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Canadian CCS Projects
Pre-Combustion
Advanced
Brayton-Cycle-Based Zero-Emission Power Plants Burning Fossil Fuels
Description:
A promising means of reducing emissions from power plants burning fossil fuels
is a Brayton-cycle-based semi-closed O2/CO2 cycle, with or without a bottoming
Rankine cycle (zero-emission plant).
Partners:
Environment Canada 
Deloro Stellite
Project Manager:
Dr. Donald Gauthier,
donald_gauthier@carleton.ca
Feasibility
of integration of membrane reactor with gasification for clean coal application
Description:
Integrated gasification combined cycle (IGCC) has the potential to become the
most cost effective method of power generation using coal with near-zero
airborne emissions. IGCC involves producing an easily cleaned syngas through
the gasification of coal followed by the combustion of the syngas in a gas
turbine. Waste heat from the process is utilized for driving a steam turbine.
A near-zero emissions IGCC plant can be built using conventional technologies.
The coal is gasified and then treated in a cold gas clean-up system for
contaminant removal. The clean syngas is passed through a water gas shift
reactor with steam to increase the fraction of hydrogen in the syngas according
to reaction.
Partners:
Engelhard
KTI
Project Manager:
Jan Galuszka
CanmetENERGY, Ottawa
(ON) Research Centre
Email: galuszka@nrcan.gc.ca
Zero
Emissions Hydrogen Production via Gasification (ZEHP)
Description:
The objective of the project is to develop a process with the following
attributes:
1.
A
product fuel gas stream consisting of greater than 95% pure hydrogen suitable
for oil sands upgrading and for use in fuel cells. Particulate and alkali
concentrations in this stream will be reduced to such an extent that the stream
will be suitable for feed to fuel cells, gas turbines, and membrane separation
processes.
2.
A
product gas stream consisting of greater than 95% pure CO2 with CO2 capture
greater than 90%, suitable for sequestration.
3.
A
product solids stream suitable for feeding to a cement kiln. The product stream
will consist of calcium species, coal ash, and additional mineral species.
4.
Ability
to process a variety of Canadian solid and liquid fuels including coal (high
& low rank), petroleum coke, bitumen, and liquid resid.
5.
Near-zero
airborne emissions.
6.
In-situ
monitoring of H2, CO, CO2, H2O, and CH4 within the gasifier reactor.
The technology is expected to be able
to supply very large volumes of hydrogen for oil sands upgrading, for
electrical power production, and for the transportation sector with no CO2
emissions in the 2015 to 2030 time frame.
Partners:
Canadian Clean Power Coalition
(CCPC)
Alstom
University of Toronto
University of Ottawa
University of BC
Instituto de Carboquimica
Project Manager:
Ben Anthony
CanmetENERGY, Ottawa
(ON) Research Centre
Email: banthony@nrcan.gc.ca
Post-Combustion
Development and demonstration of cost
effective amine based solvent scrubbing technologies for carbon dioxide capture
from combustion flue gases
Description:
The objective of this project is to develop and demonstrate cost effective,
state of the art CO2 emissions control technologies by treating the flue gas
after its combustion in air. The post combustion CO2 capture technologies of
this nature are needed to help Canadian industry cope in a transitional
marketplace where nearly complete replacement of existing and partially
paid-off capital infrastructure with other competing capture technologies may
be risky and costly.
Currently the technology is being evaluated for modular design and
manufacture and for a number of international projects at commercial scale.
Partners:
Alberta Province
Alberta Science and Research Authority
Babcock and Wilcox
E.On - United Kingdom
EnCana Corporation
EPCOR Utilities Inc. (one year only)
HTC Purenergy
Natural Resources Canada
RITE (Research Institute of Innovative
Technology for the Earth)
RWE npower
Sask Energy and Resources
SaskPower Corporation
Saudi Aramco
Stantec
The University of Regina
Project Manager:
Malcolm Wilson,
International Test Centre
Email:malcolm.wilson@uregina.ca
Increasing Gasifier Availability via
Improved Refractory and Injector Designs
Description:
The objective of the project is to address one of the major technical hurdles
facing the widespread adoption of integrated gasification combined cycle (IGCC)
for power production - low gasifier availability. At present IGCC plants have
average availabilities of 85% for power production. This availability is
unacceptable to a large number of electrical power utilities, power regulators,
and consumers. Low availability translates into an increased cost for power
production and/or the need for backup power plant.
Gasification technology has been identified as one of the most
promising methods of reducing CO2 emissions. Novel integrated gasification
concepts with carbon dioxide capture could potentially result in electrical
power production efficiencies as high as 65%. These concepts generally involve
gasification, advanced shift reactors, multi-pollutant capture operations, and
electrical power production operations (steam turbines, gas turbines, fuel
cells. etc.). This work is targeted to provide improved technology for western
Canadian feedstocks to improve the business case for the construction of a
demonstration gasification plant showcasing clean coal, hydrogen and electrical
power production in
Partners:
Albany Research Center
LxSix Photonics
Project Manager:
Ben Anthony
CanmetENERGY, Ottawa
(ON) Research Centre
Email: banthony@nrcan.gc.ca
International Test Centre for Carbon
Dioxide Capture (ITC)
Description:
The International Test Centre (ITC) is developing post-combustion capture
technologies that will reduce the cost and energy penalty of CO2 production.
This work will pave the way for the development of new storage and industrial
use opportunities.
