bluuebunny/crossref_metadata_2025 huggingface dataset:
The Impacts of National Culture on Safety Culture in the Global Oil and Gas Industry
Authors: Merritt Steve
Published: September 2012

Safety culture is one of the most-studied subjects in the safety literature today, although no agreement exists on exactly what it means. Most safety culture research has been conducted in high-hazard industries such as nuclear power, aviation, and offshore oil and gas production. Only limited research has investigated links between safety culture and the prevailing national culture. This paper proposes that efforts to build safety culture and improve safety performance in the oil and gas industry will be enhanced if the prevailing national culture is assessed and a location-specific plan is developed.

Within Chevron, current safety culture initiatives include defining and advocating for "Operational Discipline" and focusing on "Behaviors to Support Managing Safe Work" in the upstream sector. Both of these approaches have distinctly North American cultural underpinnings. The HSE opportunity this paper addresses is building a strong safety culture across the many varied national cultures where Chevron operates. This paper reviews the key attributes by which national cultures are characterized with a particular emphasis on the areas most applicable to safety culture in oil and gas settings. For example, in a national culture characterized by high power distance and predominantly masculine traits such as those found in Latin America or the Middle East, techniques that work well in North America or Europe will likely not be as effective. It will argue that fit-for-purpose safety culture maturation plans are needed for each location.

The paper should be of particular interest to leaders who are working in business units outside of their home country. Hopefully they will learn something that will help them to better understand key aspects of national cultures and allow them to customize and accelerate their safety culture development efforts back on the job.
Learning from Events: A Process Approach
Authors: Drupsteen Linda , Zwetsloot Gerard , Groeneweg Jop
Published: September 2012

Many organizations try to prevent reoccurrence of incidents by analyzing incidents and implement recommendations based in their findings. Unfortunately this approach is not without pitfalls. Between ‘reporting’ and ‘evaluation of the effect of actions’ there are several hurdles to be taken. Only by looking at all the steps in the process organizations can ‘learn from incidents’. This contrasts with the traditional view that success can be achieved by looking at a limited number of factors, e.g. ‘the tool’ itself. Furthermore, organizations mistakenly believe that by formally zorganizing each of the steps they take away the hurdles. A checklist was generated aimed at the identification of the hurdles in the learning from incident process. Several hundred safety professionals in the Netherlands and employees in a tank storage company were asked to identify the so called ‘bottlenecks’ in their own organization and describe if each of the steps has been formally organized and how it worked in practice. Interviews with focus groups were held to identify causes of the hurdles. The learning potential from accidents is reduced, many of the steps in the learning from incidents process have flaws.

This cannot be improved by taking one weak link out, only an approach that takes all steps into account can significantly improve the learning potential of organizations. Furthermore, the level of formal organizations has little predictive value for the ‘real situation’. Learning from incidents is of key importance for organizations to prevent their reoccurrence. This paper will describe the ‘learning from incident process’, will describe the main hurdles and their causes and will help organizations understand why ‘Its not the tool’ and why formal organization is not sufficient to guarantee success.
Fariiq DOIRC—A Strategic Enabler for Top Quartile Performance in Safety in Abu Dhabi
Authors: Boucif Mustapha , Kuyken Chris , Al Hammadi Adel , Ghany Wael Abdel , El-Adawy Ahmed
Published: September 2012

The Drilling Operations Incident Review Committee (DOIRC) was formed in UAE in 2006 as a means to discuss incidents that have occurred during the last month to ensure that all lessons learned are shared among all contractors and disseminated throughout their organizations. Members of this committee include the Abu Dhabi Company for Onshore Oil Operations (ADCO) Drilling Division, the National Drilling Company (NDC), and various members from key service providers. DOIRC meetings are useful for discussing and explaining any new safety improvement initiatives with the rest of the committee.

The success of the program clearly shows that the behavior of all stakeholders in drilling can be changed through effective communication, visible commitment, and involvement by top management. Maintaining constant communication between the drilling crews, service providers, and the top management of ADCO and its contractors has had a positive impact on the safety behavior of the drilling crews since the committee was formed.

The DOIRC program was the key factor for ADCO drilling to reach and maintain a world-class performance of 0.09 LTIFR, the lowest in ADCO drilling history in 2008, 2009, and 2010, with more than 20 million km driven without injuries. From a service-provider perspective, Halliburton has performed the last eight years with ZERO recordable motor vehicle incidents and one lost time personal injury incident.
Behavior Management: A Successful Approach
Authors: Tauseef Abid , Villegas Mauricio , Bordage Pierre , Turner Lee
Published: September 2012

In the last two decades, organizations have used safety programs and advanced safety management systems to improve their safety performance. Safety management systems, policies, procedures and standards along with better tools and equipment have played an important role in decreasing incident and injury frequencies in the oil and gas industry. However the industry has realized that employee participation is the key to success for all safety programs. Unless employees demonstrate a positive behavior in actively enforcing the safety programs and standards in place, the organization's safety programs remain virtually ineffective.

