f/EPA—
United States
Environmental Protection
Agency
Detailed Study of the
Petroleum Refining Category -
2019 Report
September 2019
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U.S. Environmental Protection Agency
Office of Water (4303T)
1200 Pennsylvania Avenue, NW
Washington, DC 20460
EPA 821-R-19-008
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Table of Contents
Table of Contents
Page
1. Introduction 1-1
1.1 References 1-2
2. Petroleum Refining Regulation History 2-1
2.1 Effluent Limitation Guidelines 2-1
3. Data Sources 3-1
3.1 Existing Data Sources 3-1
3.2 Primary Data Collection 3-4
3.2.1 Site Visits 3-4
3.2.2 2017 Data Request 3-4
3.2.3 Industry-submitted Data 3-5
3.3 References 3-5
4. Industry Profile 4-1
4.1 Number of Refineries and Location 4-1
4.2 General Refinery Operations 4-4
4.2.1 Refining Unit Operations 4-5
4.2.2 Supporting Units 4-8
4.2.3 Air Pollution Control Technologies 4-8
4.2.4 Wastewater Treatment Units 4-10
4.3 References 4-11
5. Study Analyses 5-1
5.1 Wastewater Influent C oncentrati on Analy si s 5-1
5.2 Baseline Loadings Estimate 5-5
5.2.1 Effluent Concentrations 5-5
5.2.2 Wastewater Treatment Effluent Flows 5-7
5.2.3 Loadings Estimate 5-7
5.3 Wastewater Treatment-In-Place 5-8
5.3.1 Wastewater Treatment Prior to End-of-Pipe Treatment 5-9
5.3.2 Wastewater Treatment Within End-of-Pipe Wastewater Treatment System 5-9
5.4 Permit Limits Analysis 5-12
5.5 Review of New Technologies or Improved Performance 5-15
5.5.1 Removal of Selenium in Refinery Effluent with Adsorption Media 5-15
5.5.2 Evaluation of Activated Sludge Microfiltration for Refinery Wastewater
Reuse 5-16
5.5.3 Tertiary Filter Pilot Study for Mercury Removal from Refinery
Wastewater 5-17
5.6 References 5-18
Appendix A - U.S. Refinery Population
Appendix B - Wastewater Treatment in Place at Petroleum Refineries
in
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List of Figures
List of Figures
Page
Figure 4-1. Map of United States Petroleum Refineries 4-2
Figure 4-2. Petroleum Refinery Process Diagram 4-4
Figure 5-1. WWT Systems at Refineries Subject to BAT Requirements 5-11
iv
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List of Tables
List of Tables
Page
Table 2-1. 40 CFR Part 419 Subcategories and Applicability 2-2
Table 2-2. Example Calculation for Crude Units for a 125,000 bbl/Stream Day Refinery 2-3
Table 2-3. 40 CFR Part 419 Effluent Limitations in lb per 1,000 bbl of Feedstock 2-4
Table 3-1. Existing Data Sources for Petroleum Refining Detailed Study 3-2
Table 3-2. Petroleum Refinery Site Visits 3-4
Table 3-3. Industry-Submitted Data Evaluated for Detailed Study 3-5
Table 4-1. U.S. Refineries by State 4-3
Table 4-2. U.S. Refineries by Discharge Status 4-3
Table 4-3. U.S. Refineries by Subcategory 4-4
Table 4-4. Petroleum Refining Process Categories 4-5
Table 4-5. Petroleum Refining Processes, Products, Byproducts, and Wastewater Streams 4-6
Table 4-6. Petroleum Refining Supporting Processes 4-8
Table 4-7. Characteristics of Air Pollution Control Technologies 4-9
Table 4-8. Wastewater Treatment Processes 4-10
Table 5-1. Pollutants of Interest in Petroleum Refining Wastewater 5-2
Table 5-2. Pollutant Concentrations in WWT System Influent 5-4
Table 5-3. Average Effluent Concentrations of Pollutants of Interest at 82 Refineries with DMR
Data for Outfalls Discharging WWT Effluent 5-6
Table 5-4. Estimated 2017 Baseline Loadings 5-8
Table 5-5. WWT Technologies at 129 Petroleum Refineries 5-10
Table 5-6. Pollutants Found in 10 or More Petroleum Refining Permits 5-12
Table 5-7. Petroleum Refining Permit Requirement Data by State and EPA Region 5-14
Table 5-8. Bench-Scale Tests of Influent Water Quality at Five Refineries 5-16
Table 5-9. Microfiltration Pilot Study Results 5-17
Table 5-10. Mercury and TSS Performance Data for Tertiary Filtration Technologies 5-18
v
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1 —Introduction
1. Introduction
This report summarizes information collected and analyzed by the United States Environmental
Protection Agency (EPA) as part of a detailed study of the petroleum refining industry. The EPA
conducted this study to review discharges from petroleum refineries and to determine whether the
current wastewater discharge regulations for these operations should be revised.
The EPA promulgated effluent limitations guidelines and standards (ELGs) for the Petroleum Refining
Point Source Category in 1974. The ELGs were challenged in the U.S. Court of Appeals; as a result of
the litigation, the EPA made revisions and finalized the ELGs on October 18, 1982. In 1985, EPA
revised the Best Available Technology Economically Achievable (BAT) effluent limitations for total
chromium, hexavalent chromium, and phenolic compounds (phenols) to reflect additional flow
reduction basis and lower attainable concentrations. The EPA also incorporated BAT, Best Practicable
Control Technology Currently Available (BPT), and Best Conventional Pollutant Control Technology
(BCT) effluent limitations for contaminated runoff, per a 1984 settlement agreement.1 The regulation
applies to discharges from any facility that processes raw petroleum crude into gasoline, fuel oil, jet fuel,
heating oils and gases, petrochemicals, and other products. Petroleum refineries are categorized under
North American Industry Classification System (NAICS) code 32411 and Standard Industrial
Classification code 2911, Petroleum Refineries. Section 2 of this report provides further information on
the current ELG. Currently, only biochemical oxygen demand (BODs), total suspended solids (TSS),
chemical oxygen demand (COD), oil and grease, phenolic compounds, ammonia, sulfide, and chromium
are included in the regulation.
The EPA conducted a review of the petroleum refining industry from 1992 to 1996 to determine whether
revisions to the ELGs were warranted. For this evaluation, the EPA reviewed data from the Toxics
Release Inventory (TRI) and Discharge Monitoring Reports (DMR) included in EPA's Permit
Compliance System (PCS). In addition, the EPA collected sampling data during visits to six refineries.
The Agency published the results of this review in the Preliminary Data Summary for the Petroleum
Refining Category, April, 1996. The study provides a general description of the industry, treatment
technologies used, water usage, analysis of dioxins in catalytic reformer wastewater, estimates of
pollutant discharges, environmental issues, and an economic profile (EPA, 1996). The EPA again
reviewed the industry in 2004, using data from the TRI and DMR reporting databases (EPA, 2004).
Neither study resulted in recommendations for revisions to the ELGs.
In the 2011 Annual Effluent Guidelines Review Report, the EPA selected the Petroleum Refining Point
Source Category (40 CFR Part 419) for a preliminary category review because it ranked high in toxic-
weighted pound equivalents (TWPE) (EPA, 2012a). At that time, the EPA found that the TWPE were
largely due to TRI-reported discharges of dioxin and dioxin-like compounds, polycyclic aromatic
compounds (PACs), and DMR-reported discharges of sulfides, chlorine, and metals. The EPA reviewed
this category during the 2012 Annual Review to verify facilities' discharges and confirmed the results of
the 2011 Annual Review. The EPA also reviewed new air pollution control (APC) regulations to
identify whether the regulations could result in new wastewater streams.
1 The 1984 settlement agreement was the result of a petition filed by the Natural Resources Defense Council (NRDC).
1-1
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1 —Introduction
The EPA conducted a detailed study of this industry beginning in 2014 to determine if changes to the
existing ELGs are needed.
• Changes to the industry may have resulted in new wastewater streams or wastewater
characteristics.
• An increase in the number of refineries reporting metals discharges, but only one metal
(chromium) is included in the current Petroleum Refining ELG.
The following sections of this report provide an overview of the petroleum refining industry and a
summary of the analyses conducted by the EPA as part of the detailed study.
• Section 2 provides an overview of current regulations affecting the petroleum refining
industry (air, water, and solid waste).
• Section 3 summarizes the data sources used in this study.
• Section 4 summarizes the industry profile, including details on the petroleum refining
population and background on refinery operations and air pollution control devices in place.