The Centre builds on the existing internationally recognised
expertise at the
These include three pilot plant units for testing high efficiency
gas treating systems which consists of different sizes of absorption and
regeneration towers packed with a variety of high performance packings. We have
also built and/or acquired a number of pieces of research units for solvent
absorption capacity testing, solvent stability and corrosion studies, and
gas/liquid diffusivity determination.
Partners:
SaskPower
Fluor Canada Ltd .
Nexen Canada Ltd.
Luscar Ltd.
TransAlta Utilities Corp.
EnCana
EPCOR Utilities Inc.
Petrobras
Alberta Science and Research Authority
Saskatchewan Energy & Mines
IEA Greenhouse Gas R&D Programme
Duration: 2002 - on-going
Project Manager:
Amy Veawab, Ph.D.
International Test Centre for CO2 Capture
Faculty of Engineering
University of
E-mail: veawab@uregina.ca
Website: http://www.co2-research.ca
Micro-porous hollow fiber for
Greenhouse Gas Separation and Capturing
Description:
The state-of-the art in CO2 separation is packed bed absorption with aqueous
amine as absorbing solvent. The application of current technologies for
separating and capturing CO2 from flue gases has been proven to be expensive.
Considerable work is being conducted focusing on improvement of existing
processes specifically for carbon dioxide capture. These efforts can be
summarized as: 1) improving the gas-liquid contact surface area; 2) improving
the absorbing liquid formulation to increasing reaction kinetics and decreasing
reaction heats; and 3) process optimization.
Project Objectives:
Development of a technology using a micro-porous hollow fibre membrane module
as gas-liquid contactor to achieve efficient low cost CO2 capture from flue gas
for CBM and other application.
Initiate the application of this technology for post-combustion
CO2 capture from flue gas (a), and the pre-combustion gas cleaning from natural
gas (b).
Engage the potential of incorporate this technology with current
available liquid absorption processes.
Partners:
Alberta Newsprint Company
University of Waterloo
Project Manager:
Brent Lakeman
Alberta Research Council
Email: lakeman@arc.ab.ca
Non-Thermal Plasma Multi-Pollutant
Control Technology for Flue Gas Pre-Cleaning before Amine-CO2 Scrubbing
Operation
Description:
This proposed research work will explore the use of the radical shower plasma
generating technology as a flue gas cleaning technology prior to an amine
reactor as an effective control technology to remove SO2, NOx and Hg from the
coal-fired flue gas. This technology has been identified as a cost effective
method to clean flue gas by the utilities.
In this program a plasma radical shower reactor will be designed
and tested on a coal-fired flue gas stream to obtain the radical shower plasma
multi-pollutant control performance versus the operation conditions such as
flue gas temperature, plasma discharge voltage and reagent amount.
Amine-CO2 scrubbing technology is one of the technologies being
developed and evaluated as a future CO2 mitigation technology platform by
Canadian Power Utilities. To achieve acceptable performance from the amine-CO2
scrubbing technology, the pollutants in the flue gas, such as SO2 and NOx, must
be removed prior to the amine reactor in order not to diminish the effectiveness
of the amine solution.
Partners:
SaskPower
Ontario Power Generation (OPG)
Nova Scotia Power (NSPI)
Project Manager:
Quan Zhuang
CanmetENERGY, Ottawa
(ON) Research Centre
Email: qzhuang@nrcan.gc.ca
Zero Emission Oxy-Fuel Combustion Technologies for
Clean Fossil Fuels
Description:
The majority of current combustion technologies for fossil fuels result in the
emission of copious amounts of carbon dioxide, water vapor, and other
pollutants such as oxides of nitrogen and unburned hydrocarbons. All of these
emissions, with the possible exception of water vapor, are emerging as threats
to the long-term health of the planet. The "Zero Emission Oxy-Fuel
Technologies for Clean Fossil Fuels" is focused on developing new and
enabling technologies and research infrastructure that could be utilized to
reduce GHGs and other pollutants in general, and CO2 in particular, of fossil
combustion systems to near zero in short/medium range and to zero in long
range. This would be complemented by the production of useful industrial
by-products or benign discharge of solid and liquid wastes to land and water.
The primary focus of this project will be geared to the
development of the "second generation" of zero emission, oxy-fuel
combustion technologies for natural gas, oil and coal that will have higher
efficiency and significantly lower capital and operating costs.
Partners:
O2/CO2 Consortium
Carleton University
Project Manager:
Kourosh Zanganeh
CanmetENERGY, Ottawa
(ON) Research Centre
Email: kzangane@nrcan.gc.ca
Injection
Degree of Coal Swelling and Loss of
Permeability Associated with Sequestration of CO2, H2S and Flue Gas - Selecting
Optimum Coals for Sequestration
Description:
Coal seams are being currently investigated as potential sequestering sites for
carbon dioxide. Coal is a microporous material that possesses a very high
surface area and hence sorption capacity for gas. In the subsurface coal,
commonly has economically significant amounts of sorbed methane (coalbed
methane). Because coal has a greater sorption affinity for carbon dioxide than
methane, injection of carbon dioxide with simultaneous production of methane
may be viable.
Project Manager:
Email: bustin@unixg.ubc.ca
Enhancing the Capacity of CO2 Storage
by Removing the Remaining Water in Depleted Oil Reservoirs
Description:
The objective of this proposal is to develop CO2 storage injection techniques
for efficiently displacing and producing the water retained in reservoirs after
an EOR process, thus enhancing the CO2 storage capacity of these reservoirs.
