Low-carbon-emissions FPSO (Floating, Production, Storage, and Offloading) designs are developed and compared, using process simulation in HYSYS, and an original economic analysis approach. FPSO units ...with power-intensive operations (e.g., fields with high gas-to-oil ratio) are the focus of the study. Three designs are evaluated: Case A considers a floating natural-gas-combined-cycle power unit with post-combustion CCS (Carbon Capture and Storage) connected to an existing FPSO. Case B.1 retrofits a CCS unit downstream of a conventional FPSO with simple-cycle power generation. B.2 adds a more efficient combined cycle to B.1. The removed CO2 is injected for enhanced oil recovery. Marginal abatement cost is investigated for oil prices of 60/80/100 USD/bbloil and recovery of 0.0/1.5/3.0 bbloil/tCO2 injected. The added weights to topsides are 4,326t (A), 2,762t (B.1) and 3,445t (B.2). CO2 intensity (kgCO2/boe) is reduced from 6.92 in the conventional design to 0.74 (A-B.2) and 0.92 (B.1). The marginal abatement cost of B.1 and B.2 are alike, approaching zero at 1.5 bbloil/tCO2 oil recovery. Taking technical retrofitting challenges aside, Case B.1 is the most cost-effective alternative. Cases A and B.2 have a slightly better environmental performance than B.1, but B.2 presents a superior economic performance and lower operational risks compared to A.
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•Oil companies consume 1.5 GJ/y of energy, 71% for internal heat and power supply.•FPSO (without CCS) designed for Brazilian pre-salt releases 6.9 kgCO2/boe.•Carbon intensity reduces to 0.92 and 0.74 kgCO2/boe using CCS and NGCC + CCS.•Added weights to topsides are 12 and 15.7% for CCS and NGCC + CCS (base: 22 kt).•NGCC + CCS requires larger hulls with higher marginal abatement costs than CCS.
Offshore oil production in ultra-deepwater, with associated natural gas showing high carbon dioxide content and high gas to oil ratio, poses stringent constraints to upstream gas processing ...technologies. Under such circumstances, oil and gas are processed in Floating Production Storage and Offloading rigs, whose topside facilities are limited in terms of weight and footprint of equipment. Energy demands, supplied by on-site generation, also reduce the availability of space and weight to oil and gas processing. This work evaluates carbon dioxide separation alternatives applicable to this challenging scenario in terms of technical, economic and environmental aspects, considering early enhanced oil recovery as the destination of carbon dioxide. The Brazilian Pre-Salt fields are used as case study due to their unusual high capacity gas processing on the production topside, a consequence of the high gas to oil ratio and carbon dioxide content. The set of studied carbon dioxide separation technologies encompasses membrane permeation, chemical absorption by aqueous methyl diethanolamine with piperazine, physical absorption with propylene carbonate and hybrid variants physical absorption and membranes, membranes and chemical absorption, and two stages membrane, technically assessed by process simulation. Due to the continuous injection of carbon dioxide to enhanced oil recovery, the reservoir content of carbon dioxide increases along production life-cycle, which means that the performances of technologies have to be compared under short-term, mid-term and long-term carbon dioxide content in the associated gas, respectively, of 10%, 30% and 50% (mol), for gas production of 6 million sm3/d. Chemical absorption exhibits the lowest hydrocarbon losses and the lowest specific electric power consumption at the expense of the highest footprint, for all investigated scenarios. The lowest life-cycle costs are for chemical absorption and two stages membrane, respectively $0.57 and $0.46 million/GJ of exported gas, while the largest cost belongs to the hybrid membrane and chemical absorption ($1.78 million/GJ of exported gas). Chemical absorption holds the lowest carbon dioxide emission per ton of injected carbon dioxide (0.15 t/t), seconded by membrane permeation (0.19 t/t). Hybrid membrane and chemical absorption inherits the small footprint of membrane permeation and, despite its highest life-cycle cost, is recommended for flexibility reasons due to increasing carbon dioxide content in the reservoir life-time in cases of ultra-deepwater fields with high gas to oil ratio, high carbon dioxide content and early carbon dioxide enhanced oil recovery. Contrarily to the widely acceptance of membrane permeation as a leading small footprint solution, the overall performance analysis, under the adopted premises, remarkably favors chemical absorption.
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•Technologies for CO2 separation from high CO2 content natural gas are analysed.•Gas processing in ultra-deepwater FPSO has severe footprint and power constraints.•Membrane permeation has lowest life-cycle cost of 0.47 MM$/GJ NG.•Chemical absorption has lowest CO2 emission of 0.15 t /t CO2 injected.•Hybrid membrane permeation + chemical absorption has low footprint & flexibility.
