The International Association of Oil and Gas Producers (IOGP) is a global forum in which member companies identify and share best practices to achieve improvements in many areas including upstream process safety. The IOGP Safety Committee has undertaken a multi-year strategic project to focus on fatality prevention, known as Project Safira, which addresses transportation safety, personal safety and process safety. This paper presents data analysis work conducted on process safety and the associated learnings. In 2010, the IOGP started a pilot project to collect upstream process safety event (PSE) data in alignment with the upstream and downstream reporting criteria. Since 2014, an annual quality control and validation review of process safety event data, reported by IOGP member companies, has been undertaken by a group of process safety engineers and data reporting experts. This group has, over a period of years, developed a list of point of releases and refined a set of key words based on the threat lines in a generic PSE bow tie. With five years of PSE data reported by IOGP Member companies, this paper presents the findings from the data analysis process as well as insights and learnings. Submitted Tier 1 narrative descriptions have been analyzed annually, as well as collectively, to determine trends in points of release, category key words, causal factors and chronological patterns in fatal incidents. The results have shown differences in causes related to events with fatal or environmental outcomes. This provides the basis for a standardized industry approach in prevention strategies to eliminate process safety fatal incidents. Having the largest database of upstream process safety performance and fatality data enables analysis of upstream PSE trends and learning that is not possible in individual companies. IOGP is in a unique industry position to encourage international upstream industry collaboration and sharing of industry best practices to prevent process safety incidents, and their potential impact on life, the environment and assets loss.

Monitoring, understanding, and communicating the impact of offshore oil and gas exploration and production (E&P) activities on marine mammal (MM) biodiversity can be challenging. Here, we share methods, results, and experiences accumulated during seven years of monitoring MM and underwater sound in a mature E&P activity area in the North-East Atlantic. We collected data on the distribution and behaviour of MM, their prey and changes associated with impulsive (e.g., seismic) and continuous (e.g., platform) sound generated by E&P operations. A program was created as an incentive for offshore staff to report systematically incidental MM sightings. Underwater acoustic recorders were placed around producing facilities and across a 3D seismic survey area before, during and after acquisition. A 2 nd Generation Environmental Sample Processor (ESP) was deployed to collect and analyse environmental DNA (eDNA) from seawater to identify MM species and their potential prey. Monitoring data were shared with relevant stakeholders through publications in scientific journals, presentations at conferences and meetings, or through social media. Our data provided evidence of MM activity in the E&P activity area year-round. A total of eight species were sighted from platforms and vessels; harbour porpoise being the most common MM. Harbour porpoises were recorded as being within 800m of the platform three times more often than at stations further away. Near installations, acoustic data showed porpoises actively searched for prey whilst eDNA confirmed the presence of prey species - validating a strong reef-effect. Decrease in porpoise echolocation to 8-12 km from an active seismic vessel, is suggestive of a temporary displacement of animals in the corresponding area. There was no large scale or long-term displacement as harbour porpoises were detected again in the area few hours after airgun operations ended. The results indicate that despite elevated sound level in the E&P area, porpoise distribution appears to be linked to higher availability of prey around the artificial reef created by subsea O&G structures. The monitoring efforts generate valuable scientific knowledge, which form a sound basis to support management and regulation of E&P activities in Denmark. Additionally, several simultaneous tangible benefits resulted from the study such as staff awareness of biodiversity and increased stakeholder interactions. Results and methodologies may be used by HSE practitioners and O&G project managers to assess the potential impact of sound generated by O&G industry on marine mammals. Our success illustrates the value of long-term monitoring and should inspire and support HSE practitioners in their future environmental monitoring initiatives.

