material will subsequently go to the splitter and debutanizer, respectively. The
existing reformer and light end unit will also be expanded to cater for the thermal
cracker light products. The gas oil from the thermal cracker will be hydrotreated in
a new or expanded hydrotreater to meet diesel pool requirements. Thus, new unit
sizes will be
Naphtha hydrotreater : Total new flow ¼ 14, 809 BPCD þ 12, 732 BPCD
¼ 27, 541 BPCD
New size at 86 % service factor ¼
27, 541
0:86
¼ 32, 024 BPSD
which is an increase of 72 % above the existing unit. This is too large to consider a
revamp: therefore, build a new 13,500 BPSD unit in parallel. The same applies to
the splitter.
Catalytic Reformer
New feed to the reformer is 16,191 BPCD. At a 86 % service factor, the new size will be
17, 504
0:86
¼ 20, 353 BPSD:
Revamp the catalytic reformer by 9,000 BPSD.
Light Ends
New total feed to the debutanizer is 9,283 BPCD. With a service factor of 90 %, this
gives a new capacity of 10,000 BPSD, an increase of 58 %. This unit will be
revamped at a cost of 10 % of a new unit.
The depropanizer and deethanizer will be expanded with parallel units the same
size as the existing ones.
The Diesel Hydrotreater
A new hydrotreater of 9,000 BPSD will be designed to cater for the additional gas
oil from the thermal cracker. The new total amount of gas oil to be treated is 4, 894
BPCD þ 7, 851 BPCD ¼ 12, 745 BPCD. There is 706 BPCD spare capacity in the
existing hydrotreater through improved catalyst and service factor. Taking this into
consideration with a service factor of 80 %, the additional capacity required will be
9,000 BPSD.
Operating Costs
The following tables (Tables 5 and 6) give approximate factors for utilities and
labor for some refinery plants. Note: the use of these is acceptable for the screening
analysis given here. For detailed economic analysis of the selected configuration,
more accurate operating costs using certified vendor and licensor data must be used.
Petroleum Refinery Planning and Economics
707
existing reformer and light end unit will also be expanded to cater for the thermal
cracker light products. The gas oil from the thermal cracker will be hydrotreated in
a new or expanded hydrotreater to meet diesel pool requirements. Thus, new unit
sizes will be
Naphtha hydrotreater : Total new flow ¼ 14, 809 BPCD þ 12, 732 BPCD
¼ 27, 541 BPCD
New size at 86 % service factor ¼
27, 541
0:86
¼ 32, 024 BPSD
which is an increase of 72 % above the existing unit. This is too large to consider a
revamp: therefore, build a new 13,500 BPSD unit in parallel. The same applies to
the splitter.
Catalytic Reformer
New feed to the reformer is 16,191 BPCD. At a 86 % service factor, the new size will be
17, 504
0:86
¼ 20, 353 BPSD:
Revamp the catalytic reformer by 9,000 BPSD.
Light Ends
New total feed to the debutanizer is 9,283 BPCD. With a service factor of 90 %, this
gives a new capacity of 10,000 BPSD, an increase of 58 %. This unit will be
revamped at a cost of 10 % of a new unit.
The depropanizer and deethanizer will be expanded with parallel units the same
size as the existing ones.
The Diesel Hydrotreater
A new hydrotreater of 9,000 BPSD will be designed to cater for the additional gas
oil from the thermal cracker. The new total amount of gas oil to be treated is 4, 894
BPCD þ 7, 851 BPCD ¼ 12, 745 BPCD. There is 706 BPCD spare capacity in the
existing hydrotreater through improved catalyst and service factor. Taking this into
consideration with a service factor of 80 %, the additional capacity required will be
9,000 BPSD.
Operating Costs
The following tables (Tables 5 and 6) give approximate factors for utilities and
labor for some refinery plants. Note: the use of these is acceptable for the screening
analysis given here. For detailed economic analysis of the selected configuration,
more accurate operating costs using certified vendor and licensor data must be used.
Petroleum Refinery Planning and Economics
707