Cost-Effectiveness of Flexible Carbon Capture and Sequestration for Complying with the Clean Power...
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Transcript of Cost-Effectiveness of Flexible Carbon Capture and Sequestration for Complying with the Clean Power...
Cost-Effectiveness of Flexible Carbon Capture and Sequestration for
Complying with the Clean Power Plan
Michael CraigAdvisers: Paulina Jaramillo, Haibo Zhai, and Kelly Klima
USAEE Conference, Pittsburgh, PAOctober 26, 2015
2
Outline
• Background• Clean Power Plan• Flexible Carbon Capture and Sequestration
• Methods• Power system modeling• Flexible CCS modeling
• Initial Results• Conclusions and Policy Implications• Future Work
3
Clean Power Plan
• Limits CO2 emissions from existing fossil-fired generators (Final Rule, 1507-1542)
• Less coal-fired generation, more NGCC and renewable generation
• States choose compliance strategy • Type of standard (Final Rule, 882-884)
• Plan type (Final Rule, 879-880)
• Single vs. multi-state (Final Rule, 880-881)
• 1 compliance option: carbon capture and sequestration (CCS) retrofit (Final Rule, 34857)
• Little research on alternative compliance strategies with CPP (ISOMAP)
4
Normal and Flexible CCS
• Continuous operation by normal CCS unit:• Reduces CO2 emissions rate• Reduces net capacity, net efficiency, and ramp rate
5
Flexible CCS differs from normal CCS by including venting and solvent storage components.• Venting: bypass CO2 capture system• Solvent storage: store some rich and lean solvent in tanks
• Stored solvent displaces continuously regenerated solvent• Charging: regenerate stored lean solvent• Discharging: generate electricity using stored lean solvent
6
Normal and Flexible CCS
• Continuous operation by normal CCS unit:• Reduces CO2 emissions rate• Reduces net capacity, net efficiency, and ramp rate
• Venting by flexible CCS unit (relative to CCS unit):• Increases CO2 emissions rate• Increases net capacity, net efficiency, and ramp rate
• Discharging stored solvent by flexible CCS unit (relative to CCS unit):• Maintains post-CCS CO2 emissions rate• Increases net capacity, net efficiency, and ramp rate• Requires stored lean solvent
7
Why Flexible CCS?
• May provide system-wide benefits (van der Wijk et al. 2014, Cohen et al. 2013, Cohen et al. 2012, Delarue et al. 2012, Chalmers and Gibbins 2007)
• Reduce wind curtailment and reserve and dispatch costs
• May be more profitable than normal CCS (Bandyopadhyay and Patiño-Echeverri 2014, Oates et al. 2014, Versteeg et al. 2013, Patiño-Echeverri et al. 2012, Delarue et al. 2012, Ziaii et al. 2009)
• But past papers on system benefits compare flexible CCS to normal CCS (van der Wijk et al. 2014, Cohen et al. 2013, Cohen et al. 2012)
• Not more common CO2 emission reduction technologies
8
Research Motivation and Question
• Little analysis of alternative compliance with CPP• No system comparisons of flexible CCS to wind, re-dispatch, and other
common emissions reductions technologies
• Accounting for system benefits, is flexible CCS a cost-effective compliance strategy with the CPP?
• Compare to normal CCS retrofits, generation at existing NGCC, and new wind• Develop operational model of flexible CCS that can be included in a unit
commitment model
9
Power System Modeling
• Use unit commitment and economic dispatch (UCED) model in PLEXOS
• Co-optimize energy and reserve markets• No transmission constraints
• Build 2030 “base” CPP-compliant fleet• Add wind, normal or flexible CCS to base
fleet to create alternate fleets
• Study region: MISO• Lots of coal and wind resources
Source: amcharts.comSource: misoenergy.org
Left: MISO market area. Right: my modeled region.
10
Modeling CPP
• Fleet dispatching effects: CO2 price (Oates et al. 2015)
• 1) Set CO2 price • 2) Apply CO2 price to affected units• 2) Run economic dispatch for year (MATLAB)• 3) Compare affected unit annual emissions to CPP regional mass limit• 4) If emissions > mass limit, increase CO2 price and go back to step 2
• Include final CO2 price in dispatch and reserve costs of affected units
11
Flexible CCS Model
• Develop original set of parameters, generators and constraints to model flexible CCS operations
• Break 1 flexible CCS generator into multiple components in UCED• Estimate parameters via literature review and regressions with IECM data• Couple operations of units with over 35 constraints
• Include flexible CCS model in UCED model• Provides better approximation of operations, costs and emissions
than prior models (van der Wijk et al. 2014.)
