Abstract Booklet 2006 - Swanson School of Engineering - University ...

5-5
Enhanced Hydrogen Production with in-situ CO 2 Capture
in a Single Stage Reactor
Liang-Shih Fan, Mahesh Iyer, Shwetha Ramkumar, Danny Wong, The Ohio State
University, USA
Enhancement in the production of high purity hydrogen from fuel gas, obtained from coal
gasification, is limited by thermodynamics of the Water Gas Shift Reaction which is used to
shift the carbon monoxide towards hydrogen. However, this constraint can be overcome by
concurrent water-gas shift (WGS) and carbonation reactions to enhance H 2 production by
incessantly driving the equilibrium-limited WGS reaction forward and removing the CO 2
product from the fuel gas mixture in-situ. This not only improves the H 2 yield but also
augments the purity of the product by removing the CO 2 co-product and achieving near
complete conversion of the CO reactant. This process developed at the Ohio State University
can effectively and economically produce a pure H 2 stream, at high temperature and
pressure, via coal gasification while integrating capture of CO 2 emissions, for its subsequent
sequestration. The enhanced water gas shift reaction for H 2 production with insitu
carbonation was studied using the commercial High Temperature Shift (Iron Oxide) catalyst
and calcium sorbents in an integral fixed bed reactor setup. We have identified a high
reactivity patented, mesoporous calcium oxide sorbent for the in-situ CO 2 capture. The
morphological properties of our patented precipitated calcium carbonate sorbent (PCC) can
be tailored using surface modifiers to demonstrate a high CO 2 capture capacity of about 70%
by weight (~700g of CO 2 /kg sorbent ) at elevated temperatures (600-700°C). Experimental
evidence clearly shows that this proprietary calcium sorbent (PCC) performance dominates
over that of commercial limestone sorbents at any given time. Thus, product gas
composition analyses demonstrate complete carbon monoxide conversion as well as CO 2
removal during the initial part of the breakthrough curve, thus demonstrating the synthesis of
pure hydrogen.
6-1
SESSION 6
GLOBAL CLIMATE CHANGE:
GEOLOGIC CARBON SEQUESTRATION – 1
Effects of CO 2 and Aquifer Brine on Well Plugging Cements
Steve Gerdemann, G.E. Rush, Bill O’Connor, NETL, USA
General consensus is that CO 2 at injection pressures in a saline environment will degrade
portland based well plugging cements. Long term exposure, years or decades are typical
time frames mentioned and modeled. Actual cement samples from CO 2 environments such
as oil fields in which CO 2 has been used to extend field production are rare, and actual
brackish to saline aquifer rock with CO 2 exposure still less common. Laboratory experiments
to simulate the saline environments were run with interesting results.
6-2
Using Pinnate Well Patterns for CO 2 Sequestration in
Allison Unit Reservoir Simulation Study
Jalal Jalali, Shahab Mohaghegh, West Virginia University, USA
Concerns about rising concentrations of carbon dioxide (CO 2 ) in the atmosphere and the
necessity of reducing greenhouse gas emissions has led to consideration of large-scale
storage of CO 2 in subsurface. Carbon dioxide is injected into unminable coal seams for
enhancing the coalbed methane recovery, which also has the extra advantage of long-term
CO 2 sequestration. Pilot projects exist in North America and some European countries to
study the feasibility of CO 2 sequestration in depleted oil and gas reservoirs.
Among different well patterns currently used for primary recovery of coalbed methane,
horizontal pinnate wells demonstrate high methane recovery in a short period of time along
with cost reductions and smaller footprints.
In this study, a pinnate well is first used for primary recovery of methane and then converted
into an injector for CO 2 injection to enhance the methane recovery and eventually long term
sequestration. The large contact area between the wellbore and the formation helps fast
dewatering, hence producing the methane, which is desorbed from the coal matrix into the
natural fractures. The pinnate pattern distributes the CO 2 in a large area of the formation
before it reaches the producing wells. Therefore, a larger amount of CO 2 could be stored in
the formation before CO 2 breakthrough occurs.
In this paper, a feasibility study of CO 2 sequestration using pinnate patterns into a coal seam
in the Allison Unit is presented. Several characteristics of the pinnate pattern and the CO 2
injection strategy are studied and optimized using a numerical reservoir simulator in order to
increase the methane recovery and total CO 2 that can be stored before breakthrough. Results
will be compared with the results from the well pattern currently used for CO 2 flooding in
the field.