A review of the integrated project management (IPM) arm of an oilfield services company incident reporting database revealed that most of the risk identification reports (RIRs) logged in the system were related to unsafe conditions, whereas only a few were related to unsafe acts. In an effort to reduce this trend, a decision was made to launch a behavior based safety (BBS) program called observation intervention program.

The program had already been introduced in some parts of the company but was not formalized. The program was implemented through the company's health, safety and environment (HSE) management system utilizing the company's existing BBS-based program. To measure the success of the program, a number of leading and lagging indicators were chosen from the driving and injury prevention areas. There were four specific areas of observations created in the reporting system: driving, injury prevention, environmental and general observation interventions. The campaign was launched in 2010, and the indicators were monitored for 2010, 2011, and 2012. An analysis of the results revealed that these indicators showed a remarkable improvement with increased employee participation in the BBS program.

This paper describes the process of the successful development and implementation of a BBS program and the essential factors that need to be considered in order to improve employee participation and avoid failures.
Beyond Bulletins and Presentations: Use of Scenarios to Learn from Incidents
Authors: Novatsis Emily , McCormick Paul , Lardner Ronny
Published: September 2012

Many organisations in the process industries seek to improve how they learn and embed lessons from incidents. Yet we hear less from such organisations on trialling novel learning methods in search of better ways to learn from incidents. This paper describes a project that used an engaging and interactive method to help personnel learn generic lessons from previous isolation incidents. A realistic written scenario was developed based on the common characteristics of previous isolation incidents. The scenario was completed by teams in facilitated workshops. Information about the scenario was progressively revealed, and at each stage participants were asked to identify what they would think and do as the events unfolded. Correct answers were discussed as a group, illustrating potential "holes" in organisational barriers if understanding or application of these barriers was lacking. Evaluation of the approach indicated that the scenario was a more interesting and engaging method of learning from incidents than passive methods such as emails, bulletins, and presentations. This project is being extended to scenarios for lessons from other themes of incidents. Using scenarios to strengthen individual learning impact from incidents is unusual, and can be applied by other organisations seeking a deeper level of learning from incidents.
Developing Internal Human Factors Capability in an Australian Oil and Gas Company
Authors: Novatsis E. , McCormick P. , Lardner R
Published: September 2012

The contribution of human factors in major accident events is well established and accepted. Organisations are increasingly seeking help on how to best understand and manage human factors issues. This paper describes how Woodside has progressively strengthened its internal human factors capability over the past five years to complement its existing skill set and improve health and safety performance. Woodside began by creating a new role in its health and safety function for an organisational psychologist. The purpose of this role was to deliver a range of human factors projects, increase the profile and knowledge of human factors in the business, as well as provide and guide the use of human factors tools and methods. The first project was on the subject of safety culture and the work scope has progressed to cover a wide range of human factors topics important for high hazard industries. Human factors focal points were also established and these people are given more knowledge and skills on certain topics to provide support at a local level. This capability is supported by a steering group, aligned plans, preferred tools and practices, and human factors competencies. Woodside now has multiple full time human factors advisers, a wide network of human factors focal points, and many human factors "spotters". Improvement in a number of areas has been achieved and a demand and enthusiasm created for using human factors methods to improve all aspects of performance, not just health and safety. This paper will interest organisations wanting to strengthen their internal human factors capability.
International Collaboration to Advance Sustainable Oil & Natural Gas Production and Climate Protection
Authors: Chakraborty A. B. , Kalita Kapil Deb , Bartos Scott , Seastream Sandra , Shartzer Andy
Published: September 2012

Directly supporting the Global Methane Initiative (GMI), the Natural Gas STAR International Program is a voluntary partnership between the oil and natural gas industry and the United States Environmental Protection Agency (EPA) that promotes use of cost-effective technologies and practices to reduce methane emissions. In 2008 and 2009, the Oil and Natural Gas Corporation LTD (ONGC), the first Natural Gas STAR International Partner in India, undertook a desktop review and in-country methane emissions measurement study and analysis to identify and quantify baseline methane emissions levels for seven of its production, processing and transmission facilities. The measurement study was conducted using infrared camera technology to identify emission sources; and a combination of turbine meters, high volume samplers, and calibrated bagging techniques to measure their emission rates.

This paper details the survey activities and quantitative measurements for the seven surveyed facilities. EPA's Natural Gas STAR International (NGSI) Partners are eligible to receive recommendations on technologies or practices, a facility-specific assessment of their technical feasibility, anticipated methane emission reductions, and the economic and environmental value of the proposed emission reductions. The paper further describes mitigation projects ONGC has deployed as a result of their collaboration with EPA.