12
Flexible CCS Model: Parameter Estimation
• Two methods:• Literature review (van der Wijk et al. 2014, Oates et al. 2014, Versteeg et al. 2013, Cohen et al. 2013, Patiño-
Echeverri et al. 2012, IEAGHG 2012)
• IECM regressions
7000 7500 8000 8500 9000 9500 100000%5%
10%15%20%25%30%35%40%45%50%
f(x) = 6.86086786344904E-05 x − 0.232945257667419R² = 0.969270357417209
f(x) = 7.4943793521862E-05 x − 0.277574820531305R² = 0.967846689423969
SubbitLinear (Subbit)
Pre-CCS Net HR (Btu/kWh)
CCS
Net
HR
Pena
lty (%
)
13
Flexible CCS Model: Generators
Base Coal Plant
14
Traditionally, model CCS parasitic load internal to CCS plant.
Base CCS Generator
CO2 Capture System
15
I break out CCS parasitic load as separate component...
Base CCS Generator
CO2 Capture System
16
And add separate component for generation while venting...
Base CCS Generator
Venting Generator
CO2 Capture System
17
And add separate components for solvent storage…
Base CCS Generator
Venting Generator
Stored Solvent Pump Unit 1
Charging Dummy 1
Discharging Dummy 1
Discharging Dummy 2
Charging Dummy 2
Stored Solvent Pump Unit 2
CO2 Capture System
18
And add a venting while charging component.
Base CCS Generator
Venting Generator
Stored Solvent Pump Unit 1
Charging Dummy 1
Discharging Dummy 1
Discharging Dummy 2
Charging Dummy 2
Stored Solvent Pump Unit 2
Venting when Charging Generator
CO2 Capture System
19
Flexible CCS Model: Constraints
• Electricity generation• Solvent flow rate• Offered reserves• Minimum stable load• Ramping• Volume of stored solvent• Units on/off
20
Initial Results: Clean Power Plan
0 200 400 600 800 1000 1200 1400 1600 1800 20000
50
100
Carbon Price ($30/ton)
Ele
c. P
rice
($/M
Wh)
Hour of Year
0 200 400 600 800 1000 1200 1400 1600 1800 20000
50
100
No Carbon Price
Ele
c. P
rice
($/M
Wh)
Hour of Year
• CPP increases averageelectricity price butdecreases price variance
• Suggests lower profitabilityof flexible CCS
Jan. 1Day of Year
Mar. 24
21
Initial Results: Flexible CCS Model OperationsOperations of 595 MW flexible CCS generator in CPP fleet.
22
Flexible CCS unit generates electricity mostly at base CCS generator, acting like a normal CCS unit.
6/1/2030 6/1/2030 6/2/2030 6/3/2030 6/4/2030 6/5/20300
100
200
300
400
500
600
700
Date
Elec
tric
ity G
ener
ation
(MW
h)
Base CCS
SS DischargeVent
23
Solvent storage discharge units mostly provide regulation up reserves.
6/1/2030 6/1/2030 6/2/2030 6/3/2030 6/4/2030 6/5/20300
20
40
60
80
100
120
140
160
180
Date
Reg.
Rai
se R
eser
ve (M
W)
SS Discharge
Base CCS
Vent
24
Solvent storage discharge units also provide raise reserves.
6/1/20306/1/20306/2/20306/3/20306/4/20306/4/20306/5/20300
20
40
60
80
100
120
140
160
180
Date
Rais
e Re
serv
e (M
W)
SS Discharge
Base CCS & Vent
25
Pending Results: Cost-Effectiveness of Flexible CCS versus Alternative Compliance Strategies
Compliance Fleet
CO2 Emissions (tons)
Total Operating Costs (Energy + Reserves) ($)
Total Capital Costs ($)
Cost-Effectiveness of CO2 Emissions Reductions ($/ton)
Base (NGCC re-dispatch)Flexible CCSNormal CCSWind
26
Conclusions and Policy Implications
• CPP’s suppression of price variability may reduce profitability of flexible CCS
• Based on analysis so far, value added of flexible CCS is provision of reserves
• Could yield cost savings as reserve requirements increase with wind penetration
• Comparison to normal CCS retrofits, new wind, and existing NGCC fleets will inform attractiveness of flexible CCS as CPP compliance strategy
27
Future Work
• Run normal CCS, flexible CCS, and new wind fleets• Compare emissions and costs
• Run low and high natural gas price scenarios• Compile capital cost data• Calculate break-even flexible CCS capital cost with respect to
alternative CO2 emissions reduction technologies
28
Acknowledgements
• Thanks to Paulina Jaramillo, Haibo Zhai and Kelly Klima (CMU)• Thanks to Achievement Rewards for College Scientists, the National
Science Foundation (Grant Number EFRI-1441131) and The Steinbrenner Institute for financial support
• Thanks to Energy Exemplar for academic license
Thanks!Questions?
