemical data obtained between stations located at 200 m and about 10 km away from well stations showed: –No significant differences for most of the parameters from the preliminary observations,–No contamination level of aromatic hydrocarbon in the superficial sediment, but differences in barium concentrations, due to drilling mud which contaminated the sediment near the well.–Unexpected richness in organic carbon of the sediment not only in the surface but down to 15 cm,–Similarity of macrofauna density to that observed in other bathyal zones of the world, with however, a presence of macrofaunal organisms deep into the sediment, which can be explained by the high organic carbon content observed,–The absence of sessile fauna due to the fluidity of the sediment and the lack of hard substrate.

The discovery of localised rich biological communities of large bivalves and pogonophorans linked to fluid and gas emission shows that two types of ecosystems exist on that passive margins: the detritus based ecosystem is indirectly linked to photosynthetic production whereas the more localised cold seep ecosystem depend on chemosynthetic processes.
Compliance with Industrial Safety Legislation in Russia
Authors: Kozlov M. Ya. , Kozlov M. M.
Published: December 2007

This paper is intended to demonstrate experience gained by Halliburton Energy Services in Russia. The experience pertains to compliance with Russian safety legislation regarding hazardous industrial facilities including oil and gas facilities. The Federal Law of the Russian Federation on Industrial Safety of Hazardous Industrial Facilities, as approved by the President of the Russian Federation on July 21, 1997, determines the legal and economic basis for safe operation of hazardous facilities in Russia. This law covers all aspects of industrial safety including (1) licensing; (2) require ments for design, construction, commissioning, and operation of hazardous facilities; (3) requirements for accident investigation; (4) safety expertise; (5) liability insurance for damages; and (6) liability for non-compliance with the safety regulations. In the course of providing its services in Russia, Halliburton has demonstrated its capability to comply with all requirements of this Russian federal law. Halliburton, however, had to learn from its own mistakes; but it is now clear that Halliburton understands the law and is able to proficiently pursue its business.

Training foreign personnel about local safety regulations — irrespective of their international or national certificates — is one very important aspect in training for compliance. Another imp ortant aspect is instruction about obtaining Russian certificates and permits for any equipment used at hazardous facilities. Many Russian rules and standards are more stringent than those of Western countries. Some examples will be considered in the paper.

The findings of this paper can be effectively used by foreign companies and by exporters of equipment for hazardous oil and gas production facilities in the Russian Federation. These facilities are subject to supervision of the Federal Mining and Industrial Inspectorate of the Russian Federation.
Systematic Approach to Occupational Health and Safety in the Engineering Phase of Offshore Development Projects. Experience from the Norwegian Petroleum Activity
Authors: Zachariassen S. , Knudsen S.
Published: December 2007

Many employees on offshore oil and gas installations have to rely on personnel protective equipment to avoid work related diseases. This is not recognised as a proper prevention strategy. High noise levels and bad ergonomic solutions are often intimately embedded in the design of the installations. To rectify a hazardous design by technical modifications in the operating phase are difficult to achieve and expensive to perform. Occupational health and safety achievements seem not to fit well into traditional cost benefit based decision-making.

The Norwegian Petroleum Directorate (NPD) has since 1995 enforced an occupational health and safety legislation that focus in particular on a systematic approach in the planning phase of offshore development projects. The NPD has followed most of the recent offshore projects closely through audits and verifications.

The Norwegian petroleum industry has followed up the legislative initiative by developing specific standards for how to implement occupational health and safety requirements in the engineering phase.

Over the last few years we have observed substantial improvements of the engineering practice. A common understanding of requirements and structured co-operation between project management, experienced workers, design engineers and occupational health and safety experts seems to be important pre-requisites for success.

This paper will describe and discuss key elements of the Norwegian legislative basis and bring forward some of the experience gained trough project auditing and follow-up activity related to implementation of occupational health and safety requirements in the engineering phase of offshore development projects.
Emergency Management: The Development of an Integrated Approach Between Industry and Government
Authors: Bettencourt Michael de , Chai Lee Ten
Published: December 2007

Optimally, emergency management within a society is completed at all levels by all organizations regardless of the cause and the consequences. Challenges to this idealistic model include the high cost of emergency response, the limitations of training in an industrial related incident, differing levels of expectations across governments, companies, and cultures, and the jurisdictional confusions in a society where legal authorities may be broad and generic.

Integrated emergency response is the full integration of all response resources, training programs, and exercises. This is particularly important when the disaster may no longer be a result of an act of nature, but is man-made. In the instance of a petrochemical emergency, local responders outside of the originating facility may not have the ability to operate safely within the affected area. Well meaning, but uninformed responders, may become additional casualties.

In developing an emergency management program, a three pronged comprehensive system must be used. It must encompass: Common terminology across disciplines using a commond incident command systemIntegration of preparedness, prevention, readiness and response programsProvisions for continuous improvement

An integrated approach to emergency response addresses all response resources including the properly equipped local community and regional fire, police, medical, and relief agencies that are capable and willing to provide response resources. Also necessary in an integrated program is a comprehensive response management system that ensures each agency and organization is capable of communicating on a common system using the same terminology, language, and processes.