Detection and quantification of gas leakage by infrared technology This article aim to present the technology for detection and quantification of fugitive gas emissions in deep offshore activities of TOTAL E&P Angola (hereafter mentioned as "Company"). Company has been operating in Angola for more than 60 years, totally committed to the environmental sustainability through full compliance to the local regulation, Company standards, and best oilfield environmental practices. Fugitive emissions represent a general set of emission from industrial sources that cannot be connected through controlled means to a definitive emission point. These normally and relatively small and hard-to- detect emissions from valve packing, pump seal, compressor seals and piping connections occur as part of normal industrial operations. They are characterized by a diffused release of VOC (Volatile Organic Compounds: methane, ethane, methanol, etc) or other pollutants into the atmosphere. Methane’s global warming potential is higher than carbon dioxide. Methane emissions in Company’s operated scope stood at 2.3 Mt CO2-eq in 2015 and nearly half or 1.1 Mt CO2-eq were specifically related to gas production. In all, they account for less than 0.5% of Company’s marketed operated production; therefore improving methane measurement and mitigating these emissions are part of climate change strategy of the Company. Reducing oil and gas methane emissions is an essential, low-cost strategy for slowing the accelerated pace of today’s Global Warming. It is a major opportunity for climate progress that cannot be missed. This is why all efforts were centered to join the Climate and Clean air Coalition (CCAC) Oil & Gas Methane Partnership, important step to understand the scope of the company methane emissions. The CCAC Partnership provides companies with a credible mechanism to systematically address their methane emissions and demonstrate this systematic approach to stakeholders.

The aim of this paper is to present TOTAL E&P Angola (subsidiary of TOTAL in Angola, hereafter mentioned as "Affiliate") last environmental monitoring campaign. The document presents the strategy and summarizes the results of indicators which are used to follow up cumulative impacts on deep water environment. The campaign was performed between 1998 and 2015, and different laboratories were used. The impact of field operations proved to be rather low or negligible, and acceptable on the long term. Since February 1998, when the first environmental baseline study (EBS) was performed (in Block 17: Girassol) to describe the initial state of the environment, the Affiliate has been conducting regular offshore monitoring campaigns with the aim of characterizing the water column, and marine sediments around existing installations and developing fields. These surveys are not limited to Block 17, but also extend to other Affiliate offshore blocks in Angola. In March 2015, the Affiliate’s most demanding Global Environmental Baseline & Monitoring Survey (GEMS) was completed, which covered six different offshore blocks, with a work scope ranging between EBS and EMoS (environmental monitoring survey), comprising 226 sampling stations for sediment and benthic macrofauna, 26 for seawater, 17 for phytoplankton and 8 for foraminifera. Another specificity of this latest GEMS was the scientific vessel that was shared among Operators through a joint agreement, of course with some legal and operational constraints considering the socio-geographic context of the project. Technically, besides the Affiliate’s required guidelines and rules, the parameters to be tested also had to meet recent regulations from the Ministry of Petroleum. Physico-chemical and biological data obtained over the past 17 years have been used as indicators of environment quality, and its regular monitoring allows assessment of the sensitivity of the marine environment to petroleum activities.

The International Association of Oil and Gas Producers (IOGP) has collected environmental data from its member companies every year since 1999. The objective of this programme has been to allow member companies to compare their performance with other companies in the section, with the aim to lead to improvement and more efficient performance. It also contributes to the industry's wish to be more transparent about its operations ( IOGP, 2017 ). There is growing attention to methane emissions from the oil and gas industry supply chain. Natural gas operations contribute to global anthropogenic methane emissions and if not properly managed may undermine the widely recognized environmental benefit of gas utilization. Nevertherless, statistics for methane emissions, particularly from O&G sector, are widely variable. This is not only a risk for climate change mitigation, but also financial and regulatory risk for both investors and operators.