• Sections 5.1 through 5.4 summarize the analyses conducted by the EPA as part of the
detailed study.
1.1 References
1. EPA. 1996. U.S. Environmental Protection Agency. Preliminary Data Summary for the
Petroleum Refining Category. Available online at:
https://www.epa.gov/sites/production/files/2015-lQ/documents/petro-refining-elg-
study 1996.pdf (April) EPA 821 -R-96-015. DCN PROO158.
2. EPA. 2004. U.S. Environmental Protection Agency. Notice of Availability of 2004
Effluent Guidelines Program Plan. Available online at:
https://www.federalregister.gov/documents/2004/09/02/04-20040/notice-of-availability-of-
2004-effluent-guidelines-program-plan. (2 September) EPA-HQ-OW-2003-0074-1209.
3. EPA. 2012a. U.S. Environmental Protection Agency. The 2011 Annual Effluent Guidelines
Review Report. Available online at: https://www.regulations.gov/document?D=EPA-HQ-
QW-2010-0824-0195. EPA-HQ-OW-2010-0824-0195.
1-2
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2—Petroleum Refining Regulation History
2. Petroleum Refining Regulation History
This section summarizes the history of the petroleum refining regulation.
2.1 Effluent Limitation Guidelines
In 1974, the EPA promulgated standards for Best Practicable Control Technology Currently Available
(BPT), Best Available Technology Economically Achievable (BAT), New Source Performance
Standards (NSPS), Pretreatment Standards for Existing Sources (PSES), and Pretreatment Standards for
New Sources (PSNS) for the petroleum refining point source category (40 CFR Part 419). BAT was
remanded after legal challenge in 1976, and the EPA continued to study industry treatment practices
used in 1976. In 1982, the EPA re-promulgated BAT, setting it equal to BPT (i.e., the 1974 level of
control). In 1985, the EPA revised BAT for phenol and chromium, based on additional flow reduction
and lower attainable concentrations for these two pollutants. At that time, the EPA also set BCT limits
for the industry for biochemical oxygen demand (BODs), total suspended solids (TSS), oil and grease,
and pH.
BPT limitations are based on both in-plant and end-of-pipe technologies. See Section 4.2 for information
on petroleum refining processes.
In-plant technologies
• Sour water strippers to reduce sulfide and ammonia entering treatment plant.
• Elimination of once-through barometric condenser water by using surface condensers or
recycle systems with oil water cooling towers.
• Segregation of sewers so that unpolluted storm water and once-through cooling water are not
treated with process and other polluted water.
• Elimination of polluted once-through cooling water by monitoring and repairing surface
condensers or by use of wet and dry recycle streams.
End-of-pipe technologies
• Equalization and storm water diversion.
• Oil and solids removal (API separator or baffle plate separator).
• Carbonaceous waste removal using biological treatment (activated sludge, aerated lagoons,
oxidation ponds, trickling filters, or combination).
• Effluent polishing following biological treatment (polishing ponds or sand, dual-media, or
multimedia filter).
The ELGs for petroleum refining consist of five subcategories addressing different levels of processing
complexity. Table 2-1 presents applicability details for each subcategory.
2-1
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2—Petroleum Refining Regulation History
Table 2-1. 40 CFR Part 419 Subcategories and Applicability
r.i.c;
Siihpiirl
Siihpiirl
N;i 1110
A|)|)lic:il)ilil>
Part 419.10,
Subpart A
Topping
Any facility that produces petroleum products by the use of topping and catalytic
reforming, whether or not the facility includes any other process in addition to topping
and catalytic reforming. However, this subpart does not apply to facilities that include
thermal processes (coking, thermal cracking (visbreaking), etc.) or catalytic cracking.
Topping refineries separate crude oil by atmospheric and/or vacuum distillation, solvent
de-asphalting, and catalytic reforming. Guidelines for the topping subcategory include
allowances for ballast water. Ballast is defined as the flow of waters, from a ship, that is
treated along with refinery wastewaters in the main treatment system.
Part 419.20,
Subpart B
Cracking
Any facility that produces petroleum products by the use of topping and cracking,
whether or not the facility includes any process in addition to topping or cracking.
However, the provisions of this subpart are not applicable to facilities that include the
processes specified in subpart C, D, or E.
Part 419.30,
Subpart C
Petrochemical
Any facility that produces petroleum products by the use of topping, cracking, and
petrochemical operations whether or not the facility includes any process in addition to
topping, cracking, and petrochemical operations. However, the provisions of this subpart
are not applicable to facilities that include the processes specified in subpart D or E.
Petrochemical operations meet one of two definitions.
• Production of second-generation petrochemicals (e.g., alcohols, ketones, cumene and
styrene), or
• Production of first-generation petrochemicals and isomerization products (e.g.,
benzene, toluene, xylenes, olefins, and cyclohexane) when 15 percent or more of the
total refinery production is as first-generation petrochemicals and isomerization
products.
Part 419.40,
Subpart D
Lube
Any facility that produces petroleum products by the use of topping, cracking, and lube
oil manufacturing processes, whether or not the facility includes any process in addition
to topping, cracking, and lube oil manufacturing processes. However, the provisions of
this subpart are not applicable to facilities that include the processes specified in subpart
C orE.
Part 419.50,
Subpart E
Integrated
Any facility that produces petroleum products by the use of topping, cracking, lube oil
manufacturing processes, and petrochemical operations, whether or not the facility
includes any process in addition to topping, cracking, lube oil manufacturing processes,
and petrochemical operations.
Source: 40 CFR Part 419.
Currently, under BPT and BAT, the EPA has established production-based mass limitations for the
pollutants included in the ELG. Table 2-3 below presents these limits on a mass-production basis
(pounds of pollutant per 1,000 barrels (bbl) of feedstock). The ELG currently regulates BODs, TSS,
COD, oil and grease, phenolic compounds, ammonia, sulfide, and only one metal (chromium). The
regulation outlines stricter NSPS effluent limitations for all pollutants. BCT limits for BOD5, TSS, oil
and grease, and pH are set equal to BPT limits.
Also, each subcategory includes PSES and PSNS for indirect discharges to publicly owned treatment
works. For Subparts A, B, C, D, and E, the PSES and PSNS limits are 100 mg/L for both oil and grease
and ammonia (as N). The PSNS also include a limit of 1 mg/L for total chromium.
The regulation provides tables of refinery size (based on barrels of feedstock processed per day) and
process configuration factors that are used to scale pollutant discharge limits. The regulations establish
process configuration factors based on the units present at the refinery. Limits for each parameter must
2-2
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2—Petroleum Refining Regulation History
be established by multiplying the limits shown in Table 2-3 by both the size factor and process
configuration factor.2 BAT limitations for phenols, chromium, and hexavalent chromium are calculated
by multiplying an effluent limitation factor specific to each process type by the size and process
configuration factors.
Process configuration factors are calculated from the unit capacity and the weighting factor established
in the regulations. The EPA assigned the following weighting factors by process type.
• Crude processes: 1.
• Cracking and coking processes: 6.
• Lube processes: 13.
• Asphalt processes: 12.
For each process, the capacity relative to total throughput must be calculated and multiplied by the
weighting factor for the process group. The Subcategory D regulations show a detailed calculation for a
lube plant. Table 2-2 shows an example calculation for crude units. The process configuration factor of
2.48 would be added to the process configuration factors for all other processes at the lube plant. The
size factor specified in the regulation for a 125,000 bbl/stream day refinery is 0.97.
Table 2-2. Example Calculation for Crude Units for a 125,000 bbl/Stream Day Refinery
I nil
CapaciM
( apacitv Kclali\clo
Total ThmuiilipiM
Weiiihlinii
l-aclor
Process
(onli^d ration I'a dor
Ainiobplienc DibUllalion
125,UUU
1.0
Vacuum Distillation
60,000
0.48
Desalting
125,000
1.0
Total for Crude
2.48
1
2.48
2 See 40 CFR Part 419 for size and process configuration factors.
2-3
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2—Petroleum Refining Regulation History
Table 2-3. 40 CFR Part 419 Effluent Limitations in lb per 1,000 bbl of Feedstock
Polliiliini or
Polliiliinl
Properly
I'llTliicnl
1 Jinil Tjpe
Siihp:i
l);iil\
M;i\iimi in4
•t A1-2
3II-I);i>
Axenisie5
Suhpiii
l);iil\
Miixiiiiuni4
1 1
3!!-l);i>
A\cr;ijie;
Suhpiii
l);iil\
Miixiiiiuni4
1 C-J
30-l):i\
A\ er;i!ie;
Suhpii
l);iil\
.Miixiiiiuni4
I I)-4
3!!-l);i>
A\er;iiie;
Suhp;
l);iil\
Miixiimi in4
i i i-:-'
3II-I);i\
A\er;ijie;
BODs
BP!