30
Citations• Bandyopadhyay, R., and D. Patiño-Echeverri. (2014). Alternative energy storage for wind power: coal plants with amine-based CCS. Energy Procedia
(63): 7337-7348. • Chalmers, H., and J. Gibbins. (2007). Initial evaluation of the impact of post-combustion capture of carbon dioxide on supercritical pulverized coal
power plant part load performance. Fuel (86): 2109-2123.• Cohen, S. M., et al. (2013). Optimal CO2 capture operation in an advanced electric grid. Energy Procedia (37): 2585–2594.• Cohen, S.M., et al. (2012). Optimizing post-combustion CO2 capture in response to volatile electricity prices. Intl. J. of Greenhouse Gas Control (8): 180-
195. • Delarue, E., P. Martens and W. D’haeseleer. (2012). Market opportunities for power plants with post-combustion carbon capture. Intl. J. of Greenhouse
Gas Control (6): 12-20. • IEAGHG. (2012). Operating Flexibility of Power Plants with CCS. • Fischbeck, P., H. Zhai, and J. Anderson. (2015). ISOMAP: A techno-economic decision support tool for guiding states’ responses to the EPA Clean Power
Plan. Available at http://www.cmu.edu/energy/cleanpowerplantool/• Oates, D.L., and P. Jaramillo. (2015). State cooperation under the EPA’s proposed Clean Power Plan. Electricity Journal (28): 1-15. • Oates, D. L., et al. (2014). Profitability of CCS with flue gas bypass and solvent storage. International Journal of Greenhouse Gas Control (27): 279–288.• Patiño-Echeverri, D., et al. (2012). Reducing the energy penalty costs of postcombustion CCS systems with amine-storage. Environmental Science and
Technology (46): 1243–1252. • U.S. Environmental Protection Agency. “Carbon Pollution Emission Guidelines for Existing Stationary Sources: Electric Utility Generating Units; Final
Rule.” [Pre-publication.] Aug. 2015. • U.S. Environmental Protection Agency. Regulatory Impact Analysis for the Clean Power Plan Final Rule. Aug. 2015. • Van der Wijk, P.C., et al. (2014). Benefits of coal-fired power generation with flexible CCS in a future northwest European power system with large scale
wind power. International Journal of Greenhouse Gas Control (28): 216-233. • Versteeg, P., et al. (2013). Cycling coal and natural gas-fired power plants with CCS. Energy Procedia (37): 2676-2683. • Ziaii, S., et al. (2009). Dynamic operation of amine scrubbing in response to electricity demand and pricing. Energy Procedia (1): 4047-4053.
Supporting Slides
32
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Net
Cap
acity
(MW
)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
250
500
750
1000
CO2
Ems R
ate
(kg/
MW
h)Base CCS Flex
CCS, Vent
Flex CCS, SS
0
5
10
15
Net
HR
(MM
Btu/
MW
h)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Ram
p Ra
te (M
W/h
r.)
How do CCS and flexibleCCS retrofits affect powerplant characteristics?
33
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Net
Cap
acity
(MW
)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
250
500
750
1000
CO2
Ems R
ate
(kg/
MW
h)Base CCS Flex
CCS, Vent
Flex CCS, SS
0
5
10
15
Net
HR
(MM
Btu/
MW
h)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Ram
p Ra
te (M
W/h
r.)
Coal-fired generatorcharacteristics pre-CCSretrofit.
34
Retrofitting CCS reducesCO2 emissions but also reduces net capacity,net heat rate, and ramp rate.
