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38th International Symposium on Combustion, 2021

作者： Choudhary, Rishav Girard, Julian J. Clees, Sean Johnson, Sarah E. Shao, Jiankun Davidson, David F. Hanson, Ronald K. Aradi, Allen A. Department of Mechanical Engineering Stanford University 418 Panama Mall Room 104 Stanford CA 94305 United States Shell Projects and Technology Development Houston TX 77082 United States

The first shock tube measurements of formaldehyde during the first stage ignition of n-heptane, 2-methylhexane, and 3,3-dimethylpentane were performed in highly diluted fuel/oxygen mixtures in the pressure range of 7–10 atm and temperature range of 700–880 K. Combined time histories of all carbonyl (–C = O) species, CO, and fuel were also measured simultaneously to study the impact of fuel structure on the concentration and the rate of evolution of first stage ignition products. Of the three isomers considered, n-heptane was the fastest, while 3,3-dimethylpentane was the slowest. The differences in the time scale of formation, and plateau concentration of the intermediates between the isomers across the entire range of test conditions suggested a strong dependency of the measured time histories to fuel structure. These species act as markers of the Negative Temperature Coefficient behavior of fuels and could be used as targets for developing semi-empirical, hybrid chemistry models of complex, multi-component petroleum derived gasoline, and jet fuels.

关键词： Heptane

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New material application limits of duplex stainless steel in sour service

New material application limits of duplex stainless steel in...

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Corrosion Conference and Expo 2019

作者： Al Kharusi, Amjad Saithala, Janardhan Rao Suryanarayana, Manoj Al Nebhani, Talal Al Behlani, Nasser Wilms, Marc Yang, B. Petroleum Development of Oman PO Box: 81 Muscat Oman Shell Projects and Technology BN Amsterdam Netherlands

Duplex Stainless steel 22Cr (DSS) is one of the corrosion resistant alloys (CRA) that is used extensively in oil and gas industry for critical applications such as wet gas production flow lines and pipelines. A number of new sour oil & gas projects in the company with high salinity (exceeding 200000 ppm NaCl) will be developed in the coming years. So far 22Cr DSS material is qualified up to 10 mbar partial pressure of H2S (ppH2S) in 160,000ppm chloride levels. The operating conditions of these new projects are outside these current material operating limits of 22Cr DSS defined within the company standards. The objective of the study was to enable wider use of 22Cr grades in higher sour projects in high chloride environments and qualify as lower cost alternative to more expensive CRA materials like 25Cr super duplex, alloy 825 or alloy 625. Pitting, crevice and stress corrosion cracking (SCC) and sulphide stress corrosion cracking (SSC) tests were conducted on both parent material and representative welds in high ppH2S and in high chloride environments using four-point bend test method (FPBT). The results established the new threshold sour service limits of DSS material which resulted in significant cost savings for various projects. This paper will present the test results and discuss the opportunities for 22Cr DSS application. © 2019 by NACE International.

关键词： Stress corrosion cracking

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Estimation of oil-rim thickness with analogue data in the absence of definite fluid contacts: A case study from onshore Niger delta

Estimation of oil-rim thickness with analogue data in the ab...

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SPE Nigeria Annual International Conference and Exhibition 2017

作者： Fouzdar, Amit Kilic, Cem Das, Anindya Shell Projects and Technology United States Shell Petroleum Development Company of Nigeria Limited Nigeria

ISBN: (纸本)9781510846807

One of the major challenges in field development is to estimate the possible oil-rim thickness, when only known contact is Gas-Down-To (GDT) or Oil-Down-To (ODT), and where seismic analysis cannot resolve the uncertainty. A reliable, repeatable, and practical technique to estimate the ranges of possible oil-rim thickness with the regional analogue would allow for making development decisions, as well as meeting the local regulatory requirements. An analog database with numerous proven hydrocarbon (gas and oil) column heights provides a trend for "gas-to-oil column ratio" by depth, which can be used for predicting possible oil-rim thickness at specific reservoirs with the contact uncertainty. For all the analog reservoirs, fluid thicknesses have been tabulated and a "gas-to-oil column ratio" has been calculated. A simple plot between the "gas-to-oil column ratio" and reservoir depth reveals a certain trend of increasing "gas-to-oil column ratio" by depth. In addition, database also provides a cumulative distribution of regional column heights, which could be used to constrain the maximum estimated hydrocarbon column thicknesses. The trend of increasing "gas-to-oil column ratio" by depth indicates that gas-columns gets much bigger compare to oil-columns as the reservoir depth increasing. With given depth information and estimated "gas-to-oil column ratio" from the database, it is possible to estimate possible range of oil-rim thickness. By investigating the scatter in the trend, it is also possible to estimate a range of "gas-to-oil column ratios". With the help of this methodology, in absence of any definite fluid contact, it is possible to estimate a range of oil-rim thicknesses, which has an impact on field development scenarios;i.e. "gas-only", "oil-then-gas", or "concurrent oil-and-gas" development options. In addition, it could also help field development plan to meet the regulatory requirements;i.e. providing a strong case not to develop or appraise the oil rim