ONGC, acting immediately upon the Partnership's recommendations, and consistent with ONGC's corporate carbon management program, have to date reduced methane emissions in the studied facilities by 30 percent, achieving annual natural gas savings of more than 9 million cubic meters (MMcm). This paper also reviews ONGC's future climate protection plans.
A Release Criterion for Oil and Gas Production Equipment with NORM Contamination
Authors: de Witt R. F. , Rutkowski S. J. , Young J. G. , Cooper M. B
Published: September 2012

The deposition of small amounts of radioactive material on the surface of oil and gas processing equipment creates, in time, a scale that can potentially pose a safety, health and environmental risk. Release criteria are usually defined in terms of the activity concentration of the radionuclides in a material; however this constrains the measurement of NORM in equipment to an impractical and prolonged testing process. This paper evaluates field data to establish a practical empirical relationship between the activity concentration present in a NORM deposit and measurements obtained with a hand-held Geiger-Müller radiation monitor. This has been done for varying circular diameters to account for geometrical variations introduced by measuring a curved surface with a flat probe.
Facing Up to Demands for Small Bribes: Legal Requirements and Operational Challenges in Weak Government Zones
Authors: Bray John
Published: September 2012

Until recently, international anti-corruption initiatives focused almost exclusively on ‘grand bribes’ to secure contracts or obtain licenses. Now small bribes or ‘facilitation payments’ connected with day-to-day operational matters such as customs clearances, environmental inspections and security are rising up the international legal and corporate agendas. The increased focus on small bribes reflects wider international enforcement trends, including in the US. However, the greatest single driver has been the UK Bribery Act, which does not distinguish between large and small payments.

Demands for small ‘operational bribes’ present particular challenges for E&P companies working in weak government zones where such payments are often customary, even if they are against the host country's written law. Demands are typically backed up by what amounts to a form of extortion. At a minimum, failure to pay will result in expensive commercial delays and, in many cases, there is an implicit threat of violence. Indigenous employees are often at greater physical risk than expatriates.

This paper draws on the recent consultancy experience of the author and his colleagues working with international companies at both headquarters and the operational levels in a range of complex environments in Africa, the Asia-Pacific and the Middle East. It briefly reviews the changing international legal context, before focussing on the practical strategies that companies have adopted to resist demands.

The paper argues that small bribes are a corrosive phenomenon, and that companies should not pay them. With skill and determination, they can reduce their exposure to demands, and they have a social as well as a legal responsibility to do so. It concludes with recommendations for companies and their partners in ‘host’ and ‘home’ governments as well as international agencies.
Offshore Environmental Monitoring: Evolving Approaches and Technologies to Support the Oil and Gas Industry
Authors: Glickman Andrew , Mine Jacques , Nilssen Ingunn , Lystad Einar , Buffagni Melania , Findlay Abigail
Published: September 2012

Abstract:(previously submitted to SPE)

The International Association of Oil and Gas Producers (OGP) Offshore Environmental Monitoring Task Force has developed a compendium of guidance and best practices for offshore environmental monitoring. Environmental monitoring has increased and become more sophisticated as concerns around the ecological impacts of offshore drilling and production have grown. Environmental monitoring is now integrated into the full life cycle of an offshore oil field, from early seismic evaluations through production to decommissioning. Traditionally, water column analyses, and physical, chemical and biological analyses of sediments have composed the basic elements of an environmental monitoring program. These analyses have often been coupled with dispersion modeling assessments that estimate the spatial footprint of drilling and production discharges both within the water column and on the sea floor. More recently, new technologies are becoming part of the environmental monitoring toolbox. These include subsea chemical and physical sensors attached to subsea landers, remote observational vehicles equipped with video, sensor and sampling capabilities, whole effluent toxicity testing, and biomarkers in organisms caught or caged within the oilfield. This new OGP guidance will enable an operator to define the scope of monitoring appropriate for their operation and stage of development, select from a range of monitoring technologies, and take steps to ensure high quality data is obtained.

Extended Abstract:

The International Association of Oil and Gas Producers (OGP) Offshore Environmental Monitoring Task Force has developed a compendium of guidance and best practices for offshore environmental monitoring. Environmental monitoring can be driven by regulatory requirements or to meet internal environmental stewardship expectations. The compendium provides guidance to offshore operators on when and how to conduct an environmental monitoring programme.