This paper presents the contextualized overview of the CO2 capture technology, with critical evaluation of state-of-art and technological development through patents applications and scientific ...articles. The scientific research and technological development and innovation of CO2 capture is mapped, providing not only an overview, but also concrete basis to define and optimize research and development (R&D) perspectives. It relates the stage of scientific, technologic and innovation development relate to the actions of the Intergovernmental Panel on Climate Change (IPCC) to ensure the reduction of the global warming due to anthropogenic emissions of greenhouse gases (GHG) into the atmosphere. The yearly monitoring of actions is presented, focusing on scientific, technologic and innovation from governments and companies acting within various countries in an attempt to mitigate the effects of global climate change. The mapping of the capture technologies was focused on absorption, adsorption, membranes, cryogenic, enzymatic and hybrid. The capture technologies are also mapped according to the CO2 capture process (post-combustion, pre-combustion and oxy-combustion). The results are analyzed in terms of priority date, annual evolution of the patents portifolia, technology owners (country, continent, sector of society, companies, (R&D institutions), inventors and their countries, authors of scientific articles, article copyright owners, institutions and countries where the scientific research reported in the articles was performed, patent type (process, method, prototype, product, etc.), patents classification codes showing technologic trends and fields, type of gas source where CO2 is captured, type of processes and type of gas outputs after CO2 capture, details of the components and of the processes for each method capture, among other trends. The results are contextualized in terms of methods of CO2 capture processes, focusing on technology for IPCC, roadmaps, and government programs and strategies for reducing CO2 emissions into the atmosphere. All the capture technologies are growing yearly, both in patent applications and in articles. Absorption and adsorption are the most used capture technologies, post-combustion is the most used capture process, and most of the patents refer to CO2 separation and removal. Most of the copyrights belong to Elsevier and American Physical Society, USA detains 52% of the patent applications and 31% of the articles published. The other patent applications belong mainly to Germany, France, Japan and United Kingdom. The countries with more aggressive appropriation policies are France, Norway, Germany, USA and Netherland. There is a strong correlation between countries of the technology owners and clear CCS government policies. The patent applications refer to over thirty entry gas currents, being focused on combustion and post combustion processes, followed by natural gas specification. New trends like Chemical Looping Combustion (CLC), Chemical Looping Reforming (CLR) are also focused.
Currently one of the main challenges in CO2 storage research is the development, testing and validation of accurate and efficient Measuring, Monitoring and Verification (MMV) techniques to be ...deployed at geological sequestration sites that are cost effective yet help minimize risk. This perspective motivated PETROBRAS, the National Oil Major in Brazil, through its R&D investments portfolio to prioritize research projects that would contribute to decreasing the technological gap in the area. The Company's periodic surveys indicated the lack of infrastructure, as well as expertise in CO2 MMV, as two of the most critical issues at the national level. In order to bridge that gap, initial steps were taken in 2010 for the start-up and development of the first CO2 MMV Field Lab in Brazil, fully sponsored by PETROBRAS, with a long term goal of enabling the ranking of the best, most cost- effective MMV technology alternatives to be deployed at commercial large scale CCGS sites scheduled to be installed in the country. In addition to providing basic infrastructure to carry out the CO2 injection and controlled release experiments, the facility was designed for the simultaneous testing of multiple measuring methodologies. Additional benefits of the initiative are the creation of expertise and the acceleration of the know-how in MMV in Brazil, as well as the development of a deeper and more practical knowledge of CO2 dynamics and impacts in a real world, open air scenario. Under the full support of the PETROBRAS R&D Center (CENPES), through its Climate Change Mitigation Technological Program (PROCLIMA), the Brazilian Pilot CO2 MMV Lab was made possible through a joint 4-year research Project, conceived and carried out by PETROBRAS and local academia in Brazil, in close cooperation with international experts. An overview of the Project and the multiple research areas encompassed will be presented, together with the preliminary results of the first CO2 injection campaign, which took place in 2013.
The first CO2 Field Lab built in Brazil was developed at the Ressacada Farm, in Florianopolis, SC with the goal of diminishing technical gaps in CO2 storage covering research in Measuring, Monitoring ...and Verification (MMV) techniques, a need identified in the PETROBRAS Strategic Plan. Through the Company R&D Center (CENPES), and the Climate Change Mitigation Technological Program (PROCLIMA), PETROBRAS is sponsoring a joint 4-year research Project, in which both company and local academia personnel are collaborating to deploy, test and assess multiple near-surface CO2 detection technologies. Longer term objectives include the validation of accurate and efficient detection, measurement and quantification tools to be deployed in large scale commercial CGS (Carbon Geological Storage) sites scheduled to be installed in the country to assist in validating storage efficiency and minimizing risk. In September 2013, the first CO2 injection campaign was carried out, in which small volumes of gaseous food-grade industrial CO2 (with a delta 13C signature of ca.-32 ppmil) were injected into the ground at shallow levels through a vertical 3 m depth well and then migrated into the atmosphere. The campaign was run over 12 days, for 24hours a day, at injection rates low enough not to offer any risks to the formation integrity and enabled the simultaneous assessment of CO2 behavior in the soil, in the groundwater, at the surface and in the air. This paper presents an overview of the atmospheric measurements carried out at Ressacada, covering the background, injection and post-injection scenarios.
