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Biogas upgrading by a Spinning Fluids Reactor
Robert Aranowski
BEIC Seminar on Biogas Upgrading, Malmö 14th August 2018
1
Principles of SFR operation
2
Reactor Head
Reactor Body
Inner Porous Partition
LIQUID INLET
GAS INLET
Liquid flow in SFR
Miller, J,D,, J, Hupka, and R, Aranowski, Spinning fluids reactor, 2012, Patent US 20110223091 A1; WO 2010014918 A3
Mechanism of bubble generation in
stagnant liquid
3
wFF
gNd
r ggc
p
k )(6
2
3
3
)(12
gN
rd
ggc
kp
Bubble generation in stagnant liquid
Where: rk - radius of capillary, - surface tension, dp - diameter of bubble,
c - density of liquid, g - density of gas, g - gravitational acceleration, Ng - dimensionless centripetal acceleration
Mechanism of bubble generation in SFR
4
ow FFF
42
22
bc
o
duF
2
16
u
rd
c
kb
4
1
32
24
c
kp
f
r
ud
Bubble generation in flow liquid
Where: db, dp - diameter of bubble, u - linear liquid velocity, - resistance coefficient depended from Reynolds's number,
- viscosity, f - friction factor
Laminar flow Turbulent flow
Inner porous partition
5
Pictures of the air bubbles
generated in SFR 5
0 L
/min
Water 5 ppm MIBC
30
L/m
in
70
L/m
in
Wate
r flow
rate
As the Inner porous partition can be used porous
materials or fine screens
Bubble size generated in SFR
6
Bubble size distribution for QW = 20 dm3/min, QG= 25 m3/h
Bubble size distribution for QW = 20 dm3/min, QG= 35 m3/h
Bubble size distribution for QW = 20 dm3/min, QG= 55 m3/h
Bubble size distribution for QW = 30 dm3/min, QG= 45 m3/h
Ab
un
dan
ce (
%)
Ab
un
dan
ce (
%)
Ab
un
dan
ce (
%)
Ab
un
dan
ce (
%)
Diameter (mm) Diameter (mm)
Diameter (mm) Diameter (mm)
Residence time of liquid in SFR
7
Porous Partition -
Perforated Plate
0 20 40 60 80 100 120
0,2
0,4
0,6
0,8
1,0
Re
sid
en
ce
Tim
e (
s)
Gas flow (m3/h)
Liquid flow (dm3/min)
37.5
56.3
75.0
7 m
0,7 m
0,40 m
0,24 m
Comparison of absorption column
size vs, SFR system
8
Typical interfacial area in absorption column is 60-440 m2/m3
Interfacial area in SFR system is up to 20 000 m2/m3
Ajay Mandal, Gautam Kundu* and Dibyendu Mukherjee, Interfacial Area and Liquid-Side Volumetric Mass Transfer Coefficient in a Downflow Bubble
Column, The Canadian Journal of Chemical Engineering, Volume 81, April 2003, 215-219
0 20 40 60 80 100 120
0
5000
10000
15000
20000
25000
Inte
rfe
cia
l a
rea
(m
2/m
3)
Gas flow (m3/h)
Liquid flow (dm3/min)
18.7
37.5
56.3
75.0
Block diagram of biogas
upgrading process
ABSORPTION I
ABSORPTION II
ABSORPTION III
HEAT RECOVERY
HEATING
DESORPTION COOLING
BIOGAS
CO2
CH4 RICH AMINE
LEAN AMINE
9
CO2-DGA absorption – desorption equilibrium
10
0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8
0
200
400
600
800
1000
1200
Ciś
nie
nie
(kP
a)
nCO2/nDGA (-)
40st.C
100st.C
280 300 320 340 360 380
0
20
40
60
80
100
Prę
żn
ość (
kP
a)
Temperatura (K)
Dane eksperymentalne
Aproksymacja P(T)=Aexp(T/B)+To
Partial pressure of carbon dioxide vs, temperature in
60% solution of DGA
Partial pressure of carbon dioxide vs, CO2
concentration in 60% solution of DGA
Diglicolamine was selected due to sufficient CO2
absorption capacity and high reaction rate
required for SFR - very short residence time
Most common solvents used in biogas upgrading process are
mainly primary or secondary amines (monoethanolamine,
diethanolamine, diglycolamine),
NH2
O OH
Diglycolamine
Pa
rtia
l pre
ssu
re (
kP
a)
Pa
rtia
l pre
ssu
re (
kP
a)
Temperature (K)
Lay-out of biogas upgrading system
ABSORPTION UNIT DESORPTION UNIT HEAT RECOVERY AND MAKE UP UNIT
BIOGAS FEED UNIT HEAT RECOVERY AND MAKE UP UNIT
DESORPTION UNIT ABSORPTION UNIT
11
Design of SFR absorption module
BIOGAS
BIOGAS UPGRADED
LEAN AMINE
RICH AMINE
LEAN AMINE
RICH AMINE
BIOGAS
BIOGAS UPGRADED
12
Control system
13
Fully automatic control Automatic start-up an hold-up Recording all of measured and set parameters
View of container modules of upgrading
biogas system
14
View of absorption unit of upgrading
biogas system
15
View of heat recovery and make up unit (on left) and
desorption unit (on right) of upgrading biogas system
16
Methane concentration in biogas before
and after upgrading process
17
0
50
100
150
200
250
300
24:00
Bio
ga
s flo
w r
ate
(N
m3/h
)
Time (h)8:30
0
20
40
60
80
100
Methane concentration
beforea upgrading process
fter upgrading process
Co
nce
ntr
atio
n (
%)
Carbone dioxide concentration in biogas
before and after upgrading process
18
95
100
105
110
De
so
rptio
n te
mp
era
tura
(d
eg
C)
Time (h)
0
20
40
60
80
100
Carbon dioxide concentration
before upgrading process
after upgrading process
8:30 24:00
H2S concentration in biogas before and
after upgrading process
19
0
2
4
6
8
10
Pre
ssu
re d
rop
(kP
a)
Time (h)
0
100
200
300
400
500
600
C
on
ce
ntr
atio
n (
pp
m)
H2S concentration
before upgrading process
after upgrading process
8:30 24:00
Energy consumption and operation
cost to remove 1kg of CO2
Factor Quantity/1kgCO2 Quantity/year Unit
Electricity 0.234 163 987 kWh
Soft water 0.014 9811 dm3
DGA 0.003 1598 dm3
Thermal oil 0,0034 103 dm3
Diethyl glycol 0,0016 49 dm3
20
21
This work was founded by The National Center for Research and Development under Strategic Program of Research and Development titled Advanced Technology of Energy Production, task no, 4 and by ENERGA S,A, Company,
Acknowledgements
Jan Hupka, Bartosz Dębski, Kacper Kamienicki,
Łukasz Banach, Przemysław Wojewódka
Chemical Faculty, Department of Chemical Technology
Gdansk University of Technology
Thank you for your attention