To scope out potential environmental data needs for a monitoring programme, OGP developed the e-SHRIMP1 toolbox to assist offshore operators in the assessment and management of impacts in all project activities throughout the full field development lifecycle. Different project phases can be mapped to the e-SHRIMP1 framework (OGP, 2007).
Dropped Object Prevention Scheme (DROPS) - An Asia Pacific Perspective
Authors: Leong Weng Fei
Published: September 2012

Dropped Object Prevention Scheme (DROPS) has been in existence since the late 1990s with the first DROPS grouping in the United Kingdom and developed out of a Step Change Initiative in the North Sea to tackle the high number of dropped object incidents in the industry. The DROPS chapter in Asia was established in 2009 and has come a long way with the active participation many of the oil and gas industry companies through activities organized by the Asian DROPS chapter. However, anecdotal evidence suggests that success with any DROPS initiative in the region is usually operator dependent or driven largely by the international drilling contractors. Companies like Shell and Transocean are leading the pack globally on DROPS and the focus on DROPS given by these organizations does benefit the DROPS initiatives in the Asia Pacific region. The progress of DROPS in Asia Pacific will be examined objectively and the challenges and strategies in preventing dropped object incidents in the oil and gas industry in Asia Pacific will be looked at critically. We will also examine some of the efforts taken by the companies within the Asia Pacific region in managing dropped object risk in the industry as well as the efforts of DROPS Asia in bringing the focus on DROPS across the entire industry supply chain. For example, engaging rig constructors on building rigs or offshore installations that eliminated dropped object risk from the design stage.
Challenging Our Societel Performance
Authors: Win Swe Swe
Published: September 2012

Yadana consortium, partnership of Unocal, PTTEP, the Myanmar Oil and Gas Enterprise (MOGE) and Total Exploration & Production Myanmar (TEPM) as an operator, is operating the Yadana gas field located in the Gulf of Mottama. The extracted natural gas is exported to Thailand via a 63 kilometer onshore pipeline that passes through Kanbauk area in the region of Tanintharyi, south of Myanmar.

As part of its Corporate Social Responsibilities, Yadana consortium has been implementing a socio-economic program for the inhabitants of the villages neighboring the pipeline since 1998.

The coverage was extended step by step from 13 villages to 25. As of May 2012, the program directly covers about 33,000 inhabitants, but it is estimated that about 50,000 people benefit directly or indirectly of the activities implemented. For instance villagers from non-covered areas are also being welcomed to seek consultations in supported health facilities.

The Yadana’ socio economic program is extended beyond the pipeline area to the national level supporting mainly on public health, education and social welfare infrastructure. Some projects are implemented by specialized NGOs.
Partnering with the Wildlife Conservation Society to Protect Marine Mammals and Turtles
Authors: Maruca Sheryl , Augusto Benvinda , Wolinsky Gary , Mann Nicole , Rosenbaum Howard , Formia Angela , Cerchio Salvatore , Collins Tim , Pendoley Kellie
Published: September 2012

Marine mammals, including coastal dolphins, West African manatees, offshore cetaceans (baleen whales and larger odontocetes), and marine turtles are increasingly under threat; many are rare, although some cetaceans are showing recovery from commercial exploitation. When Angola Liquefied Natural Gas (LNG) began using Chevron's Operational Excellence Process for Environmental, Social and Health Impact Assessment (ESHIA) to manage the potential environmental impacts of a proposed LNG facility in the Congo River Basin, they collaborated with the Wildlife Conservation Society (WCS) to address issues identified in the Angola LNG ESHIA Process and to develop programs to protect the marine turtles and marine mammals through cooperative science and management, training, and education.

The Marine Mammal Program fieldwork, conducted by WCS and Angola LNG in the Congo River Basin area and South Atlantic coastline near Soyo, Angola, was completed between 2008 and 2009. Activities included the assessment of inshore and Congo River environments and marine mammals, and the use and deployment of Marine Autonomous Recording Units (MARUs; shown in Figure 1) as a cost-effective means of surveying whales in the South Atlantic Ocean. This was the first time MARUs were used off the coast of West Africa.

The MARUs allowed for long periods of continuous monitoring for vocalizing cetaceans, cetacean behavior and anthropogenic contributions to ocean ambient noise with relatively minor field effort. The technique also allowed for uninterrupted acoustic monitoring investigations, otherwise impossible with boat-based visual methods during night hours and inclement weather. However, there were certain challenges in using the MARUs, such as the analysis and management of large datasets, as well as the identification of signals in the recordings when there is little to no possibility of verifying all possible signals through simultaneous visual surveys and sightings. Due to logistical and safety limitations for conducting numerous offshore surveys for identification, existing data from other parts of the world were used for comparisons to confirm species of vocalizing whales. In many cases, some of the signals will remain unknown.
Why Quiet? Legislative, Commercial and Ethical Drivers Behind the Design of Quieter Offshore Facilities in Australia
Authors: Chandran Andrew
Published: September 2012

This paper outlines the legislative, commercial and ethical drivers behind the design of quieter offshore production platforms in Australia and explains why decisions should be made during the Front-end Engineering and Design (FEED) phase of a facility to ensure that operational noise risks are as low as reasonably practicable (ALARP).

