BP Cherry Point Refinery - Permitting Information
1. Facility Information
BP Cherry Point Refinery
2. Location
Northwestern Whatcom County, 7 miles southeast of Blaine, Washington.
3. Distance from US/Canada Border
8 miles
4. Facility Type and Size
Large complex petroleum refinery (225,000 barrels crude processed per day) is proposing a Clean Gasoline Project. The project consists of a Straight Run Naphtha Dehexanizer, a Naphtha Hydrotreater, and a Benzene Saturation - Isomerization Unit (UOP Penex-PlusT). The purpose of the project is to process light naphtha feedstocks to produce a gasoline blend component that has essentially no benzene, olefins, or sulfur, and is higher in octane than its feed. The project will allow the refinery to meet the 2005 federal standard for sulfur in gasoline and will decrease benzene in all gasoline produced at the refinery.
5. Sources of Emissions
New Isomerization Unit (process heaters and fugitive emissions from equipment leaks), Existing Boilers, Existing Hydrogen Heaters, Existing Storage Tanks, Existing Sulfur Recovery Unit.
6. Type of Fuel
Refinery Fuel Gas.
7. Type and Quantity of Emissions & Emission Control Technology
BP is required to install best available control technology (BACT) on new Isomerization Unit process heaters. For the two new process heaters (100 MMBtu/hr & 18 MMBtu/hr), BP estimates the following potential emissions and proposes the following controls as BACT:
| Pollutant | Quantity of Emissions (tons / yr) |
Emission Control Technology |
|---|---|---|
| NOx | 18.1 | Callidus Ultra BLUE Low NOx burners (or equivalent) |
| PM10 | 3.9 | Proper combustion |
| SO2 | 28.9 | NSPS Subpart J compliant refinery fuel gas |
| VOC | 2.8 | Proper combustion |
| CO | 23.7 | Proper combustion |
- VOC emissions from new Isomerization Unit equipment leaks will be controlled through compliance with EPA's Refinery MACT requirements at 40 CFR Part 63, Subpart CC. This MACT is considered BACT for this project.
- BACT is not required of units simply experiencing an increase in utilization. These units include existing boilers and hydrogen heaters.
- BP anticipates increased feed to the Sulfur Recovery Unit by less than 1 percent, and no detectable increase in emissions is anticipated.
- BP estimates that evaporative VOC emissions from existing tanks will decrease by 2 tons annually as a result of this project.
The overall project's emissions increases (not considering contemporaneous emissions increases and decreases) are as follows:
| Pollutant | Quantity of Emissions (tons / yr) |
|---|---|
| NOx | 166 |
| PM10 | 11 |
| SO2 | 84 |
| VOC | 31 |
| CO | 47 |
| H2SO4 | 2 |
9. Date Permit Application Received
July 25, 2002.
10. Stack Height and Diameter
Stack 1 (100 MMBtu/hr Isom Heater):
Height: 165 feet
Diameter: 7 feet
Stack 2 (18 MMBtu/hr Isom Heater):
Height: 165 feet
Diameter: 3.97 feet
For additional stack (including emissions) information for units experiencing increased utilization, please contact permitting authorities noted below.
11. Permit Agency Contact
State of Washington Department of Ecology
Air Quality Program
Attn: Robert Burmark
P.O. Box 47600
Olympia, WA 98504-7600
Phone: 360.407.6812
Northwest Air Pollution Authority
Attn: Lynn Billington
1600 South Second Street
Mt. Vernon, WA 98273-5202
Phone: 360.428.1617, ext 213