Techno-Economic Analysis of the Link between Above Ground CO2 Capture, Transport, Usage for Enhanced Oil Recovery (EOR) and Storage

Interdisciplinary PhD Workshop on Sustainable Development, April 2015

Clea Kolster1,2, Sam Krevor3 and Niall Mac Dowell1,2

Imperial College London1Centre for Environmental Policy, 2Centre for Process Systems Engineering,

3Department of Earth Science and Engineering

https://soukimlay.files.wordpress.com/2011/09/4745890-global-warming-cartoon-illustration-with-globe-and-thermometer-measuring-the-planet-temperature1.jpg

What is CO2 Capture and Storage?

Florin N., Fennel P., Carbon capture technology: future fossil fuel use and mitigating climate change - Grantham Briefing Paper 3, November 2010.

A Value for CO2 : Enhanced Oil Recovery (EOR)

Advanced Resources International and Melzer Consulting, Optimixation of CO2 Storage in CO2 Enhanced Oil Recovery Projects, prepared for UK Department of Energy & Climate Change, November 2010.

Why is CCS not Currently Deployed Around the World?

http://fresnobeehive.com/wp-content/uploads/2012/11/Puzzle-Pieces.gif

Air Separation Unit (ASU) & Power Plant

CO2 Compression and Purification (CO2CPU) Section

Flue GasFlue Gas

Oxy-Combustion Capture

ηloss± 5% ηloss± 5%

η loss

± 1

0%

Air Separation Unit (ASU) & Power Plant

Optimise CO2CPU and drive down costs for a

cheap CO2 product

CO2 Compression and Purification (CO2CPU) Section

Oxy-Combustion Capture

What are the Effects of Impurities on CO2 Transport, Storage and Usage for

Enhanced Oil Recovery?

Effect of Impurities on CO2 for Transport, Storage and EOR

CO2 Transport Quality

Recommendations(Dynamis)

Canyon Reef SACROC

CO2-EOR Project

CO2 >95.5% >95%

H2S <200 ppm <1500 ppm

N2 <4% <4%

O2 <4% (saline aquifers)100-1000ppm (EOR)

<10 ppm (weight)

Ar <4% <4%

SO2 <100ppm Total sulphur <1450 ppm

NO <100 ppm

H2O <500 ppm No free water in the vapour phase

• H2O causes corrosion in CO2 transport pipeline

• Presence of O2, N2, Ar: • increases pipeline

diameter due to volume uptake

• reduces storage capacity

• Presence of O2 in oil reservoir: • Can cause oil oxidation• Risk of biological growth• Can cause overheating at

injection point• Lack of fundamental

research on the link between concentration and risks

CO2CPU Model – Independent Entity

CO2 Compression and Purification (CO2CPU) Section

Raw material: exhaust gas (waste from the power plant)

+Energy input (=money)

=Waste stream: gas impurities + water

+Product stream : CO2 @ high

pressure & high purity

CO2 Compression and Purification Unit with 6-stage Distillation Column

CO2 Compression and Purification Unit with Double Flash System – High Purity

(HP)

CO2 Five-Stage Compression and Dehydration (C&D) for Oxy-Combustion

Process Results, Costs and Storage Suitability

Power Plant Net Efficiency Loss

5.7% 5.1%

4.5%

21% Reduction21% Reduction

CO2 price (£) per ton sold for EOR for a Minimum Rate of Return on Investment of 20% as a Function of CO2 Stream Purity

A Value for CO2 : Enhanced Oil Recovery

Hard Constraint @ Injection PointHard Constraint @ Injection Point

Currently Problematic ? – Low oil prices

The Economist, The new Economies of Oil, Sheiks vs Shale, Dec. 6 2014

15

43 44 45 46 47 48 49

36 37 38 39 40 41 42

29 30 31 32 33 34 35

22 23 24 25 26 27 28

15 16 17 18 19 20 21

8 9 10 11 12 13 14

1 2 3 4 5 6 7

3.8

33.7

24.2

6.0

7.3 15.7

25.511.5

103.164.4

48.2

9.0

105.0

Flowrate (MtCO2/yr)

Capture Target 105 MtCO2/yr

Prada P., Konda M., Shah N., et al. Development of an Integrated CO2 Capture, Transportation and Storage Infrastructure for the UK and North Sea using an Optimisation Framework , Imperial College, MSc Thesis, 2010.

Multiple Sources

Multiple Purification

Options

CO2 Transport Networks – UK Example

16

Optimize for Highest Purity?

Optimize for Highest Purity?

99.98% CO299.98% CO2

Distillation:99.98% CO2 @

19.5 £/ton

Distillation:99.98% CO2 @

19.5 £/ton

Double Flash:97.5% CO2 @

16.5£/ton

Double Flash:97.5% CO2 @

16.5£/ton

Compression & Dehydration:83% CO2 @

11.5£/ton

Compression & Dehydration:83% CO2 @

11.5£/ton

Optimize for Lowest Cost?Optimize for

Lowest Cost?

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CO2

HUB HUB

HUB

HUBHUB

INJECTION@ 14.7 £/tCO2

96% CO2

INJECTION@ 14.7 £/tCO2

96% CO2

96% CO2

99.8 MtCO2/year96% CO2

99.8 MtCO2/year

HUB

CO2 Transport Networks – UK Example Optimised for Lowest Cost

Obtained a price at which the final CO2

product at the network sink can be

sold for the purpose of EOR, whilst

maintaining CO2CPU ROR at 20%.

