bluuebunny/crossref_metadata_2025_split huggingface dataset:
Successfully Leveraging Gas Flaring Reduction through the CDM – Overcoming Methodological Barriers
Authors: Juez Jaime Martín , Mackinnon Jamie , Monzón Enrique Girón , Sánchez-Luengo Ángel Bueno 
Published: July 2010

Abstract
There are over 1,900 projects registered under the Clean Developing Mechanism of the Kyoto Protocol, with an annual average reduction of nearly 300 million tCO2eq. The last data published by Global Gas Flaring Reduction Partnership (GGFRP) show that over 150 billion cubic meters of natural gas are being flared and vented annually, accounting for over 400 million tCO2eq in annual emissions. However, today there are only 8 gas flaring reduction projects registered with annual expected reductions of just over 7.8 million tCO2eq. There are many possible reasons for this clear mismatch between the huge gas flaring reduction potential and its presence in the CDM, although we believe, and will try to demonstrate along the paper based on our experience, that the lack of a clear and universal methodology that embraces all the different possible projects under "gas flaring reduction" is a major hurdle.
In this paper we will analyse in detail the five current existing methodologies (AM0009, AM0037, AM0055, AM0074 and AM0077) that try to cover the gas flaring reduction field. We will go through the difficulties in their application and show the different CER generation result they produce. The analysis will be done through two concrete examples which cover significant examples of widespread project types that can be encountered in the O&G industry. Finally, the effect on the applicability of these methodologies of expected CDM progress towards sectoral approaches will be hinted.
A Human Factors Approach to Reduce Hydrocarbon Leakages on the Norwegian Continental Shelf
Authors: Bunn James , Berentsen Rune , Glittum Eli , Steinsvik Louise Kristiansen 
Published: July 2010

Abstract
Investigations following hydrocarbon leakages from Norwegian Continental Shelf (NCS) installations have focused almost exclusively on measures related to technical and mechanical causal factors, despite human and organizational failures being accepted as a significant underlying contributor to unwanted incidents.
The aim of this project was to examine recent large leakage incidents to look for common underlying causes relating to human and organizational factors and write appropriate recommendations based upon the findings. The project formed part of a larger Norwegian Oil Industry Association project to reduce hydrocarbon leakage incidents and subsequently improve HSE performance on the NCS.
Hydrocarbon leakage incidents from five offshore installations in the Statoil portfolio were assessed during a series of focus group workshops conducted with management and technical representatives from each installation, process specialists, and Human Factors specialists.
The incident reports and HTO (Human, Technology, Organization) annotated timeline diagrams were examined against at 14- point Human Factors keyword list adapted from the UK Health and Safety Executive's Major Hazards website.
Eighty one findings relating to the fourteen keywords plus twenty eight existing recommendations in the Synergi incident reporting and follow-up system were grouped into four themes for discussion at a follow-up plenary workshop; governing documentation for issuing permits to work, system understanding during abnormal situations, inspection & maintenance programs, and interaction between modification projects and the operational organization.
Based upon the discussion of these four themes, five recommendation topics were prepared; permits to work, land-based support during abnormal situations, understanding of technical systems and risk during abnormal situations, inspection and maintenance (tubing and fittings), and interaction between modification projects and the operational organization. Specific actions relating to each topic were then written for company duty holders for follow-up as part of a company integration process.
The keyword method revealed new findings, particularly relating to organizational deficiencies that had not been considered in the initial incident investigations. The methodology also gave operational management insight into how the Human Factors discipline contributes to incident investigation work.
Energy Efficient Designs; Facing New Challenges with Best Practices and Innovative Thinking
Authors: Godfrey Mike , Watlow Annette 
Published: July 2010

Abstract
The climate change agenda is to move from a trend of increasing green house gas (GHG) emissions to either holding emissions flat then reducing over the next few decades. By examining upstream projects early enough in the project lifecycle and using tools to assess energy usage over the field life of the project, reductions in GHG emissions can be achieved, which results in savings of operating costs and future carbon dioxide (CO2) trading costs.
Several techniques and tools have been developed which, when applied at the correct stage of the project, can help to optimise energy intensity and CO2 emissions. These include workshops, forecasting software for GHG emissions and flowsheeting tools to evaluate various design configurations taking into account cost, reliability and project variables such as weight and space. Results show that by applying these tools early in the design life energy intensity can be significantly reduced, which results in lower operating costs for fuel and potential CO2 costs.
Results and Lessons Learned from a 3-Year Intensive Coral Communities Monitoring During the Construction of a LNG Plant in Yemen
Authors: Chaîneau Claude-Henri , Hirst Robert , Al-Thary Ibrahim , Dutrieux Eric , Thorin Sébastien , Caragnano Annalisa , Benzoni Francesca , Pichon Michel 
Published: July 2010