关键词： Gases

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CO 2 Fate Comparison for Depleted Gas Field and Dipping Saline Aquifer

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Energy Procedia 2014年 63卷 5586-5601页

作者： Jeroen Snippe Owain Tucker Shell Projects & Technology – Innovation Research and Development Kessler Park 1 2288 GS Rijswijk The Netherlands Shell Projects & Technology – Upstream Development. 1 Altens Farm Road Aberdeen AB123FY UK

An important metric for CO 2 storage is the CO 2 fate plot, which displays the partitioning of mobile/capillary trapped/dissolved/mineralised CO 2 as a function of time. The archetype version of this plot (Fig. 1, from the IPCC 2005 report [1] ) is idealised. While a simplification is a good way to illustrate physical mechanisms, the problem with this plot is that due to its popularity it is now easily misinterpreted to be a universal plot. However, for actual case studies the curves behave quantitatively and sometimes qualitatively differently from the archetype plot. The reason for this is that reservoir settings are different from case to case, having a profound impact on the characteristic times, shapes, and magnitudes of the CO 2 fate curves. The objective of this work is to generate a realistic range of CO 2 fate plots, derived from reservoir simulations on simple geometries but with realistic input parameters, expressing the impact of key control parameters. This new range of plots can be used for communication purposes to a wider audience, and also as a Quality Control tool for future modelling studies. Our results bring out major differences between a depleted gas field setting (more generally: structurally closed setting) and a dipping saline aquifer setting (more generally: structurally open setting). In a structurally closed setting the CO 2 dissolution and/or mineralisation takes orders of magnitude longer than in a structurally open setting. This result is quite robust under variation of other parameters such as vertical to horizontal permeability, reservoir thickness, reservoir dip angle, relative permeabilities and geochemical variations. Moreover, only a small subset of structurally open cases, and none of the structurally closed cases, leads to CO 2 fate plots that are similar to the one in the IPCC 2005 report. Therefore the CO 2 fate plot from the IPCC 2005 report should not be used for quantitative statements regarding the relative size and timi

关键词： CCS trapping geochemistry Reactive Transport Modelling

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Quality control of porosity changes predicted by geochemical modelling in CCS case studies

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Energy Procedia 2014年 63卷 2861-2869页

作者： Jeroen Snippe Shell Projects & Technology – Innovation Research and Development Kessler Park 1 2288 GS Rijswijk The Netherlands

Assessment of long-term stability of injected CO 2 for geological storage requires a certain level of dynamic modelling, including geochemical modelling of fluid-rock interactions triggered by the injected CO 2 in geological formations. One of the key outcomes of a geochemical simulation is the predicted porosity changes. Decreasing porosity implies an overall plugging of the pore system and therefore probably a reduction in permeability, while increasing porosity implies the possibility of the opening up of flow paths. Therefore the predicted porosity change is an important indicator for self-healing versus self-accelerating behaviour of potential CO 2 leak paths. Based on project studies and natural analogue comparisons, several easy-to-use metrics and cross-correlations are developed in this paper. This is done by starting from a mass balance analysis, and re-writing it as a volume balance analysis plus correction terms. In this way porosity changes can be rigorously split up in distinct contributions from salinity changes, density changes and (de)mineralisation of CO 2 and H2O. By cross-correlating the porosity changes to these contributions, using 11 CCS case studies and natural analogues examples (covering a wide range of settings such as aquifer/gas field, geographic location, geochemical reaction paths, salinity, temperature), distinct patterns and rules of thumb emerge. The methodology and resulting cross-correlations can be applied as a quick and powerful sanity check on geochemical modelling results. The key conclusions that can be drawn from this work are: • The amount of mineralised CO 2 is a reasonable predictor for the porosity change • The amount of mineralised H2O and the density change can be significant contributors to the porosity change, but (without taking into account mineralised CO 2 ) are poor predictors for the porosity change The salinity change is only a minor contributor to the total porosity change. The main conclusion is that the poros

关键词： CCS geochemistry Reactive Transport Modelling porosity

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The Peterhead-goldeneye Gas Post-combustion CCS Project

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Energy Procedia 2014年 63卷 6258-6266页