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Net
Cap
acity
(MW
)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
250
500
750
1000
CO2
Ems R
ate
(kg/
MW
h)Base CCS Flex
CCS, Vent
Flex CCS, SS
0
5
10
15
Net
HR
(MM
Btu/
MW
h)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Ram
p Ra
te (M
W/h
r.)
35
Flexible CCS venting eliminates CCS parasiticload and increasesCO2 emissions.
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Net
Cap
acity
(MW
)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
250
500
750
1000
CO2
Ems R
ate
(kg/
MW
h)Base CCS Flex
CCS, Vent
Flex CCS, SS
0
5
10
15
Net
HR
(MM
Btu/
MW
h)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Ram
p Ra
te (M
W/h
r.)
36
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Net
Cap
acity
(MW
)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
250
500
750
1000
CO2
Ems R
ate
(kg/
MW
h)Base CCS Flex
CCS, Vent
Flex CCS, SS
0
5
10
15
Net
HR
(MM
Btu/
MW
h)
Base CCS Flex CCS, Vent
Flex CCS, SS
0
150
300
450
600
Ram
p Ra
te (M
W/h
r.)
Flexible CCS solvent storagedischarge eliminates CCS parasitic load and maintains CO2 capture rate.
37
Base Fleet Composition
• 1,024 units• 228 coal• 383 natural gas• 22 nuclear• 77 wind• 38 solar
Coal
Natural
Gas
Nuclear
Hydro
Wind
Solar
BiomassMSW
LF Gas
Fwas
te
Non-Fossi
l
Geotherm
al Oil0
10
20
30
40
50
60
70
Fuel Type
Inst
alle
d Ca
paci
ty (G
W)
38
UCED Data SourcesData Data SourceGeneration fleet IPM Parsed FileUnit commitment parameters PHORUMHourly plant-specific wind generation profiles
NREL Eastern Wind Dataset
Hourly plant-specific solar generation profiles
NREL Transmission Integration Study
Monthly hydropower capacity capacity factors
EIA Form 923
Demand profile (2030) IPM (hourly profile), CPP (energy efficiency assumption)
Flexible CCS Parameters IECM, literature review
39
UCED FormulationMinimize Total Operating Costs
where:
Subject to:
Supply = demand
Reserves = reserve requirements
Unit-specific max and min load constraints
Unit-specific minimum up time
Unit-specific ramp constraints
TC=total costs; p=electricity generation; OC=operating cost; r=offered reserves; ROS=reserve offer scalar; v=turn on; SU=startup cost; nse=non-served energy; CNSE=cost of nse; HR=heat rate; FC=fuel cost; ER=emissions rate; EC=emissions cost; P=demand; R=reserve requirement; PMAX=max capacity; PMIN=min stable load; u=on/off; w=turn off; MDT=min down time; cUP=ramp up; cDOWN=ramp down; RL=ramp limit
40
Full UCED Formulation
Objective Function: minimize total operating costs
Where:Subject to:
Supply=demand
41
Meet reserve requirement foreach type:
Supplemental reservesmade of spinning and replacement reserves:
Replacement reserves definition:
Provided reserves constrainedby spare reserves:
Provided reserves constrained byoffer quantity:
Spare down reserves constrainedby decrease in generation:
Spare up reserves constrainedby available capacity:
Spare spinning reserveslimited by available capacityand spare regulation reserves:
42
Generation constrained bymax capacity:
Generation constrainedby minimum load:
Definition of ramp up anddown variables:
Limit ramp up values:
Limit ramp down values:
Enforce minimum down time:
Relate on/off to turn on:
Relate turn off to on/off and turn on:
43
Flexible CCS Modeling in Other Papers
Original Coal-Fired Generator
HR = NetHR0
HR = NetHR = NetHR0*(1+HRPCCS)
CCS Retrofit Coal-Fired Generator
Continuous Solvent Regeneration
Retrofit CCS
Venting Generator
Stored Solvent Pump Unit
Constraints Constraints0
20
40
60
80
100
120
Venting or Stored Solvent Generator
Base CCS GeneratorG
ener
ation
(MW
h)
Generation from Base CCS Generator + Added Flexible Units
44
Full Flexible CCS Formulation
45
Flex CCS: Generation Constraints Between Units
𝑝𝐶𝐶𝑆≤𝑃𝑀𝐴𝑋𝐶𝐶𝑆 −
𝐸𝑡𝑜𝐺𝑟𝑖𝑑𝐸𝑡𝑜𝐶𝑂 2𝐶𝑎𝑝𝑡𝑢𝑟𝑒+𝑅𝑒𝑔𝑒𝑛𝑒𝑟𝑎𝑡𝑜𝑟
∗(1+ 𝐸 𝐸𝑥𝑡𝑟𝑎𝐶𝑜𝑛𝑡𝑖𝑛𝑢𝑜𝑢𝑠𝑆𝑜𝑙𝑣𝑒𝑛𝑡𝐸𝑡𝑜𝑆𝑡𝑜𝑟𝑒𝑆𝑜𝑙𝑣𝑒𝑛𝑡 )∗𝑚𝑃𝑢𝑚𝑝1
𝑝𝑆𝑜𝑙𝑣𝑒𝑛𝑡=1
𝐸𝑡𝑜𝐺𝑟𝑖𝑑𝐸𝑡𝑜𝐶𝑂 2𝐶𝑎𝑝𝑡𝑢𝑟𝑒
∗𝑝𝐶𝐶𝑆+𝐸 𝐸𝑥𝑡𝑟𝑎𝐶𝑜𝑛𝑡𝑖𝑛𝑢𝑜𝑢𝑠𝑆𝑜𝑙𝑣𝑒𝑛𝑡
𝐸𝑡𝑜𝑆𝑡𝑜𝑟𝑒𝑆𝑜𝑙𝑣𝑒𝑛𝑡𝑚𝑃𝑢𝑚𝑝1−𝑚𝑃𝑢𝑚𝑝2
𝑝𝑉𝑒𝑛𝑡≤𝑃𝑀𝐴𝑋𝑉𝑒𝑛𝑡 −𝑝𝐶𝐶𝑆∗ 1−𝐶𝑃𝑉𝑒𝑛𝑡
1−𝐶𝑃𝐶𝐶𝑆
𝑝 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒≤𝐸𝑡𝑜𝐺𝑟𝑖𝑑
𝐸𝑡𝑜𝐶𝑂 2𝐶𝑎𝑝𝑡𝑢𝑟𝑒∗ (𝑚𝑃𝑢𝑚𝑝1+𝑚𝑃𝑢𝑚𝑝2 )∗ 𝑃𝑀𝐴𝑋
𝐶𝐶𝑆 −1
𝑃𝑀𝐴𝑋h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒
46
Flex CCS: Generation and Reserve Constraints
𝑟𝐶𝐶𝑆+𝑟𝑉𝑒𝑛𝑡 +𝑟 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒1+𝑟 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒2+𝑟 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑝𝐶𝐶𝑆+𝑝𝑉𝑒𝑛𝑡+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒1+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒 2+𝑝 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑝𝐶𝑜𝑛𝑡𝑆𝑜𝑙𝑣𝑒𝑛𝑡+𝑚𝑃𝑢𝑚𝑝1+𝑚𝑃𝑢𝑚𝑝2≤ 𝑃𝑀𝐴𝑋𝑉𝑒𝑛𝑡
𝑟𝐶𝐶𝑆+𝑟 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑝𝐶𝐶𝑆+𝑝 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒≤𝑃𝑀𝐴𝑋𝐶𝐶𝑆
47
Flex CCS: Solvent Flow Rate and Stored Solvent Volume Constraints
𝑝𝑃𝑢𝑚𝑝 1+𝑚𝑃𝑢𝑚𝑝1+𝑝𝑃𝑢𝑚𝑝2+𝑚𝑃𝑢𝑚𝑝2+𝑝𝐶𝑜𝑛𝑡𝑆𝑜𝑙𝑣𝑒𝑛𝑡≤ 𝑃𝑀𝐴𝑋𝐶𝑜𝑛𝑡𝑆𝑜𝑙𝑣𝑒𝑛𝑡
𝑒𝑣𝐿𝑒𝑎𝑛1+𝑒𝑣𝐿𝑒𝑎𝑛2≤𝐸𝑉 𝑀𝐴𝑋𝐿𝑒𝑎𝑛1
48
Flex CCS: Min Load Constraints
𝑝𝐶𝐶𝑆+𝑝𝐶𝑜𝑛𝑡𝑆𝑜𝑙𝑣𝑒𝑛𝑡+𝑝𝑃𝑢𝑚𝑝𝐷 1+𝑝𝑃𝑢𝑚𝑝𝐷 2+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒1+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒2+𝑝 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑝𝑉𝑒𝑛𝑡≥𝑃𝑀𝐼𝑁 ,𝐵𝑜𝑖𝑙𝑒𝑟𝐶𝐶𝑆
¿
𝑝𝐶𝐶𝑆+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒1+𝑝 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒2+𝑝 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑝𝑉𝑒𝑛𝑡≥ 𝑃𝑀𝐼𝑁 ,𝑆𝑇𝐶𝐶𝑆
49
Flex CCS: Ramping and On/Off Constraints
𝑐𝐶𝐶𝑆+𝑐 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒1+𝑐 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒 2+𝑐𝐶𝑜𝑛𝑡𝑖𝑛𝑢𝑜𝑢𝑠𝑆𝑜𝑙𝑣𝑒𝑛𝑡+𝑐 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑐𝑃𝑢𝑚𝑝𝐷 1+𝑐𝑃𝑢𝑚𝑝𝐷 2+𝑐𝑉𝑒𝑛𝑡≤𝐶𝐶𝐶𝑆
𝑐𝐶𝐶𝑆≤𝐶𝐶𝐶𝑆+(𝑢 h𝑉𝑒𝑛𝑡𝐶 𝑎𝑟𝑔𝑒+𝑢 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒 1+𝑢 h𝐷𝑖𝑠𝑐 𝑎𝑟𝑔𝑒 2+𝑢𝑉𝑒𝑛𝑡 )∗ 𝑃𝑀𝐴𝑋𝐶𝐶𝑆
50
Flex CCS: On/Off Constraints
51
Flex CCS: Reserve Provision Constraints
52
Flexible CCS ParametersUnit Max Power Capacity (MW) Heat Rate
(MMBtu/MWh)Ramp Rate CO2 Emissions Rate
(ton/MWh) [see note 3]
CCS Unit PMAXCCS = PMAX
PreCCS * (1 - CPCCS) [see note 1]
HRCCS = HRGrossCCS [see
note 2]CCCS during normal operations; group constraint applied when vent or discharge generator on.
ERPreCCS * (1-ERRCCS)
Continuous Solvent Unit PMAXSolvent =
PMAXCCS/(EGrid/ECapture)
HRSolvent = HRGrossCCS Only group constraint applied (see