Depleted oil reservoirs with different conditions and oil production histories
will be investigated for CO2 storage injection. This project will find the
answer to the question: how should CO2 be injected in different reservoirs to
achieve a maximum storage capacity? The techniques to be developed in this
project are crucial for CO2 storage injection in a depleted oil reservoir once
it is selected for CO2 storage.
Partners:
Saskatchewan Research Council
Petroleum Technology Research Centre
Duration: April 1, 2004 - March 31, 2008
Project Manager:
Email: Mingzhe.Dong@uregina.ca
Experimental Investigation of CO2/Coal
Interaction
Description:
The objective of the project is to investigate the interaction between dense
(high pressure) CO2 and coal, for the purpose of CO2 storage and enhanced
coalbed methane recovery.
Injecting CO2 into coal seams has been discussed as one method of
disposing of greenhouse gases. There has also been interest in using CO2 for
enhanced coalbed methane (ECBM) recovery, thereby recovering natural gas while
simultaneously disposing of greenhouse gases. The Alberta Research Council has
led the way in investigating ECBM in
Gaseous CO2 is stored in coal by physical adsorption, just as
methane is. CO2 adsorption capacities are higher than methane adsorption
capacities by a factor of two or more, depending on coal rank. This would
suggest coal as an attractive geologic medium for CO2 storage.
Partners:
TIPM Laboratory
Project Manager:
Apostolos Kantzas
TIPM Laboratory
Email: akantzas@ucalgary.ca
Optimizing CO2 Storage in Oil
Reservoirs
Description:
The objectives of this Research Project are:
1.
Increase
the CO2 storage in oil reservoirs at the enhanced oil recovery stage by
changing the field operating parameters (to the practical extent possible) with
the aim of optimizing the total oil production revenues and potential CO2
storage credits.
2.
Evaluate
the various options for increasing CO2 storage at the post-enhanced oil
recovery stage with economic constraints.
3.
Evaluate
the overall storage capacity if CO2 injection begins at an early stage of the
oil development cycle (i.e. before primary and/or water flood)
In the short to medium term, storing CO2 in oil reservoirs should
be a clear favourite among the many options of geological storage. The reasons
for this are many, namely: (1) the reservoir is well defined, as it has records
of production history; (2) reservoir access is certain, as the ownership is
known; (3) the integrity of the reservoir is assured, as it has stored
hydrocarbons before and therefore it should be capable of storing CO2 as well;
and (4) it produces an oil revenue stream that can potentially offset the cost
of storage. However, when it comes to CO2 storage capacities, the numbers
become less certain. We believe more research efforts are required to
understand the mechanisms of oil production and CO2 storage and the economic
interplay between the two. Essentially, the species: oil, water, CO2 and other
mixed gases (if present) must compete for the pore space. In addition, the
issues are complicated by the fact that at each stage of the oil development
cycle (primary, water flood and enhanced oil recovery) the occupants of the
pore space change depending on production strategies.
Partners:
Alberta Research Council (ARC)
CMG
Project Managers:
Sam Wong
Alberta Research Council
Email: wong@arc.ab.ca
Investigations on the Greenhouse Gas
Storage Capacity of Oil Reservoirs
Description:
This project focuses on CO2 and flue gas storage in naturally fractured
reservoirs. As a specific example, the naturally fractured Midale field
operated by Apache Canada Ltd. will be used. The optimal storage condition is
the major concern but the increase of oil recovery during the operation will
also be considered from the project cost and Apache’s on-going investments
points of view. In addition to the Midale field, there are several more potential
depleted oil reservoirs in
We postulate that the rock matrix in naturally fractured
reservoirs is a convenient long term storage medium for CO2 . Therefore, the
objectives are to:
- identify the effects of the matrix
properties (permeability, wettability, amount of water and size) and
- clarify the importance of the content
of the CO2 in the injected gas (pure versus impure CO2), and the state of
the CO2 (supercritical or subcritical) on the storage of CO2, and
- identify the CO2 entrapment (physical,
chemical, and physicochemical) mechanisms and
- optimize the storage process based on
the injection rate of CO2.
In all these efforts, incremental oil recovery would be a concern
as it is the key parameter to offset the cost of the process.
Partners:
Apache Canada Ltd.
Natural Sciences and Engineering Research Council (NSERC)
Duration: Jan 2006 - Dec 2008
Project Manager:
Tayfun Babadagli, PhD, PEng
Professor of Petroleum Engineering
University of
email: tayfun@ualberta.ca
Integrated Systems
Canadian Clean Power Coalition (CCPC)
Description:
The CCPC is an association of responsible, leading Canadian energy companies,
as well as the Government of Canada and provincial governments. Members also
include
Its aim is to secure a future for coal-fired electricity
generation, within the context of
Phase I was completed in early 2004 with the assessment of the
technologies to be used in the demonstration. Phase II (technology gap
analysis) commenced in spring 2004 and was completed in 2007. Phase III is
expected to commence in 2008. The CCPC’s work has led to spin-off projects by
SaskPower and EPCOR where more detailed engineering has been done on potential
demonstration projects.