8.0
4.25
9.9
5.5
12.1
0.5
17.9
9.1
19.2
10.2
BAT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
BCT
8.0
4.25
9.9
5.5
12.1
6.5
17.9
9.1
19.2
10.2
NSPS
4.26
2.26
5.8
3.1
7.7
4.1
12.2
6.5
14.7
7.8
TSS
BPT
5.6
3.6
6.9
4.4
8.3
5.25
12.5
8.0
13.2
8.4
BAT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
BCT
5.6
3.6
6.9
4.4
8.3
5.25
12.5
8.0
13.2
8.4
NSPS
3.06
1.96
4.0
2.5
5.2
3.3
8.3
5.3
9.9
6.3
COD
BPT
41.2
21.3
74.0
38.4
74.0
38.4
127.0
66.0
136.0
70.0
BAT
41.2
21.3
74.0
38.4
74.0
38.4
127.0
66.0
136.0
70.0
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
21.76
11.2s
41.5
21
47.0
24.0
87.0
45.0
104.0
54.0
Oil and Grease
BPT
2.5
1.3
3.0
1.6
3.9
2.1
5.7
3.0
6.0
3.2
BAT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
BCT
2.5
1.3
3.0
1.6
3.9
2.1
5.7
3.0
6.0
3.2
NSPS
1.36
0.706
1.7
0.93
2.4
1.3
3.8
2.0
4.5
2.4
Phenolic
Compounds
BPT
0.060
0.027
0.074
0.036
0.088
0.0425
0.133
0.065
0.14
0.068
BAT
7
7
7
7
7
7
7
7
7
7
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
0.0316
0.0166
0.042
0.020
0.056
0.027
0.088
0.043
0.105
0.051
Ammonia
asN
BPT
0.99
0.45
6.6
3.0
8.25
3.8
8.3
3.8
8.3
3.8
BAT
0.99
0.45
6.6
3.0
8.25
3.8
8.3
3.8
8.3
3.8
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
1.06
0.456
6.6
3.0
8.3
3.8
8.3
3.8
8.3
3.8
Sulfide
BPT
0.053
0.024
0.065
0.029
0.078
0.035
0.118
0.053
0.124
0.056
BAT
0.053
0.024
0.065
0.029
0.078
0.035
0.118
0.053
0.124
0.056
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
0.0276
0.0126
0.037
0.017
0.050
0.022
0.078
0.035
0.093
0.042
2-4
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2—Petroleum Refining Regulation History
Table 2-3. 40 CFR Part 419 Effluent Limitations in lb per 1,000 bbl of Feedstock
Polliiliini or
Suhpiirl A1-
Suhp;irl 1
Suhpiirl ( :'
Suhpiirl I)--4
Suhpiirl I-:-'
Polliil;iiil
I'llTliicnl
l);iil\
30-l);i\
l);iil\
30-l);i\
l);iil\
30-l);i\
l);iil\
30-l);i\
I);iil\
30-l);i\
Properly
1 Jinil Tjpe
M;i\iimi in4
A\er;i»e"
Miixiiiiuni4
A\CHIliC'"
Miixiiiiuni4
A\ er;i!ie"
Miixiiiiuni4
A\er;iiie~
Miixiimi in4
A\er;i»e"
BPT
Ol^
(.).(.) "1
0.15
(KISS
U.1S3
n in"
n
o.loo
n ""j
0.1"
Total
BAT
7
7
7
7
7
7
7
7
7
7
Chromium
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
0.0646
0.0376
0.084
0.049
0.116
0.068
0.180
0.105
0.220
0.13
BPT
0.01
0.0044
0.012
0.0056
0.016
0.0072
0.024
0.011
0.025
0.011
Hexavalent
BAT
7
7
7
7
7
7
7
7
7
7
chromium
BCT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
NSPS
0.00526
0.00256
0.0072
0.0032
0.0096
0.0044
0.022
0.0072
0.019
0.0084
BPT
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
a
00
BAT
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
BCT
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
NSPS
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
6.0-9.0
Source: 40 CFR Part 419.
1 Subpart A also includes BPT, BAT and BCT limits for ballast and contaminated runoff water and NSPS limits for ballast water. See 40 CFR Part 419 Subpart A for
details.
2 BPT, BAT, BCT, and NSPS size and process configuration factors, based on facility refining operations, apply. See the comprehensive example in 40 CFR 419.42(b)(3)
and the comprehensive example in 40 CFR 419.43(c)(2).
3 Subpart also contains BPT, BAT, and BCT limits for contaminated runoff water. See 40 CFR Part 419 for details. The ballast water limits from Subpart A also apply.
4 Daily maximum values are for any reported day.
5 30-day average values are for any 30 consecutive reported days.
6 Units are per 1,000 gallons of flow, not 1,000 bbl of feedstock.
7 BAT effluent limitation for phenols, total chromium, and hexavalent chromium vary by process type. BAT effluent limitations for these pollutants are calculated by
multiplying the limitation factor by the size factor and the process configuration factor. See 40 CFR 419 for the BAT limitation factors for each subpart.
8 pH limit expressed in units of pH (quantity is dimensionless).
2-5
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3 —Data Sources
3. Data Sources
This section describes the data sources evaluated by the EPA as part of the petroleum refinery detailed
study. The EPA gathered information from publicly available data sources (discussed in Sections 3.1)
and collected primary data (discussed in Section 3.2).
3.1 Existing Data Sources
Table 3-1 lists all data sources that the EPA consulted as part of the detailed study. Included in the table
is a description of each data source and information on how each is being used for the detailed study.
3-1
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3 —Data Sources
Table 3-1. Existing Data Sources for Petroleum Refining Detailed Study
l);il;i Soiiito
Description
1 so in Dcliiilcd S(ud\
Energy Information
Administration (EIA)
(EIA, 2013; 2014; 2015; 2016;
2017; and 2018)
EIA tracks the number of operating refineries annually. All active refineries are
required to complete Form EIA-820 - Annual Refinery Report. Information collected
includes capacity, refinery unit processes, capacity for atmospheric crude oil
distillation units and downstream units, country of origin of crude oil imports, and
production capacity for crude oil and petroleum products. The EPA reviewed the EIA
Refinery Utilization and Capacity Reports (2013 through 2018), which present data
from EIA Form 820.
Used to establish population of U.S.
petroleum refineries and develop
industry profile.
National Pollutant Discharge
Elimination System (NPDES)
Permits
(ERG, 2019a)
The EPA obtained copies of NPDES permits and/or permit applications for individual
refineries from the following 16 states: AL, AR, CA, CO, DE, IL, IN, KY, LA, MS,
NJ, OH, OK, PA, TX, WA. Information contained in permits and permit applications
includes refining unit processes, on-site wastewater treatment processes, outfall
descriptions, and destinations of wastewater discharges from the refinery (ERG,
2019a).
Used to confirm population of U.S.
petroleum refineries and confirm
wastewater treatment in-place, discharge
locations, and unit operations data.
Discharge Monitoring Report
(DMR) Pollutant Loading Tool
(ERG, 2019b)
The EPA downloaded Integrated Compliance Information System National Pollutant
Discharge Elimination System (ICIS-NPDES) data for 2007 through 2017 from the
online Water Pollutant Loading Tool. The data include pollutant discharge
information (i.e., concentration and quantity) and discharge flow rate data for
refineries operating in the U.S. Refineries are only required to report data for the
parameters identified in their NPDES permit.
Used to establish population of U.S.
petroleum refineries, evaluate wastewater
characteristics, estimate industry
loadings, and identify pollutants with
permit limitations or monitoring
requirements.
1982 Development Document for
Effluent Limitations Guidelines
and Standards for the Petroleum
Refining Point Source Category
(1982 TDD)
(EPA, 1982)
This document outlines the technology options considered and rationale for selecting
the technology levels on which the current ELG pollutant limitations are based. The
1982 TDD includes flow rate data and concentration data for toxic, non-conventional,
and conventional pollutants from the petroleum refining industry that were collected
as part of the 1982 rulemaking.
Used to conduct a preliminary evaluation
of wastewater characteristics.
Office of Air and Radiation
(OAR) Petroleum Refining Sector
Information Collection Request
(EPA, 2012b)
The EPA reviewed the publicly available data collected as part of the 2011 survey of
refineries conducted by OAR. The 2011 information collection request gathered
information on processing characteristics, air emissions, and wastewater generation.