Oil spill risk assessments are carried out in different ways, depending on the background for and the purpose of the analysis. One reason for these differences is the fact that oil spill risk assessment is a discipline at the interface between the technical/statistical analysis in Quantitative Risk Assessments (QRAs) and the biological/socio-economic analysis in Environmental Impact Assessments (EIAs). As a consequence of the EU Offshore Safety Directive (2013/30/EU), the risk of major environmental accidents shall now be included in QRAs for offshore oil & gas installations. Environmental Critical Elements (ECEs) shall be defined, in parallel to the Safety Critical Elements (SCE), which are analysed in QRAs. Moreover, limit values need to be defined for oil spill risk. Whereas including oil spill risk in QRAs has only been carried out systematically the latest few years, it has for many years been included in EIAs. But the extend of such analysis has varied significantly, also for the same type of projects in the same environmental settings. This paper reviews the background for the oil spill risk analysis in QRAs and EIAs, and outlines how the approaches used differs, where the QRAs analyse the likelihood component most detailed, and the EIAs analyse the consequence component most detailed. The reason for these differences is mainly historical. QRAs have traditionally been carried out focused on safety risk for people, calculating the likelihood of accidental scenarios and the consequences in terms of number of fatalities. Also, QRAs have been carried out with the aim of identifying which elements of the system should be improved in order to reduce the likelihood of accidental events, and to identify mitigation measures that can be applied when the likelihood has been reduced as much as reasonably practicable. In contrast, EIAs has mainly focused on the consequences of oil spills which are taking place; oil dispersion is modelled, and the biota, fishery and beaches possibly being impacted are being identified and assessed. The analysis has to a large degree been qualitative in contrast to the quantitative analysis in the QRAs; partly because the consequences of oil spills are so diverse, but probably also because EIAs typically are authored by biologist mainly focusing on qualitative analysis of the impacts on the marine life, whereas QRAs are mainly authored by engineers focused on the quantitative aspects. By highlighting the background for and the difference between oil spill risk analysis carried out in QRAs and EIAs, respectively, it is the ambition to provide a more enlightened basis for selecting methods and level of detail in oil spill risk analysis for various types of projects, and to establish a closer connection between oil spill risk analysis carried out for QRAs and oil spill risk analysis carried out for EIAs.

Executive Summary As the oil industry have developed a wide range of additional response tools to intervene in a subsea well incident, OSRL has taken the responsibility of mobilising, subsea intervention, dispersant injection, capping and containment equipment in addition to its traditional surface resources such as containment and recovery equipment and aerial dispersant systems. OSRL has developed detailed logistics execution documents to aid in this process, however recognised early that the mobilisation of these additional pieces of equipment would require a new way of coordinating and managing OSRLs personnel and activities, and that the number of personnel involved in managing the initial mobilisation phase would be significantly greater than previously experienced, and that the mobilisation activities would be managed over a wide range of geographical locations. Recognising these challenges, during 2014 OSRL approached this by detailing the tasks and responsibilities, assessing the level of personnel requirement in detail, deriving an IMS based organisation structure, detailing roles and responsibilities in a Major Mobilisation Plan. To verify the Major Mobilisation Plan, OSRL conducted an internal Major Mobilisation Exercise in May 2015 with a realistic scenario of an offshore subsea incident in West Africa. The exercise was conducted over a 2 day period, across all of OSRLs bases and involving personnel from all parts of the organisation. Some of the key challenges in a Major Mobilisation are the prioritisation and deconfliction of the international logistics (air transport) and the legal and financial issues of liabilities and indemnification and ensuring that OSRL is able to manage cash flow in the early stages and receive payment from customers quickly in order to keep paying contractors and suppliers. This paper will detail the process OSRL went through, the challenges faced and the lessons learned in the exercise as well as the follow up steps and outcomes of future exercises to continually improve the Major Mobilisation Plan and to demonstrate to both itself and its members that it has the capability and competence to deliver it.

