Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Abstract There are at present a number of industry (e.g. IPIECA/ OGP/API) and non-industry (e.g. CDP, GRI, ISO) initiatives to develop greenhouse gas (GHG) reporting standards for oil and gas exploration and production activities. However, the focus of these projects is on measurement and reporting of direct and indirect emissions from operating companies—little is being done to accommodate the specificities of oilfield service companies within these standards. Oilfield service company GHG emission profiles and emission intensities are significantly different from those of their operating company clients. Fuel use in road vehicles and in marine vessels and drilling units are likely to be the most significant forms of energy use, and therefore the most significant emissions sources. A large service company may have several thousands of road vehicles, or tens of marine vessels in operation, either owned or contracted. These emission sources are likely to be geographically dispersed and mobile, which when coupled with the number of emission sources can make data collection very challenging. Emissions from fixed facilities will, in comparison, probably be relatively insignificant. This paper examines what is being done at one oilfield services company. Looking further along the business supply chain, indirect emissions associated with service company activities generally fit into three categories: logistics and business travel; production of materials; and utility services (e.g. electricity supply). Indeed, a conservative analysis suggests that levels of the most significant indirect emissions exceed those of direct emissions for service companies. The absence of a systematic, global GHG reporting practice combined with the dispersed nature of the sources makes the collection of emissions data associated with these services and activities difficult. Additionally the inclusion of service companies with operators in certain indexes makes compromises comparability.
Global energy-industry-related carbon dioxide (CO2) emissions rose by 6% in 2021 to 36.3 billion tons, the highest-ever level, as the world economy rebounded strongly from the COVID-19 crisis, according to an International Energy Agency (IEA) report. Combined with the methane emissions estimates that the IEA published earlier this year and estimates of nitrous oxide and flaring-related CO2 emissions, the new analysis shows that overall greenhouse-gas (GHG) emissions from the energy industry also rose to their highest-ever level in 2021--40.8 In the Middle East, decarbonization initiatives are gathering pace as environmental regulations become stricter around the world and companies are vying to be at the forefront of emission-reduction initiatives. While CO2 emissions in the Middle East are less compared with those in other regions, these oil- and gas-producing countries are under pressure to enhance their climate-change measures further. A thorough understanding of a company's current GHG footprint is fundamental in identifying effective emissions-reduction opportunities and design a pathway to net zero by 2050.
- Europe > Middle East (0.46)
- Asia > Middle East (0.46)
- Africa > Middle East (0.46)
- Research Report > New Finding (0.35)
- Research Report > Experimental Study (0.35)
Abstract The global Oil & Gas industry has been an active contributor to the development of sectoral guidance for accounting and reporting of Greenhouse Gas (GHG) emissions and has participated with multiple stakeholders in the developments of international and national GHG standards and protocols. With the emergence of emissions trading systems and new GHG reporting and disclosure schemes, attention is now being focused on the inherent uncertainty of the data used for emission estimates. For the Oil & Gas Industry, the accuracy of calculating GHG emissions is determined by the uncertainties of the estimates of the key (largest) contributing sources. Those, in turn, depend on the quality and availability of sufficient data, or on the ability to measure emissions, or related activity parameters, and properly account for their variability. The Oil & Gas industry, through its global and regional associations, is pursuing these issues on many fronts, from global workshops, dialogue forums and other collaborative activities with peer associations and regulatory bodies. The goal of these activities is to gather information - and diverse perspectives - from all stakeholders. Issues that were discussed include cost-effective methods for quantifying uncertainty and data quality expectations (and level of significance sought) by regulators and by industry. This paper discusses a range of activities undertaken by the industry to investigate key sources of uncertainty and address issues of lowering data uncertainty, including some joint efforts with other trade associations and with the U.S. EPA. It also provides highlights from the International Workshop on 'Addressing Uncertainty' (held in Brussels, January 2007), which resulted in a list of key issues that were prioritized for future collaboration. Introduction The assessment of greenhouse gases GHG emissions and emission reductions are high on both political and scientific agendas in many countries. The global oil & natural gas (O&G) industry has been an active contributor to the development of sectoral guidance for accounting and reporting of GHG emissions, such as IPIECA (2003) Petroleum Industry Guidelines for Reporting GHG Emissions, and compiling emissions