Refinery unit capacities

Complexity: 13.9

Major process units:

Atmospheric distillation - 375 kbpd - CDU 1 and CDU 2

Vacuum distillation - 330 kbpd

Coker - 105 kbpd - Three trains (DC A-C) - Foster Wheeler, 6 drums, 27 ft diameter drums

FCC - 88 kbpd - two units

Hydrocracker - 119 kbpd - Two units: Chevron Isocracker

Reformer - 62 kbpd - Continuous CCR - UOP platformer

Reformer - 40 kbpd - Semiregen

Naphtha hydrotreater - 61 kbpd

Kerosene hydrotreater - 34 kbpd

Distillate hydrotreater - 36 kbpd

VGO hydrotreater - 154 kbpd

Alkylation - 22 kbpd

Aromatics extraction - 21 kbpd

Hydrogen production - 230 MMscfd

Base oil plant - 25 kpd

Pet coke - 36 kbpd

Sulfur plant - 1264 t/d

Land -  3000 acres

Four marine terminals with 7 berths

200 tanks, with 600MM ga capacity

Refinery history

1963 - Built by Standard Oil of Kentucky (subsidiary of Standard Oil of California). Included crude unit (100 kbpd) , FCC, hydrocracker, reformer, alkylation, and hydrogen plant. $103 MM

1966 - Added paraxylene unit and ammonia plant (later closed). $54MM

1968 - Expansion to double capacity with new crude unit, hydrocracker, reformer, hydrogen plant, and sulfur plant. $91MM

1974 - $96MM project adding new reformer, replacing sulfur plant with two new ones, adding VGO hydrotreater, naphtha splitter, and flexible hydrotreater.

1977 - Company changed name to Chevron

1983 - Major deep conversion project ($1.3B) adding a Coker added (71 kbpd), second alkylation and hydrogen plants, two sulfur tail gas units, coker, hydrodenitrification unit, and converted VGO hydrotreater to diesel hydrotreater. 

1992 - Addition of Aromatics unit ($200MM)

1996 - $240MM project to expand paraxylene and ethylbenzene

2001 - Merged with Texaco to form Chevron Texaco

2003 - $150 million expansion Clean Fuels Project, added a new low-pressure vacuum column at the Crude I Unit and modified the Crude II Unit and the VDU (Vacuum Distillation Unit) to provide heavier feed to the Coker Unit; replaced six petroleum coke drums with larger capacity drums and replaced the wet-gas compressor at the Coker Unit; reconfigured the Coker HDN (Hydrodenitrification) Unit), that previously treated FCC feed, to a diesel treating plant; and reconfigured the RDS Unit, which previously provided feed to the Coker Unit, to pre-treat feed going to the FCC Unit. Additional modifications were made to support facilities such as new feed pumps and conveyor modifications at the Blending and Shipping Areas, and compressor modifications at the Water Treating Plant.

2005 - Changed name to Chevron

2006 - $150MM additional FCC 

2010 - Replaced existing reformers with new CCR (platformer)

2013 - Added base oil plant (25 kbpd) and two new berths at the Chevron wharf, 16 new product tanks, new railcar capabilities. $1.4B project.