In the oil & gas industry there is a trend towards more subsea activities such as the processing of the Oil and Gas in so-called ‘subsea factories’. Regulations aimed at managing the impact of underwater sound on marine life are being put in place by different nations. Many offshore operations require an assessment of the potential impact of underwater noise on the environment, which requires knowledge of the sound transmitted by the subsea components. However, until now little is known about the underwater source mechanisms, the acoustic strength of these complex installations, the coupling of the emitted source sound to the surrounding medium and the impact of the sound on the underwater wildlife. With the measured noise spectrum (in air) of a complete turbo compressor installation and correcting for the differences between radiation into air and sea water, a stylized, equivalent noise source power spectrum is constructed. Steps towards validation of the radiation correction are in progress. The contribution of the source to the subsea soundscape is computed by coupling the source model to an acoustical propagation model. Predicted levels can be used as an input for environmental impact studies. In water source and radiated sound levels are presented in this paper. The accuracy of the in air to underwater conversion methodology is discussed and knowledge gaps are identified. The high speed turbo compressor dominates the broadband sound pressure levels generated by the total subsea processing factory. Subsea processing sound exceeds the sound from a ship, especially is shallow water and for calm sea states due to the high frequency content of the subsea processing sources. The sound field of the compressor contains almost all of its energetic content above 1000 Hz, while for example ship generated sound is typically below 500 Hz.

The petroleum industry in Australia has an important role to play in minimising the spread of marine pests by contributing to the effective management of biofouling on contracted vessels, rigs and immersible equipment. The introduction of Invasive Marine Species into sensitive coastal waters has the potential to cause significant social, economic and environmental impacts. Woodside Energy Ltd (Woodside) has developed and implemented a systematic risk-based approach to the management of marine biofouling within Australian waters. Most recently, the risk management process has been reviewed and expanded for application to Woodside's expanding international portfolio. The risk assessment methodology assesses the likelihood that a vessel, rig or immersible equipment has been infected by invasive marine species of concern by evaluating its prior operational and maintenance history. A semi-quantitative scoring system is used to determine whether further management measures such as inspections, cleaning or treatment of internal seawater systems are required. The approach simplifies the management of invasive marine species into a standardised toolkit including a management plan, risk assessment tool, inspection procedures and a contractor information pack. The fit-for-purpose process is embedded in Woodside's systems, procedures and contractual requirements and is consistently applied to all marine operational activities. Since implementation of the process in 2009, 230 risk assessments have been carried out on a range of vessels, rigs and other immersible equipment using Woodside's methodology. Verification of the effectiveness of the tool has also been undertaken by proactively inspecting all 20 vessels used for the offshore Western Australian North Rankin Complex Redevelopment Project, in parallel to using the risk assessment tool. The data from this project verified the methodology is delivering excellent marine biosecurity and environmental outcomes, whilst targeting effort and resources to areas of greatest concern. The approach is applicable and transferable to activities beyond the oil and gas industry. Woodside has openly shared its simple methodology and tools with other petroleum companies, regulators and educational institutions. New challenges arise internationally due to the lack of baseline data and knowledge of local species in some areas. Woodside's approach allows for increased flexibility while maintaining the same level of management control and prevention of marine pest introduction. The effectiveness of Woodside's approach has been formally recognised by receiving the inaugural Western Australian Department of Fisheries Excellence in Marine Biosecurity Award in 2014 and the Australian Petroleum Production and Exploration Association (APPEA) 2015 Health, Safety and Environment Award. This paper will outline the key drivers for managing marine biofouling and detail Woodside's risk-based approach to preventing the introduction of invasive marine species both in Australia and internationally. The data gathered to verify the effectiveness of the approach, case studies and learnings will also be detailed.

Risk of position loss is intrinsic to all DP vessels. A position loss may happen on DP1 vessels, as well as on DP2 and DP3 vessels. The consequence is vessel and operation specific, and can be catastrophic to personnel, environment and asset. Quantification of the risk originated from DP vessel position loss is viewed necessary for the offshore oil and gas industry and is a good way to focus the attention in DP risk management. The paper presents a five-step methodology to perform quantified risk analysis of DP operations. That is, 1) Assess frequency of position loss, 2) Establish vessel speed and distance profile involved in position loss, 3) Estimate probability of successful intervention in case of position loss, 4) Calculate frequency of accident and estimate accident consequences, and 5) Conclude the risk picture and investigate risk reduction measures. Key principles are described with case studies to illustrate the methodology. One of the main challenges for a quantified risk analysis of DP operations is related to the frequency of positon loss. The DP incident reporting scheme in the industry at present however does not provide position loss frequency. The authors recommend an alternative DP incident data reporting scheme which combines both incidents and corresponding DP operational time. By having transparency on reporting and deriving less uncertain position loss frequency figures, such reporting scheme will contribute to the DP safety management and in the long run bring benefits to all stakeholders involved in offshore DP marine operations.

