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Storing Carbon Dioxide in Coalbeds a Laboratory and Simulation Investigation
A.R. (Tony) KovscekStanford UniversityPetroleum Engineering DepartmentStanford, CA 94305-2220
Overview
• Stanford’s Sequestration Program• Experimental Program ECBM• Conceptual/numerical model development• Results• Permeability vs Gas Composition (prelim)• Conclusions
Geologic Storage of CO2GCEP: Global Climate and Energy Project
Project Components:
Site selection and evaluation: effective methods to assess the integrity of geologic seals that limit CO2 migration.
Fluid migration: efficient methods for predicting the flow paths and long-term fate of injected CO2.
Monitoring: appropriate tools for monitoring the state of injection projects at each stage.
Project Components:
Site selection and evaluation: effective methods to assess the integrity of geologic seals that limit CO2 migration.
Fluid migration: efficient methods for predicting the flow paths and long-term fate of injected CO2.
Monitoring: appropriate tools for monitoring the state of injection projects at each stage.
Site Selectionand Evaluation Mark Zoback and coworkers
• How will CO2 injection affect the reservoir seal?
• Did production and depletion affect the seal?
• What are the geomechanical mechanisms governing capacity?
Trap and Seal Framework
Fluid Migration : ECBM Prediction Lynn Orr, Tony Kovscek and Coworkers
• Such methods are useful to– predict where CO2 is likely to flow– interpret the volume and space contacted– optimize injection and recovery operations
• What assumptions necessary?
50 x 50 x 10 blocks
AcquisitionStrategies
Modeling &Simulation
Imaging &Inversion
GCEP 4D:• Continuous imaging, e.g.,
weekly or daily• Adaptable to dynamic
storage conditions• Exploits models for
porous media and flow prediction
ConventionalTime-lapse
High Spatial ResolutionLow Temporal Resolution
GCEP4-D
Lower Spatial ResolutionHigher Temporal Resolution
Monitoring in Real TimeJerry Harris and coworkers
Experimental Objective
• Establish a feasible CO2/CH4/N2adsorption/desorption model and displacement mechanism so that modeling of CBM production and CO2 storage on field scale is improved.
• Probe:•adsorption/desorption behavior•permeability with respect to gas composition•recovery efficiency and CO2 storage
Flow Through Apparatus
• Unconfined pack• Gas mixtures made in the lab by weight
Coal Holder
Flow-MeterBack Pressure Regulator
Gas Container
poverburdenp2
pi
To Vent
∆p
Relevant Coalpack DataPowder River Basin, WY Coal
As received After grinding
Coalpack #1 #2 #3 Size of coal particles, meshes <60 <60 <60 Length of the coalpack, cm 25.0 25.0 25.0 Diameter of the coalpack, cm 4.25 4.25 4.25 Porosity, % 44 37 34 Permeability, md 144.0 43.0 26.3 Weight of coal, g 218.0 231.0 239.4Swi, % 0 0 8-10
Coalpack
Mixed Gas Injection Data
Temperature: 72oF
Pressure: 600 psia
Initial Water Saturation: 0
Gas Injection Rate: 0.5 cc/min
Injection-gas composition:
-100% CO2, 0% N2 (c100n0)
-85% CO2, 15% N2 (c85n15)
-46% CO2, 54% N2 (c46n54)
-24% CO2, 76% N2 (c24n76)
-0% CO2, 100% N2 (c0n100)
CO2 Displacing CH4Piston like advance of CO2
coal
& C
H4
CO2
CH4 +CO2
gas analyzer
Chromatographic Separation of CO2 & N2co
al &
CH
4
46% CO2 54% N2
CH4 +CO2 + N2
gas analyzer
Adsorption/Desorption/Transport Modeling
• 1D, 2 phase:
• extended Langmuir:
• primary and secondary (grain): φ= φ1+φ2– instantaneous equilibrium– 2%< φ2 <8%
• PR-EOS with
• Finite difference solution
φ∂Ci
∂t+ (1− φ)
∂ai
∂t+ ∇⋅ (vCi) = qi
ai =αiβ iyi
1+ βkykk∑
Vads = zii∑ bi
CO2, CH4, N2 Adsorption/DesorptionPowder River Basin, WY Coal
• Correct for volume of adsorbate
• All adsorption data (pure) is well fit by Langmuir isotherm
• CO2 adsorbs preferentially
• adsorption hysteresis for all gases
• scanning loops are evident
22 °C
3 CO2 : 1 CH4
Binary Gas SystemsExperiment and Simulation, φ2=7.4%N2
CH4 + N2
CO2
CH4 + CO2
Ternary Gas SystemsExperiment and Simulation, φ2=7.4%
76%N2+24% CO2
CH4 + N2 + CO2
CH4 + N2 + CO2
54%N2+46% CO2
Ternary Gas SystemsExperiment and Simulation, φ2=7.4%
15%N2+85% CO2
CH4 + N2 + CO2
Permeability Evolution of CoalpackSteady State
Experimental and Simulation Discrepancy• mass transfer limitations