Abstract
The Yemen LNG plant construction started in September 2005 in Balhaf in the Gulf of Aden and lasted over 4 years. The 1 km2 plant, within a 10 km2 fenced site, lies along 7 km of coastline. This paper describes the approach of Yemen LNG along with its main shareholder Total E&P, concerning the protection of the coral biodiversity during marine construction activities in a sensitive environment. This approach was developed according to three stages: establishing biodiversity, monitoring coral communities and protecting the reef ecosystem with mitigation and compensation means.
Knowledge of the coral biodiversity was an indispensable preliminary stage to evaluate the sensitivity of the site. The Environmental Baseline Studies have highlighted the richness of the marine ecosystem. The plant is bordered by a dense, diversified coral community forming a narrow reef extending from the shore to a depth of 15 metres. Almost 85 coral species occur in the reefs, colonizing about 85% of the substrate. The largest coral colonies are approximately 400 years old. Therefore, these corals are a valuable and delicate resource.
Monitoring composition and diversity of corals communities is considered an integral part of biodiversity conservation. The monitoring plan allowed to measure several parametres: some of which were related to the natural environment, others measured the effects of the works on water quality and finally, most observations included a direct measurement of coral community health.
Protecting the reef ecosystem by implementing mitigation and compensation measures is aimed at keeping reef biodiversity at its highest level by preventing and/or reducing the negative impacts on the ecosystem. Initially, part of the marine construction work encroached on existing coral outcrops. A planned, but not yet implemented, Marine Protected Area nearby also increased the pressure on the construction teams who had to fulfill the Social and Environmental Impact Assessment Study requirements as well as World Bank and IFC standards. It is recognized that some limited physical damage to corals occurred despite the implementation of these mitigation measures.
Lessons learned from the monitoring will be used to provide feedback to the industry in general. This offers a positive way forward when constructing installations in sensitive coastal marine environments.
Undertaking a $4Bn Dollar LNG Project in a High Risk Security Context and Achieving Exemplary Safety Performance
Authors: Hirst Robert , Syed Bilal , Zerriatte Reda 
Published: July 2010

Abstract
Yemen is ranked among the poorest countries in the world, according to World Bank indicators. Constant security threats, coupled with persistent tribal conflicts make it a high risk context within which to operate. In spite of these major hindrances, the consortium of seven International Companies who are shareholders in Yemen LNG, led by Total, took on the challenge to undertake the largest ever industrial investment project in Yemen – namely constructing an LNG terminal and pipeline to provide gas to the international markets from an area which is one of the remotest and poorest of Yemen.
The engineering resource, infrastructure and the human capital required to undertake this huge project have proven to be the biggest challenge. The mobilization required significant manpower (the peak being over 14,000 personnel); a large proportion of whom came from the local community. They had to be trained to come up from a "zero safety culture" in order to meet the required international standards and to be able to work together in spite of individual and tribal differences. The multinational team of up to 67 nationalities on the site gelled together to produce the end result and are proud of having achieved an undertaking, whose safety record is one of the best of any major project being undertaken by an OGP member company. This achievement in the face of the aforementioned challenges, not normally faced by businesses elsewhere, is a real credit to the team spirit and indomitable faith in project success.
This could not have been possible without the safe working environment culture which was inculcated in the largely uneducated workforce, serving the needs of the project. Through capacity building and interface at grass root levels between the tribes, the government and the local nomadic communities, the stakeholders were encouraged to share a common platform. At the start of each phase regular dialogue, needs assessments and a follow-up mechanism were implemented. Training and development initiatives were undertaken with the local communities. From changing mindsets to introducing better practices and creating a harmonious work environment, the challenge has been considerable. The bottom line is that awareness of the benefits of working together in a safe environment brings safety success.
How the OGP Land Transportation Safety Recommended Practices Led One Company to Significantly Reduce Fatalities in Just 18 Months
Authors: Allison David , Frasineanu Mihai 
Published: July 2010

Abstract
This paper demonstrates that the application of the elements of the International Association of Oil & Gas Producers, (OGP), Land Transportation Safety Recommended Practices was instrumental in reducing traffic related fatalities to zero over an 18 month period. The paper describes the gradual step by step development of a Company Land Transportation Standard; the key elements applied so far and shares the learning's of the Company in Romania.
Although full compliance to the Recommended Practices and the Company Standard is not completed, the result is a dramatic reduction in automobile related serious injuries and fatalities within the Company.
GHG Data Management, from Data Acquisition to Report Compilation
Authors: Aryaguna A. , Novendra O. S. 
Published: July 2010