Understanding the utilisation of seafloor heterogeneity by different fish species is an essential prerequisite for the implementation of effective spatial management of marine ecosystems. The North Sea has long been a vital ground for the exploitation of natural resources, supporting one of the world’s most active fisheries as well as oil and gas exploration which has resulted in the construction of over 500 offshore platforms across the region. These facilities represent the major man-made structures installed on the seabed, adding substantial components of seafloor heterogeneity to the normally flat, featureless or soft sedimentary surroundings. While there is a growing body of evidence demonstrating that a variety of fishes aggregate around these subsea features, it still remains unclear whether the fish individuals merely concentrate around the structures from surrounding areas or whether such effects can have beneficial effects for fisheries by facilitating net increase in fish stock sizes. The research presented here investigates the relationship between fish and the physical presence of artificial structures in order to elucidate the potential role of offshore oil and gas platforms in the ecology of fish populations in the North Sea. To capture representative fish specimens closely associated with offshore platforms, seasonal fish sampling has been carried out since September 2010 at the BP Miller platform, a large steel jacketed facility in the Central North Sea. Although fishing from an operational platform is normally banned in the North Sea due to safety concerns, the Miller platform provides a unique opportunity for researcher to examine the possible effects of obsolete platforms on fish populations because it ceased production in 2007 and has since been used as a search and rescue helicopter base with minimum manning. Results show that commercially important fish such as cod ( Gadus morhua ), haddock ( Melanogrammus aeglefinus ) and saithe ( Pollachius virens ) were the most characteristic species observed around Miller platform. However, there were marked changes in species composition and their relative abundances between seasons as well as years, suggesting highly dynamic nature of interactions between fish movements and the physical presence of the platform. Based on these results together with a range of studies from the relevant literature, implications for the ecological impacts of decommissioning on North Sea fish populations will be discussed.

Artificial illumination on offshore oil and gas installations has a variety of effects on migratory and non-migratory birds, especially at night during foggy or overcast conditions. Birds attracted to platform lighting during the autumnal migration can result in encirclement causing elevated avian mortality rates from bird strike, incineration in the flare (when the flare is in operation) and exhaustion. The problem has been documented for many years from areas as diverse as the North Sea, the Gulf of Mexico and Western Australia ( Wiese et al., 2001 ). The impact of artificial light sources at night on migratory birds is a phenomenon not just linked to oil and gas platforms but also to other illuminated offshore and coastal structures such as wind farms, ships, harbors and lighthouses, all of which contribute to light pollution at night. Following several years of detailed observations, the Dutch E&P company NAM ( Nederlandse Aardolie Maatschappij ), established that conventional lights on offshore installations were the critical factor in luring migratory birds to offshore installations and keeping them trapped flying in circles for prolonged periods of time, particularly during so-called ‘broad front’ migration in combination with fog or cloudy weather when all the platforms in the same region experience the encirclement phenomenon. The following research with the lamp manufactory Philips Lighting, established that the red part of the spectrum in the emitted light was responsible for this circling phenomenon and that removing the long wavelength components of the spectrum reduces the visual and orientation impact on birds ( Poot et al., 2008 ). On the basis of these studies, a light source (spectral modified lighting or green light) was developed that reduces this fatal bird attraction, creates safe working conditions and results in a highly positive public response. The only unresolved safety factor was conflicting opinions on helicopter approach and landing. Circumstantial evidence was found that window glazing with a UV-blue filter – as used in some helicopters - is the cause for this. This paper reviews the experience regarding the use of spectral modified lighting (and related approaches) and puts them in a new perspective. It elaborates on safety factors, especially those related to helicopter approach and landing and discusses the potential application of the technology for new projects. Drawing on recent experience in Europe and North America to apply spectral modified lighting, the paper address certification and permitting issues and briefly discuss emerging regulatory trends affecting this technology.