estimation methods, such as API (2004, 2005) Compendium of GHG Emissions Methodologies for the Oil and Gas Industry. This guidance has been recently augmented by API/IPIECA (2007) by its Guidelines to Account for Reductions Associated with Greenhouse Gas Projects. All these efforts were centered on common approaches that were adapted for use by the industry sector and are reflective of emission sources and emitted by O&G operations. Sector members have also participated with multiple stakeholders in the development of several international and national guidelines and reporting standards. For an O&G company's GHG emission inventory, as is also the case in national GHG inventories, the overall uncertainty is determined by the uncertainties of the estimates of its key (largest) contributing sources. In turn, each of these uncertainties depends on the quality and availability of sufficient data to estimate emissions, or on our ability to measure emissions and properly account for their variability. With the emergence of emissions trading systems, and new reporting and disclosure schemes, data robustness is getting increased attention as a prerequisite for accurate determinations of GHG emissions and emission reductions.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.50)
Abstract Exhaust emissions from a single cylinder heavy-duty diesel engine were measured to assess the effects of fuel properties on engine emissions. The AVL 8-mode steady-state simulation of the EPA transient test procedure was used in the engine tests. The results show that an increase in cetane number of the fuel reduced nitrogen oxide emissions (NOx), and possibly carbon monoxide emissions (CO). However, increasing the cetane number of the fuel caused an increase in particulate matter emissions (PM). The results also suggest that the fuel with lower total aromatic content produced slightly lower NOx and noticeably lower PM emissions. For fuels having comparable total aromatic contents, the one with a higher tri+-aromatic content produced slightly higher NOx emissions and noticeably higher PM emissions. However, the number of fuels in the fuel matrix and the fuel matrix design were not satisfactory to claim universality for the observed relationship between aromatics and engine exhaust emissions. Introduction It is generally agreed that exhaust emissions are affected by changes in fuel properties. However, the bulk of the emissions are dependent on the characteristics of the engine and its ability to utilize the fuel over the test cycle. Overall, the changes in emissions due to the independent changes in fuel properties appear small relative to the mean emission levels, although these changes are considered significant to achieve future emission standards. Most studies assume a priori causative relationships between primary fuel variables and certain emissions. These assumptions have not been clearly confirmed yet. The vast literature on the relationship between diesel fuel variables and exhaust emissions is full of contradicting results and claims. In this study, the main objective is to understand the influence of fuel properties on engine emissions. The fuel properties that are under consideration at this stage of the research program are the aromatic content and the cetane number. Ultimate questions that we aim to answer are:Is the oil sand derived diesel fuel different from the conventional crude oil derived diesel fuel as far as the exhaust emissions are concerned? Do polynuclear aromatics carry the same or more weight relative to mono- and di-aromatics in terms of their contribution to emissions? Experimental Test Engine The test engine used in this program was a single-cylinder Ricardo Proteus research engine. The engine was a direct injection type and had a displacement volume of 2 litres. Major engine configuration data are shown in Table 1. The performance and exhaust emission levels measured over the load and speed range were representative of current premium heavy-duty diesel engines. The speed and the load of the test engine were controlled independently by a dynamometer and a fuel control system. The fuel injection pump governing system was disabled to allow fixed fuelling levels. Static fuel injection timing can be adjusted 30 crank angle degrees either side of the top dead centre (TDC). To simulate a turbocharger, externally compressed air, controllable for temperature and pressure, was supplied to the engine.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Downstream (1.00)
Understanding the sources and quantities of - Outline detailed procedures for conversions greenhouse gas (GHG) emissions is critical to between different measurement unit systems developing an emissions inventory that accurately with particular emphasis on implementation of represents oil and natural gas industry oil and gas industry standards. In response to continued interest by -Provide descriptions of the multitude of its member companies about consistency in oil and gas industry operations--from E&P emissions estimation, the American Petroleum through refining to the marketing of products, Inst. The the associated emissions sources that should Compendium is a result of more than a yearlong be considered. In this work, all oil and gas industry segments - Outline scope and boundary issues and provide from E&P to transportation, refining, and distribution suggestions on how to handle them in constructing were considered. Particular emphasis has an overall inventory.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.51)