Abstract
Global warming is one of the hottest issues in the last decades. The 2007 assessment report compiled by the Intergovernmental Panel on Climate Change (IPCC) observed that "Changes in atmospheric concentrations of greenhouse gases and aerosols, land cover and solar radiation alter the energy balance of the climate system", and concluded that "Increases in anthropogenic greenhouse gas concentrations is very likely to have caused most of the increases in global average temperatures since the mid-20th century".
Total E&P Indonésie (TEPI) as the largest gas producer in Indonesia has a very strong commitment to demonstrate their environment stewardship. One of the ways is by providing accurate reporting of GHG releases. Currently, many developing countries do not have any specific, GHG related regulations, taxes incentives or disincentives as applied in some developed countries. In this issue, TEPI demonstrated their leadership by monitoring GHG emission as a base for further action. In addition, the reporting system that TEPI utilizes has been audited by a reputable international audit firm.
This paper explores GHG data management, from data acquisition to report compilation in TEPI, as a part of environment reporting that covers the following areas: Referential / Corporate Management System. The internal rules and guidance document for the development of the TEPI GHG report.Data gathering on Production Site. Identification of related GHG Emission sources that will be described in data mapping.Roles and responsibility. Related entities that are responsible for each step of the processData Extraction and Compilation. The links between the available Production Site data, the user interface in the office, and the data compilation in automated GHG computer software.Verification and Validation. The inconsistency check that will be clarified and validated by the authorized entities.Report development. Compilation of validated data report to be provided to TEPI Management and subsequently, to Corporate Offices in France.
Through this process, TEPI will be able to review Environment Key Performances Indicator (KPI) such as; Flaring Volume, GHG volume, GHG Intensity, etc. After reviewing, TEPI could decide what will be the way forward for improving the Environment Performances.
Proactive Indicators of Risk in Remote Operations of Oil and Gas Fields
Authors: Johnsen S. O. , Okstad E. , Aas A. L. , Skramstad T. 
Published: July 2010

AbstractRemote operations, remote support and use of new technology introduce new ways of operating oil and gas fields. These new practices are often called "field of the future" or "integrated operations" - IO. These new practices are being implemented on the Norwegian Continental Shelf, leading to increased hydrocarbon recovery and increased collaboration between onshore and offshore sites. IO is raising new challenges related to HSE (Health, Safety and Environment), but IO should not increase the risks of major accidents or increase the risks of HSE.We are suggesting a set of proactive indicators to ensure that risks are controlled when IO is implemented and operated. A proactive indicator is used as a measure of risk related to a causal factor, to be controlled in risk management. The indicators have been developed based on analysis of accidents, discussion of theory and collaboration with the oil and gas industry. Our suggested approach is to collaborate with stakeholders and agree on indicators to increase the understanding and focus of the risks among the stakeholders.The most important causal factors of incidents seem to be poor design and poor validation of equipment, poor risk analysis of critical operations and deviations from established procedures. A causal factor that is suggested to be important in remote operations is miscommunication between actors during critical operations.Several proactive indicators are suggested, among them the level of exploration of scenario analysis/safety cases during design and risk assessments/scenario analysis prior to operations. Risk perception among stakeholders involved in operations is a suggested indicator too. Important indicators in remote operations are suggested to be the assessment of shared communication and shared risk perceptions when critical tasks are distributed among different organizations and different places.To validate the indicators, we are correlating the indicators with actual HSE levels, safety culture and risk perceptions. We suggest exploring how shared risk perceptions can impact safety and resilience, when task are distributed between onshore and offshore.
Global Practices and Regulations for Land application and Disposal of Drill Cuttings and Fluids
Authors: Clements Kayli , Veil John A. , Leuterman Arthur J. 
Published: July 2010

Abstract
The process of exploration and production (E&P) in the oilfield typically generates large volumes of drilling fluids and cuttings that must be properly managed. Cuttings reinjection, thermal desorption, stabilization, landfill disposal and other techniques have been used to mitigate potential hazards from drill cuttings and used drilling mud. These methods have been historically favored methods of treatment from a regulatory perspective. However, land treatment avoids hauling drilling mud and cuttings long distances to disposal sites, allows on-site mitigation and natural attenuation of potential hazards, and promotes waste minimization. When properly applied, land application is an excellent technique to protect surface and groundwater supplies.
Globally, common concerns about potential environmental damage from drill cuttings and fluids continue to drive research, technology and regulations with the goals of beneficial reuse and decreased footprints in oil and gas operations. Global trends for the introduction of new technology and the development of regulatory approaches are examined along with a critical review of the scientific research used to support these standards. Additionally, this paper contrasts and summarizes the current regulatory and management practices in active onshore oilfields.
Results and information collected from this research are compiled onto an interactive site which is accessible to those interested parties in the industry as a reference tool.
Industry sharing of knowledge and practices contributes to including environmentally protective standards and new technologies in the development of future regulations in all parts of the globe to protect our onshore resources. This information can aid key stakeholders to reach a higher level of understanding regarding the current state of onshore drilling waste management.
The Operation of the Multiphase Flow Meters on the Sour Environment of Qatif Field: Case Study
Authors: Al-Dossary Faisal M. , Al-Ghamdi Abdulrahman A. 
Published: July 2010