The Peregrino field, operated by Statoil ASA, is located 80km south of Cabo Frio, in the Campos Basin area, Brazil. The field is operated with two well head platforms drilling production and injection wells and a FPSO located between these. The seabed hosts a calcareous algae (CA) habitat, an area with relatively rich biodiversity. Conventional sediment monitoring has been found not to give sufficient information about potential impact of drill cuttings. A tailor suited, in-situ sensor based monitoring approach was developed for the field including testing and qualification of a number of sensor systems for visual observation, oceanographic parameters, light and turbidity, all placed on a seabed observatory frame. 4, 6-months sampling campaigns were carried out with this system. In addition, three sediment traps were placed at different locations, over totally 7, 4-months campaigns. Data were combined with discharge information and laboratory studies of drill cuttings effects to CA and associated species, to identify potential exposure and impact in the field. Discharge and environmental risk modeling were performed to identify which data gave significant and vital information for the purpose of environmental monitoring of the CA habitat. Combining discharge information with in-situ observations and modeling gives a strongly improved basis for identifying impact of drill cuttings discharges in a field like Peregrino. Technology for this has been developed to a readiness level available for multiple use. A new, cost beneficial monitoring program is proposed as an alternative to traditional sediment monitoring.

The Deep-ocean Environmental Long-term Observatory System (DELOS) was installed in Block 18 Angola in February 2009, and will celebrate its 5th anniversary in February 2014. The two DELOS platforms are located in 1,400m of water, one within 50 metres of subsea facilities, and the second 16km away from any sea floor infrastructure. Each platform comprises two parts: a sea floor docking station that was deployed on the sea floor at the start of the monitoring program and will remain for the 25 year project duration; and a number of observatory modules that are designed to perform specific environmental monitoring functions. Each observatory module has enough battery and storage capacity for 12 months of autonomous operation. Towards the end of the 12-month deployment period each platform requires ROV (Remotely Operated Vehicle) intervention to recover observatory modules to the surface for service, calibration, and data offload. DELOS has already provided the scientific community with a unique long-term dataset to study the natural environmental conditions in the deep waters of the Atlantic Ocean. The data collected so far has provided a valuable opportunity to examine the spatial and temporal variability of physico-chemical conditions and biological communities. Studies to date have shown, for example, a high degree of temporal variability in fish communities present at both of the sites. The reasons for the observed changes in fish abundance and community composition are not known but are possibly related to natural variation in water column oxygen levels. Based on the results already collected by the project, the scientific community has strongly advocated the further development of paired, deep-water observatories in other regions of the World’ oceans. This paper will chart the successes, and challenges, of the DELOS project to date, examine some of the data collected during the first 5 years, and discuss the need for continued, long-term observations of the deep ocean both offshore Angola and elsewhere.

Being a significant transporter in the Andean, Baker Hughes developed and uses an internal assurance process to ensure chemical mobilization supports the operations of the company, protects the environment (spills), and worker and public safety. Key features of the assurance process include: Specification and Condition of Vehicles Driver Qualifications Contractor Qualifications Journey Management Practices Load Securement Specification standards Use of the assurance process, internally and with qualified contractors, demonstrates positive impact to the business: 20% decrease in vehicular accidents during transportation of chemicals. 60 % increase in reporting of incidents, demonstrates a shift in local HSE culture, by sub-contractors and local transporting suppliers. Note: In the past such companies did not report spills or problems during transportation until arriving to well site. Today when an incident occurs they inform as the event occurs. 30 % improvement with transit control with the contractors, which includes journey tracking, attending emergency calls, monitoring contractor performance, and assurance of JMP (Journey Management Plan) adherence. 23% increase in contract companies involved in the process of chemical transportation, with training in HSE standards and practices, quarterly audits to the process and local workshops. The implementation of this assurance process (driver and vehicle qualifications, training, load securement, etc…) has proven to decrease incidents related to the transportation of chemical products by land.