Additionally, an integrated response organization will operate with one set of goals and objectives under a unified system of command. This requires a tremendous amount of trust between the agencies and organizations, and a tremendous amount of skill to operate cohesively and efficiently.

The paper discusses a process for developing an integrated emergency management program that is being currently used in several parts of the world. The presenters discuss the issues and challenges in developing a cohesive and integrated emergency management system. This system is revising age-old practices and setting standards of integration for contingency planning, training, and exercise management. The goals of these programs are to assure that all emergencies are handled expeditiously and efficiently with minimal threat to the local population and maximum benefit of the local response agencies in an integrated response organization.
Introducing a Risk Based Dynamic Oil Spill Response Regime for the Norwegian Continental Shelf. Response from Operators, Authorities and other Stakeholders
Authors: Brekne Tharald M. , Skeie Geir Morten
Published: December 2007

By July 1st, 2001, the Norwegian Clean Seas Association for Operating Companies (NOFO) completed a three-year R & D programme for development of a dynamic, risk based oil spill response regime for the entire Norwegian continental shelf, including coastal areas and the shoreline.

The results from this programme are made available for operators, authorities, other stakeholders and the general public through the NOFO web site http://www.nofo.no. This web includes operational plans, documentation of methodology and analyses, as well as intuitive interfaces to databases, oil spill sensitivity maps and GIS tools.

Significant effort has been made to train the personnel included in the oil spill response organisation. In this process, industry, authorities and local community personnel have been involved.

The content of the web serves as reference and documentation for authority audits of fields and installations.

An important area of use is for cost effective analysis and evaluation of oil spill response requirements for new developments and exploration drilling, as basis for consent applications.

Comments and suggestions from audits and consent applications have been actively collected and organised through the first six months of operation of this new regime.

Additionally, the response from industry users, stakeholders and the general public to this form of open and transparent information sharing has been invited and reviewed.

This paper presents our experiences from these processes, along with our objectives for further development.
A Practical Approach to SH&E Risk Assessments Within Exploration & Production Operations
Authors: McCulloch Brian R.
Published: December 2007

Risk Management is a common element within industry SH&E Management Systems. Expectations for conducting risk assessments are often defined within these management systems, however, the process required for completing risk assessments is often misunderstood by operations personnel assigned with this responsibility. Decisions on the appropriate level of risk assessment (e.g., qualitative, semi-quantitative, quantitative) to use, as well as the appropriate level of risk to evaluate, can be problematic. Additionally, communicating identified risk issues and their relative risk priority to senior management unfamiliar with risk terminology can be a challenge.

This paper describes a process used by Texaco Exploration and Production to effectively evaluate the SH&E risks associated with its operations. Risk categories included those associated with people, assets, environment, and reputation. Since the organization was in the midst of a company merger, transitional risk (i.e., reduction in emphasis on SH&E) was also evaluated. The process included the development of an SH&E risk checklist and risk matrix (probability vs. consequence) and the assessment of risk via interviews throughout all levels of the business unit organization. Field visits by multi-functional teams were also conducted to ensure a thorough understanding of the risks identified as a result of the employee interviews.

Application of this practical, integrated SH&E risk assessment process has a positive impact on the business units. The results of the assessment focus on risks with higher probability and consequence (more than regulatory compliance issues), as well as a means to set SH&E strategies and objectives to reduce risk. Full integration of business unit representatives throughout the process gains a common understanding of the risks as well as a commitment for further mitigation action.
A Medical Emergency Response System for North Sea Operations
Authors: Sande Audun
Published: December 2007

This presentation describes Statoil's system for medical emergency preparedness in the Norwegian sector of the North Sea, and the improvements made with regard to emergency response.

Statoil currently operates 15 offshore oil and gas producing platforms and 10 – 15 drilling rigs – with a total population of approximately 1800 at any time.

Each installation has a medical staff of one or two nurses depending on the number of employees on board. An onshore doctor is on 24 hrs. call to give advice on treatment, see evacuated patient, and to be flown to the installation if required.

Each installation or field has a dedicated physician who is professionally responsible for the qualifications of the nurses, the quality of the procedures and availability of equipment and medicines.

The number of injuries requiring medical treatment has been significantly reduced since the end of the nineteen seventies. In the same period the occurrence of cardio-vascular diseases has increased with the average age of the employees on our offshore installations.

In the course of the last years, there has been a strong development as regards treatment of acute medical diseases in general, and of cardio-vascular diseases in particular. This includes diagnosis and intensive care in the acute stage as well as technical equipment and medication. One of the consequences has been an increased demand for competence and retraining of our medical staff.

In addition patients, their next of kind, authorities, media and the society in general expect our medical emergency response level to be as high as it is onshore.