It explains how the requirements of current noise management legislation can be met during the design of new Major Capital Projects (MCPs) in Australia and how strategic implementation of engineering noise controls during FEED can increase shareholder value. This will ensure that future reliance on personal hearing protectors to mitigate occupational hearing loss is minimised over a facility's operational life and can turn MCPs into valued legacy operations for years to come.

It provides: An overview of the current occupational health and safety (OH&S) legislation in Australia that applies to new offshore facilities, including noise mitigation requirements;A cost comparison of implementing production-critical engineering noise controls during early FEED as opposed to late FEED and then after retrofitting them to an operational facility;A recent case study of best practice noise control during offshore facility design in Australia;A discussion of cost-benefit models used in Australia and Singapore and potential enhancements to both models that can satisfy both legislative and economic goals of facility designers and operators; andA brief discussion of design ethics and responsible facility design.
Lessons Learned Applying Human Factors Engineering in Capital Projects
Authors: Seet Alfred , McLeod Ron
Published: September 2012

This paper describes the model of Human Factors Engineering (HFE) as it is applied in capital projects in Shell. Best practices from Shell projects in writing and implementing a HFE strategy are discussed together with examples where relevant. Finally, the paper presents some challenges and key success factors for implementing an HFE strategy.
Challenges When Ambient Air Standards are Set Near Background Levels
Authors: Rabideau Christopher , Satin Kenneth
Published: September 2012

Despite improvements in air quality and uncertain science about health effects at near-background levels of pollutant exposure, regulatory agencies continue to push for lower ambient air standards based on modeled adverse health effects that are believed to result from pollutant exposures. Consequently, nearly pristine rural areas have the potential of being labeled as "non-attainment" and attaining, if possible at all, may require control of any local anthropogenic pollutant source. This paper will focus on one of the most ubiquitous air quality pollutants that affects the United States: enhanced concentrations of ground-level ozone. We will review ozone formation in the presence of sunlight and other ambient pollutants, health effects associated with ozone, changes in the national ambient air standard, trends in ozone air quality, contributions to ground-level ozone concentrations from a variety of natural and manmade sources including long-range transport, stratospheric-tropospheric exchange, lightning and wildfires, and estimation of "policy-relevant background" levels. We will show there is little basis for setting a standard near background exposure concentrations and doing so may render the standard unattainable.
Win-for-All: Strategic Approach in HSE Management for E&P in Malaysia
Authors: Yusoff Nor Hashim , Hamzah Rosnan , Taib Norazah M
Published: September 2012

Since the first oil exploration in 1910, Malaysia has advanced to join the global oil and gas players in redefining the industry's landscape by making discoveries in newer frontier and challenging fields such as ultra deepwater, High Pressure High Temperature (HPHT) and high CO2. As the entrusted entity and the custodian to manage the hydrocarbon resources under the Malaysia Petroleum Development Act 1974, PETRONAS has discovered over 400 fields, developed and operated by joint-venture agreements with 16 international oil and gas companies.

Compliance with the prescriptive Malaysian regulations for E&P activities is not the only condition to ensure effective Health, Safety and Environment (HSE) management and implementation. This paper discusses the philosophy and strategic approach that PETRONAS, through its Petroleum Management Unit (PMU), has taken to formulate the "win-for-all" concept and harmonized standards in steering the E&P operators’ HSE management. As PETRONAS leads the oil and gas industry in Malaysia, it is PMU's obligation to bridge the Government's expectation and E&P operators’ conformance, whilst taking into account the latest technology available derived from international standards and industrial best practices.

With the evolving relevant Malaysian laws and regulations, increasing public awareness in HSE, and managing new E&P players and subcontractors; PETRONAS has effectuated the self-regulatory principle by influencing the E&P operators to adopt their own global HSE standards for continuous improvement. Through this concept, PETRONAS has developed several HSE standards to be met by E&P operators at minimum, in which the challenges and anticipated achievement will be discussed further in this paper.

The key success factor for PETRONAS in managing HSE in E&P is the ability to manage the portfolio for assets in Malaysia and balancing those between minimizing HSE risks and maximizing the profit returns, as the highest contributor to the nation economic growth.
Setting a New Benchmark in Managing Biofouling on Vessels in a Sensitive Marine Environment
Authors: Wells Fred , Booth Greg
Published: September 2012

The water surrounding Barrow Island (BWI), Western Australia is an internationally significant marine protected area for coral and turtle conservation. A key commitment of the Gorgon Project is that no marine pests be introduced to island waters. A comprehensive quarantine strategy has been developed to prevent the introduction of marine pests, monitor for any that have penetrated the quarantine barriers, and respond to any introductions of such pests.