The use of Autonomous Underwater Vehicles (AUV) is an emerging technology in many fields of marine activity (military, scientific, industrial), offering a significant potential in cost savings and extension of the operational capabilities related to the solutions currently adopted in offshore operations. Commercially available AUVs are mainly used by the oil & gas industry for the execution of seabed surveys and they are not routinely applied for carrying out the environmental monitoring and asset integrity around oil&gas offshore infrastructures. Eni e&p and its subsidiary Eni Norge, in cooperation with Tecnomare, have launched the CLEAN SEA project (Continuous Long-term Environmental and Asset iNtegrity monitoring at SEA) with the objective to use a commercially available AUV, properly upgraded with key enabling technologies, for the execution of environmental monitoring and asset integrity in offshore fields where eni operates. This paper will address how to reach this goal. A custom designed mission payload, arranged as modular and interchangeable pods, has been installed at the AUV. These modules, characterised by a set of sensors, are built to perform different offshore monitoring activities according to specific needs: automatic water samples collection; visual inspection (asset, seabed) and hydrocarbon leakage detection; automatic chemical analyses of trace pollutants and acoustic survey of seabed and pipelines / flowlines. This paper will in addition illustrate the possible future extension of the AUV operational capabilities through the integration and field demonstration of key technologies such as underwater docking, wireless underwater communication for mission data downloading and wireless power recharge for increased autonomy. This may enable a "permanent" operation subsea independently of support from surface. A comprehensive technical overview of the concept will be presented as well as the results of the demonstration tests.

In a world where perception is reality it is crucial for oil & gas companies to maintain transparent and constructive relationships with their stakeholders. To ensure business continuity companies must build strategies that are centered on respect, listening, dialogue and stakeholder involvement. This has come to be known as establishing a "social license to operate." With this in mind, and with the help of the Altermondo consultancy, Total developed the SRM+ tool in 2006. This is a methodology by which an entity (a project group, a subsidiary) compares its internal vision of the societal context in which it operates with the perception of its external stakeholders and builds action plans aimed at bridging the gaps between them. In 2011 the Ichthys LNG Project in Australia, a Joint Venture between INPEX (operator) and Total, applied the SRM+ tool. A total of 35 external stakeholder groups were interviewed, from the Northern Territory, Western Australia and the Australian Capital Territory. Although most stakeholders stated they were very satisfied with the quality of their relationship with INPEX and the Ichthys Project, several valuable suggestions were made on how to improve the dialogue and strengthen relationships. The SRM+ process provided valuable insights that are difficult to glean from routine interaction with stakeholders. It also gave confidence to the Project managers that they understand the issues, concerns and expectations of key stakeholders and that external risks are being appropriately managed. Following the SRM+ engagement, several Project managers made adjustments to their strategies. Possibly the most important outcome of SRM+ was that it has created the foundation for the Ichthys Project's long-term approach to stakeholder engagement. Going forward, INPEX plans to build on the SRM+ process by developing and deploying a stakeholder relationship management software package for the Ichthys Project that will enable the organization to identify, manage and respond to issues of importance to its stakeholders. Doing so will ensure that the Ichthys Project is able to maintain its social license to operate.