– no discrepancy in binary results– coal particles are small and times for diffusion
are less than 0.1 s• coal shrinkage/swelling
– no discrepancy in binary results– N2 did not affect permeability
• prediction of sorption– hysteresis, scanning-loops, multicomponent– extended Langmuir
• constant selectivity• selectivity independent of total pressure and gas-
species concentration
Sensitivity SimulationTernary Gas System
CH4 + N2 + CO2
54%N2+46% CO2
• Case 1: Base case• Case 2: Use only desorption curve for N2
Permeability Versus Gas Composition (CH4, N2, CO2)
Core Holder
coalpack: 1 inch diameter, 12 inches long
Flow Through Apparatus
• Net overburden pressure=400 psi, Pore pressure: 60~1100 psi• Gas mixtures made in the lab by weight
Coal Holder
Flow-MeterBack Pressure Regulator
Gas Container
poverburdenp2
pi
To Vent
∆p
Steady-State PermeabilityPconfining-Ppore = 400 psi
Permeability Reduction Correlates With Surface Coverage
Pure Gases
Coverage vs Permeability ReductionPure and Mixed Gases
Permeability ReductionPhase Behavior (CO2/N2)
experimental temperature, T
T > Tcno phase behaviorgas-solid interactions dominant
T < Tcphase behaviorvapor-vapor interactions dominant
Tc(°C)CH4 -83N2 -147CO2 31
Coverage vs Permeability ReductionPure and Mixed Gases
T > Tcno phase behaviorgas-solid interactions dominant T < Tc
phase behaviorvapor-vapor interactions dominant
Conclusions• The interplay of gas sorption and transport in coal
yields rich dynamical behavior that is sensitive to the details of adsorption
• The transient behavior of binary gas systems is well represented by the numerical model.
• The qualitative behavior of ternary gas systems is well represented in simulation results; however, quantitative agreement of breakthrough times and the elution profiles for gas species remains to be proven.
• Permeability decreases as pore space fills with immobile adsorbed gas– reduction in porosity available for flow– possible correlation to surface coverage– some N2 appears to preserve permeability
• Gas injection enhances CBM recovery significantly (at least 94% OGIP)
Acknowledgment
• This work was supported by Stanford University Global Climate and Energy Project (GCEP). Funding is acknowledged gratefully.
• Collaborators:– Lynn Orr– Kristian Jessen– Tom Tang– Wenjuan Lin– Tanmay Chaturvedi
Sequestration Time Scales
• Convection–flow between wells (detailed geological description necessary?)
• Dissolution of CO2 in brine• Gravity redistribution• Gravity overturn of dense CO2-brine• Chemical reactions in brine phase• Geologic formation to surface
transport–if applicable (detailed and/or stochastic geological description necessary?)
SL
SL
Reality check: the volumes are very large!
• At a CO2 density of 500 kg/m3 (1000 m depth at 50˚C), injection of 1 billion tonnes/yr of CO2 is equivalent to ~ 35 million barrels/day.
• At a CO2 density of 700 kg/m3, 1 Gt CO2 is equivalent to ~ 25 million barrels/day.
• Worldwide emissions of CO2, ~ 25 Gt/yr:~ 625 – 825 million barrels/day!
• World oil production is currently ~80 million barrels/day.
• These volumes are large enough that it is unlikely that CO2storage in geologic formations alone will solve the problem of CO2 emissions to the atmosphere.
expe
rimen
tsi
mul
atio
nMethane Recovery
Why is there hysteresis?Surface geometry heterogeneity–Seri-Levy and Avnir (1993)
• Monte Carlo simulation• gas-surface interactions
greater than gas-gas• rough surfaces
• various hysteresis curves obtained by modifying surface geometry
Why is there hysteresis?Surface geometry heterogeneity–Seri-Levy and Avnir (1993)
rough surface
p/p0=0.13 p/p0=0.13
p/p0=0.61 p/p0=0.61
adsorption
desorption
Experimental SetupAdsorption/Desorption CO2/N2/CH4
Electronic balance
Coreholder
Pressure gauge
Pressure gauge
Reference cell
Gas Cylinder
Vacuum pump
CH4 Scanning LoopsInitial pressure influences desorption hysteresis
22 °C
Adsorption on Moist Coal (uncorrected for volume of adsorbate)
22 °C
Effect of T on Coalpack Permeability
Data Acquisition Strategies
CO2
Seal
Fault
Injection Well
Our 4-D approach:
• Embedded detectors• Embedded low-power sources• Coded, continuous signals• Adaptive synthetic apertures
- e.g., the Stanford Cross
The Stanford Cross Array