constraints)0
SS Pump 1 Unit PMAXPump1 = (PMAX
CCS-1) / (EGrid/ECapture) / (1 + ECont/EStore)
1 Only group constraint applied (see constraints)
0
SS Pump Dummy 1 Unit PMAXPumpD1 = PMAX
Pump1 HRPumpD1 = HRGrossCCS Only group constraint applied (see
constraints)0
SS Discharge Dummy 1 Unit
PMAXDischarge1 = PMAX
Base * (1 - CPDischarge) HRDischarge1 = HRGrossCCS *
(1 + HRPDischarge)Stored solvent discharging ramp rate (4%/min.), and group constraints
ERPreCCS * (1-ERRCCS) * PCCS / PDischarge1
SS Pump 2 Unit PMAXPump2 = PMAX
Solvent – PMAXPump1 0 Only group constraint applied (see
constraints)0
SS Pump Dummy 2 Unit PMAXPumpD2 = PMAX
Pump2 HRPumpD2 = HRGrossCCS Only group constraint applied (see
constraints)0
SS Discharge Dummy 2 Unit
PMAXDischarge2 = PMAX
Base * (1 – CPDischarge) * PMAX
Pump2 / (PMAXPump1 + PMAX
Pump2)HRDischarge2 = HRGross
CCS * (1 + HRPDischarge)
Solvent discharging ramp rate (4%/min.), and group constraints
ERPreCCS * (1-ERRCCS) * PCCS / PDischarge2
Venting When Charging Unit
PMAXVentCharge = PMAX
CCS HRVentCharge = HRGrossCCS Venting ramp rate (4%/min.), and
group constraintsERBase
Venting Unit PMAXVent = PMAX
Discharge HRVent = HRDischarge Venting ramp rate (4%/min.), and group constraints
ERBase
53
Flexible CCS Parameters: Lit Review vs. IECM
Parameter Estimation MethodSolvent storage tank size Literature ReviewRegenerator size Literature ReviewRamp rate during venting and stored solvent discharging operations Literature Review
Steam turbine minimum stable load Literature ReviewCCS capacity penalty Regression on IECM Results
CCS heat rate penalty Regression on IECM Results
Capacity penalty during full discharge of stored solvent Regression on IECM Results
Heat rate penalty during full discharge of stored solvent Regression on IECM Results
Energy delivered to grid per unit of energy used to capture CO2 during normal CCS operations
Regression on IECM Results
Energy delivered to grid while discharging stored solvent per unit of energy used to store solvent
Regression on IECM Results
Energy required for solvent to capture CO2 emissions from fuel used for energy to store solvent per unit of energy used to store solvent
Regression on IECM Results
54
Lit Review ParametersParameter Value Used in Our ModelRegenerator size Right-sizedSolvent storage tank size 2 hoursRamp rate during venting and stored solvent discharging operations (as percent of total capacity of venting and stored solvent units)
4% of maximum venting and stored solvent discharging capacity per minute
Steam turbine minimum stable load
30% of maximum capacity
55
7000 7500 8000 8500 9000 9500 100000.00%5.00%
10.00%15.00%20.00%25.00%30.00%35.00%40.00%45.00%50.00%
f(x) = 6.86086786344904E-05 x − 0.232945257667419R² = 0.969270357417209
f(x) = 7.4943793521862E-05 x − 0.277574820531305R² = 0.967846689423969
SubbitLinear (Subbit)Bit
Pre-CCS Net HR (Btu/kWh)
CCS
Net
HR
Pena
lty (%
)
7000 7500 8000 8500 9000 9500 10000
-35.00%
-30.00%
-25.00%
-20.00%
-15.00%
-10.00%
-5.00%
0.00%
f(x) = − 3.70072443795609E-05 x + 0.0557693396402443R² = 0.97899496023403f(x) = − 3.8126323434682E-05 x + 0.0596242511745435