A specific hearing conservation program was developed by Total E & P Angola (TEPA) due to the particular conditions of the country: 1)During 30 years of war people were exposed to high levels of noise and all this time no medical assessment was done. 2) Angolans have the habit to play music very loud. 3) Working offshore exposes them to noisy equipments. Considering the above cited stressors, TEPA developed a robust program of Noise protection. An international recognized Company made a noise mapping study on the FPSO's where the noisiest places were distinguished from the less noisy. This information got regularly updated during frequent offshore assessments by the Industrial Hygiene team and also by on site personnel who received specific training to make direct measurements. In addition the workforce on board was distributed over similar exposure groups (SEG) and the workers of SEG's with elevated exposure to noise received an individual noise dosimeter, which they carried around during their shifts. The collected data was then downloaded in specific software. Based on the acquired noise maps, noise awareness campaigns were delivered to all personnel working on the respective offshore site, including subcontractors. The objective of such campaigns was to ensure workers are aware of the potential consequences of excessive noise exposure and train them to protect themselves and colleagues. An epidemiologic study taking into account Angolans specific habits was developed with the objective of measuring possible prevalence of hearing problems arising from earlier occupational exposure. A population of non-exposed people (office staff) was compared with offshore workers. The results did not show any significant difference in hearing capabilities. Out of these actions, others became mandatory: ensuring provision of hearing protection devices to all personnel where noise level exceeds 85db(A) and performing audits; performing regular monitoring and noise dosimeter studies, requesting annual audiometric testing for the exposed SEG’s, ensuring all personnel on board attend noise awareness campaigns and hearing protection training; installing complementary safety signs (where required) in all areas above 85db(A), as per maps and floor paintings; installing complementary safety signs for areas requiring double protection (earplugs and earmuffs) and performing a epidemiologic study involving people that might be exposed to noise in the past.

The US OCS frontier areas provide a challenging environment for regulating oil and gas as well as renewable energy safety. The Bureau of Safety and Environmental Enforcement (BSEE) relies heavily on the use of technology assessment and research to provide safe and environmentally sound decisions. The BSEE continually re-examines current technology and procedures that may be used in the OCS because of the evolving challenges that frontier areas bring. The BSEE collaborates with national and international federal agencies to provide consistency and to ensure that the best available and safest technology is used in the OCS. This paper will look at regulatory improvements made from research conducted post hurricane. It will also highlight post Macondo research that is being pursued by the BSEE for drilling, cementing, and human factors. The results of the research are used in the development of offshore regulations, standards, and inspection policies of more than 3400 OCS facilities and more than 33,000 miles of pipelines. For example, projects were completed which have determined appropriate structural assessment methods that did not exist previously. A new web based system is being used as a tool to ensure that recommendations formed from research findings are used expeditiously. This paper will highlight improvements being made at the new agency formed in the Department of the Interior in an effort to promote safety, protect the environment, and conserve resources offshore through vigorous regulatory oversight and enforcement.

Oil companies planning to locate FPSOs (or FSOs) in shallow water need to consider the performance of such operations relative to environmentally sensitive coastal habitats. This paper is based on a global study Battelle performed on FPSO safety performance and, in particular, with respect to risk management of nearshore operations. The study provides an environmental best practices benchmark. It examines the international safety performance of FPSOs operating in various geographies and environmental conditions. To this end, it reviews risk analyses published over the past ten years on the subject of major FPSO failure hazards, such as collision, offloading, equipment failure, and tanker spills. The study then examines eight cases of FPSOs operating in nearshore locations around the globe identifying proven risk mitigation and management practices and lessons learned that might benefit future FPSO projects. The study confirms there is a strong safety record available on more than 1,000 years of FPSO operation around the globe. Extensive research conducted by agencies and researchers in the United Kingdom, Norway, the United States and elsewhere on FPSO design, operation and performance offers a rich body of information on FPSO safety guidance. In addition, detailed review of the eight case studies confirms what the literature suggests: the FPSOs that have been operated to date have had an extraordinary safety record. Very few incidents, such as collisions and spills have occurred. No major incident or loss of cargo has occurred. None of the minor touches and collisions has resulted in the release of cargo. Virtually all recorded and reported releases have been small, and most of them were less than one barrel. As one oil company representative stated, an "all-accidents- are-avoidable" mindset combined with strong design and operating practices and systems are capable of avoiding or reducing theoretical failure risks to very low and acceptable levels. The results of this study suggest there is an arsenal of measures operators can consider in order to ensure high safety performance of any planned FPSO. Failure and spill risks summarized in this study may be extrapolated for planned systems and proven risk reduction and mitigation measures adopted.