This presentation describes how Statoil seeks to ensure optimal treatment of the patients on board, fast and efficient reporting to obtain medical assistance and transportation, and will include: –Qualifications and training of involved personnel (doctors and nurses)–Standardization and harmonization of procedures (standing orders)–Standardization of equipment–Requisitioning of helicopter transportation
Salted cuttings stabilization
Authors: Morillon-Jeanmaire Anne , Marcillat Yannick , Thomas Fabien , Filippov Lev
Published: December 2007

The saline geological formations often display facies that are very prospective for oil. When drilling such formations, management of salted cuttings generated in areas where disposal at sea is prohibited is a real challenge. A strong impact on the terrestrial environment can be expected from salt, either on the aquifers or on the soils. An adequate stabilisation process that is well controlled is therefore necessary.

The paper presents an innovative approach to the complex problem of the stabilisation of salted cuttings. Several options have been investigated during a two years study to come up with a process that is efficient, reliable and easy to implement.

Leaching tests and salt content determination of the leachates were carried out, to screen the efficiency of the different processes investigated. –The "molecular option", consisted in attempting to make salt crystals hydrophobic by tying amines onto them.–The "macroscopic option", consisted in evaluating the efficiency of the addition of ferric chloride, to generate an insoluble precipitate around each cutting grain.–The "mechanical option", investigated the effect of adding either pure cement or cement with phosphate in order to trap the salt crystals in a solid matrix. The purpose of adding phosphate is to generate an insoluble phase by reaction with the Calcium cations of the cement.

The last option is based on a compacting process followed by a cement coating. Whereas the first three options produced mixed results, in particular with regard to stability with time, the last one led to very encouraging results. This process is currently being optimised and will lead to an industrial scale test, based on 500 kg drill cuttings, in January 2002.

The implementation of this technique could constitute a major breakthrough in the drilling industry both onshore and offshore.
Mapping and Monitoring the Technical Safety Level
Authors: Thomassen Odd , Sørum Morten
Published: December 2007

Measuring the "true" safety performance of the oil & gas industry has been a challenge for the industry for many years. Indicators such as "Total recordable injury frequency", "Lost time frequency" and similar parameters have been used, and are generally only reflecting minor incidents and injuries, but the causes of minor and major incidents may not necessarily be the same. Other indicators may be better to give a picture of the safety level for major hazards.

A clear picture of the condition of our plants and installations, methods and indicators that can monitor the safety level are all vital elements to maintain a lowest possible risk for major hazards.

This paper describes a review method to map and monitor the technical safety level on our offshore platforms and land based facilities based on the status of safety critical elements, safety barriers, and their intended function in major accident prevention. The method is based on a review technique using defined performance requirements in accordance with ISO 13702 (ref. /1/) and ISO 61508 (ref. /2/), and based upon the function and role of the safety critical elements.

In a plant or facility the condition of safety barriers are measured against "best practices" as well as against minimum requirements, and thereby possible improvements are identified. A set of examination activities is defined and used to check each performance requirement, including document reviews, interviews, visual inspection and field tests. Such verification activities are to be repeated at regular intervals to ensure that the technical safety barriers remain intact.

Between reviews major trends in risk level will be monitored through a set of key performance indicators. Deviations in these and significant trends will be flagged to allow for necessary intervention prior to safety barriers are weakened.
Practical Aspects of Managing HSE in a Remote Oilfield Operation
Authors: Ryan M. G.
Published: December 2007

ChevronTexaco operates the Barrow and Thevenard Island oilfields situated off the NW coast of Western Australia. Chevron Australia assumed operatorship of the Barrow and Thevenard Island oilfields in February 2000, prior to this Chevron had provided management and technical support to West Australian Petroleum (WAPET), the previous operator. In October 2001 Chevron and Texaco merged to form ChevronTexaco.

The aim of this paper is to provide a practical lookback on the issues that have affected the way a safety management program is managed and implemented in a remote operating environment. The paper primarily focuses on a number of issues, which have affected overall safety performance, these include: Technology and engineering;Management systemsBehaviours

The challenges that have faced ChevronTexaco in the management of safety in the Barrow Island and Thevenard Island operations have not been unlike that of other operators in similar remote situations. The Barrow Island oilfield was the first commercial oilfield in Western Australia and also one of the earliest onshore oilfield developments in Australia. As such when the field was being developed in 1964 oilfield technology, management systems and safety culture were all issues which either were in an immature state of development or did not exist at all. In addition to this the remoteness of

Barrow Island to the wider oilfield community together with the absence of peers in a similar operating environment presented both a challenge and an opportunity in the development of a safety culture.

Over the past 10 years the organization has experienced a number of changes all of which have had an impact on safety management and overall safety performance. This paper addresses the issues that have had an impact on the overall management of safety in a remote operation and to characterize which aspects of the systems that were put into place which resulted in the most impact in improving overall safety performance. The paper also focuses on the latest issues that the organisation is addressing with respect to the development of a sound safety culture. In particular the issues of visible leadership and personal accountability are discussed in the context of a HSE management system framework.