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Collaborating Authors
Energy
Harmonizing the Quantification of Greenhouse Gas Emission Reductions Through Oil And Natural Gas Industry Project Guidelines
Kheshgi, Haroon (ExxonMobii Research and Engineering Company) | Hochhalter, Theresa (ExxonMobii Research and Engineering Company) | Shires, Theresa (URS Corporation,) | Lev-On, Miriam (The LEVaN Group) | Siveter, Robert (LLC, ) | Ritter, Karin (International Petroleum Industry Environmental Conservation Association, )
The oil and natural gas industry is addressing the challenges of meeting the world's growing energy demands in a responsible manner. Real and sustainable actions to reduce greenhouse gas (GHG) emissions are an important aspect of achieving this objective. To this end, the American Petroleum Institute (API) and the International Petroleum Industry Environmental Conservation Association (IPIECA) have collaborated on guidelines to promote the credible, consistent, and transparent quantification of GHG emission reductions from emission reduction projects of interest to the oil and natural gas industry. This paper will provide an overview of the Petroleum Industry Guidelines for Greenhouse Gas Emission Reduction Projects (referred to as the Project Guidelines), developed to provide oil and natural gas companies with a framework for evaluating, quantifying, documenting, and reporting GHG emission reductions achieved through discreet projects. The Project Guidelines address the selection of appropriate baseline candidates and boundaries for scenario assessment. It also addresses potential emission sources to be incorporated for the selected scenarios, along with compatible monitoring considerations. The guidelines focus on technical considerations and provide flexibility in adapting the approach in view of applicable public policy mandates. Case studies will be used to demonstrate the application of these emission reduction principles for two categories of significant GHG emission reduction projects: (a) cogeneration of electricity and steam, and (b) carbon dioxide capture and geological storage.
Abstract EITI, launched in June 2003, is recognized as very successful among various Initiatives (PWYP, EU, G8) for transparency in the resource-rich countries. After considering the negative consequences of huge flows of wealth from natural resources into developing countries - the โresource curseโ and โDutch diseaseโ the international community searched ways of introducing more transparency in the sources, management and use of such wealth. The expected outcomes being a large debate at local and international levels, higher accountability of governments, more effective involvements of civil society, etc. - After 4 years of implementation and immediate support by western governments, pilot developing countries, companies, international financial institutions and NGOs, EITI achieved a rapid institutional and technical development, through a set of recognized principles and criteria, a general framework for implementation (the 'Source Book')and the set up of an International Board in 2006, representing developing and developed countries, companies and NGOs. - Out of 53 potential 'EITI countries'more than 20 rapidly endorsed EITI. At the top of the list, 3 had reached the fourth and final EITI phase - publishing audited and reconciled data. In two other countries, numerous Transparency publications resulted in significant worldwide discussions. At the bottom, some of the 15 countries least performing might be de-'EITIlisted', by the Board, this September. Also, the Board will soon submit listed EITI countries to control by independent professionals, thus responding to many requests for EITI's enhanced โbrandโ and credibility. - EITI, NGOs and professionals have listed crucial pending issues for the future, among which - involving โheavy weightโ extractive emerging countries (China, Brazil, Russia, India) - work closer with other existing Initiatives and norms - implement EITI at sub-national levels develop specific tools for Mining industries - promote supports at technical and financial levels - and provide protection to EITI actors.
- Africa (1.00)
- South America > Brazil (0.25)
- Europe > Russia (0.25)
- (3 more...)