6-3
Experimental Measurements of the Solubility of CO 2 in
the Oriskany Sandstone Aquifer
Robert M. Dilmore, Patrice Pique, Sheila Hedges, Yee Soong, R. J. Jones,
DOE/NETL, USA
5
Douglas Allen, DOE/NETL, Salem State College, USA
Experiments were conducted to determine the solubility of CO 2 in a natural brine
solution of the Oriskany sandstone formation under elevated temperature and pressure
conditions. These data were collected at pressures between 100 and 450 bars and at
temperatures of 21 and 75ºC. In addition, data on CO 2 solubility in pure water were
collected over the same pressure range as a means of verifying reliability of
experimental technique. Experimentally determined data were compared with CO 2
solubility predictions using a model developed by Duan and Sun (2003). Model results
compare well with Oriskany brine CO 2 solubility data collected experimentally,
suggesting that the Duan and Sun model is a reliable tool for estimating solution CO 2
capacity in high salinity aquifers in the temperature and pressure range evaluated.
6-4
Evaluation of CO 2 Flood on the Geomechanics of Whole Core Samples
Steve Gerdemann, Hank Rush, Bill O'Connor, NETL, USA
Geological sequestration of CO 2 , whether by enhanced oil recovery (EOR), coal-bed
methane (CBM) recovery, or saline-aquifer injection, is a promising near-term sequestration
methodology. While tremendous experience exists for EOR, and CBM recovery has been
demonstrated in existing fields, saline-aquifer-injection studies have only recently been
initiated. Studies evaluating the availability of saline aquifers suitable for CO 2 injection show
great potential.
This study evaluated the physical and chemical effects on Mt. Simon sandstone core from
the Illinois Basin exposed to simulated deep-aquifer brine saturated with super-critical CO 2 .
Conducting these tests on whole core samples rather than crushed core allowed an
evaluation of the impact of the CO 2 flood on the rock-mechanics properties as well as the
geochemistry of the core and brine solution. Preliminary results show an increase in porosity
and a decrease in crushing strength of the core after exposure to CO 2 for 2000 hours.
6-5
Sequestration of CO 2 in Mixtures of Bauxite Residue and Saline Waste Water
with Carbonate Mineral Formation and Caustic Byproduct Neutralization
Robert Dilmore, Yee Soong, Sheila Hedges, Angelo Degalbo, DOE/NETL, USA
Douglas Allen, DOE/NETL, Salem State College, USA
Jaw K. Fu, Charles L. Dobbs, ALCOA, USA
Chen Zhu, Indiana University, USA
Under consideration is a process designed to enhance the CO 2 trapping capacity of
brine solutions through addition of bauxite residue with subsequent carbonation of the
caustic mixture. A set of experiments was conducted to explore the concept of utilizing
mixtures of bauxite residue and brine to sequester carbon dioxide from industrial gas
streams such as flue gas from coal fired electric utility boilers. Factors affecting the
solubility of acid gasses in such mixtures include temperature, pressure, and water
chemistry properties including pH, ionic concentration, and salinity. Bauxite
residue/brine mixture of 90/10 by volume exhibited a CO 2 sequestration capacity of
greater than 9.5 grams per liter when exposed pure CO 2 at 20ºC and 100 psig. Calcite
formation was verified as a product of bauxite/brine mixture carbonation. Data
presented herein provide a preliminary assessment of overall process feasibility and
probe the influence of several variables on treatment efficiency. It is demonstrated that
CO 2 sequestration is augmented by adding bauxite residue as a caustic agent to acidic
brine solutions, and that trapping is accomplished through solubilization and ultimate
mineralization.
SESSION 7
GASIFICATION TECHNOLOGIES:
APPLICATIONS AND ECONOMICS – 2
7-1
The Shell Coal Gasification Process
Hugo T. P. Bos, F.G. van Dongen, Shell Global Solutions International BV, THE
NETHERLANDS
The latest status of the Shell Coal gasification Process (SCGP) is discussed.
Applications of gasification for chemicals production and power production are given.
Projects throughout the world are presented including the status of completion/ startup.
The latest developments of the Shell Coal gasification Process are presented such as
combined oil + coal gasification, biomass/coal to liquids conversion and methods for
CO 2 sequestration.
7-2
The GSP Gasification Process; State-of-the-Art and Further Development
Manfred Schingnitz, Klaus-Dieter Klemmer, Future Energy GmbH, GERMANY
The development of the GSP-Process, a pulverized fuel pressure gasification technology,
was started in 1975 by Deutsches Brennstoffinstitut Freiberg/Sa. (DBI, German Fuel
Research Institute). Main objective for this development was the demand to save crude oil