Diapositiva 1

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A FEASIBILITY STUDY FOR PIPELINE
TRANSPORTATION OF CO2 AND ITS STORAGE IN A
SEMI-DEPLETED GAS RESERVOIR   ÖZGÜR
GÜNDOGAN  
Supported by Turkish Petroleum Corporation

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THE RESERVOIR
Kuzey Marmara

• Offshore Marmara Sea
• Onstream since 1997
• OGIP5.1MMSm3
• Natural depletion reservoir
• Anticlinal structure
• Reservoir rock bioclastic limestone
• Reservoir top 1150m
• f20, k50mD
• Pi2075psia(143bar), T68C

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STORAGE OF NATURAL GAS
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CAPTURE - TRANSPORTATION STORAGE OF CO2
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CAPTURE
Source of CO2

• NGCC (Natural Gas Combined Cycle) plant
• nominal capacity 468 MW
• real capacity 85 of nominal capacity
• emission factor 450 kg CO2/MWh
• concentration of CO2 in flue gas 4 volume
• working hours 8000 h/year

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CAPTURE
Fluor Daniel Econamine FG process

• post-combustion capture
• chemical absorption
• monoethanolamine (MEA) at 30
• pureness of CO2 99
• recovery rate 90

Absorber
2R-NH2 CO2 ? R-NH3 R-NH-COO-
Stripper
R-NH-COO- R-NH3 (calore) ? CO2 2R-NH2
RHO-CH2CH2
3530 tons of CO2 per day
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COMPRESSIONE
Number of stages
16 MW
Potenza (MW)
Pin3bar (43,5psia) Pout141bar (2050psia)
Tin38C Q1,800 MSm3/d
E80
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CONDITION OF CO2
Phase diagramme of CO2
Density of CO2
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TRANSPORTATION
Performance requirements

• nominal capacity of 2,0 MSm3/day
• maximum inlet pressure 2200 psia (152 bar)
• inlet temperature 35C
• maximum soil temperature 24C

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TRANSPORTATION
Sensitivity analysis
Tubing curve for 8
Tubing curve for 6
Tubing curve for 10
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TRANSPORTATION
Pipe thickness
Parameters

• 100 CO2
• The pipeline has cooled to 6,2C, which is the
  minimum temperature of the soil at 1m of depth.
• Maximum inlet pressure is 2200 psia (152 bar)
• The pipe can be stressed to 72 of specified
  minimum yield strength
• Internal corrosion none

7,8mm
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STORAGE
Reservoir model
Tank model

• zero-dimensional
• uniform porosity
• uniform saturation
• constant temperature
• uniform pressure

Material balance equation
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STORAGE
Model calibration
History matching
Tank pressure and cumulative gas production
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STORAGE
Model calibration
History matching - Sensitivity
Standard deviation against gas in place
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STORAGE
Model calibration
History matching production prediction
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STORAGE
Cushion and working gas
Pcushion1200 psia (82,7 bar) Pmax2014,7 psia
(139 bar)
Pi2075 psia (143 bar)
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STORAGE
Well capacity
5 Offshore wells maximum capacity0,54
0,86SMm3 6 Onshore extended reach wells maximum
capacity1,3 1,6SMm3
Well model VLP/IPR intersection
IPR
IPR MODEL
VLP
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STORAGE
Simulation

• Simulation has four phases
• depletion phase
• storage of CO2
• repressurization
• storage cycles

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STORAGE
Depletion phase
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STORAGE
Depletion phase

• Period 01/06/2005 29/11/2008
• Final pressure 755psia
• Cumulative factor 3375 MSm3
• Recovery factor 66

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STORAGE
Storage of CO2
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STORAGE
Storage of CO2
Tank pressure and cumulative gas injection with
storage of 2349 MSm3 of CO2
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STORAGE
Repressurization
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STORAGE
Storage cycles
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ECONOMICAL ASSESSMENT
Costs

• The cost of the project can be divided in three
  classes
• Capital costs (Capex)
• Operation and maintenance costs (Opex)
• Energy costs.

    CAPEX ()   OPEX ()
  COST UNIT TOTAL COST
Pipeline Onshore 125,00 30.000,00 3.750.000,00 50.000
Pipeline Offshore 375,00 2.563,00 961.125,00 50.000
Capture Process 135.000.000,00 1,00 135.000.000,00 14.000.000
Compressione 11.500.000,00 1,00 11.500.000,00 800.000
Storage     250.000
Total 151.211.125,00 15.100.000
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ECONOMICAL ASSESSMENT
Energy costs
  Capture Compression Total () /tCO2 /tCO2seq
1 year 12.352.500 2.819.585 15.172.085 12,44 14,46
2 year 12.352.500 3.095.375 15.447.875 12,66 14,72
3 year 12.352.500 3.405.875 15.758.375 12,92 15,02
4 year 7.178.625 2.143.119 9.321.744 13,15 15,29
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ECONOMICAL ASSESSMENT
Costs
  Capex Opex Energy Total () /tCO2 /tCO2seq.
1 year 47.910.862 15.100.000 15.172.085 78.182.947 64,08 74,52
2 year 47.910.862 15.100.000 15.447.875 78.458.737 64,31 74,78
3 year 47.910.862 15.100.000 15.758.375 78.769.237 64,56 75,08
4 year (7months) 27.948.003 8.800.000 9.321.744 46.069.747 64,98 75,56
Total 171.680.589 54.100.000 55.700.079 281.480.668 64,43 74,91
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ECONOMICAL ASSESSMENT
Costs
  CAPEX (/CO2seq) OPEX (/CO2seq) ENERGY (/CO2seq) TOTAL (/CO2seq)
CAPTURE 40,85 13,35 11,77 65,97 88,06
TRANSPORTATION 4,84 0,81 3,05 8,70 11,62
STORAGE - 0,24 - 0,24 0,32
TOTAL 45,69 14,40 14,82 74,92 100
60,99 19,22 19,79 100
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ECONOMICAL ASSESSMENT
Revenue
  Gas production (MSm3) Value ()
30.11.2005 417 41.700.000
30.11.2006 566 56.600.000
30.11.2007 339 33.900.000
30.11.2008 197 19.700.000
Total 1.519 151.900.000
  Capex- V. gas Opex Energy Total () /tCO2 /tCO2seq
1 Anno -285.561 15.100.000 15.172.085 29.986.524 24,58 28,58
2 Anno -285.561 15.100.000 15.447.875 30.262.314 24,81 28,84
3 Anno -285.561 15.100.000 15.758.375 30.572.814 25,06 29,14
4 Anno (7 mesi) -166.568 8.808.000 9.321.744 17.963.176 25,34 29,46
Total -1.023.251 54.108.000 55.700.079 108.784.828 24,90 28,95
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ECONOMICAL ASSESSMENT
Credits ( 20 / tCO2) Constant
/t CO2 seq
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ECONOMICAL ASSESSMENT
Value of cushion gas (0,10 ) Constant
/t CO2 seq
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• Sequestration of CO2 in a semi-depleted gas
  reservoir is a valid option.
• The substitution of cushion gas with CO2 is
  economically valid.
• The economical analysis showed that the actual
  value of emission credits, 20 per ton of CO2,
  is insufficient to offset the investments.
• Costly to capture CO2
• Mixing between natural gas and CO2?
• The physical and chemical interactions between
  CO2, natural gas, water, reservoir and caprock?
• Long run fate of CO2?
• Future of capture plant?

CONCLUSIONS
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THANK YOU FOR YOUR ATTENTION!