Partners:
Basin Electric Power Corporation (BEPC)
EPCOR
Electric Power Research Institute (EPRI)
SaskPower
Sherritt
TransAlta
Nova Scotia Power
Commenced: 2001 - on-going
Project Manager:
Bob Stobbs
E-mail: bstobbs@saskpower.com
Website: www.canadiancleanpowercoalition.com
Development of a Generalised Systems
Scheduling Framework for the Operation of Generating Stations with CO2
Constraints in
Description:
Our long term research objectives are to develop optimal national solutions to
effectively implement carbon dioxide reduction, capture, transportation, and
storage in
Partners:
Ontario Power Generation
Project Manager:
Email: pdouglas@uwaterloo.ca
The CO2 Hub
Description:
Advancement of a Multi-Tiered Online Auction Website Designed to Foster the
Development of a Sustainable Carbon Dioxide (CO2) Market.
Duration: on-going
Project Manager:
Michelle Heath
E-mail:information@theco2hub.com
Website: www.theco2hub.com
Development of Zero Emissions Direct
Ammonia Fuel Cells for Efficient CHP
Description:
The main objective of the project is to develop a zero emissions solid
electrolyte fuel cell that operates directly on ammonia. Targeted industrial
applications are in stationary decentralized power generation (DG), combined
heat and power (CHP), and industrial refrigeration. This project also aims to
conduct a field trial demonstration using alkaline or conventional solid oxide
fuel cells, in order to assess the technical barriers related to integrating a
fuel cell with CHP and industrial refrigeration. The field trial/feasibility studies
will help to achieve early adaptation of the technology. By 2025 in
Project Manager:
Andrew McFarlan,
CanmetENERGY, Ottawa
(ON) Research Centre
Email: anmcfarl@nrcan.gc.ca
Description:
One leading candidate method for geological storage of CO2 is enhanced coal bed
methane (ECBM). This CO2 storage option possesses a unique advantage over most
other methods in that it generates incremental revenue from gas production that
can offset a significant portion of the costs of CO2 capture, transport and
storage. In the future when price signals are defined for CO2 storage credits,
it will become advantageous to maximize CO2 storage. Two important questions
must be addressed before this is likely to come about. What are the costs of
CO2 capture, transport and ECBM storage and what are the economics of the
entire process under different market based CO2 credit scenarios? These are
difficult questions to answer because of the complex nature of the problem.
Quantification of the economic viability of ECBM CO2 sequestration is a
necessary precondition to acceptance of the technology and commencement of
industry sponsored pilot projects and commercial ventures.
This project involves the development of a computer model that
will simulate the overall economics of capturing CO2 from emission point
sources, transporting the CO2 via pipeline to coal beds, injection of the CO2
to induce production of gas and sequester the CO2 in the coal bed.
Partners:
Alberta Energy & Utilities Board (EUB)
Energy Navigator Inc.
Computer Modeling Group Inc.
SNC Lavalin
Duration:
NRCan funding ended March 31, 2008
Model development complete, working out integration issues with last partner,
Energy Navigator Inc. Bench-marking and calibration of the model will continue
into the spring
Project Manager:
Brent Lakeman
Alberta Research Council
Email: lakeman@arc.ab.ca
International Performance
Assessment Centre for Geologic Storage of CO2 (IPAC-CO2)
IPAC-CO2 will assess and advise on CCS projects around the
world and share findings with other research organizations.
IPAC-CO2 is an independent, credible and non-aligned
organization that addresses the growing demand for expertise in sub-surface
reservoirs for the geological storage of CO2. In addition to evaluating performance and
risk issues and assessing proposed projects, IPAC-CO2 will:
- Network
internationally to share and build on the findings of other academic and
public organizations and institutions with CCS expertise;
- Interact
with key stakeholders to identify emerging issues and ensure effective and
acceptable risk assessment techniques are developed, applied and
communicated;
- Create
communications to inform the public and build broad acceptance of CCS;
- Develop
a pool of qualified personnel in the areas of performance and risk
assessment.
For more information on how to become involved in this leading-edge
centre, contact:
Dr. Malcolm Wilson, Director
Office of Energy and Environment
Email: Malcolm.Wilson@uregina.ca
National Intelligence Centre on Near
Zero Emissions Clean Coal Technologies
Description:
In an effort to avoid duplication and foster collaboration in
advancing near zero emission clean coal technology in Canada, the Clean Coal
Technology Roadmap has advised that a web-based "National Intelligence
Centre" be established to offer Canadian stakeholders access to screened
information on clean coal technology developments that are happening
throughtout the world and presented in a concise way as being relevant to
Canada's clean coal strategic needs.
Project Manager:
Kourosh Zanganeh
CanmetENERGY, Ottawa
(ON) Research Centre
Email: kzangane@nrcan.gc.ca
Website: http://canmetenergy.nrcan.gc.ca/eng/clean_fossils_fuels/clean_coal/knowledge_centre.html
Optimisation of Integrated CO2 Capture,
Transportation and Storage in
Description:
Our long term vision for this research is to propose optimal national solutions
to effectively implement carbon dioxide reduction, capture, transportation, and
storage.
These carbon management solutions shall include various processes
associated with decarbonisation; carbon dioxide capture, transport, and
sequestration; the use of new and/or improved fuel sources (nuclear, fossil
fuels, renewables); improved efficiency of energy conversion and utilization;
economic and market analysis; and alternative
This proposal builds on current work of a number of our graduate
students and also on other contracts and grants we have with NRCAN, OPG, and
NSERC to develop modules for CO2 capture and sequestration processes. These
modules include various technologies ranging from chemical absorption to fuel
cells to the use of membranes.