Used to identify process unit operations,
wastewater treatment, and air pollution
controls at petroleum refineries.
Industrial Wastewater Treatment
Technologies (IWTT) Database
(EPA, 2018)
The EPA's IWTT database contains information on treatment technology advances
identified through the EPA's Annual Reviews. As part of its screening of industrial
wastewater discharges, the EPA reviews literature regarding the performance of new
and improved industrial wastewater treatment technologies and inputs the data into its
IWTT database.
Reviewed data in the IWTT database to
identify any new technologies or changes
to technologies used at petroleum
refineries to treat wastestreams.
3-2
-------
3 —Data Sources
Table 3-1. Existing Data Sources for Petroleum Refining Detailed Study
l);il;i Soiiito
Description
1 so in Dcliiilcd S(ud\
Department of Energy (DOE)
Energy and Environmental Profile
of the U.S. Petroleum Refining
Industry
(DOE, 2007)
This November 2007 document describes the petroleum refining industry and refining
processes. The document provides an overview of the following refining processes,
including their energy requirements, air emissions, effluents, and wastes/by-products:
atmospheric and vacuum distillation, cracking and coking, catalytic reforming,
alkylation, hydrotreatment, additives and blending components, lubricating oil
manufacturing, and other supporting processes (sulfur management, chemical
treatment, water treatment, process heating).
Provides background information on the
U.S. refining industry, refining
processes, and wastewater treatment.
Used to identify process unit operations,
wastewater treatment, and air pollution
controls at petroleum refineries.
Emerging Technologies and
Approaches to Minimize
Discharges into Lake Michigan
(Purdue-Argonne, 2012a)
Report published by Purdue University Calumet Water Institute and Argonne National
Laboratory detailing emerging technologies and approaches for minimizing
wastewater discharges from a petroleum refinery.
Used to identify any new technologies or
management approaches for handling
refinery wastewater.
3-3
-------
3 —Data Sources
3.2 Primary Data Collection
The EPA collected additional data from the petroleum refining industry through primary data collection
activities.
• Site visits to specific refineries of interest (Section 3.2.1).
• Data request to a subset of the industry (Section 3.2.2).
• Industry-submitted data (Section 3.2.3).
3.2.1 Site Visits
The EPA conducted phone calls and site visits with personnel at petroleum refineries to gather
information on refinery unit operations, wastewater generated by refineries, and the methods for
managing wastewater to allow for recycle, reuse, or discharge. The EPA used information from
available data sources to identify refineries for site visits.
In support of the detailed study, the Agency visited 10 petroleum refineries in four states between April,
2015, and September, 2017. Table 3-2 presents the refineries visited, the visit dates, and the document
control numbers (DCNs) of any supporting documentation. During site visits, the EPA toured refinery
unit operations of interest and wastewater treatment systems.
Table 3-2. Petroleum Refinery Site Visits
Kcl'incn Name
Locution
Sile \ isil Dale
Rcfcrcncc(s)
PBF Energy Paulsboro Refinery
Paulsboro, NJ
April 29, 2015
PR00047
Valero Benicia Refinery
Benicia, CA
April 11,2017
PR00084; PR00085
Phillips 66 San Francisco Refinery
Rodeo, CA
April 10, 2017
PR00125
Chevron Richmond Refinery
Richmond, CA
April 12, 2017
PR00083
Tesoro Martinez Refinerya
Martinez, CA
April 13, 2017
PR00082
Shell Martinez Refinery
Martinez, CA
April 14, 2017
PR00086
Marathon Michigan Refinery
Detroit, MI
July 11,2017
PR00102; PR00123
Shell Convent Refinery
Convent, LA
September 19, 2017
PR00095
Phillips 66 Alliance Refinery
Belle Chasse, LA
September 20, 2017
PR00096
Valero Meraux Refineiy
Meraux, LA
September 21, 2017
PR00097; PR00098
a - This refinery is currently operated by Marathon Petroleum Corp.
3.2.2 2017 Data Request
In July 2017, the EPA administered the Data Request for the Petroleum Refining Industry Detailed
Study (data request) (EPA, 2017) to nine companies (comprising 22 refineries) subject to the Petroleum
Refining ELGs to collect information on water use, crude processed, production rates, unit operations,
wastewater characteristics, pollution prevention, and wastewater management, treatment, and discharge
for calendar year 2016. The memorandum titled Selecting Recipients for the Petroleum Refining
Detailed Study Data Request (ERG, 2018) describes the EPA's procedure for selecting refineries for the
data request.
Twenty-one refineries responded to the data request. EPA excused ExxonMobil's Baytown Refinery
from participation due to severe hurricane damage to the facility just after distribution of the request.
3-4
-------
3 —Data Sources
See the memorandum Petroleum Refining Industry Data Request Responses for the data request
responses of the 21 refineries (ERG, 2019c).
3.2.3 Industry-submitted Data
The EPA obtained information on petroleum refinery operations, wastewater discharges, and wastewater
characterization from correspondence with trade associations (American Petroleum Institute (API) and
American Fuel & Petrochemical Manufacturers (AFPM)), and from submissions received directly from
refineries, as shown in Table 3-3. The table includes a description of each data source and how the data
are being used for the detailed study.
Table 3-3. Industry-Submitted Data Evaluated for Detailed Study
Diilii Sou i ce
Description
1 so in Dcliiilcd S(ud\
Refinery Process
Water and
Wastewater Sampling
Data
(CBI, 2017)
On December 7, 2017, one refining company provided
the EPA with operational and analytical data related to
petroleum refinery process water and wastewater streams.
The dataset includes analytical and operational data for
refineries in the company's fleet collected between
October 2015 and July 2016. These data are claimed as
confidential business information (CBI).
Used to conduct a preliminary
evaluation of wastewater
characteristics
API List of
Refineries and
Discharge Status
(API, 2019)
On March 6, 2019, API provided the EPA with a list of
148 petroleum refineries operating in the U.S., including
the parent company, location, discharge status, receiving
water, and NPDES permit numbers for each refineiy.
Used to augment the list of
petroleum refineries in the U.S. and
industry profile.
3.3 References
1. API. 2019. American Petroleum Institute and American Fuel and Petroleum Manufacturing.
2019 API List of Refineries and Discharge Status. (6 March) DCN PR00131.
2. CBI. 2017. Confidential Business Information. Industry-Submitted Analytical Data
Workbook. (7 December) DCN PR00092A1.
3. DOE. 2007. U.S. Department of Energy Industrial Technologies Program. Energy and
Environmental Profile of the U.S. Petroleum Refining Industry. Prepared by Energetics
Incorporated. Available online at: http ://energy. gov/eere/amo/downloads/itp-petroleum-
refining-energy-and-environmental-profile-us-petroleum-refining (November)
DCN PR00156.
4. EIA. 2013. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2013. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2013/refcap2013.php. (25 June)
DCN PR00163.
5. EIA. 2014. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2014. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2014/refcap2014.php. (21 June)
DCN PRer00164.
3-5
-------
3 —Data Sources
6. EIA. 2015. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2015. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2015/refcap2015.php. (19 June)
DCN PR00165.
7. EIA. 2016. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2016. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2016/refcap2016.php. (22 June)
DCN PR00154.
8. EIA. 2017. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2017. Available online at:
http://www.eia.gov/petroleum/refinervcapacitv/archive/2017/refcap2017.php. (21 June)
DCN PR00166.
9. EIA. 2018. U.S. Energy Information Administration. U.S. Energy Information
Administration. Refinery Capacity Report Archives With Data as of January 1, 2018.
Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2018/refcap2018.php (25 June)
DCN PR00167.
10. EPA. 1982. U.S. Environmental Protection Agency. Development Document for Effluent
Limitations Guidelines and Standards for the Petroleum Refining Point Source Category
(1982 TDD). (October) DCN PR00157.
11. EPA. 2012b. U.S. Environmental Protection Agency. 2011 Petroleum Refinery Information
Collection Request. Available online at: https://www.epa.gov/stationary-sources-air-
pollution/comprehensive-data-collected-petroleum-refining-sector#RawData. (June) EPA-
HQ-OAR-2010-0682-0064. EPA-HQ-OAR-2010-0682-0065. EPA-HQ-OAR-2010-0682-
0066. EP A-HQ-OAR-2010-0682-0067. EP A-HQ-OAR-2010-0682-0068.
12. EPA. 2017. U.S. Environmental Protection Agency. Data Request for the Petroleum
Refining Industry Detailed Study (Data Request). (26 July) DCN PR00110.
