university of rome "la sapienza" faculty of engineering
DESCRIPTION
UNIVERSITY OF ROME "LA SAPIENZA" FACULTY OF ENGINEERING. Department of Chemical Engineering , Raw Materials and Metallurgy. “A FEASIBILITY STUDY FOR PIPELINE TRANSPORTATION OF CO 2 AND ITS STORAGE IN A SEMI-DEPLETED GAS RESERVOIR ” ÖZGÜR GÜNDOĞAN - PowerPoint PPT PresentationTRANSCRIPT
“A FEASIBILITY STUDY FOR PIPELINE TRANSPORTATION OF CO2 AND ITS STORAGE IN A SEMI-DEPLETED GAS RESERVOIR”
ÖZGÜR GÜNDOĞAN
Supported by Turkish Petroleum Corporation
UNIVERSITY OF ROME "LA SAPIENZA"FACULTY OF ENGINEERING
Department of Chemical Engineering, Raw Materials and Metallurgy
THE RESERVOIR
Offshore Marmara Sea
Onstream since 1997
OGIP:5.1MMSm3
Natural depletion reservoir
Anticlinal structure
Reservoir rock: bioclastic limestone
Reservoir top: 1150m
:20%, k:50mD
Pi:2075psia(143bar), T:68°C
Kuzey Marmara
STORAGE OF NATURAL GAS
TRASPORTATION GAS
PROCESS
&
COMPRESSION
INJECTION
&
WITHDRAWALINJECTION
&
WITHDRAWAL
CO2
INJECTION
COMPRESSION
TRANSPORTATION
SOURCE CAPTURE
CAPTURE - TRANSPORTATION – STORAGE OF CO2
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
3530 tons of CO2 per day
post-combustion capture
chemical absorption
monoethanolamine (MEA) at 30%
pureness of CO2: ≥ 99%
recovery rate: 90%
CAPTURE
Fluor Daniel Econamine FG process
2R-NH2 + CO2 → R-NH3+ + R-NH-COO-
R=HO-CH2CH2
Absorber:
Stripper: R-NH-COO- + R-NH3+ + (calore) → CO2 + 2R-NH2
GAS FLUE
CO2
COOLER
DIRECT CONTACT COOLER
COOLERABSORBER
REGENERATOR
REBOILER
CROSS HEAT EXCHANGERPOMPA
BLOWER
EXHAUST GAS
MEA STORAGE
FLASHER
COMPRESSIONE
0
5
10
15
20
25
0 0,5 1 1,5 2 2,5 3 3,5 4 4,5
No. di fase
Po
ten
za (
MW
)
Pin=3bar (43,5psia)
Pout=141bar
(2050psia)
Tin=38°C
Q=1,800 MSm3/d
E=80%
Number of stages
16 MW
CONDITION OF CO2
Operation range
Operation range
Density of CO2
Phase diagramme of CO2
TRANSPORTATION
Performance requirements
nominal capacity of 2,0 MSm3/day
maximum inlet pressure: 2200 psia (152 bar)
inlet temperature: 35°C
maximum soil temperature: 24°C
Onshore
Offshore
30000m2500m
63m
TRANSPORTATION
Tubing curve for 6”
Sensitivity analysis
Tubing curve for 8”
Tubing curve for 10”
TRANSPORTATION
7,8mm
Pipe thickness
Parameters
100% CO2
The pipeline has cooled to 6,2°C, 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
STORAGE
Reservoir model
Tank model
)(1
)(
PPS
CCSBBB
WBGGBG
iw
fww
ggg
pwipg
i
i
ii
zero-dimensional uniform porosity uniform saturation constant temperature uniform pressure
Material balance equation
STORAGEModel calibration
History matching
Tank pressure and cumulative gas production
STORAGEModel calibration
History matching - Sensitivity
Standard deviation against gas in place
STORAGE
History matching – production prediction
Model calibration
STORAGE
Cushion and working gas
Pcushion=1200 psia (82,7 bar) Pmax=2014,7 psia (139 bar)
Pi=2075 psia (143 bar)
iZP
ZPGIIP
)/(
)/( .max= 4,95*109 Sm3
Maximum capacity =
i
cushion
ZP
ZPGIIP
)/(
)/(Cushion gas = = 2,86*109 Sm3
Working gas = Max. capacity– Cushion gas = 4,95*109 – 2,85*109 =2,1*109 Sm3
STORAGE
Well capacity
IPRVLP
5 Offshore wells: maximum capacity:0,54 – 0,86SMm3
6 Onshore extended reach wells: maximum capacity:1,3 – 1,6SMm3
IPR MODEL:
nwfr PPCQ )( 22
Well model: VLP/IPR intersection
STORAGE
Simulation
Simulation has four phases:
1. depletion phase
2. storage of CO2
3. repressurization
4. storage cycles
STORAGEDepletion phase
STORAGE
Depletion phase
Period: 01/06/2005 – 29/11/2008
Final pressure: 755psia
Cumulative factor: 3375 MSm3
Recovery factor: 66%
STORAGE Storage of CO2
STORAGE
Storage of CO2
Tank pressure and cumulative gas injection with storage of 2349 MSm3 of CO2
STORAGERepressurization
STORAGEStorage cycles
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 3.750.000,0050.000
Pipeline Offshore 375,00 2.563,00 961.125,00
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
Total151.211.125,0
0 15.100.000
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
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 55.700.079281.480.66
8 64,43 74,91
ECONOMICAL ASSESSMENT
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
Costs
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 -1.023.25154.108.00
0 55.700.079108.784.82
8 24,90 28,95
ECONOMICAL ASSESSMENT
-30
-20
-10
0
10
20
30
40
0,1 0,125 0,15 0,175 0,2
valore del gas (€/Sm3)
costo energia
costo finale (alnetto dei crediti)€/
t C
O2 s
eq
Credits (= 20 € / tCO2) : Constant
-15
-10
-5
0
5
10
15
20
20 25 30 35 40
Valore dei crediti (€/t CO2seq)
costo energia
costo finale (alnetto dei crediti)
ECONOMICAL ASSESSMENT
€/t
CO
2 s
eq
Value of cushion gas (0,10 €): Constant
CONCLUSIONSSequestration 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?
THANK YOU FOR YOUR ATTENTION!