Partners:
Ontario Power Generation (OPG)
University of Waterloo
Project Manager:
Email: pdouglas@uwaterloo.ca
Aquistore
Aquistore is an
integrated CO2 Capture, Transport and Storage project that will run for at
least five years to investigate the feasibility of storing CO2 in deep saline
aquifers in
Approximately 500
tonnes/day of CO2 will be captured from the CCRL refinery on the outskirts of
Regina, Saskatchewan, transported by pipeline and injected to about 2200 m
depth in a saline water-bearing porous geological formation. An extensive program designed to characterize
the geological characteristics of the injection site and to monitor the stored
CO2 is being implemented.
The Petroleum Technology
Research Centre (PTRC) in
For
more information please contact:
Steve Whittaker
Senior Project Manager
Petroleum Technology
Research Centre
(306) 787-9910
Email: Steve.Whittaker@ptrc.ca
Or
Kyle
Worth
Project Manager
Petroleum Technology
Research Centre
Phone:(306) 787-5623
Email:
kyle.worth@ptrc.ca
MMV (Monitoring, Measurement &
Verification)
Analysis of Acid Gas Injection Sites in
Description:
Deep injection of acid gas (CO2 and H2S) produced at gas plants in
Partners:
Fekete Associates Inc
Apache Canada Ltd.
Conoco-Phillips Canada
Bearspaw Petroleum Ltd.
University of Calgary
Duration: April 1, 2006 - March 2008
Project Manager:
Dr. Stefan Bachu
Energy Resources Conservation Board
stefan.bachu@ercb.ca
CO2 Monitoring at Penn
Description:
The Penn West CO2-EOR Monitoring Pilot Project is a key initiative under the
federal-provincial Energy Innovation Network (EnergyINet) CO2 Management
Program. The project will further advance the understanding of the fate of CO2
injected into petroleum reservoirs and enhance our understanding of the role
that geological CO2 storage can play in responding to the risks of climate
change. This project, which is utilizing leading-edge CO2 monitoring tools and
applications, will add to the growing body of knowledge that is being developed
in
- Baseline geology and hydrogeology
- Baseline leakage
Reservoir surveillance
- Environmental monitoring
- Geophysical monitoring
- Reservoir testing
- Geochemical monitoring
- Reservoir simulation
Partners::
Alberta Energy Research Institute
Western Economic Diversification
Alberta Environment
Penn West Energy Trust
University of Alberta
University of Calgary
Alberta Energy and Utilities Board
Duration:
To be completed by December 2008
Project Manager:
Brent Lakeman
Alberta Research Council
Email: lakeman@arc.ab.ca
Website: www.pennwest.com
IEA GHG Weyburn CO2 Monitoring and
Storage Project
Description:
The IEA GHG Weyburn Monitoring and Storage Project is an international research
and demonstration project intended to establish the degree of security with
which greenhouse gases, particularly CO2 can be sequestered in geological
formations during large scale, commercial, EOR operations. This will be
accomplished through the scientific mapping of the movement of CO2 in the
reservoir, and technical prediction of the future long-term storage and
migration characteristics of the CO2. It builds upon a $1.5 billion commercial,
world-class, CO2-EOR operation at
Partners:
Natural Resources Canada
US Department of Energy
Saskatchewan Industry and Resources
Alberta Energy Research Institute
European Community
IEA GHG R&D Programme
EnCana Corporation
SaskPower
Nexen Canada
Total
Chevron Texaco
BP America
Dakota Gasification Co.
TransAlta Utilities Corp.
Engineering Advancement Association of Japan
(ENAA)
Duration: Phase I: September 2000 - July 2004; Phase II: July 2004
- July 2008
Project Manager:
Frank Mourits,
Projects Manager
CanmetENERGY, Ottawa
(ON) Research Centre
E-mail: fmourits@nrcan.gc.ca
Website
Pembina-Cardium CO2-EOR Monitoring
Pilot
Description:
In
late 2004, a CO2 EOR flood pilot within the Cretaceous Cardium
Formation within the Pembina oil field in
Ultimately, the Pembina Oil Field in
For more information on this project please
contact:
Brent Lakeman
Near and Far Field Effects of CO2
Injection in Geological Formations: Toward Integrated Monitoring and Modelling
Protocols
Description:
Tthe overarching philosophy of this proposed research project is to establish a
framework of integration between and within the INJECTION, RELIABILITY and
MONITORING activities and to pursue a research program that integrates
experimental, numerical and field observation (monitoring) approaches to meet
the project needs.
The modelling approaches adopted in this research project have worldwide
applicability. Research on uncertainty and upscaling issues will assist not
only Canadian geological storage proponents but will also assist the
international community in addressing these issues.
The experimental based programs have a smaller focus or extent
because formation samples that are tested and the downhole cement formulations
are generally characteristic on the
Monitoring technologies and protocols would have far-reaching
impacts with the potential to significantly influence how geological storage
projects are monitored world-wide.