- North America > United States > Kansas > State Field (0.89)
- Asia > Middle East > Israel > Tel Aviv District > Southern Levant Basin > National Field (0.89)
ABSTRACT In today's drive to improve plant availability and utilisation, process control systems provide refinery operation staff with more information than they know what to do with. However, is this surfeit of information useful or is it actually a draw back in managing a state of the art refinery? Do operators actually know what the temperature and pressure of a specific process stream means in terms of that streams physical properties? How does an operator control the properties of a stream when that property can not be measured directly? How can this information be used to deliver improvements in availability and utilisation. The use of process modelling has been with us for over forty years since being founded by simulation sciences. Today's process models provide a range of information capabilities that give engineers and operators the ability to calculate numerous process parameters. However a traditional steady state model, built as part of the original plant design, if not constantly updated will soon be totally out of step with the actual plant performance. Today by linking the plant operational data, generated by the control system, and thus tuned to the actual performance of the plant allows operators and engineers to interrogate the process, quickly and accurately, and make operational decisions based on facts not educated guesswork. This paper details how an operation decision support system has been developed and implemented around the globe brining increases in availability and utilisation. The capabilities of the system are described and ways in which it can be applied by operators, engineers and plant management to deliver cost savings of up to 5%; increased throughputs up to 2%, engineering productivity increases up to 10% and up to 5% improvements in maintenance efficiency; thus delivering the desired availability and utilisation increases. Introduction Economic constraints have forced manpower levels in manufacturing industry to decrease to half of what they were 20 years ago. At the same time the complexities of chemical plants and their related production methodologies have increased exponentially. Thus overall production levels have almost doubled in some sectors.
- Energy > Oil & Gas > Downstream (1.00)
- Energy > Oil & Gas > Upstream (0.94)
- Production and Well Operations (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Management > Risk Management and Decision-Making > Decision-making processes (0.68)
- Facilities Design, Construction and Operation > Measurement and Control > Process control and automation (0.54)
Abstract Global demand for light olefins (ethylene and propylene) points to strong prospects for growth, stimulating investments in overall productive capacity. With propylene demand growing slightly faster than that of ethylene, rising prices and difficulties in supplies of petrochemical feedstocks such as naphtha or natural gas, steam crackers alone are not able to fill the light olefins gap nor do they allow extraordinary margins. As petrochemical market dynamics also influence refining activities, there has been significant progress in the development of technologies for petrochemical refining, leading to a larger degree of integration between the refining and petrochemical industries. This integration offers great opportunities for synergism since both industries share many common challenges, like increasing process efficiency, meeting more severe environmental requirements and optimizing the use of utilities. New specifications for fuels also contribute to this approximation since additional olefinic and aromatic hydrocarbon streams will become available in refineries. Petrochemical FCC is an example of advances in petrochemical refining. Based on a higher severity operation of the traditional FCC, it permits high ethylene and propylene yields, besides producing highly aromatic naphtha. However, to take full advantage of the opportunity to add value to non-conventional oils (which tend to increase in importance in oil markets) while to still have enough feedstock for cracking, deep conversion and treatment processes should also be present in refining schemes. Refinery off-gases correspond to another alternative feedstock for petrochemicals. Thus, a refinery (originally projected for production of fuels) has become an alternative source of petrochemicals, making possible the conception of petrochemical refineries that may be integrated or not to a petrochemical complex. This paper provides an overview of the recent impacts of light olefin demands on refining processes as well as an update of the refining-petrochemistry scenario in the world. Introduction Global demand for light olefins points to strong prospects for growth, forcing the expansion of refining and petrochemical activities that need to deal with the challenge of an increasing market share of non-conventional oils (SZKLO et aI., 2006; LEN & PAVONE, 2004; PLOTKIN, 2005). As these activities have an interdependence relationship due to the privileged refining position as an important link in the petroleum productive chain, understanding how petrochemistry impacts configuration strategy of refining industry is quite important (SANTOS et aI., 2006). Closer integration of refining and petrochemistry units is also supported by more severe environmental laws and fuels specifications. In this context, more aromatic and olefinic hydrocarbon streams will be available and may be directed to the petrochemical production, generating products of great added value. Nevertheless, other characteristics of petrochemicals market also seem to promote this integration (GOMES et aI., 2005).
- North America (1.00)
- South America > Brazil (0.97)
- Asia > Middle East > Saudi Arabia (0.33)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- South America > Brazil > Campos Basin (0.99)
- North America > Canada (0.99)
Abstract Captive is a bona fide insurance or reinsurance company owned by a non-insurance company and which insures or reinsures the risks of its parent of affiliated companies to meet the need for risk management, especially for the companies with high operating risk. It is very useful to use captive to control, transfer or benefit from the operating risk. Almost every big oil company has one or more captives. The more Chinese oil companies get involved in global competition, the more important role the captive plays for enhancing the international competitive advantage and communicating with the international players at the same level. So far, CNOOC, CNPC and Sinopec have set up captive or self-insurance fund for their risk management. In this paper, we would introduce the captive practice in Chinese Oil Industry. We also study the CNOOC real case to describe how the captive contributes to the parent company. Finally we would give some suggestions to develop the captive in China's oil industry.