Abstract
Qatif field is the first intelligent field in Saudi Aramco equipped with measurement, communication, control and software enabling semi real-time and automated asset management and field rate optimization. Qatif is fully automated with remote controls, due to its complex reservoir characteristics and fluids with high H2S concentration up to 16% (160,000 ppm). Difficulties were experienced with one of the main intelligent components of the surveillance systems, the Multiphase Flow Meter (MPFM), due to the H2S variations, which can reach up to 5% within the same reservoir.
Qatif field was developed with three producing reservoirs with API ranges from 28° to 42° due to the different reservoir characteristics and compartmentalization. The production from the three reservoirs is commingled inside the Gas Oil Separation Plant (GOSP) to produce blended Arab light crude. Measuring mechanism of the multiphase flow meters (MPFMs) is dependent on the accurate PVT properties of the fluids. PVT Reports based on black oil models were Initially used, but did not match the fluid characteristics due to the H2S presence in the produced gas in addition to the sulfur substance in the produced fluids, which has resulted in inaccurate water liquid ratio (WLR) measurements that was showing as high as 60% water cut on dry wells. Each MPFM is serving multiple wells from the three producing reservoirs. Without allocating the right rate for each single producing well utilizing the MPFM, it was very difficult to produce the blended Arab light crude that Saudi Aramco was committed to produce. To enhance the matching of fluid PVT characteristics and due to the limited number of wells with PVT analysis, generic PVT reports from simulation models were generated, then cross-checked with the output readings of the oil, water and gas rates with a three-phase portable separator in series with the MPFM. Separator test results almost matched the rates from the MPFM loaded with known PVT reports from wells and within an acceptable accuracy compared to the readings from wells with generic PVT reports.
IA for the Goliat Offshore Oil Field Development. World's Northernmost Offshore Oil Development?
Authors: Bjørnbom Erik , Nesse Steinar , Hansen Ole , Foldnes Grethe 
Published: July 2010

Abstract
The Goliat field is the first offshore oil field in the Barents Sea planned for development and operation. The field is probably the worlds' northernmost offshore field being located at the 71.2 latitude (Figure 1). The oil field is located in an environmentally sensitive area with high political focus and strict environmental requirements. It will be the first field in Norway to meet the special environmental requirements for discharges to the sea for the Barents Sea, which is stricter than the general "zero harmful discharge" requirement for the Norwegian Continental Shelf (NCS). In addition, strict requirement for emissions to air will be met by transmitting electricity from shore to cover the power demand offshore. The paper will address how thorough and focused planning (the IA1 process) over several years has ensured that the zero discharge requirements and strict obligations on oil spill planning will be met. Further, the paper will address how the project successfully managed the stakeholder dialogue, involving key stakeholders already in an early planning phase and contributing to partly changing the negatively focused perceptions by fishermen, indigenous people and the society in general.
Environmental Performance in the E&P Industry: Data for 2007 and 2008
Authors: Findlay A. J. , Poore W. M. 
Published: July 2010

Abstract
Since 2001, the International Association of Oil and Gas Producers (OGP) has collected environmental performance information from its member companies on an annual basis. This programme has continued and new sets of data for activities in 2007 and 2008 have now been produced.
The performance information has been collected under the following five categories: Emissions to air.Aqueous discharges.Discharges of non-aqueous drilling fluids on cuttings.Accidental spillages of oil and chemicals.Energy consumption and flaring.
The ultimate aim is to provide a representative statement on the environmental performance in the upstream oil and gas industry. Subsidiary objectives are to provide a basis for individual member companies to compare their environmental performance and to demonstrate the industry's wish for greater transparency concerning its activities to help identify better and more efficient ways of operating.
Performance results are presented on a global and regional basis, onshore and offshore, and normalised to hydrocarbon production. Results are shown, for ease of comparison, alongside the previous years' published results. The paper will address the emerging trends in environmental performance as well as factors that underpin the data.
32 OGP member companies took part in the survey representing about a third of known world production. Contributing companies provided data from 62 countries worldwide; however geographical coverage of the reported data remains uneven, ranging from 98% in Europe, to 20% of known production in the Middle East and 8% in the Former Soviet Union.