All vessels mobilising to Barrow Island must be free of secondary biofouling (barnacles, bryozoans, hydroids and worms) at the time of mobilisation. In meeting this criterion, all vessels undergo an initial risk assessment to determine the risk of being infected with marine pests and measures are taken to remediate or mitigate such risks. A preference exists to drydock vessels. In-water inspections and cleaning are also undertaken for vessels that remained in high risk areas following drydocking.

The key question "How long can vessels remain in-water and still be considered to be free of secondary biofouling?" is ecologically and economically significant. To address this, the results of 32 vessel inspections were analysed, including vessels commencing, ongoing and departing from Gorgon service. A range of vessels were considered: offshore support vessels, landing craft tankers, dredges, barges, utility vessels and crew transport vessels. The results have significant implications for all vessel owners that work in sensitive marine areas. It is also an important indication that the current risk assessment methods underestimate the risks vessels present to marine ecosystems, more so when vessels operate in marine protected areas.

To date, quarantine measures to prevent the introduction of marine pests to Barrow Island from overseas have been effective.
Safety Case Analysis as a Tool for Assessing Safety System Effectiveness
Authors: Turnbull R. , Watkiss R. , Taylor M.
Published: September 2012

The IADC safety case template for land rigs is well known within the industry. Many safety cases will be a "living document" used as an integral element of a project or well operations. However, a risk exists that the safety case may be used as a one-off demonstration of HSE management and then put aside.

This paper describes the development of a "living" safety case as an approach to assessing the completeness and effectiveness of equipment and systems at a company rather than rig level.

The development process involved, first, describing all company land rig operations over the preceding three years. Thereafter hazard and effect registers were compiled, bow-ties generated and matrices of permitted operations constructed. Company equipment and systems of work were then compared with measures identified by the safety case analyses.

The comparison process delivered a three-fold benefit. Firstly, it provided a gap analysis tool to identify where controls were assumed rather than present. Secondly, it provided a more detailed specification for the development or revision of safe systems of work. Finally, it provided an assurance framework by which equipment and systems can be assessed on an ongoing basis.

The major findings from the exercise identified a greater range of operations than generally perceived within the company. Gaps in standards, procedures and other controls to cover this operational range were identified. The content, clarity and consistency of documents between rigs were highlighted as areas for improvement as was the specification and selection of equipment.

The exercise also generated a "generic" safety case document that can be stripped down to an individual rig level for operational use. This offers a wide range of advantages by helping to define required actions for inclusion in general rig management documentation, standard job descriptions and vocational training materials.
Implementation of the Oil Spill Preparedness for the Goliat Offshore Oil Field Development – The First Oil Field Development in the Barents Sea
Authors: Bjørnbom Erik , Hansen Ole , Engen Frode , Knudsen Sjur W.
Published: September 2012

The Goliat field operated by Eni Norge AS (Eni Norge), with Statoil Petroleum AS (Statoil) as only partner, will be the first offshore oil field in the Barents Sea and the world's northernmost offshore oil field. The production will commence during the last quarter of 2013. The field is located in the south western part of the Barents Sea, relatively close to the coastline in an area perceived to be environmentally sensitive. The area has high political focus, especially on oil spill preparedness, and strict environmental requirements.

The implementation of the Goliat oil spill preparedness will introduce new technologies and methods, which are the results of R&D projects and initiatives developed in cooperation with Statoil and the Norwegian Clean Seas Association for Operating Companies (NOFO). This will give an increased oil spill response capability, especially for the coastal zone, both for the Goliat field and for other oil and gas activities on the Norwegian Continental Shelf (NCS). It is also expected that this implementation will have a positive impact on oil spill preparedness in general and for access to new acreage on the NCS.

This paper will address how the oil spill preparedness for Goliat will bring the coastal oil spill preparedness on the NCS up to a new level. Goliat will be the first field in Norway to implement permanent use of fishing vessels, a special acute phase task force, and an integrated field oil spill detection and surveillance system. The oil spill preparedness focuses on locally adapted solutions for quick and effective response.

This paper will in addition, illustrate how the oil spill response planning and development has been conducted over several years and how the oil spill preparedness is being implemented for both the production drilling and production phase at Goliat.

The paper is closely linked to the SPE paper 156795-PP "Coastal Oil Spill Preparedness Improvement Programme (COSPIP) and Memorandum of Understanding – Comprehensive Joint&Industrial project focusing on coastal oil spill challenges" (1). It is also related to the SPE paper 98593 "High resolution oil spill response planning for operations in a sensitive Arctic environment. Sharing information between operators, national authorities, local oil spill response groups, and the general public" from 2006 (2) and SPE paper 126598 "IA for the Goliat Offshore Oil Field Development. World's northernmost offshore oil development?" from 2010 (3).
Changes in Dissolved Hydrocarbon Content of Shallow Waters During and Shortly After the Deepwater Horizon Incident
Authors: Ross Andrew S , Stalvies Charlotte , Qi Xiubin , Crooke Emma , Fuentes David , Armand Stephane , Revill Andy T , Talukder Asrar
Published: September 2012

The Deepwater Horizon incident began on April 20th 2010 and oil was released into the Gulf of Mexico until July 15th 2010. Over the 1,500 m ascent to the surface, mixing between the rising hydrocarbons and seawater, as well as mixing between the surface slick and seawater resulted in dissolution of components susceptible to partitioning into the aqueous phase. Such compounds include benzene, toluene, ethylbenzene, xylenes, naphthalenes and polyaromatic hydrocarbons. This paper focuses on the dissolved hydrocarbon compounds and oil droplets detected and measured in the surface waters of the Gulf of Mexico during and shortly after the release.