In a joint R&D project under the full sponsorship of PETROBRAS, the Brazilian National Oil Company, the first CO2 monitoring field lab was started-up in Brazil in 2011.The site chosen, the Ressacada ...Farm, in the Southern region of the country, offered an excellent opportunity to run controlled CO2 release experiments in soil and shallow subsurface (< 3 m depth). This paper focuses on the presentation and comparison of the results obtained using electrical imaging, CO2 flux measurements and geochemical analysis of the groundwater to monitor CO2 migration in both saturated and unsaturated sand-rich sediments and soil. In 2013 a controlled release campaign was run, covering an area of approximately 6,300 m2. Commercial food-grade gaseous carbon dioxide was continuously injected at 3 m depth for 12 days. The average injection rate was 90g/day, totaling ca. 32kg of gas being released. The low injection rate avoided fracturing of the unconsolidated sediments composing the bulk of the local soil matrix. Monitoring techniques deployed during 30 consecutive days, including background characterization, injection
The development and application of CO2 separation technologies and geological storage is a strategic opportunity in terms of GHG mitigation especially for the energy industry. PETROBRAS has recently ...established strategies to face this technological challenge. In 2007 a corporate program was started off–PROCLIMA–under the coordination of PETROBRAS R&D Center (CENPES), aiming to provide technical management and support for the full development of the PETROBRAS’ CCS portfolio. Under the leadership of PETROBRAS, PROCLIMA articulates with the Climate Change and Carbon Sequestration Network, integrating Brazilian Universities and R&D institutions, also including international cooperation.
In this work is assessed the Brazilian potential for Carbon Capture and Geological Storage (CCS) through CO2 capture from biomass sources with focus on bioethanol production facilities. In the ...present document their geographic distribution is associated with localization of the sedimentary basins as well as the potential geologic reservoirs for CCS is presented, thus providing concrete basis to define and optimize longer term goals, consistent with Brazil’s volunteer commitment to help mitigate the effects of global climate change.
It was found that USA, England, Canada, Australia, Germany, France, Netherlands and Japan not only are quite active in the research and technologic development, but also have strong relationships between them, owning several joint products.
Historic data point out an increase in ethanol annual production in the last years, being produced mainly by Sao Paulo (61% of the domestic production). The CO2 emissions were estimated for each Brazilian state based on the ethanol production and the CO2 emissions due to the fermentation process. There were 26,959,209 m3 of total ethanol produced, corresponding to about 11.2 billion m3 of CO2 emissions at 20 °C and 1 atm, and to about 29 million m3 of CO2 in reservoir conditions.
The CCS scenarios were built considering porosity in the range from 18% to 24%, using the average of the Brazilian basins for oil production. The Paraná Basin should receive over twenty million m3 of CO2, encompassing eight Brazilian states, which requires from 110 to 147 million m3 of rock. Other Basins, such as Ceará, Marajó or Maranhão, Pelotas, Potiguar, Recôncavo or SEAL, and Tacutu require from 12 to 10,861 thousand m3 of rock, having each one a specific requirement. In all scenarios, the rock volumes are smaller than the real Basins volume, thus a very favorable negative balance can be achieved for bioethanol.
Pure component adsorption equilibrium of CH
4
and CO
2
on activated carbon have been studied at three different temperatures, 298, 323, and 348 K within a pressure range of 10-2000 kPa. Binary ...adsorption equilibrium isotherm was described using extended Sips equation and ideal adsorbed solution theory (IAST) model. Experimental breakthrough curves of CO
2
/CH
4
(40:60 in a molar basis) were performed at four different pressures (300, 600, 1200, and 1800 kPa). The experimental results of binary isotherms and breakthrough curves have been compared to the predicted simulation data in order to evaluate the best isotherm model for this scenario. The IAST and Sips models described significantly different results for each adsorbed component when higher pressures are set. These different results cause a significant discrepancy in the estimation of the equilibrium selectivity. Simulated and experimental equilibrium selectivity data provided by IAST presented values of around 4, for CO
2
/CH
4
, and extended Sips presented values of around 2. Also, simulated breakthrough curves showed that IAST fits better to the experimental data at higher pressures. According to the simulations, in a binary mixture at total pressure over 800 kPa, extended Sips model underestimated significantly the CO
2
adsorbed amount and overestimated the CH
4
adsorbed amount.
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BFBNIB, DOBA, GIS, IJS, IZUM, KILJ, KISLJ, NUK, PILJ, PNG, SAZU, UILJ, UKNU, UL, UM, UPUK
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