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.

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ECONOMICAL ASSESSMENT
Energy costs
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ECONOMICAL ASSESSMENT
Costs
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ECONOMICAL ASSESSMENT
Costs
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ECONOMICAL ASSESSMENT
Revenue
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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!