R² = 0.977615674770612
SubbitLinear (Subbit)Bit
Pre-CCS Net HR (Btu/kWh)
CCS
Capa
city
Pen
alty
(%)
10000 11000 12000 13000 14000 150000.00%0.50%1.00%1.50%2.00%2.50%3.00%3.50%4.00%4.50%5.00%
f(x) = 3.25843839545568E-06 x − 0.0025949728708702R² = 0.980948637377155
f(x) = 3.16212682589337E-06 x − 0.00269276845857734R² = 0.980734283741392
Subbit
CCS Net HR (Btu/kWh)
Net
HR
Pena
lty W
hile
Dis
char
g-in
g St
ored
Lea
n So
lven
t (%
)
10000 11000 12000 13000 14000 15000
-4.50%-4.00%-3.50%
-3.00%-2.50%
-2.00%-1.50%
-1.00%-0.50%0.00%
f(x) = − 3.10993314224103E-06 x + 0.00208295315490609R² = 0.982226214191381f(x) = − 2.97165029638085E-06 x + 0.00160629942347718R² = 0.977199220973694
Subbit
CCS Net HR (Btu/kWh)Ca
paci
ty P
enal
ty W
hile
Dis
-ch
argi
ng S
tore
d Le
an S
olve
nt
(%)
IECM Parameter Regressions
56
IECM Parameter Regressions
10000 11000 12000 13000 14000 150000.000.050.100.150.200.250.300.350.400.45
f(x) = 2.98141408064133E-05 x − 0.0229172817016849R² = 0.991290782582552
f(x) = 2.99516799978839E-05 x − 0.0196303449948082R² = 0.991115314445526
Subbit
CCS Net HR (Btu/kWh)
Ener
gy F
or E
xtra
Con
tinuo
us
Solv
ent P
er U
nit o
f Ene
rgy
Use
d to
Sto
re S
olve
nt (M
Wh/
MW
h)
10000 11000 12000 13000 14000 150000.00
0.50
1.00
1.50
2.00
2.50
3.00
3.50
f(x) = − 0.000270050125172712 x + 5.99079939122409R² = 0.999552320251202f(x) = − 0.000222787207730518 x + 5.35596976745242R² = 0.999645921002792
SubbitLinear (Subbit)Bit
CCS Net HR (Btu/kWh)
Net
Ele
ctri
city
to G
rid
Per
Uni
t of
Ene
rgy
Use
d fo
r CO
2 Ca
ptur
e (M
Wh/
MW
h)
10000 11000 12000 13000 14000 150000.000.501.001.502.002.503.003.504.004.50
f(x) = − 0.000271916124438599 x + 6.88236959354894R² = 0.999522716731054f(x) = − 0.000224911857421137 x + 6.2562469315387
R² = 0.999467620641999
SubbitLinear (Subbit)
CCS Net HR (Btu/kWh)
Net
Ele
ctri
city
to G
rid
Whi
le
Dis
char
ging
Sto
red
Solv
ent P
er
Uni
t of E
nerg
y U
sed
to S
tore
So
lven
t (M
Wh/
MW
h)
57
IECM Regressions: IECM Heat Rates vs. Retrofit Plants Heat Rates
75007700790081008300850087008900910093009500
Bituminous
Plants to Retrofit IECM
Net
HR
Pre-
CCS
(Btu
/kW
h)
7500
8000
8500
9000
9500
10000
Subbituminous
Plants to Retrofit IECM
Net
HR
Pre-
CCS
(Btu
/kW
h)
58
Release from rich storage:
Inflow to rich storage:
Release from lean storage:
Inflow to lean storage:
Volume balance for lean storage:
Pump load constrained bypump capacity:
59
Normal Coal PlantBoilerFuel
(Coal) SteamSteam Turbine Electricity
Flue Gas
Net Electricity to Grid
60
Normal CCS Coal PlantBoilerFuel
(Coal) SteamSteam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
61
Two key parameters: capacity and net heat rate penalty from CCS retrofit.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
62
Flexible CCS Coal Plant: VentingBoilerFuel
(Coal) SteamSteam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Vented Flue Gas
63
Venting eliminates parasitic load of CCS system.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Vented Flue Gas
64
Key parameters: reduction in CCS capacity and heat rate penalty when venting.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Vented Flue Gas
