By John Kemp
LONDON Nov 27 For the past year, 1,000 metric
tonnes a day of carbon dioxide from the Archer Daniels Midland
ethanol plant at Decatur have been pumped into a sandstone
reservoir 7,000 feet beneath the corn fields of Macon County,
By its first anniversary last week, the project had injected
317,000 metric tonnes of carbon dioxide (CO2), almost a third of
the planned total of 1 million tonnes.
Following intensive monitoring, the U.S. Energy Department
pronounced that the reservoir "is performing as expected, with
good injectivity, excellent storage capacity, and no significant
adverse environmental impacts."
The Illinois Basin-Decatur Project is the first
industrial-scale demonstration project to inject CO2 directly
into a saline aquifer in the United States. It is one part of
the Energy Department's ambitious programme to cut emissions by
demonstrating and commercialising technology for carbon capture
utilisation and storage (CCUS).
The eventual goal is to capture most of the CO2 emitted from
coal and gas-fired power plants, cement kilns, steelworks and
ammonia plants, locking it away underground in depleted oil and
gas fields, uneconomic coal seams, and salt water aquifers, so
it is not is not released into the atmosphere.
Technology for storing CO2 into depleted oil and gas fields
is relatively well understood. But depleted oil and gas fields
account for only a relatively small share (around 7 percent) of
the total storage capacity identified in the United States. The
big prize would be storing CO2 in salt water aquifers deep
Saline aquifers account for 85 percent of the country's
potential underground carbon storage capacity, according to the
"North American Carbon Storage Atlas" published by the U.S.,
Canadian and Mexican governments earlier this year.
The Illinois Basin-Decatur Project is therefore vital to
prove significant volumes of CO2 can be safely injected and
stored deep underground in saline formations, without escaping
to the surface or causing seismic activity.
"The demonstration-scale project provides the opportunity to
test how a real-world injection operation will perform where
brief interruptions -- such as planned maintenance of the
compression equipment and various well tests, as well as
required by regulations -- will occur," the Department's Fossil
Energy Office explained in a statement.
DILUTE CO2 PROBLEM
The Energy Department is investing heavily in projects to
demonstrate all aspects of CCUS. But the biggest stumbling block
remains the high cost of capturing the CO2 in the first place.
Initial capture accounts for more than half of the total cost of
To be suitable for transportation by pipeline and injection
underground, the CO2 needs to be fairly pure.
Ethanol distilleries, cement factories, ammonia plants and
steam methane reformers all produce fairly concentrated CO2. It
is relatively easy and economical to strip the CO2 from the
waste gas stream, purify and concentrate it, and then compress
it into a liquid for transport by pipeline or tanker car to the
But more than 30 percent of all U.S. emissions come from
coal-fired power plants, with more from gas-fired generators.
The CO2 content in the exhaust streams from coal and
gas-fired power plants is much lower -- typically just 3-15
percent by volume, compared with 15-30 percent for a cement
plant. Separating the CO2 from the other waste gases at a power
station, purifying it and compressing it is vastly more
Engineers have focused on three options for capturing CO2
from power generators: pre-combustion capture, post-combustion
capture, and oxyfuel.
Pre-combustion efforts centre on integrated gasification and
combined cycle (IGCC) plants. Fuel (natural gas, coal or
biomass) is partially oxidised to produce synthesis gas (a
mixture of hydrogen and carbon monoxide). The synthesis gas is
then reacted with steam to produce a mixture of hydrogen and
The hydrogen is burned in a traditional jet turbine and the
waste heat is used to raise steam and drive a secondary turbine.
The concentrated stream of CO2 produced as a co-product can be
handled fairly economically.
The problem is that IGCC plants are exceptionally expensive
to build even without the addition of CCUS technology. Duke
Energy's Edwardsport IGCC plant, which is currently under
construction, will cost around $3.3 billion for a 618 megawatt
The other difficulty is making all the different components
(gasification, power production and CO2 capture) work
efficiently together. For the most part, power generators have
given up on IGCC as too complicated and costly.
Many generators are drawn to oxyfuel combustion. Oxyfuel is
the least developed of the three CO2 capture processes but the
one the electricity industry likes best because it would be a
fairly simple adaptation of existing power plants and avoids
lots of complicated and unfamiliar chemical processing.
Rather than burning coal, gas or biomass in air (which is
mostly nitrogen), oxyfuel burns coal or gas in a stream that
contains a much higher than normal volume of oxygen. The result
is a waste gas that contains a much higher volume of CO2. The
downside is that oxygen must be separated in the first place,
which is enormously energy intensive and expansive.
"The challenge is the massive oxygen requirement ... The
benefits of higher combustion efficiency with oxygen combustion
are lost once the large energy demands of producing oxygen plus
the smaller energy demands of CO2 recycling are considered"
(Global Energy Assessment, 2012).
Most power plants have therefore fallen back on
experimenting with post-combustion amine or ammonia scrubbers
that strip very dilute CO2 from the flue gas. Post-combustion
capture has the advantage that existing power plants could be
retrofitted easily. The technology is mature and it has been
widely used to capture CO2 from some industrial plants.
But the scrubbers needed to strip dilute CO2 from the flue
gas of a power plant would be enormous and expensive to operate.
So the focus is on developing cheaper and more effective methods
of removing CO2 from exhaust gases.
The Energy Department's Advanced Research Projects Agency
(ARPA-E) is funding 15 projects under its Innovative Materials
and Processes for Advanced Carbon Capture Technologies (IMPACCT)
programme. "IMPACCT is geared toward minimising the cost of
removing CO2 from coal-fired power plant exhaust by developing
materials and processes that have never before been considered,"
according to its website.
ARPA and others are researching all sorts of membranes,
enzymes and solvents to improve the efficiency of the process.
Efficiency improvements are essential: "CO2 capture adds
44-87 percent to the capital cost of (a new coal-fired plant),
and 42-81 percent to the cost of electricity, while achieving
CO2 reductions of approximately 80-90 percent per net kilowatt
hour produced," according to the Intergovernmental Panel on
"In all cases, a significant proportion of the total CO2
capture cost is due to the energy requirement for CO2 capture
and compression ... Plants with CO2 capture require 24-42
percent more fuel input per megawatt hour ... Roughly half the
energy is required for solvent regeneration and a third for CO2
The Energy Department has been keen to find commercial
applications for captured CO2, such as enhanced oil recovery, as
a way to offset some of the costs associated with this "energy
penalty," which is why officials now refer to utilisation and
storage rather than storage alone.
But improving the efficiency and reducing the cost of
stripping dilute CO2 from exhaust gas streams is critical if CO2
capture is ever to become a widespread reality. So while the
Decatur injection project is a powerful symbol of the advance of
CCS, the real breakthrough will have to come from the materials