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1 The Energy Seminar Stanford University April 9, 2008 Stanford University Global Climate & Energy Project CO 2 Sequestration: What have we found? What should future priorities be? Tony Kovscek Energy Resources Engineering Stanford, CA
2 Geological Sequestration 2
3 The Promise of Sequestration The Gap Assumed Advances In Fossil Fuels Energy intensity Nuclear Renewables Gap technologies Carbon capture & disposal Adv. fossil Adv.Transportation Biotechnologies Soils, Bioenergy, adv. Biological energy Source: J. Edmonds, PNNL 3
4 Sequestration Today Natural Gas Carbon Dioxide Helium Hydrogen Sulfide LaBarge, WY Gas Processing Plant Gas Injection Well Drive solely by economics Rangely Colorado Utah 4 i
5 114 Million Bbl Incremental Incremental Production 5
6 My Opinion Today, we can select sites drill and complete wells for CO 2 injection manage the subsurface flows in oil and gas settings monitor the progress of CO 2 migration plug and abandon wells
7 My Opinion But, we have not tackled the hard issues, such as 90-99% of all organic matter deposited was never captured by a trap oil seeps are common leakage from gas caps in the North Sea is documented CO 2 /water, CO 2 /oil displacements are unstable => how to predict cannot conduct compelling simulations for coalbed and ocean sediment settings
8 Project Components: GCEP: CO 2 Storage Efforts Site selection and evaluation: effective methods to assess the integrity of geologic seals that limit CO 2 migration. Fluid migration: probe the physics and long-term fate of injected CO 2 via experiments and high resolution numerical simulation. Monitoring: appropriate tools for monitoring the state of injection projects at each stage. True Model sparse dataset
9 2 Vignettes ECBM Physics Unstable Displacements
10 Why study coalbeds? IEA comparison at costs up to $20/t CO 2 IEA: 40 Gt CO 2 <2% of Emissions to 2050 Parson & Keith: Gt CO Gt CO 2 45% of Emissions to 2050 Parson & Keith: Gt CO ,000 Gt CO % of Emissions to 2050 Parson & Keith: Gt CO 2 add certainty to volume estimates store other contaminants significant challenges for monitoring methane coal is intrinsically interesting
11 ECBM and Sequestration Elucidate fundamental mechanisms relevant to enhanced methane production and greenhouse/acid gas storage in coal because poor predictions result, in part, from incomplete knowledge of physical mechanisms. Reduce, potentially, volume of produced water. Our niche is our ability to probe simultaneously sorption, transport, and permeability to gas experimentally analytically numerically
12 Pure components are well fit by Langmuir isotherm CO 2 adsorbs preferentially adsorption hysteresis for all gases scanning loops are evident CO 2, CH 4, N 2 Sorption Dry Powder River Basin (WY) Coal Tang, Jessen, and Kovscek, 2005
13 IAS vs Extended Langmuir IAS = Ideal Adsorbed Solution
14 IAS vs Langmuir Adsorption Selectivity: Selectivity, CO 2 /N 2 s 2,1 = (x/ y) 2 (x/ y) 1 = (x / y) CO 2 (x/ y) N2
15 Adsorption/Desorption/Transport Modeling 46/54 CO 2 /N 2 φ C i t + (1 φ) a i t + (vc i) = q i coal & CH 4 p = 600 psi S w = 0 CH 4 + CO 2 + N 2 gas analyzer V ads = i z i b i
16 CH 4 CO 2 100% CO 2 (25 grid blocks) coal & CH 4 p = 600 psi S w = 0 gas analyzer CH 4 CO 2 (25 grid blocks) CH 4 + CO 2 no parameter adjustment
17 CH 4 N 2 46/54 CO 2 /N 2 (25 grid blocks) CO 2 coal & CH 4 p = 600 psi S w = 0 CH 4 N 2 gas analyzer (25 grid blocks) CO 2 CH 4 + CO 2 + N 2 no parameter adjustment
18 Coal Permeability to Gas 18
19 Composite Coal Total length: cm Porosity: 7% Diameter: 2.79 cm Permeability to He: 1.7 md Intact composite coal plugs more dense 1200 CT Corresponding CT-images 0 less dense
20 Is permeability sensitive to gas? hysteresis loading/unloading CH 4 p overburden p pore net effective stress = 300 psi