Partners:
Alberta Research Council
University of Alberta
University of Calgary
CanmetENERGY, Ottawa
(ON) Research Centre
University of Western Ontario
Project Manager:
Brent Lakeman
Carbon and Energy Management
Alberta Research Council
E-mail: lakeman@arc.ab.ca
Website: www.ieagreen.org.uk/weyburn5.htm
Timelapse seismic monitoring of CO2
injection into Ardley coals (CSEMP project)
Description:
Repeated surface and down hole 3D-3C reflection seismic surveys are proposed at
an enhanced coalbed-methane (CBM) production site operated by Carbon Storage
and Enhanced Methane Production (CSEMP) and located in Alberta. Baseline
surveys to image the Ardley coals are currently planned and will be executed
within the first half of 2005. These will provide an accurate depth model of
the coals in the survey area, and detect lateral facies changes in the coals
that may inhibit gasification, and provide baseline measurements against which
later datasets will be compared.
The sequestration of CO2 in porous subsurface reservoirs is both
technologically possible and financially attractive. Geological sequestration
of CO2 involves pumping fluid CO2 underground and trapping it in porous rocks,
in the same manner that hydrocarbons are trapped. This is possible in depleted
oil and gas reservoirs, coal beds, and high-salinity aquifers (Wawerski and
Rucnicki, 1998).
Partners:
Alberta Energy Research Institute (AERI)
Weir-Jones
CSEMP consortium
Project Manager:
Email: lawton@ucalgary.ca
Oxy-fuel Combustion
The CANMET CO2 Consortium
Description:
Development of Oxy-fuel combustion technology for CO2 capture and storage.
Currently in Phase 9, the program focuses on development and
demonstration of advanced near-zero emission fossil fuel technologies with the
goal to improve the overall economics and performance of these systems. CANMET
is the primary performer of the work. The research program aims at gaining
better understanding of combustion, heat transfer and pollution forming
behavior in different oxy-fuel combustion modes, system integration and cycle
development for O2/FGR, pure O2 combustion, and hydroxy-fuel combustion of
fossil fuels. The program also includes the development of novel integrated
multi-pollutant control strategies for NOx, SOx, Hg, and particulate with
optimization, integration and low-grade heat recovery, advanced zero-emission
gas turbine cycles and integration with fuel cells.
Partners:
Ontario Power Generation
SaskPower
Government of Canada
Government of Alberta
Babcock and Wilcox
US Dept. of Energy
CCP2 [ a consortium of 8 major oil & gas companies, US DOE, European
Commission, The Research Council of Norway]
Commenced: 1994 - on-going
Project Manager:
Kourosh Zanganeh
CanmetENERGY, Ottawa
(ON) Research Centre
E-mail: kzangane@nrcan.gc.ca
Description:
We will generate experimental data needed for designing larger direct carbon
fuel cells (DCFC) by building a small experimental unit and testing the
performance of direct carbon conversion in catalytically activated molten
carbonate mixtures.
Recent R&D showed carbon could be electrochemically oxidized
to CO2 using molten carbonate ions as the oxygen carrier. Electrochemical
oxidation of carbon in carbonate salts does not consume the electrolyte
(carbonate salts). Between mid- and late-1970's USDOE researched carbon/air
fuel cells using molten carbonate electrolytes but like many other coal
research, due to the abundant supply of cheap crude oil, this work was
discontinued too. Only in recent years some American companies, DOE, and
European research centres began to re-explore the technology.
Partners:
GenCell
Project Manager:
Michio Ikura
CanmetENERGY, Ottawa
(ON) Research Centre
Email: mikura@nrcan.gc.ca
Electrical Power Production from
Circulating Fluidized Bed Combustor (CFBC) Boilers with CO2 Capture
Description:
The objectives of this project are to demonstrate CO2/O2 firing in a CFBC
(circulating fluidized bed combustion) boiler using the 1MWt CETC pilot-scale
CFBC boiler with a range of Canadian feedstocks. The program will allow the
concept to be fully tested at a reasonable pilot scale level, verifying that
low conventional emissions (NOx, SOx, CO, mercury and unburned hydrocarbons)
can be achieved alongside the production of a near pure CO2 stream for
sequestration.
This work will allow Canadian utilities to test Canadian fuels,
and to verify that a CO2/O2 strategy can be applied to an advanced CFBC boiler.
A commercial plant is anticipated by 2015.
Potential carbon dioxide reductions are on the order of 1.5e6
Mt/yr by 2015 and 8e6 Mt/yr by 2025.
Project Manager:
Ben Anthony
CanmetENERGY, Ottawa
(ON) Research Centre
Email: banthony@nrcan.gc.ca
Integrated High-Efficiency Oxy-Fuel
Combustion Process for CO2 Capture Comprising Slagging Combustor, Air Separation,
and Gas Turbine Technologies
Description:
More than 90% of the world's primary energy requirements are met by fossil
fuels. Current fossil fuel combustion technologies emit large amounts of carbon
dioxide, oxides of nitrogen and sulphur, unburned hydrocarbons, and particulate
matter which are detrimental to human health and pose a threat to the
environment. The objective of this project "Integrated High-Efficiency
Oxy-Fuel Combustion Process with CO2 Capture Comprising Gas cooled slagging combustor,
Air Separation, and Gas Turbine Technologies" is to develop a new second
generation oxy-fuel combustion process with near zero emissions and higher
efficiency performance.
Carbon dioxide is emitted to the atmosphere in the flue gas of
power stations and industrial plants such as blast furnaces and cement kilns.
The CO2 concentration in power station flue gas is about 4 percent (by volume)
for natural gas-fired combined-cycle plants and about 14 percent (by volume)
for pulverized coal-fired boilers. Flue gas could be compressed and stored
underground, but the energy required for compression would be large given the
amount of nitrogen in the flue gas stream. Additionally, the underground
reservoirs would quickly become full. It is therefore necessary to separate CO2
from the flue gas before injecting the CO2 into the ground.