Obtained a price at which the final CO2

product at the network sink can be

sold for the purpose of EOR, whilst

maintaining CO2CPU ROR at 20%.

Established an optimum combination

of product purities to put into a transport

network of CO2

(source – hub – sink) that will result in

an injectable CO2 stream.

Understood the effect that different

impurities (N2, O2, Ar, H2O…) have on

CO2 transport, storage and usage for

Enhanced Oil Recovery.

Established a set of oxy-combustion

CO2 Compression and Purification

Unit Models that incur different costs for

different CO2 product purities.

Conclusions

Future Work

Drive choice of CO2 transport network combinations

Drive choice of CO2 transport network combinations

Select the appropriate CO2 Compression and Purification Unit

Establish a maximum price at

which CO2 could be sold to oil

producers

Understand the Economics of

CO2-EOR

Thank You

References

• IEAGHG. Effects of Impurities on Geological Storage of CO2. Global CCS Institute, Paris: IEAGHG, 2011, 87.

• Godec, Michael L. Global Technology Roadmap for CCS in Industry Sectoral Assessment CO2 Enhanced Oil Recovery. Market Report, United Nations Industrial Development Organization, Arlington: Advanced Resources International, 2011, 44.

• Wettenhall B., Race J.M., Downie M.J. "The Effect of CO2 Purity on the Development of Pipeline Networks for Carbon capture and Storage Schemes." Internation Journal of Greenhouse gas control, no. 30 (2014): 197-211.

• Optimization of CO2 compression and purification units (CO2CPU) for CCS power plants. Posch S., Haider M. 2012, Fuel, pp. 254-263.

• Dynamis CO2 quality recommendations. de Visser E., Hendriks C, Barrio M, Mølnvik MJ, de Koeijer G, Liljemark S, et al. 2, 2008, Int J Greenhouse Gas Control, pp. 478-84.

• Posch S., H. M. (2012). Optimization of CO2 compression and purification units (CO2CPU) for CCS power plants. Fuel, 254-263

• National Grid. "Safety Statement Document 6.47." The Yorkshire and Humber (CCS Cross Country Pipeline) Development Consent Order. 2009. http://infrastructure.planningportal.gov.uk/wp-content/ipc/uploads/projects/EN070001/2.%20Post-Submission/Application%20Documents/Environmental%20Statement/6.4.7%20Safety%20Statement.pdf (accessed January 2015).

• Boot-Handford M.E., A. J.-C. (2014). Carbon Capture and Storage Update. Energy Environ Sci, 130-189.

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IV. Process Assumptions

• Models developed using Aspen HYSYS – Peng Robinson property method• Pulverized coal firing plant at nominal load (flue gas composition calculated in

retrofit study of existing plant - Posch et al. 2012[1]) • Plant operation 8460 hours per year • Plant operating lifetime: 35 years• Power output requirements in agreement with literature values[2]

• Aspen HYSYS process utility cost assumptions:

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Name FluidConditions

Pressure (gauge)/Temperature Cost Units

Electricity 0.05760 £/KW

Propane Refrigerant 105 kPag; -40 C 0.05800 £/ton

LP Steam Steam 0 kPag ; 125 C 0.000002 £/KJ

Refrigerant 1 Propane 0 kPag; -24 C 0.000003 £/KJ

Ethane Refrigerant 105 kPag; -90 C 0.036000 £/ton

Freon 12 Refrigerant 105 kPag; -29.8 C 0.170000 £/ton

[1] Posch S., H. M. (2012). Optimization of CO2 compression and purification units (CO2CPU) for CCS power plants. Fuel, 254-263[2] White, V., Allam, R., & Miller, E. (n.d.). Purification of Oxyfuel-Derived CO2 for Sequestration or EOR, 1–6. Retrieved from http://www.netl.doe.gov/File Library/Research/Coal/ewr/co2/5309-Air-Products-oxy-combustion-GHGT-8-paper.pdf

Effects of Impurities in Captured CO2

Effect on Transport Effect on Storage Reasoning

Component Effect Tolerance Effect Tolerance

Saline Aquifer EOR SalineAquifer EOR

CO2 >96%vol oil viscosity, mobility

>95.5 vol% >95.5 vol% Balance with other compounds

N2 Operating Pressure due to volume = costsViscosity = Mass flux

Max 4mol% for all non condensable gases

densityStorage capacityInjectivityIFT = residual trapping

MMP= risk of reaching rock fracture pressure.

<4 vol% <4 vol% Non condensable gas with Tc & Pc below that of CO2

-shift up of two-phase region

Ar Same as above IDEM Same as above Same as above <4 vol% <4 vol% Same as above

O2 Same as above IDEM Same as above& risk of acidic pockets forming causing rock dissolution

Same as above -overheating at injection point-oxidation of oiloil viscosity-increase biological growth (?)

<4 vol% 100-1000 ppm

Same as above& oxidation with SOx and NOx & reaction with pyrite (FeS2) of rock.

H2O Corrosion& Plugging and material damage

50 ppmv No effect No effect <500-750 ppm

<500 ppm Hydrate formation & free water formation

SO2 Does not affect operating pressure

>100 ppmv storage capacitypH = dissolution of rock minerals= CO2 injectivity

MMPhigh volumes

toxic

<100 ppm <100 ppm ToxicityTc & Pc above that of pure CO2 -Shift down in 2-phase region-Sulfuric acid synthesis

23

*Saline Aquifer

CCS projects by Industry type and Region

Source: Global CCS Institute 2014