13. EPA. 2018. U.S. Environmental Protection Agency. Industrial Wastewater Treatment
Technology Database (IWTT). Available online at: https://www.epa.gov/eg/industrial-
wastewater-treatment-technology-database-iwtt
14. ERG. 2018. Eastern Research Group, Inc. Selecting Recipients for the Petroleum Refining
Detailed Study Data Request. (16 July) DCN PR00101.
15. ERG. 2019a. Eastern Research Group, Inc. Water Pollutant Loading Tool and ICIS/NPDES
Data. (22 May) DCN PR00140.
16. ERG. 2019b. Eastern Research Group, Inc. Average Concentration and Flow Data by
Refinery. (3 July). DCN PR00141.
3-6
-------
3 —Data Sources
17. ERG. 2019c. Eastern Research Group, Inc. NonCBI Petroleum Refining Data Request
Responses. (September) DCN PR00151.
18. Purdue-Argonne. 2012a. Argonne National Laboratory and Purdue University Calumet
Water Institute. Emerging Technologies and Approaches to Minimize Discharges into Lake
Michigan. Purdue-Argonne Phase 2, Module 4 Report. (March). DCN PR00168.
3-7
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4—Industry Profile
4. Industry Profile
The EPA identified the population of petroleum refineries operating in the U.S. and developed an
industry profile to characterize these refineries. The EPA used data from sources described in Section 3
to compile general refinery information (e.g., name, company, location, identification numbers,
subcategory) and details such as refinery-specific unit operations, crude and production information, air
pollution controls, wastewater treatment systems, and discharge status for each refinery identified in the
population. An overview of the petroleum refining industry is provided in Section 4.1 and a description
of general process operations within the industry, including air pollution control (APC) and wastewater
treatment (WWT) technologies, is provided in Section 4.2.
4.1 Number of Refineries and Location
The EPA identified petroleum refineries operating in the U.S. based on refineries listed in the Energy
Information Administration (EIA) Refinery Capacity Report for calendar year 2013 (EIA, 2013). Over
the course of the detailed study, the EPA continued to augment the profile as updated information was
collected (e.g., additional details on production, discharge type, or updates on closed or reopened
refineries) from the following data source.
• EIA Refinery Capacity Report for calendar years 2013 through 2018 (EIA, 2013; 2014;
2015; 2016; 2017; and 2018).
• Publicly available wastewater discharge permits and permit applications.
• Office of Air and Radiation (OAR) Petroleum Refining Sector Information Collection
Request.
• Refinery calls and site visits.
• Refinery responses to the 2017 data request.
• API List of Refineries and Discharge Status (API, 2019).
The EPA identified 143 petroleum refineries operating in the U.S. as of January 1, 2019. See
Appendix A for the complete list. Figure 4-1 includes a geographic distribution of all U.S. petroleum
refineries reported in the 2018 EIA Annual Refinery Report by operating capacity. More than half of the
U.S. refineries have operating capacities of less than 100,000 barrels per calendar day. As illustrated in
the figure, petroleum refineries are concentrated along the Gulf of Mexico (mainly in Texas and
Louisiana) and California. Table 4-1 summarizes the count of refineries in each state.
4-1
-------
4—Industry Profile
Operating Capacity
(barrels per calendar day)
Number of EIA Refineries
Included in the Category
Total Refinery Atmospheric Crude
Distillation Capacity
(barrels per calendar day)
<100,000
67
3,050,000
100,000-199,999
31
4,680,000
200,000-299,999
20
4,880,000
>300,000
14
5,960,000
Total
132a
18,600,000
Note: Capacity values are rounded to three significant figures.
a - The EPA's profile references individual refineries by NPDES ID, in some cases these refineries may be listed as
two separate refineries in EIA (e.g., an East and West) or some refineries may not have reported production for
2018 or have closed since the population was developed in 2015.
Figure 4-1. Map of United States Petroleum Refineries
4-2
-------
4—Industry Profile
Table 4-1. U.S. Refineries by State
Stale
Number of Refineries
TX
29
CA
20
LA
18
WY
6
WA
5
UT
5
AK
5
OK
5
MT
4
IL
4
MS
4
OH
4
PA
4
KS
3
NJ
3
AL
3
AR
2
HI
2
MN
2
KY
2
NM
2
ND
2
IN
2
TN
1
WI
1
MI
1
DE
1
CO
1
wv
1
NV
1
Total
143
The current Petroleum Refining ELGs establish effluent limitations for direct and indirect discharges
from refineries and defines five process subcategories of varying complexity. Table 4-2 and Table 4-3
present the distribution of U.S. refineries based on type of discharge and subcategory, respectively.
Table 4-2. U.S. Refineries by Discharge Status
Discharge Status
Number of Refineries
Direct
90
Indirect
30
Direct & Indirect
9
Zero Discharge
2
Unknown
12
Total
143
4-3
-------
4—Industry Profile
Table 4-3. U.S. Refineries by Subcategory
Topping (Part 419.10, Subpart A)
5
Cracking (Part 419.20, Subpart B)
46
Petrochemical (Part 419.30, Subpart C)
5
Lube (Part 419.40, Subpart D)
4
Integrated (Part 419.50, Subpart E)
6
Unknown
77
Total
143
Note: Four refineries were identified as subject to two ELG subcategories, Topping
(Subpart A) and Cracking (Subpart B), based on the 2019 detailed study data. In this
table, each of these four refineries is counted once, under Cracking (Subpart B).
4.2 General Refinery Operations
Figure 4-2 shows a general refinery process flow diagram. Refineries differ in the number and type of
processing units. The physical separation and chemical reaction processes at each refinery depend on the
type of raw crude processed and the desired final products.
Source: DOE, 2007.
MTBE: Methyl tertiary butyl ether.
TAME: Tertiary amyl methyl ether.
Figure 4-2. Petroleum Refinery Process Diagram
4-4
-------
4—Industry Profile
As discussed in Section 2, the current refinery ELGs define subcategories based on the types of units at
the refinery. Table 4-4 shows the general process categories at refineries, the processes included in the
category, and a description of the category. All refineries perform distillation operations; however, the
extent and variety of processes used to convert distilled fractions into petroleum products varies by
refinery.
Table 4-4. Petroleum Refining Process Categories
Process (
Processes
Description
Topping (separating crude
oil)
• Desalting.
• Atmospheric distillation.
• Vacuum distillation.
Separates crude oil into hydrocarbon groups.
Thermal and Catalytic
Cracking
• Thermal Operations.
— Delayed coking.
— Fluid coking/flexicoking.
— Visbreaking.
• Catalytic cracking.
• Catalytic hydrocracking.
Breaks large, heavy hydrocarbons from topping
process into smaller hydrocarbons.
Combining/Rearranging
Hydrocarbons
• Alkylation.
• Polymerization.
• Catalytic reforming.
• Isomerization.
Processes hydrocarbons to form desired end
products.
Removing Impurities
• Catalytic hydrotreating.
Removes impurities such as sulfur, nitrogen, and
metals from products or waste gas streams.
Specialty Products Blending
and Manufacturing
• Lube oil.
• Asphalt.
Blends product streams into final products or final
processing into specialty products.
Source: DOE, 2007.
4.2.1 Refining Unit Operations
Table 4-5 summarizes the typical process operations found at most petroleum refineries and provides the
products, wastes, and wastestreams generated.
4-5
-------
4—Industry Profile
Table 4-5. Petroleum Refining Processes, Products, Byproducts, and Wastewater Streams
I nil Opcriitinn/I'mccsscs
l-'unclion
Products
|}\ products iiml Wiislcs
\\ iis(c\\;i(ci-'
Crude Desalter
Removes salt from raw crude.
• Desalted crude.
• Desalter sludge.
• High salt wastewater.
• Desalter sludge.
Atmospheric Distillation
Separates lighter petroleum
fractions.
• Straight-run liquids
(gasoline, naphtha,
kerosene, gas oil, heavy
crude residue).
• Products further processed
or blended.
• Refinery gas - Light non-
condensable fuel gas consisting
of methane, ethane, hydrogen
sulfide, and ammonia. Refinery
gas can be treated and used as
fuel in process heaters.
• Oily sour water.
Vacuum Distillation
Separates the heavier portion
(bottoms from atmospheric
distillation).
• Vacuum gas oil (top of
column), heavy pitch
(bottom of column),
intermediate oil products.
• Refinery gas.
• Oily sour water.
Catalytic Cracking Unit
(CCU) (includes fluidized
catalytic cracking)
Breaks large hydrocarbons into
lighter components using a
catalyst.
