This document discusses capturing carbon dioxide (CO2) from power plant flue gas and depositing it underground. It analyzes depositing the waste gas from a power plant in Sırnak, Turkey underground. The goals are to store the CO2 in underground coal mines and use the space. Models show the CO2 capture costs decrease when combined with coal bed methane extraction, as the methane enhances CO2 sequestration in excavated coal seams. With projected methane yields of 200,000 cubic meters per year, CO2 capture and storage costs could drop to around $11 per ton of CO2.

1. Devlet Ciragoglu 1*, Yıldırım İ. Tosun 2
1,2 Faculty of
Engineering, University Sırnak, Sırnak
* Corresponding Author. Tel: +90(538) 3642045, Fax:
(486) 2164844, E-mail: dciragoglu@sirnak.edu.tr
1

2. Aim
 Deposition of gasified products plays an
important role in providing the power generation
fuels and chemicals.
 Subsoil deposition of waste gas of power plant for
Sırnak asphaltite
 Under ground deposition of natural gas or waste
gas CO2 into the coal mine rooms regarded in
energy aspect
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3. Scope
 The underground deposition process for waste gas




of Sırnak asphaltite ,
The subground space use,
Civil construction of gas reservoir for waste gas
and flue gas.
The process can accept methane coal gas drainage.
Deposition methane coal gas into sub soil caves.
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4.  Our main contribution is in analyzing the
economic issues related with methane
drainage enhancement, which can be seen
as a follow-up to the technical issues. CCS
technology may become available in the
Turkish market and that current cost
projections and expected efficiencies may be
rational values. We may see profitmaximizing conditions in the methane
drainage and gas market. Methane
production may retrofit to install CCS in
power plants under plausible values of an
environment tax.
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5.  The absorption technology for capturing carbon dioxide
from natural gas streams was developed more than 60
years ago to produce a more pure natural gas stream. The
technology of sequestering carbon dioxide from a power
plant’s flue gas was first implemented more than 20 years
ago. city from coal and 48 percent from natural gas.
Globally, coal and natural gas will continue to meet
growing energy demand, particularly in emerging market
counties, such as China and India [2, 4]. From 2007 to
2011, China’s total coal consumption increased by nearly 50
percent, while India’s increased by nearly 33 percent.
During that same time period, China’s total natural gas
consumption increased by more than 85 percent, while
India’s increased by approximately 48 percent. CCS
technology has the potential to yield dramatic reductions
in CO2 emissions from the power and industrial sectors by
capturing and storing anthropogenic CO2 in underground
geological formations. Given the magnitude of CO2
emissions from coal and natural gas fired electricity
generation, the greatest potential for CCS is in the power
sector.
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6. CO2 separation options using membrane separation,
cryogenic fractionation, absorption and adsorption
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7. CO2 capturing process with amine solutions
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8. 1/10000 Satelite image Coal Bed Methane Drainage
Site in circle of Coal Mine Site, Sırnak, Turkey.
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9. Industrial cost of CO2 Capture and Transport.
Industrial CO2 Source Cost of CO2 Capture
and Transport ($/
ton CO2)
Coal and biomass-to- 36.10
liquids
Natural
gas 36.29
processing
Hydrogen plants
36.67 to 46.12
Refineries (Hydrogen) 36.67 to 46.12
Ammonia plants
39.69
Ethanol plants
42.15
Cement plants
81.08
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10. Effect of injection distance over CH4 Desorption
from Coal Bed at 20 bar in 28 day.
10

11. 0
Distance to Injection Well Point,m
2
4
6
8
10
12
Vertical Distance to Bottom
Clay Layer,m
0
0.05
0.1
0.15
1 gün 7 gün
14gün
28 gün
0.2
0.25
0.3
0.35
0.4
0.45
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12. Distance to Injection Well Point,m
Methane Sorption ,%
0
10
20
30
0
10
20
30
40
50
60
70
80
90
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13. Parameter
Units
Sırnak
Plant
w/CO2 Contr
ol
Net plant capacity
MW (net)
135
75
CO2 emission rate g CO2/kWh (net)
750
83
SO2 emission rate
g SO2/kWh (net)
15
0.003
NOx emission rate g NOx/kWh (net)
0.4
0.5
CO2 sequestered
-
5
60 tonne CO2/yr
Cost of electricity $/MWh (net)
39.2
CO2 mitigation co $/tonne CO2 avoid st
ed
57.0
39.1
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14. CO2 capture Cost, $/ton
28
26
24
22
20
18
16
14
12
10
0 Methane Fuel Drainage Cost, $/1000m3 10
2
4
6
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15. •At projected capacity at near 200.000 m3/yr of coal
seam gas per year we can manage proposed 40% gas
yield and the cost of methane drainage mainly was
changed on drainage performances in coal production
method in-situ excavation site .
•CO2 capturing and transporting and sequestering costs are
decreased with flue gas desulfurization cost and even legal
environmental taxes. Methane drainage will be enhanced
with CO2 capturing and transporting and sequestering in
the old excavated coal seams. As given in Figure 4, it could
be revealed that CO2 capturing, transporting and
sequestering costs with methane drainage decreased to
near 11$/ton of CO2.
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16. •The present study has established a framework for
quantifying amine (MEA) based absorption systems
applied to coal fired power plants.
•The present study has confirmed that fuel methane
cost especially depended on coal seam parameters
such as methane drainage depth and local coal seam
methane content and also applied to coal fired power
plants.
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17. 17