Between the 5th of June and 14th of September 2010 the abundance and distribution of these compounds using a prototype hydrocarbon sensor array tuned to detect the presence of dissolved petroleum hydrocarbons in waters 1–2 meters below the sea surface. The aim of the survey was to perform continuous monitoring of the surface coastal waters in transects parallel to the coastlines of Mississippi, Alabama and Northwestern Florida to determine and map hydrocarbon levels associated with the Block MC252 oil spill

The prototype hydrocarbon sensor array used to understand the dissolved hydrocarbon content in shallow waters of the Gulf of Mexico is shown in Figure 1. The system comprised an underwater pump which was towed between 1–2m below the surface. Water was pumped through a food grade tube into a stainless steel tank located on the vessel's deck. Into this tank, four commercially available hydrocarbon sensors were mounted, past which the water continuously flowed. The Chelsea Aquatracker (S1), Contros (S2) and Trios (S3) fluorometer sensors have excitation and emission wavelengths specifically chosen to detect polyaromatic hydrocarbons (PAH’s, Table 1). The fourth sensor (S4) is a metal oxide (MOS) sensor which has a partitioning membrane in front it to allow volatile hydrocarbons, but not water, to pass into the measurement chamber. These sensors were chosen for their range in detection (Table 1) and to provide redundancy in measurement, and were operated continuously while the survey vessel was underway. The sensor signals were logged every 2 seconds via a logging station, with a GPS location appended to each record. During normal operation, the water pumped through the tank passed directly back into the ocean via an outlet hose. However, periodically or when there are changes in the sensor readings a valve is opened at the rear of the tank allowing the collection of a water sample. These 1 litre samples were then subjected to liquid-liquid extraction using dichloromethane and the extract obtained was analysed using gas chromatography mass spectroscopy (GCMS) instrumentation on board.
Simulation Of Concentrations and Depositions of Particle Matter Caused by Drilling Discharges. Comparison Between Field Measurements and Simulation Results at Coral Locations
Authors: Rye Henrik , Ditlevsen May Kristin , Moe Jannecke A. , Løkken Morten
Published: September 2012

Deepwater corals (Lophelia) was identified in the vicinity of the location of the exploration well Pumbaa on the Norwegian Continental Shelf where a drilling operation was carried out by the GDF SUEZ E&P Norge AS (GDF SUEZ). When drilling in sensitive areas, it is a requirement from the Norwegian authorities that the operator shall monitor the drilling operation. Possible impacts on the corals were simulated prior to the drilling operation. In addition, monitoring of the discharges during drilling was carried out in order to document effects on the corals. The paper considers a comparison between measured and simulated discharges of drill cuttings and mud to the sea on the Pumbaa field in the Norwegian Sea.

The actual monitoring program is presented in a separate paper on this conference (Moskeland et al. 2012). The main objective of the monitoring was to assess effects from the drilling activities on the corals south (and nearest) of the drilling location. The monitoring program included measurements of current, turbidity and sedimentation, as well as sampling of sediments from the seafloor. The data collected in the monitoring program turned out to be useful as well to validate numerical models for simulations of the discharges. In the present case, corals are located close to the drilling site, and the simulation tool could then be validated for prediction of potential exposure of the corals.

The actual comparison between model simulations and measurements is carried out by comparing the actual depositions of barite on the sea floor. In addition, turbidity recordings close to the sea floor are compared with simulated concentrations of particle matter at the locations of the turbidity recordings.

Good correspondence is obtained between model results and measurements on the occurrence of events of particle matter present in the water column at selected locations. A good similarity is found between measured/simulated depositions of barite at the sea floor, and measured/simulated concentrations of particle matter in the water column.

Use of the model validated will strengthen the operator's ability to predict exposure (and consequently potential damage) on corals (and other biological resources) prior to the drilling operation. The operator may then obtain an "early warning" on exposure (potential damage). Measures can then be initiated to eliminate or reduce environmental impact.
Innovative Approach on Water Management
Authors: Boccitto Luigi , Buttini Patrizia , Cova Carlo Alberto , Sandri Simonetta , Nardella Alessandro , Palermo Franco , Mollica Sara , Deffis Juan Manuel , Mariani Maurizio
Published: September 2012

eni's approach to effectively manage freshwater in the oil and gas industry and to develop sustainable strategies on water issues is presented. The approach combines the use of different tools in order to identify, evaluate and manage water related risks in the operational sites taking into consideration social, ethical, environmental and industrial issues.