• Gasoline, fuel oils, light
gases.
• Spent catalysts.
• Sour water.
• Steam from catalyst
regeneration.
Catalytic Hydrocracking
Breaks large hydrocarbons into
lighter components using a
catalyst and hydrogen.
• Blending stocks for gasoline
and other fuels (fuel gas,
naphtha, diesel, kerosene,
gas oils).
• Spent catalysts.
• Sour gas.
• Sour water
Delayed Coking Unit (DCU)
(thermal cracking)
Converts low value oils to higher
value gasoline and gas oils.
Typical feedstock is residual fuel
oil from the vacuum distillation
column.
• Gasoline, gas oils, fuel gas.
• Petroleum coke.
• Coke dust.
• Quench water.
• Water from decoking.
Visbreaking (thermal
cracking)
• Sour water.
Alkylation
Combines small hydrocarbons to
form a gasoline blending stock.
• Alkylate product (for
blending).
• Propane.
• Butane.
• Spent acid.
• Neutralization sludge (generated
from neutralizing acids).
• Product wash water.
• Steam stripper wastewater.
Catalytic Reforming Unit
(CRU)
Increase octane rating of
products from atmospheric
distillation and produces
aromatics.
• High octane gasoline.
• Aromatics.
• Light gases.
• Hydrogen.
• Spent catalyst.
• Process wastewater from
dehydrogenation of
naphthas.
Isomerization
Rearranges molecules to increase
octane.
• Isomerization products
(converts paraffins to
isoparaffins).
• Spent catalysts.
• Sour water from
fractionators.
4-6
-------
4—Industry Profile
Table 4-5. Petroleum Refining Processes, Products, Byproducts, and Wastewater Streams
I nil Opcnition/I'roccsscs
l-'unclion
Products
products iind Wiislcs
\\ iis(c\\;Mci-'
Polymerization
Converts propane and butane to
higher octane products.
• Higher octane products.
• Spent acid.
• Feed wash water.
• Sour water from
fractionators.
Hydrotreating
Removes impurities.
• Products vary by feed and
catalysts.
• Light fuel gas.
• Hydrogen sulfide.
• Ammonia.
• Sour water from
fractionators and separators.
Lube and Asphalt Processes
Converts heavy distillates and
residuals from vacuum
distillation to usable products.
• Lube oils.
• Waxes.
• Asphalt.
• Spent solvent.
• Sour water from steam
stripping.
• Solvent recovery
wastewater.
Sources: DOE, 2007; Gary andHandwerk, 1994.
a Sour water contains sulfides, ammonia, phenols, suspended solids, dissolved solids, and other organic chemical constituents of the crude oil.
4-7
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4—Industry Profile
4.2.2 Supporting Units
Supporting processes at refineries are used to recover byproducts of refinery production, such as the
sulfur and nitrogen compounds removed from raw crude during processing. See Table 4-5 for a list of
byproducts and wastes. Table 4-6 lists supporting operations that may be present at refineries, the
purpose of the process, and notes whether a wastewater stream is generated. The number, type, and
configuration of these units/processes will vary by refinery.
Table 4-6. Petroleum Refining Supporting Processes
Supporting Process
I'll ncl ion
\\ ;isk'\\ ;ik'r (.c'iicr;ik'd?
Hydrogen Production
Produce hydrogen for hydrotrealmg and hsdinciacking
operations. Hydrogen can be produced from steam
reforming of light products (methane, ethane, propane)
or oxidation of heavy hydrocarbons by burning the fuel
with oxygen.
Yes.
Amine Treating
Remove hydrogen sulfide and other sulfur compounds
from off-gases and fuel gas.
Little to no wastewater generated.
Sour Water Strippers
Remove hydrogen sulfide, ammonia, phenols, and other
contaminants from sour water.
Little to no wastewater generated.
Treated stripped water is reused within
the refinery if possible.
Sulfur Recovery
Recover elemental sulfur from the acid gases from
amine units and sour water strippers.
Little to no wastewater generated.
Chemical Treatment
Remove sulfur, nitrogen, or oxygen compounds from
final product streams.
Little to no wastewater generated.
Benzene Recovery Unit
(BRU)
Remove benzene to meet air regulation requirements.
No.
Sources: DOE, 2007; Gary andHandwerk, 1994.
4.2.3 Air Pollution Control Technologies
Potential air pollutants produced by refineries include volatile organic compounds (VOCs), hazardous
air pollutants (HAPs), sulfur oxides (SOx), carbon monoxide, nitrogen oxides (NOx), hydrogen sulfide
(H2S), odors, and particulate matter (PM). The Clean Air Act National Emission Standards for
Hazardous Air Pollutants (NESHAPs) and NSPS, state that petroleum refineries must have APC
technologies in place. Unit operations that commonly have APC technologies include CCUs, coking
units, and CRUs. Common APC devices, the pollutants they control, and any wastewater they may
produce are described in Table 4-7.
4-8
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4—Industry Profile
Table 4-7. Characteristics of Air Pollution Control Technologies
Aii* Pollution ( onlrol
Brief Description
Pollulsinis
(mil rolled
\\ sislcw silcr Tj picsillj
Produced?
C;ii'lxm \ilsoi'hei's
1 lie g;is s|ie;im is passed through ;i
cartridge of activated carbon, which
attracts and adsorbs gases and vapors.
\ OCs;illd II \IV
Vv
Condensers
In a condenser, gas is condensed to liquid
through changes in temperature or
pressure. Condensers may be used as
preliminary air pollution control devices
prior to other devices.
VOCs and HAPs.
Yes.
Electrostatic
Precipitators (ESP)
The gas stream is passed through an
electrical field, which creates an electrical
charge on particles. Collecting plates
attract the charged particles. The collecting
plates are cleaned either through shaking
or tapping the plate or by using water.
When water is used, the system is called
"wet ESP."
PM.
Wet ESP systems
generate wastewater;
dry ESP systems do not.
Fabric/Cartridge Filter
(Baghouse)
Gas flows through fabric filters, which
collect PM. The PM is periodically
removed to prevent the filters from
clogging.
PM.
No.
Flare
Flares are devices which combust
flammable gases, converting the gases to
carbon dioxide and water. The waste is
evaporated as steam.
VOCs.
No.
Scrubbers
Scrubbers use reagents, slurries, or liquids
to remove pollutants from the gas stream.
• Dry scrubbers inject or spray reagents
or slurries into the gas stream. Acid
gases are absorbed by the reagent or
slurry and are removed as solids.
• Wet scrubbers remove pollutants by
spraying or passing a liquid (typically
water) into the gas stream. The gas and
liquid are mixed, and pollutants absorb
onto the liquid and drop out of the gas
stream.
• LoTOX scrubbers use ozone to react
with mercury and NOx to produce
water soluble forms of mercury and
nitrogen.
PM, vapors, and
gases such as SOx
and H2S, corrosive
acidic or basic gas
streams, solid
particles, liquid
droplets, soluble
mercury.
Wet and LoTOX
scrubbers generate
wastewater; dry
scrubbers do not.
Selective Catalytic
Reduction (SCR)
To remove NOx, ammonia is injected into
the gas stream which passes into the SCR.
The ammonia and NOx react in the SCR to
form nitrogen and water. The gas is passed
through beds of solid catalytic material
where the VOCs are oxidized or reduced.
NOx and VOCs.
SCR can have ammonia
slip which could
contaminate a scrubber
stream. Water
contaminated with
ammonia is handled as
sour water.
Selective Non-Catalytic
Reduction (SNCR)
Ammonia is injected into high temperature
(1,400 to 2,000° F) gas where it reacts with
NOx and reduces them to nitrogen, carbon
dioxide, and water.
NOx.
SNCR can have
ammonia slip which
could contaminate a
scrubber stream. Water
contaminated with
ammonia is handled as
sour water.
4-9
-------
4—Industry Profile
Table 4-7. Characteristics of Air Pollution Control Technologies
Aii* Pollution Control
Brief Description
Polliilsinls
(mil rolled
\\ sislew silcr Tj picsilh
Produced?
lcrii;ir\ (\ clone
C\clones reiiune I'M In whirling lliegas
stream rapidly inside of a cylinder.
Centrifugal force is created, which causes
the particles to move to the walls of the
cylinder and drop out of the gas stream.
Large I'M
\o
Thermal or Catalytic
Incinerator/Oxidizer
Incinerators/oxidizers combust liquid or
gaseous wastes. Because these systems
operate at very high temperatures (up to
2,000° F), they are expensive to operate
and require large quantities of fuel.