65
Flexible CCS Coal Plant: Stored Solvent
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Dashed lines indicate substitutability of rich and lean solvent sources.
66
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
67
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
68
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
69
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
70
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
71
When “charging” stored solvent, regenerate stored solvent by passing stored rich solvent to regenerator and storing resulting lean solvent.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
72
Key parameter: reduction of net electricity provided to grid per ton of solvent stored during “charging”.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
73
We allow venting emissions when “charging”, which allows generator to maintain constant fuel input and net electricity to grid.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Vented Flue Gas
74
Flexible CCS Coal Plant: Stored Solvent
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
Dashed lines indicate substitutability of rich and lean solvent sources.
75
When “discharging” stored solvent, capture CO2 with stored solvent, eliminating capacity and heat rate penalty of CO2 capture system.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
76
When “discharging” stored solvent, capture CO2 with stored solvent, eliminating capacity and heat rate penalty of CO2 capture system.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
77
When “discharging” stored solvent, capture CO2 with stored solvent, eliminating capacity and heat rate penalty of CO2 capture system.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
78
Key parameter: electricity provided to grid for each ton of stored lean solvent “discharged” per energy used to store lean solvent during “charging”.
BoilerFuel (Coal) Steam
Steam Turbine Electricity
Regenerator
Flue Gas
CO2 Absorber
Lean Solvent Storage Tank
Rich Solvent Storage Tank
Isolated CO2 Compressor
Net Electricity to Grid
CO2 Stream for Sequestration
Rich Solvent
Lean Solvent
CO2 Capture System
79
MISO Reserves
• Reserve requirements (Navid 2012):• Regulating (bidirectional): 400 MW• Spinning: 1,000 MW• Supplemental: 1,000 MW
Source: “Level 200 – Energy and Operating Reserves Markets.” MISO. 29 April 2014.
80
Continuous solvent electricity use parallels electricity output by base CCS generator.
6/1/20306/1/20306/2/20306/3/20306/4/20306/5/20300
100
200
300
400
500
600
700
BaseSS Discharge 1SS Discharge 2VentVent When ChargeCont. SolventPump Dummy 1Pump Dummy 2
Date
Elec
tric
ity G
ener
ation
(MW
h)
81
Total provide reserves by solvent storage discharge are almost constant.
6/1/2030 6/1/2030 6/2/2030 6/3/2030 6/4/2030 6/5/20300
20
40
60
80
100
120
140
160
180
200
Date
Tota
l Pro
vide
d Re
serv
es (M
W)
82
Supporting Slides Citations
• Navid, Nivad. “Reserve requirement identification with the presence of variable generation.” MISO. 26 April 2012. Presentation, UVIG Spring Technical Meeting.