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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
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UNIVERSITY OF ROME "LA SAPIENZA"FACULTY OF ENGINEERING Department of Chemical Engineering, Raw Materials and Metallurgy “A FEASIBILITY STUDY FOR PIPELINE TRANSPORTATION OF CO2 AND ITS STORAGE IN A SEMI-DEPLETED GAS RESERVOIR” ÖZGÜR GÜNDOĞAN Supported by Turkish Petroleum Corporation
THE RESERVOIR Kuzey Marmara • Offshore Marmara Sea • Onstream since 1997 • OGIP:5.1MMSm3 • Natural depletion reservoir • Anticlinal structure • Reservoir rock: bioclastic limestone • Reservoir top: 1150m • f:20%, k:50mD • Pi:2075psia(143bar), T:68°C
PROCESS & COMPRESSION INJECTION & WITHDRAWAL INJECTION & WITHDRAWAL GAS TRASPORTATION STORAGE OF NATURAL GAS
INJECTION SOURCE CAPTURE COMPRESSION TRANSPORTATION CO2 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
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- R-NH-COO- + R-NH3+ + (calore) → CO2 + 2R-NH2 Stripper: R=HO-CH2CH2 3530 tons of CO2 per day
COMPRESSIONE Number of stages 16 MW Potenza (MW) Pin=3bar (43,5psia) Pout=141bar (2050psia) Tin=38°C Q=1,800 MSm3/d E=80%
Operation range Operation range CONDITION OF CO2 Phase diagramme of CO2 Density of CO2
Onshore Offshore 63m 30000m 2500m 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
TRANSPORTATION Sensitivity analysis Tubing curve for 8” Tubing curve for 6” Tubing curve for 10”
TRANSPORTATION 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 7,8mm
STORAGE Reservoir model Tank model • zero-dimensional • uniform porosity • uniform saturation • constant temperature • uniform pressure Material balance equation
STORAGE Model calibration History matching Tank pressure and cumulative gas production
STORAGE Model calibration History matching - Sensitivity Standard deviation against gas in place
STORAGE Model calibration History matching – production prediction
Cushion gas = = 2,86*109 Sm3 Maximum capacity = = 4,95*109 Sm3 Working gas = Max. capacity– Cushion gas = 4,95*109 – 2,85*109 =2,1*109 Sm3 STORAGE Cushion and working gas Pi=2075 psia (143 bar) Pcushion=1200 psia (82,7 bar) Pmax=2014,7 psia (139 bar)
STORAGE Wellcapacity 5 Offshore wells: maximum capacity:0,54 – 0,86SMm3 6 Onshore extended reach wells: maximum capacity:1,3 – 1,6SMm3 Well model: VLP/IPR intersection IPR IPR MODEL: VLP
STORAGE Simulation • Simulation has four phases: • depletion phase • storage of CO2 • repressurization • storage cycles
STORAGE Depletionphase
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
STORAGE Repressurization
STORAGE Storage 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.
ECONOMICAL ASSESSMENT Energy costs
ECONOMICAL ASSESSMENT Costs
ECONOMICAL ASSESSMENT Costs
ECONOMICAL ASSESSMENT Revenue
ECONOMICAL ASSESSMENT Credits (= 20 € / tCO2) : Constant €/t CO2seq
ECONOMICAL ASSESSMENT Value of cushion gas (0,10 €): Constant €/t CO2seq
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