High-efficiency regenerative thermal
oxidizers (regenerators) can recover heat,
which reduces costs as compared to typical
thermal oxidizers.
VOCs, gases, fumes,
hazardous organics,
odor, and PM.
No.
Vapor Balancing
System
Reduces vapors lost during loading of
liquid petroleum into transportation
vehicles. As liquid petroleum is being
unloaded from vehicles, this system
transfers gasses from the top of the bulk
tanks into the top of the vehicle.
Vapors.
No.
Water Seal
Water seals can be used in conjunction
with other air pollution controls. Water
seals are traps filled with water that create
a water barrier between the pipe and the
atmosphere.
VOCs, gases,
hazardous organics,
odor, and PM.
Yes.
Sources: A&WMA, 2007; EPA, 1995.
4.2.4 Wastewater Treatment Units
As described in Section 2.1, the technology basis for the current ELGs includes oil/water separation,
solids separation, biological treatment, clarification, and polishing steps. These wastewater treatment
steps are listed in Table 4-8.
Table 4-8. Wastewater Treatment Processes
\\ sislew siler
Trcsilmciil Step
(icncrsil Description
Trcsilmcnl Methods
Oil/Water Separation
Oil/water separation separates oil and solids from
wastewater. Some refineries operate distinct primary
and secondary oil/water separation steps. The oil
streams removed during primary and secondary
oil/water separation are typically reprocessed to
recover additional product. Solids are handled
separately.
• API separator.
• Corrugated plate interceptors.
• Parallel plate separators.
• Dissolved air flotation (DAF).
• Dissolved gas (typically nitrogen),
flotation (DGF or DNF).
• Induced air flotation (IAF).
Biological Treatment
Biological wastewater treatment systems use
microorganisms to consume biodegradable soluble
organic contaminants and bind the less soluble
portions into flocculant, which is removed from the
system.
• Suspended growth.
• Attached growth.
• Aerated surface impoundment.
• Membrane bioreactor (MBR).
4-10
-------
4—Industry Profile
Table 4-8. Wastewater Treatment Processes
\\ ;isU'\\;ik'r
1 IVillllHMII Slop
(>i'iicr;il Description
1 iViiliiHMil Methods
Filtration/
Adsorption/Polishing
If the refinery needs to meet an effluent limit, it may
use a filtration or adsorption unit as the final step in
treating wastewater. The specific type of unit often
depends on the targeted pollutant and effluent limit.
• Media filtration (e.g., sand filters).
• Adsorption (e.g., activated carbon).
• Chemical oxidation.
Sludge Handling
Sludge is produced by the oil/water separation units,
biological treatment, and some tertiary treatments.
• Aerobic digestion.
• Anaerobic digestion.
• Sludge dewatering.
4.3 References
1. A&WMA. 2007. Air and Waste Management Association. Air Pollution Emission Control
Devices for Stationary Sources. Available online at:
http://events.awma.org/files original/ControlDevicesFactSheet07.pdf. (April)
DCN PR00169.
2. API. 2019. American Petroleum Institute and American Fuel and Petroleum Manufacturing.
2019 API List of Refineries and Discharge Status. (6 March) DCN PR00131.
3. DOE. 2007. U.S. Department of Energy. Industrial Technologies Program. Energy and
Environmental Profile of the U.S. Petroleum Refining Industry. Prepared by Energetics
Incorporated. Available online at: http://energy.gov/eere/amo/downloads/itp-petroleum-
refining-energy-and-environmental-profile-us-petroleum-refining (November)
DCN PR00156.
4. EIA. 2013. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2013. Available online at:
https://www.eia. gov/petroleum/refinerycapacitv/archive/2013/refcap2013 .php (25 June)
DCN PR00163.
5. EIA. 2014. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2014. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2014/refcap2014.php. (21 June)
DCN PR00164.
6. EIA. 2015. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2015. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2015/refcap2015.php. (19 June)
DCN PR00165.
7. EIA. 2016. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2016. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2016/refcap2016.php. (22 June)
DCN PR00154.
4-11
-------
4—Industry Profile
8. EIA. 2017. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2017. Available online at:
http://www.eia.gov/petroleum/refinerycapacitv/archive/2017/refcap2017.php. (21 June)
DCN PR00166.
9. EIA. 2018. U.S. Energy Information Administration. U.S. Energy Information
Administration. Refinery Capacity Report Archives With Data as of January 1, 2018.
Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2018/refcap2018.php. (25 June)
DCN PR00167.
10. EPA. 1995. U.S. Environmental Protection Agency. AP 42, Compilation of Air Pollutant
Emission Factors. Fifth Edition. Available online at: https://www.epa.gov/air-emissions-
factors-and-quantification/ap-42-compilation-air-emissions-factors#5thed. (January)
DCN PR00161.
11. Gary, J.H., and G.E. Handwerk. 1994. Petroleum Refining Technology and Economics.
Third Edition. M. Dekker, New York, NY. DCN PR00152.
4-12
-------
5 —Study Analyses
5. Study Analyses
As discussed in Section 1, the focus of the study was to determine if recent changes in the industry have
resulted in new wastewater streams or wastewater characteristics, and to investigate the observed
increase in the number of refineries reporting metals discharges. The EPA's study analyses included
various analyses described in this section.
• Evaluating available data on untreated petroleum refining process wastewater, see Section
5.1.
• Estimating baseline loadings discharged by the petroleum refining industry, see Section 5.2.
• Evaluating available data on wastewater treatments (WWTs) used by the petroleum refining
industry and comparing end-of-pipe WWT systems to the current Petroleum Refining ELG
technology basis, see Section 5.3.
• Evaluating permits and Discharge Monitoring Report (DMR) data from current petroleum
refineries to identify any trends within the industry, see Section 5.4.
• Reviewing information on new WWT technologies and on improvements to established
technologies since the current Petroleum Refining ELG was issued, see Section 5.5.
5.1 Wastewater Influent Concentration Analysis
In developing the current Petroleum Refining ELGs, the EPA used effluent from primary oil water
separation (OWS) units to characterize untreated petroleum refining process wastewater. For this study,
the EPA applied the same approach. Using analytical data collected during the detailed study, the EPA
estimated the average concentrations of metals, nutrients, and other pollutants of interest in OWS
effluent and compared these concentrations to data available in the Development Document for Effluent
Limitations Guidelines and Standards for the Petroleum Refining Point Source Category (1982 TDD) to
determine if untreated process wastewater characteristics have changed since the previous rulemaking.
The EPA used 2013 DMR data and knowledge of the process to identify 26 pollutants likely to be
present in petroleum refining wastewater, including metals, nutrients, organics, and other priority
pollutants. Table 5-1 lists the pollutants identified by the EPA and the rationale for selecting each. This
listing includes pollutants with high toxicity (high toxic weight factors (TWF)), pollutants identified in
the existing Petroleum Refining ELGs or refinery NPDES permits, and pollutants that may be present in
wet scrubber purge. The EPA also considered naphthenic acids and alkylated polycyclic aromatic
hydrocarbons (PAHs) in the list of pollutants of interest, but the Agency determined that available data
are insufficient to determine whether these classes of pollutants warrant further consideration. Hence,
they are not included in Table 5-1.
Naphthenic acids are a complex group of cyclic carboxylic acids that are natural components of crude
oil and bitumen (Misiti et al., 2012). Naphthenic acids are formed from the bio-oxidation of naphtha
fractions in crude oils. Crude oil from older, heavier crude formations are likely to have higher
naphthenic acid content (Misiti, 2012). Results from crude oil samples demonstrated that the naphthenic
acid content in crude can range from 0.1 percent to 4.0 percent (weight/weight), depending on the source
and type of the crude oil (Misiti, 2012; Misiti et al., 2012). Studies show that these pollutants may be
transferred to refinery wastewater, mostly through desalting, when water contacts crude oil to remove
5-1
-------
5 —Study Analyses
salts and other contaminants. Studies have also shown that naphthenic acids may undergo some
degradation or removal in biological treatment systems, especially those that involve physical/chemical
treatment (Misiti et al., 2012; Syvret and Lordo, 2014).
PAHs comprise a group of over 100 different aromatic compounds that may be naturally occurring (e.g.,
maturation of crude oil and synthesis of certain plant and bacteria) or formed during incomplete
combustion of natural and anthropogenic organic substances. Alkylated PAHs are characterized by the
total number of alkyl carbon atoms present n the parent PAH compound. Studies have shown that this
group of pollutants may be present in crude oil (Andersson and Achten, 2014; Li et al., 2017; Hawthorne
et al., 2005). While these pollutants are among the most abundant and persistent toxic constituents in
Canadian Oil Sands tailings pond water and water commingling with raw petroleum during the
extraction of Canadian Oil Sands, very little information is known about the presence of these pollutants
in refinery wastewater (Li et al., 2017).