作者： Bill Spence Denise Horan Owain Tucker Shell UK 1 Altens Farm Road Aberdeen AB123FY UK Shell Projects & Technology – Upstream Development. 1 Altens Farm Road Aberdeen AB123FY UK

Full scale demonstration projects are the key to gaining policy acceptance for CCS. They also form the vital first step towards reducing the cost of clean power: only when a project is built can engineers examine it and identify improvements and savings opportunities. A number of projects are currently in development for coal CCS, but carbon capture on gas is also important if the world is to make the depth of cuts in emissions required by the current scientific consensus. shell and SSE plan to deliver the world's first full scale CCS project on gas in Scotland. Up to 10 million tonnes of carbon dioxide (CO 2 ) emissions could be captured over a 10-year period from flue-gas from a 400MW combined cycle gas turbine at the existing Peterhead Power Station in Aberdeenshire, Scotland and then transported by pipeline and stored, approximately 100 km offshore in the depleted Goldeneye gas reservoir, at a depth of more than 2 km under the floor of the North Sea. This would provide enough clean electricity to power the equivalent of 500,000 homes per year. The project is one of two preferred bidders in the UK Government's CCS Commercialisation Programme and is currently in the midst of a front end engineering and design (FEED) phase. Subject to positive final investment decisions by shell and the UK Government, and the receipt of all relevant permits and consents, the project is expected to be up and running by the end of the decade.

关键词： CCS trapping geochemistry Reactive Transport Modelling

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Prelude FLNG development environmental footprint and conditions of approval in a post Montara and Macondo world

Prelude FLNG development environmental footprint and conditi...

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SPE/APPEA International Conference on Health, Safety and Environment in Oil and Gas Exploration and Production 2012: Protecting People and the Environment - Evolving Challenges

作者： Caymo, Arphee Cohen, Brian Shell Projects and Technology Australia Shell Development Australia Australia

ISBN: (纸本)9781622763931

In May 2011 shell announced its commitment to the development of a Floating Liquefied Natural Gas (FLNG) concept by taking the Financial Investment Decision on the Prelude FLNG Project. Prelude is located in Australian offshore waters, approximately 475 km north-northeast of Broome and 825 km west of Darwin, and will be shell's and possibly the world's first FLNG development. FLNG offers a number of environmental advantages over traditional onshore LNG developments. This paper describes some of these and the associated environmental permitting/approval conditions for the project. Copyright 2012, SPE/APPEA International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production.

关键词： Investments

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Effects of process control changes on aquifer oxygenation rates during in situ air sparging in homogeneous aquifers

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GROUND WATER MONITORING AND REMEDIATION 1996年第4期16卷 132-141页

作者： Rutherford, KW Johnson, PC Kyle Rutherford received his master's degree in civil and environmental engineering from Arizona State University in December 1995 specializing in contaminant fate and transport. Rutherford was formerly an officer in the U.S. Navy Civil Engineer Corps and is a professional engineer in Arizona and Indiana. He currently manages environmental projects for Groundwater Technology Inc. in Tempe Arizona. Dr. Paul C. Johnson is an associate professor in the Department of Civil and Environmental Engineering at Arizona State University (ASU) in Tempe Arizona. (Department of Civil and Environmental Engineering Arizona State University Tempe AZ 85287-5306). He received his B.S. and Ph.D. degrees in chemical engineering from the University of California at Davis and Princeton University respectively. His research and teaching interests focus on the development of cost-effective and innovative solutions to problems related to environmental protection environmental restoration and environmental risk analyses including issues such as aquifer protection risk and exposure assessment remedial method development and waste management. Prior to joining the faculty at ASU he was a senior research engineer at Shell Oil Co.'s Westhollow Research Center from 1987 to 1994.

In situ air sparging is used to remediate petroleum fuels and chlorinated solvents present as submerged contaminant source zones and dissolved contaminant plumes, or to provide barriers to dissolved contaminant plume migration. Contaminant removal occurs through a combination of volatilization and aerobic biodegradation: thus, the performance at any given site depends on the contaminant and oxygen mass transfer rates induced by the air injection. It has been hypothesized that these rates are sensitive to changes in process flow conditions and site lithology, but no data is available to identify trends or the magnitude of the changes. In this work, oxygenation rates were measured for a range of air injection rates, ground water now rates, and pulsing frequencies using a laboratory-scale two-dimensional physical model constructed to simulate a homogeneous hydrogeologic setting. Experiments were conducted with water having low chemical and biochemical oxygen demand. Results suggest the following: that there is an optimum air injection rate;advective flow of ground water can be a significant factor when ground water velocities are > 0.3 m/d;and pulsing the air injection had little effect an the oxygenation rate relative to the continuous air injection case.

关键词： Aquifers

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