Hydrocarbon Processing - August 2022 - 32
Refining Technology
FIG. 2. CO2 capture utilizing amine or similar chemical solvents for low-pressure streams.
covery of ~500 tpd will not achieve economies
of scale.
Pre-combustion CO2
capture applied
to refinery process heating requires the
conversion of the refinery fuel to decarbonized
H2
, as discussed in the previFIG.
3. CO2 compression unit.
TABLE 3. Estimated CO2 emissions from furnaces
Furnace
Atmospheric tower
Vacuum tower
Naphtha hydrotreater
Catalytic naphtha reformer
Kerosene hydrotreater
Diesel hydrotreater
Gasoil hydrocracker
FCC post hydrotreater
Coker furnace
Coker naphtha hydrotreater
similar solvents-can achieve high levels
of CO2
cooling of flue gas, a CO2
capture due to fast kinetics and
capture requires ducting, fans,
absorber, a regenerator
and CO2 compression/drying
(FIGS. 2 and 3).
Low pressure requires large ducts and
fans, which consume significant power;
to be economical, the CO2
32 AUGUST 2022 | HydrocarbonProcessing.com
capture equipment
must be located near the emissions
source. This imposes limitations for retous
section. Because of the centralized
production of fuel for the entire refinery,
Duty, MW
73
32
11
22
12
18
31
20
97
23
CO2
, tpd
370
160
60
110
60
90
160
100
500
120
rofit applications that typically do not
have space for ducting,
strong chemical reactions. Post-combustion
CO2
capture facillarge
cooling
capture
pre-combustion can be built at economic
scale capacities. The next section discusses
CO2
capture from an SMR H2
required to produce H2
CO2
production
unit. Many existing refineries have
SMRUs to meet process H2
cated SMR H2
needs. A dediunit
with carbon capture is
for process heating.
The technical feasibility of using H2
in refinery heaters has been ascertained.3
reduction from SMR H2
production.
An SMR plant consists of four major
sections:
* Feedstock pre-treatment
* Steam reformer
* Shift reactor
* Pressure swing adsorption (PSA)
unit.
CO2 is generated by the reforming and
equipment and absorbers. Additionally,
to lower the capital cost, the CO2
units must exploit economies of scale.
Providing a dedicated CO2
ity for each furnace in the above refinery
example is not an economic choice. The
present state of the art design for CO2
capture from low-pressure streams can
handle ~3,000 tpd in a single absorber
train. Therefore, designing for CO2
rewater-gas
shift reaction, the combustion
of CO in the PSA tail gas, and the combustion
of natural gas as supplementary fuel.
This implies that CO2
could be captured
from three possible locations (FIG. 4):
1. Shifted syngas
2. PSA tail gas
3. SMR flue gas.
TABLE 4 presents the typical pressure,
CO2 mol% and CO2
quantity in
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Contents
Hydrocarbon Processing - August 2022 - Cover1
Hydrocarbon Processing - August 2022 - Cover2
Hydrocarbon Processing - August 2022 - Contents
Hydrocarbon Processing - August 2022 - 4
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Hydrocarbon Processing - August 2022 - Cover4
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