- Government > Regional Government > Asia Government > China Government (1.00)
- Energy > Oil & Gas (1.00)
- Banking & Finance (1.00)
Abstract Lithological description and permeability estimation using core-derived information of wells with just conventional well-logs is an old problem in reservoir characterization. There are many methodologies that have attacked this subject with major or minor success. Applied fuzzy logic is the matter of this article. Fuzzy logic invites the use of "partial truths" between the "completely false" and "completely true" alternatives. When it is applied to reservoir characterization, it accepts that any interpretation is possible although some are more likely than others. Whereas conventional techniques deal with absolutes, the new methods carry the inherent error term through the calculation rather than ignoring or minimizing it. One clear application is to lithofacies determination. Lithofacies typing is used in well correlation and is important for building a three-dimensional model of a field. The technique makes no assumptions and retains the possibility that a particular lithofacies type can give any log reading although some are more likely than others. In this study, core analysis of some wells and the established fuzzy relations are used to get the lithofacies description in wells having only log data. In addition, a sensibility analysis assigned to the capability of the model to predict lithotypes correctly when describing from the most basic lithology (sand or shale), to the most detailed seven core derived categories. Another application is permeability prediction. The problem with permeability is that permeability relates more to aperture of pore throats rather than pore size. In addition, determining permeability from well logs is further complicated by the problem of scale. In this study, a Fuzzy-model has been used to obtain better permeability estimations compared to some public conventional techniques (permeability prediction from effective porosity and Multi Linear Regression Methods). In addition, the method uses much basic log data sets rather than depending on new logging technology.
- Asia > Middle East > Qatar > Arabian Gulf (0.40)
- Europe > United Kingdom > North Sea > Northern North Sea (0.40)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Alwyn Area > Block 3/9 > Alwyn Area > Alwyn North Field (0.99)
- Europe > Germany > Ruhr Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
Abstract Petrobras achieved a gross income of US๏นฉ 93.8 billion in 2006, and a net profit of US๏นฉ 12.8 billion. It had an average daily production of 2,298,000 barrels/day and by the end of the year had a total of 47,955 employees (of the holding). In 2012, production shall reach 3,494,000 barrels/day and a total number of direct employees of 62,000, representing 52% and 29% growth rates respectively. Within this time frame, investments in the range of US๏นฉ 112.4 billion are projected. The 2020 strategic plan keeps the commitment to the sustainable development, and stresses the challenges in the natural gas and biofuel markets. Petrobras vision now includes becoming one of the major five integrated energy companies world wide. The plan emphasizes excellence in performance operations, technological management and human resources, key factors for implementing the Company strategies. This sets the HR strategic goals within which "guarantee adequacy of the workforce and the development of the technical and managerial competences needed for Petrobras' strategy". To attend Company growth, it has become necessary to consider the profile of the current workforce with an average age of 42, and 48% with over 20 years tenure. Since 2002, through a public selection process, 17,500 new employees were admitted, 7,700 in 2006. In 2007, 171,000 candidates ran for the 163 positions available, which is over 1000 candidates per position. Through the corporate university, the Company has been investing heavily in development programs, mainly in formation courses for the new employees, which could last as long as one year. Between 2004 and 2006 Petrobras invested US๏นฉ 481 million in developing its professionals, US๏นฉ 173 million last year. Since it joined the Dow Jones Sustainability Index (DJSI) in 2006, it was twice considered as a benchmark at developing human asset, one of the variables of the social dimension.
- Government > Regional Government > South America Government > Brazil Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Renewable > Biofuel (0.87)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Lula Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Cernambi Formation (0.99)
- (7 more...)
