Hydrocarbon Processing - June 2022 - GP-31

PROCESS OPTIMIZATION
Parametic sensitivity analysis and
simulation modeling using MDEA.
Treatment by MDEA is shown in
TABLE 6. H2
H2S and CO2
S composition in the sweet gas
was 3.625 ppm. The recovery for removed
H2
S was 99.4%, while the recovery of both
was 64.58%. The amine
strength was 32 wt%, and the amount of
regenerated steam required for the regenerator
was 306.3 tpd. The total mass
flowrate required from MDEA was 707.48
kg/hr. The concentration (mole fraction)
of methane in the sweet gas stream was
0.8046; for ethane, it was 0.1047. The
operating conditions of the rich amine
included a pressure of 48.03 kg/cm2
and
a temperature of 38.71°C (101.7°F). The
total mass flowrate required to remove
acid gas by 64.58% was 324 bpd.
Parametic sensitivity analysis and
simulation modeling using DIPA. Treatment
by DIPA is shown in TABLE 7. H2
composition in the sweet gas was 355.6
S
TABLE 5. DGA unit dashboard
Component
Reboiler duty, kcal/hr
Regenerator steam, tpd
Acid gas loading in
regenerator bottom
Acid gas loading in
regenerator feed
Value
6.493e+006
307.3
1.822e-004
Acid gas loading in acid stream 1.036e+023
0.5655
Regenerator feed
temperature, °C (°F)
Regenerator reflux ratio
(mole basis)
Amine strength, wt%
Amine recirculation rate, bpd
Lean amine temperature,
°C (°F)
Feed gas flowrate, MMft3
H2S composition
in feed gas, ppm
H2S composition
in sweet gas, ppm
H2
S composition
in acid gas, ppm
H2S composition
in regenerator bottom, ppm
H2S composition
in regenerator feed, ppm
Recovery of amine
unit for H2
S, %
Recovery of amine
unit (H2
S and CO2
), %
d
104.4 (219.92)
161
32
282
48 (118.4)
12
599.6
8.908e-002
9.606e+004
2.624e-002
4,547
99.99
99.62
ppm. The recovery for removed H2
40.7%, while the recovery of both H2
and CO2
S was
S
was 85.12%. The amine strength
was 32 wt%, and the amount of regenerated
steam required for the regenerator
was 307.6 tpd. The total mass flowrate
required from MDEA was 774.95 kg/hr.
This data showed that the concentration
of H2
S and CO2
top of the absorber. However, H2
were with the trays at the
S concentration
increased until Tray 6, and then
decreased from Tray 5 and so on.
The concentration (mole fraction)
of methane in the sweet gas stream was
0.8051; for ethane, it was 0.1048. The
operating conditions of the rich amine
included a pressure of 48.03 kg/cm2
and
a temperature of 38.73°C (101.7°F). The
total mass flowrate required to remove
acid gas by 85.12% was 360 bpd.
Parametic sensitivity analysis and
simulation modeling using PZ treatments.
Treatments by PZ activators are
TABLE 6. MDEA unit dashboard
Component
Reboiler duty, kcal/hr
Regenerator steam, tpd
Acid gas loading in
regenerator bottom
Acid gas loading in
regenerator feed
Value
6.495e+006
306.3
3.308e-004
Acid gas loading in acid stream 1.056e+019
0.3579
Regenerator feed
temperature, °C (°F)
Regenerator reflux ratio
(mole basis)
Amine strength, wt%
Amine recirculation rate, bpd
Lean amine temperature,
°C (°F)
Feed gas flowrate, MMft3
H2S composition
in feed gas, ppm
H2S composition
in sweet gas, ppm
H2
S composition
in acid gas, ppm
H2S composition
in regenerator bottom, ppm
H2S composition
in regenerator feed, ppm
Recovery of amine
unit for H2
S, %
Recovery of amine
unit (H2
S and CO2
), %
d
104.4 (219.92)
251.7
32
324
48 (118.4)
12
599.6
3.625
1.484e+005
3.012e-004
3,967
99.4
64.58
shown in TABLE 8. H2
S composition in the
S was 100%, while the
S and CO2
was also
sweet gas was 1.872e-002 ppm. The recovery
for removed H2
recovery of both H2
100%. The amine strength was 32 wt%,
and the amount of regenerated steam required
for the regenerator was 307.4 tpd.
The total mass flowrate required from PZ
was 357.3 kg/hr. The concentration (mole
fraction) of methane in the sweet gas stream
was 0.8059; for ethane, it was 0.1049. The
operating conditions of the rich amine
included a pressure of 48.03 kg/cm2
and
a temperature of 39.03°C (102.3°F). The
total mass flowrate required to remove acid
gas by 100% was 165 bpd.
Parametic sensitivity analysis and
simulation modeling using MDEA
with sulfolane. Treatments using MDEA
with sulfolane are shown in TABLE 9. H2
S
composition in the sweet gas was 1.549
ppm. The recovery for removed H2
99.74%, while the recovery of both H2
TABLE 7. DIPA unit dashboard
Component
Reboiler duty, kcal/hr
Regenerator steam, tpd
Acid gas loading in
regenerator bottom
Acid gas loading in
regenerator feed
Value
6.498e+006
307.6
3.632e-004
Acid gas loading in acid stream 1.24e+023
0.4812
Regenerator feed
temperature, °C (°F)
Regenerator reflux ratio
(mole basis)
Amine strength, wt%
Amine recirculation rate, bpd
Lean amine temperature,
°C (°F)
Feed gas flowrate, MMft3
H2S composition
in feed gas, ppm
H2S composition
in sweet gas, ppm
H2
S composition
in acid gas, ppm
H2S composition
in regenerator bottom, ppm
H2S composition
in regenerator feed, ppm
Recovery of amine
unit for H2
S, %
Recovery of amine
unit (H2
S and CO2
), %
d
104.4 (219.92)
189.5
32
360
48 (118.4)
12
599.6
355.6
4.5968e+004
8.939e-005
1,490
40.7
85.12
Gas Processing & LNG | MAY/JUNE 2022 31
S was
S
Hydrocarbon Processing - June 2022

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