Partners:
Federal Institute for Materials Research and
Testing in Germany (BAM)
Korean Institute of Energy Research
Carleton University
B&W US & Canada
Project Manager:
Kourosh Zanganeh
CanmetENERGY, Ottawa
(ON) Research Centre
Email: kzangane@nrcan.gc.ca
Performance Assessment and Siting of
CO2 Storage in Coalbeds, Combining Probabilistic and Deterministic Methods
Description:
Computational methods to assess CO2 storage concepts can be divided into two
broad categories. Reservoir simulator models are generally used to evaluate the
complex physical-chemical and fluid flow requirements within the storage
formation (e.g., coal beds, oil reservoirs, etc.). These numerical models are,
however, computationally too intensive to be practical to quantify the
uncertainty associated with potential leakage of CO2 into and within the
geosphere surrounding the proposed reservoir. To solve this type of
process-driven problem, a methodology known as probabilistic risk assessment
(PRA) was developed. In essence, the complexity and the uncertainty associated
with the geosphere characteristics are subsumed into statistical functions.
Model parameters can be defined as probability distribution or density
functions (PDF) and
Partners:
LeNeveu Simulations
Duration:
Project completed March 2007
Project Managers:
Marsha I. Sheppard
ECOMatters Inc.
Email: sheppardm@ecomatters.com
Physical Model Studies of Wellbore
Stability for Underground CO2 Storage
Description:
A great number of studies conducted on assessing the long-term fate of carbon
dioxide stored in hydrocarbon reservoirs have recognized wellbores as the
single most important potential source(s) of CO2 leakage. Hence, the
reliability of any underground storage of CO2 in hydrocarbon reservoirs is
directly related to the reliability of the wellbores.
The objective of this proposal is to build a physical model of a
wellbore in laboratory. This set up will be used for simulating the reliability
and integrity of wellbores for carbon dioxide injection, storage and well
abandonment practices. To the best of our knowledge, this would be the first
research capability of this kind in
The outcome of this proposal will have a direct and significant
effect on any project(s) designed for underground storage of carbon dioxide in
depleted oil and gas reservoirs or combined CO2 storage/EOR processes. This
study will provide guidelines for more effective methods of well abandonment at
the end of CO2 flooding, which would lead to storing CO2 more effectively.
Hence, the results obtained from this research would be of great interest for
government regulatory agencies in order to develop more effective guidelines
for well completion and abandonment processes.
Partners:
Petroleum Technology Research Centre (PTRC)
Weyburn Monitoring Project
University of Regina
Project Managers:
Email: Koorosh.Asghari@uregina.ca
Storage Assessment
The Alberta Saline Aquifer Project
(ASAP)
The Alberta Saline Aquifer Project (ASAP) is
an industry initiative being led by Enbridge Inc. to identify deep saline
aquifers in
Saline aquifers are underground formations containing brine or salt water
that is not suitable for agricultural purposes or for drinking. Once suitable
aquifers have been identified, carbon dioxide will be injected into the deep
formations, and the integrity of the process will be closely monitored.
Project Phases
Phase 1: 2008
·
Identify 3
specific saline aquifer locations.
·
Design and
cost (± 30%) a sequestration demonstration
including CO2 compression and transportation.
·
Prepare
preliminary application for saline lease/permit and approval for demonstration
pilot.
Phase 2: 2009 - 2012
·
Construct
& operate a demonstration pilot (1,000 – 3,000 tonnes/day).
Phase 3: 2013+
·
Expand to
commercial operation
Project Manager:
Rocco Vita, Senior Manager, Alternative and Emerging Technology
403-231-5936
rocco.vita@enbridge.com
info.albertaasap@enbridge.com
Website: http://www.albertaasap.com/
Cassiar Tailings Mineralogy, Toxicity
and Suitability for CO2 Sequestration, (an evaluation of)
Description:
The project will evaluate the efficacy of natural carbonation reaction
involving atmospheric CO2 and serpentine mine tailings at Cassiar as a
potential natural analogue for commercial CO2 sequestration. It will also
determine the amphibole content of the tailings. Fibrous amphibole can cause
asbestosis. Even small quantities in the tailings would complicate handling of
the tailings, detrimental to its use in commercial CO2 sequestration. It is a
collaborative project between the
This academic study has a field and laboratory component. This
project will examine, sample, and analyze the tailings pile at Cassiar to
determine if carbonation is proceeding in the natural environment, and document
the source of crystallographically bound CO2.
Depending on future funding and industry interests, this preliminary study may
lead to demonstration or commercial research project(s).
Complete consumption of the tailings pile would sequester
approximately 8 million tonnes of CO2, but the technological requirements of
conversion are not yet known.
Duration:
completed
Project Manager:
Dr. Greg Dipple
University of
email: gdipple@eos.ubc.ca
CBM/ECBM Reservoir Characterization
Methodology
Description:
This proposed research program will develop a detailed reservoir
characterization methodology directed at hydromechanical categorization of coal
seams. The methodology is aimed at understanding, identifying, and quantifying
the key hydromechanical properties controlling primary coalbed methane recovery
(CBM), enhanced coalbed methane recovery (ECBM), and geological CO2
sequestration in coalbeds.