The first level of assessment is performed using the IPIECA Global Water Tool for Oil&Gas to map supply of freshwater, according to international databases, and to identify areas of water stress, or at risk for health conditions or lacking the infrastructure for water treatment and distribution. The percentage of sites in water stressed areas is 13% according to the screening carried out in 2011.

22% of the sites is at water stress for improved sanitation; sites without improved water are 14%.

At the high risk sites, eni has started local assessments using a questionnaire developed by GEMI, to assess the facility's specific water uses/needs in comparison to the availability of water in the region in a more local context; to evaluate the impacts of the operations on the available water resources and to identify the factors that may pose a risk on the local operations. Alternative local water risk assessment methodology including biodiversity and ecosystem impact and water quality discharges are also used for comparison.

Projects for the optimization of water resources and quantitative targets are set on the basis of the assessment in order to drive forward policy and strategy implementation, both at the corporate and site level.

Eni applied this new approach in Algeria and other water stressed countries. Algerian case study is presented.
Coastal Oil Spill Preparedness Improvement Programme (COSPIP) and Memorandum of Understanding – Comprehensive Joint&Industrial Project Focusing on Coastal Oil Spill Challenges
Authors: Buffagni M. , Bjørnbom E. , Hansen O. , Foldnes G. E. , Thorbjørnsen S. , Aiello G. , Engen F.
Published: September 2012

In the first "Integrated Management Plan for the Barents Sea and the Sea Areas off the Lofoten Islands", issued by the Norwegian government in 2006, oil spill preparedness was one of the main significant issues to be addressed, with a relevant political focus for near shore petroleum activities and environmental vulnerable resources.

A need to improve the coastal oil spill response capability was therefore identified early in relation to the planning and development of the Goliat oil field, located in the south western part of the Barents Sea, and consequently a strategy was developed.

Eni Norge and eni e&p joined forces to substantially contribute to the development of this strategy through the COSPIP JIP and a Memorandum of Understanding issued with Statoil, the only license partner in Goliat.

More than 30 Research & Development projects were carried out in order to get new technologies and knowledge that could improve the coastal oil spill capability.

This paper describes the comprehensive approach adopted in the JIP. Focus has been on coastal clean-up and protection, strategy development, equipment and software improvement, spill detection and monitoring technologies, logistics and local operations as well as on the study of behaviour of oil spilled in proximity of the coast. The main obtained results, which will be applied in the Goliat Oil Spill Preparedness, are presented.

This paper also illustrates how the stakeholder management and the communication strategy were carried out successfully during the project, mainly through the participation at public meetings and the development of an oil spill preparedness website, with the aim to transfer the acquired knowledge by mean of articles and video presentation to local communities and general public.

The paper is closely related to the SPE paper 156773-PP "Implementation of the oil spill preparedness for the Goliat offshore oil field development – The first oil field development in the Barents Sea" (1).
Tool and Case Study on the Application and Benefits of Alternate Energy Supply Technologies
Authors: Rowbottom Ronald , Kuykendall Dina
Published: September 2012

The global issues related to greenhouse gas emissions, cost of electricity, and reliability of electrical supply are driving companies to evaluate options for alternative energy sources to power facilities. A robust screening tool was necessary to identify whether more environmentally sound and cost effective options were available to meet facility energy needs. This paper outlines the development, application and advantages of an alternate energy generation assessment tool for determining the feasibility of installing co generation and/or self generation to provide electrical power at company owned facilities. This tool, which is quick and easy to use, provides significant advantages over the traditional approach of engineering studies, which are often time consuming and expensive.

The tool evaluates various factors to compare utility provided power to other options including fuel cells, photovoltaic, and natural gas turbines. The power supply types are evaluated against a number of criteria including feasibility, energy quality, greenhouse gas emissions, cost, payback period and other factors.

To be a global assessment tool, the format needs to be adaptable to various conditions regarding supply and reliability in diverse power supply markets.

The application of the "alternate energy cogeneration tool" to various operation facilities in a global setting will be discussed. A case study will be outlined that concluded with the selection of a 300kW natural gas fuel cell at a facility. This resulted in annual savings of $477K in purchased electrical power and reduced greenhouse gas emissions by 1,578 metric tons of carbon dioxide equivalent (CO2e).

Calculations of greenhouse gas emissions (CO2e) will be detailed to show how to capture the environmental advantages of co-generation and self generation applications utilizing an internal carbon reporting system. These environmental benefits can be incorporated in overall sustainability reporting by the user, both internally and externally.