21 y 2 hysteresis loading/unloading hysteresis loading/unloading p overburden p pore net effective stress = 300 psi
22 Summary: Coalbeds Current Modeling Activities dispersion, non-ideal behavior, and hysteresis y i P i = x i i i Methane sorption
23 Summary: Coalbeds Huge upside 1000 TCF CBM U.S. significant sequestration potential coal separates CO2 and N2 mixtures Significant questions management of swelling and permeability reduction appropriate level of physical detail Cartoon understanding? yes Quantitative/mechanistic understanding? no
24 2 Vignettes Unstable Displacements
25 Unstable Displacements Experimental Set up Porosity CT-Images 0.25 CT scanner X-ray ISCO pump coreholder Positioning system X D =0.04 X D =0.53 X D =0.88 With 26 porosity/perm CT images 3D-porosity 0 Rock: Berea Sandstone Length: 52 cm Diameter: 5.05 cm Permeability: 377 md Porosity: PV Orientation: horizontal 3D-permeability Neutral buoyancy Tang and Kovscek, 2004
26 Unstable Displacements Direct Numerical Simulation Shock mobility ratio : Growth rate positive, M s > 1 Growth rate negative, M s < 1 growth rate Riaz and Tchelepi, 2005
27 Completely Determined Rock Steady-state Relative permeability Properties
28 High Resolution Experiments u=1.05 m/d, neutral buoyancy M 0 =0.07~0.91 M 0 =2 M 0 =12~22 injected fluid: blue
29 M v =155 DNS versus Experiments Riaz, Tang, Tchelepi, and Kovscek, 2006 M=155, Ca=2x10-7 M=155, Ca=6x10-7 injected fluid: red
30 Summary: Unstable Flows relative permeability applicable to stable flows qualitative agreement only for M > 1 onset of instability marks the threshold of validity of relperm approach a fundamental problem that we have not solved, but wave our hands at a lot build more complicated physical scenarios atop poor first order physics M v =155 M v =303 Riaz, Tang, Tchelepi, and Kovscek, 2006
31 Conclusion What have we found? Knowledge:oil/gas > aquifers > coalbed > ocean sediments unstable displacements not described well by Darcy s law Coals demonstrate rich dynamical behavior gas adsorption adsorption hysteresis temperature water ph Future Priorities? world class science and engineering science further fundamental understanding of transport and geomechanics assess through experiments and simulation, methods to access low perm systems injectivity in coals as a function of gas type, stress, and temperature
32 Acknowledgement GCEP Collaborators: Wenjuan Lin, Amir Riaz, Hamdi Tchelepi, Tom Tang, Wenjuan Lin, Kristian Jessen
33 CH 4 Scanning Loops Initial pressure influences desorption hysteresis 22 C
34 CO 2 Storage Underway or Proposed 34 Source: Peter Cook, CO2CRC
35 Geomechanics and Seal Capacity Trap and Seal Framework How will CO 2 injection affect the reservoir seal? Did production and depletion affect the seal? What are the geomechanical mechanisms governing capacity?
36 Hydrocarbon Fill Controls
37 Dynamic Controls on CO 2 Capacity When pressure limit is reached, the seal cannot support any additional CO 2 Pressure released through: Capillary entry Hydraulic fracturing Dynamic fault slip (Modified from Finkbeiner, et al 2001)
38 South Eugene Island, Gulf of Mexico Eugene Island Blocks 330 and 314 are excellent fields in which to examine CO2 sequestration potential in depleted oil and gas reservoirs in the Gulf of Mexico - Trap fill controlled by several different mechanisms - Mature fields with substantial data available - New 3D seismic interpretations are currently being performed at ExxonMobil
39 South Eugene Island 330 Fault Block A Fault Block A OI-1 Sand Fault Block A: Small oil column Highly over-pressure Pressure at top reaches Dynamic fault slip limit
40 A burp of fluid moving up SEI fault? Haney et al. (2005)
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