Partners:
Alberta Energy Research Institute (AERI)
Alberta Research Council (ARC)
Natural Sciences and Engineering Research Council
(NSERC)
Duration:
T& I Phase ends March 31 2008
PhD Research ends December 2009
Project Manager:
Dr. Rick Chalaturnyk,
email: rjchalaturnyk@ualberta.ca
CO2 Storage by
Mineral Carbonation Reactions: Kinetic and Mechanical Insight from Natural
Analogs
Description:
This project examines geologic analogs to mineral carbonation reactions to
assess the feasibility of permanently storing CO2 in subsurface magnesium
silicate rocks. Project outcomes include establishing the mechanical and
hydrologic consequences of mineral carbonation reactions, documenting reaction
paths and mechanisms, and constraining the timing and rates of carbonation
reaction in bedrock CO2 alteration systems. Field site is Atlin, northwest B.C.
Laboratory work undertaken at the
Duration:
Completed
Project Manager:
Dr. Greg Dipple
University of
email: gdipple@eos.ubc.ca
Website: Mineral Carbonation at
UBC
Fixation of Greenhouse Gases in Mine
Residues
Description:
This academic project will examine the feasibility of storing atmospheric CO2
in historical and active mine residues. Research conducted at the
The study involves fieldwork and sampling, laboratory and
experimental analysis, and geochemical modelling. It will examine the rates and
processes of natural fixation of atmospheric CO2 in a variety of mine
residues.. Depending on future funding and industry interests, this preliminary
study may lead to demonstration or commercial research project(s).
Storage capacity is dictated by the size of mine residues. Average
size mining operations could sequester hundreds of thousands to millions of
tonnes of CO2.
Project Manager:
Dr. Greg Dipple
University of
email: gdipple@eos.ubc.ca
Website: Mineral Carbonation at
UBC
Geologic sequestration of CO2 and
simultaneous CO2 sequestration / CH4 production from natural gas hydrate
reservoirs
Description:
Project Objectives:
1.
Conduct
a program of fundamental laboratory research to establish the porous media
controls on CO2 hydrate formation in geologic media, and to investigate the
thermodynamic conditions favouring the displacement of CH4 from methane hydrate
by injection of CO2.
2.
In
conjunction with drilling of the 2002 Mallik International Gas Hydrate
Production Research Well, conduct field investigations of the physical,
geothermal, and geochemical characteristics of an existing gas hydrate-bearing
reservoir.
3.
Using
archived geologic data, identify and characterize a suite of candidate marine,
lacustrine and Arctic reservoirs suitable for geologic sequestration of CO2.
4.
Assess
the feasibility of geolologic sequestration of CO2 as gas hydrate, with respect
to both terrestrial and marine reservoirs in
5.
Evaluate
the feasibility of co-production of methane gas in conjunction with CO2
injection in existing natural gas hydrate reservoirs.
Duration: 4 years
Project Managers:
Fred Wright
Email: fwright@nrcan.gc.ca
Scott Dallimore
Email: sdallimo@nrcan.gc.ca
Geological Survey of Canada, Natural Resources Canada
Hydrate technology for gas separation and CO2
capture
Description:
The objective of this project is to develop a new approach to gas separation
using hydrate technology. The main aim will be to capture CO2 from flue gas,
although other separations also are possible, and precombustion applications
(CO2/H2 separation).
Hydrate technology has long been considered a way of separating
gases. This is due, in part, to the very high gas holding capacity of hydrates
(a volume of hydrate can capture ~ 160 volumes of gas at STP), water as a cheap
working fluid, and the modest energy requirements for hydrate
formation/decomposition. However, processes using hydrate technology have been
developed to the pilot plant stage only rarely (eg methane hydrate formation
for natural gas storage and transport), as several steps are unfavourable –
reactions kinetics are slow because of the need for mixing the relatively
insoluble gas with water, and the need to separate the product hydrate from
free water. We have now shown that by dispersing water on a porous medium
the reaction can be carried out in a reactor without agitation or liquid-solid
separation, that the reaction kinetics and hydrate yield are improved
considerably and that the separation efficiency is similar to that for the reaction
in a stirred reactor containing bulk water.
Project Manager:
John Ripmeester,
National Research Council
Email: john.ripmeester@nrc-cnrc.gc.ca
PTRC Studies on CO2 Utilization and
Extraction
Description:
Researchers at the Petroleum Technology Research Centre (
Partners:
Petroleum Technology Research Centre
Saskatchewan Research Council
Duration: 2002 - 2007
Project Manager:
Brenda Tacik
Energy Branch
Saskatchewan Research Council
E-mail: tacik@src.sk.ca
Shell Quest
The first step for Shell Quest involves
drilling three test wells. Starting in 2008 and continuing into 2009, the test
well program will use conventional drilling techniques to drill more than two
kilometres into the subsurface. Injection of CO2 (supplied via truck) into the
permeable rock and salt water located at these depths will follow. Layers of
impermeable rock above the formation prevent the CO2 from rising to the surface
and escaping into the atmosphere.
The development plan for Shell Quest depends on:
·
Outcome of the test well
program;
·
regulatory processes;
·
ability to meet sustainable
development criteria;
·
economic feasibility;
·
final project costs; and,
·
ongoing consultation with
key stakeholders.
For more information on this project:
Web: http://www.shell.ca/home/content/ca-en/about_shell/what_we_do/oil_sands/quest/dir_quest.html
Email: quest-info@shell.com