ABSTRACT This paper presents well geosteering and advanced completion technologies utilized to successfully tap attic oil reserves in the most mature giant of the Saudi Arabian carbonate fields. After more than sixty years of continuous production, approximately 57% of the oil initially in place in the primary reservoir has been produced. The upper 10% of the main reservoir (-20 feet net) has a lower quality rock relative to the layer below; accordingly, it remains untapped across the whole field area. The attic oil was unattractive due to very low vertical well oil rates caused by excessive water production from the prolific, but now largely flooded reservoir section located immediately below. Most attempts to produce the attic oil selectively in vertical wells were short-lived due to low well productivity combined with water production. The first real development of these reserves started in the mid 1990's with short radius sidetracks. These early horizontal wells were plagued with poor directional control and high failure rate. The next step was medium radius sidetracks yielding much better oil production rates. In 2003, the drilling of the first mutli-Iateral Maximum Reservoir Contact well revolutionized this attic oil development. By mid 2007, 12 of these wells have been drilled, placed mainly downdip of the original first line producers. Each well produces up to four times the initial horizontal well production rates at low watercut. The wells are equipped with smart completions to reduce contribution from high watercut laterals. The main challenge for the development has been lateral placement, which requires the most sophisticated geosteering tools available in the industry. The attic oil development is now contributing more than 1/3 of the total oil production and have brought the overall field watercut down to approximately 30%..
- Asia > Middle East > Saudi Arabia (0.70)
- North America > United States > Texas > Coleman County (0.24)
Abstract PETRO BRAS' programme for expanding activities in the biofuels area has the key strategic target of leading the Brazilian production and retail market. The planned PETROBRAS' production until 2012 is 860,000 m3 biodiesel/year, associated to 10-12% of glycerin, byproduct of the reaction. Within this context, a large growth in the offer of glycerin is expected, accompanied by a market price decrease, therefore creating a challenge, as well as business opportunities, for new uses of glycerin. PETRO BRAS is pursuing two lines of action for glycerin: short term and medium/long term. In the first case, the aim is to give a quick environmentally adequate destination to the glycerin, such as produced with the biodiesel, without any further treatment. Among these are included combustion in cement factories, blending with animal food, dust collector in mining industries, etc. The second case focuses the development of technologies that include chemical transformation, adding value to the glycerin and producing financial gains. Under this line of medium term initiatives, emphasis is being given to applications inside the fossil fuels production chain of PETROBRAS, such as fluids for E&P, additives for fuels and lubricants, etc. By these means, the competitive advantage of PETROBRAS as a producer of both fossil and renewable fuels is enhanced. Furthermore, as a result of this synergy, the association with PETRO BRAS' leadership of fossil fuels in Brazil will provide quick market expansion and penetration to biofuels and glycerin derived products.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Government > Regional Government > South America Government > Brazil Government (1.00)
- Energy > Renewable > Biofuel (1.00)
- Energy > Oil & Gas > Downstream (1.00)
Abstract Because of increased production of heavy crude oil and increasingly strict laws of environmental protection, residue processing is of great importance. Residue processes can be divided into two ways, hydrogenation and decarbonization processes in terms of reaction theory. Delayed coking, visbreaking and solvent deasphalting had made great progress since 1990's. However, conventional decarbonization process could not match the requirements of effective use oil sources. For example, delayed coking is a kind of heat treatment which has poor selectivity and control; deoiled asphalt obtained by solvent deasphalting process is difficult in wholesale application. In order to overcome the above shortages, CNOOC developed a new method of upgrading heavy oil: Residue Decarbonization Combination Process (RDCP). RDCP is an evolutionary new process which aims at improving the yield of light cuts and realizing the wholesale application of carbon enriched component. RDCP process is simple in operation, low in equipment and operating cost. It not only has good reaction selectivity and easy control, but also can improve the product's structure and character. Pilot Experiments showed that RDCP technology could increase the yield of light cuts 5-10 m% in comparison with solvent asphalting processes and delayed coking. In the meantime, the carbon enriched component has a better quality than petrol coke obtained by delayed coking process. light cuts could be processed by FCC or hydrocracking processes with low carbon residue content; carbon enriched component could be made into carbon material or modifier of base asphalt due to its proper structure and favorable compatibility with asphalt. Further industrial study on RDCP technology is being carried out in the Heavy Oil Utilization Research Center, CNOOC.
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Downstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.81)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (0.93)