The EPA will continue to evaluate naphthenic acids and alkylated PAHs in petroleum refining
wastewater as data becomes available.
Table 5-1. Pollutants of Interest in Petroleum Refining Wastewater
Polliiliini
Kill i«ui;ilo
Metals
Arsenic
Higher toxicity metal (TWF > 1). Reported by 17 refineries in 2013 DMR data. Present in purge
from wet scrubbers at coal-fired power plants.
Cadmium
Higher toxicity metal (TWF >1). Reported by 3 refineries in 2013 DMR data.
Chromium
Included in current ELG. Reported by 39 refineries in 2013 DMR data. Chromium and hexavalent
chromium were included in the existing ELG due to their use as cooling water additives. This
practice is no longer a concern, but it may be helpful to evaluate concentration and load to
determine if the pollutant is still a concern in refinery operations and needs to remain in the ELG.
Copper
Reported by 23 refineries in 2013 DMR data.
Lead
Higher toxicity metal (TWF >1). Reported by 13 refineries in 2013 DMR data.
Mercury
Higher toxicity metal (TWF > 1). Reported by 21 refineries in 2013 DMR data. Present in purge
from wet scrubbers at coal-fired power plants.
Nickel
Reported by 16 refineries in 2013 DMR data.
Selenium
Higher toxicity metal (TWF > 1). Reported by 27 refineries in 2013 DMR data. Present in purge
from wet scrubbers at coal-fired power plants.
Uranium-238
Naturally occurring pollutant in some underground areas. Crude extracted from these areas may
contain higher concentrations of uranium also. Reported by 1 refinery in 2013 DMR data.
Zinc
Reported by 30 refineries in 2013 DMR data.
Organics
BODs
Included in current ELG. Reported by 81 refineries in 2013 DMR data.
BTEX
Common contaminant of concern in oil spills and occurs in gasoline. Reported by 6 refineries in
2013 DMR data.
COD
Reported by 74 refineries in 2013 DMR data.
Oil & Grease
Included in current ELG. Reported by 75 refineries in 2013 DMR data.
PAH
PAHs are common contaminants of concern in oil spills and some PAHs are known carcinogens.
Reported by 2 refineries in 2013 DMR data.
Phenol
Included in current ELG. Reported by 69 refineries in 2013 DMR data.
TOC
Reported by 47 refineries in 2013 DMR data.
Nutrients and Other Priority Pollutants
Ammonia
Included in current ELG. Reported by 78 refineries in 2013 DMR data.
Cyanide
Reported by 18 refineries in 2013 DMR data.
5-2
-------
5 —Study Analyses
Table 5-1. Pollutants of Interest in Petroleum Refining Wastewater
I'olllllillll
K;ilion;ik'
Nitrate-Nitrite
Refinery production processes such as hydrotreatment are used to remove nitrogen from some
petroleum fractions which may lead to transfer of these compounds to wastewater. Ammonia,
included in current ELGs, could be oxidized to nitrate or nitrite in refinery processes and/or
wastewater treatment. Reported by 4 refineries in 2013 DMR data.
Nitrogen, Total
Combination of ammonia, TKN, nitrate/nitrite, and other individual nitrogen parameters. May be
reported by refineries instead of individual nitrogen pollutants.
Phosphorus
Reported by 14 refineries in 2013 DMR data.
TDS
Reported by 12 refineries in 2013 DMR data. Wet gas scrubber purge may contain high TDS.
TKN
Reported by 3 refineries in 2013 DMR data.
TSS
Included in current ELG. Reported by 81 refineries in 2013 DMR data.
Sulfide
Included in current ELG. Reported by 60 refineries in 2013 DMR data.
Acronyms: BTEX (benzene, toluene, ethylbenzene, xylene); COD (chemical oxygen demand); PAH (polycyclic aromatic
hydrocarbons); TDS (total dissolved solids); TKN (total Kjeldahl nitrogen); TOC (total organic carbon); TSS (total
suspended solids); TWF (toxic weight factor)
Using analytical data available in the 1982 TDD and data collected as part of the 2019 detailed study,
the EPA calculated the average, minimum, and maximum concentrations for the 26 pollutants of interest
in refinery end-of-pope WWT influent process wastewater.
For each data source, the EPA first reviewed all available information (e.g., refinery configuration
diagrams, WWT system data) to identify primary OWS units. For data from the 1982 TDD, the EPA
used all analytical data clearly identified as separator or dissolved air flotation (DAF) unit effluent in the
analysis. Because WWT configuration details were not included in the TDD, where analytical data were
reported for effluent from multiple OWS units at a refinery, all sample results were used (7 refineries).
EPA identified 17 petroleum refineries with OWS effluent data in the 1982 TDD which includes short-
term monitoring data for 15 petroleum refineries and long-term monitoring data for 2 petroleum
refineries. The EPA identified primary OWS effluent data for 19 petroleum refineries collected for the
2019 detailed study.
To estimate average, minimum, and maximum pollutant concentrations for refinery end-of-pipe WWT
influent, the EPA first calculated refinery-level average, minimum, and maximum concentrations for
each pollutant using the following assumptions.
• Set all nondetect results to zero.3
• Set results reported below or above the reporting limit to the reporting limit (e.g., <1 |ig/L
was set to 1 |ig/L and >100 |ig/L was set to 100 |ig/L).
The EPA then calculated an industry-level average, minimum, and maximum for each pollutant for the
2019 detailed study data and for the 1982 TDD.
Table 5-2 presents the average, minimum, and maximum pollutant concentrations in WWT system
influent based on 1982 TDD data and data collected for the 2019 detailed study. The EPA compared the
3 In this study, all nondetect results are treated as a concentration of zero for the purpose of estimating concentrations because
information on detection limits is limited and varies by data source.
5-3
-------
5 —Study Analyses
average concentrations for 16 pollutants for which analytical data are available from both datasets.4 Of
these 16 pollutants, six have higher average concentrations in the 1982 TDD data and ten have higher
average concentrations in the 2019 detailed study data. The higher of the two average concentration
values is shaded red while the lower concentration is shown in blue in Table 5-2. The EPA notes the
following assumptions and limitations for this analysis.
• The concentrations reported in Table 5-2 are based on a combination of discrete sampling
results and average results due to the level of detail included in each data source.
• The 1982 TDD only presents data for pollutants detected at least once. The EPA assumed all
pollutants not presented in each 1982 TDD table were nondetect results (i.e., handled as zero
for purposes of calculating a refinery-level average).
• The methodology handles all nondetect results as zero and nonquantifiable results above the
reporting limit as the reporting limit, potentially underestimating the actual concentrations.
This methodology potentially overestimates the actual concentration.
• The sensitivity of methods and detection limits are not known for all data. Analytical
methods are not available for all data from the 1982 TDD and the 2019 detailed study.
Table 5-2. Pollutant Concentrations in WWT System Influent
Polliilanl
Refineries
willi Diilii
1«JS2 1 1)1)
Pulliilanl ( oiicoiilriilion (inii/l.)
Refineries
with Dalii
2019 l)e(;iiled Siiulj
Polliilanl ( oncen Ira lion (in^/l.)
A\ ii
Min
Max
A\ ii
Min
Max
Ammonia3
15
16.0
1.00
44.0
7
[CBI]
[CBI]
[CBI]
Arsenic
16
0.0301
ND
0.438
5
0.00823
ND
0.0250
BOD5a
15
93.0
12.0
260
2
283
46.5
1080
BTEX
0
No Data
No Data
No Data
0
No Data
No Data
No Data
Cadmium
16
0.00556
ND
0.0200
0
No Data
No Data
No Data
Chromium3
17
0.531
0.001
3.42
5
0.00208
ND
0.0120
CODa
15
384
83.0
987
9
[CBI]
[CBI]
[CBI]
Copper
15
0.0645
ND
0.286
5
0.0133
ND
0.0290
Cyanide
15
0.170
ND
1.76
0
Lead
15
0.0635
ND
0.862
5
0.00412
ND
0.0220
Mercury
15
0.00123
ND
0.0100
5
0.000472
ND
0.00710
Nickel
15
0.0131
ND
0.154
5
0.0106
ND
0.0600
Nitrate-
Nitrite
0
No Data
No Data
No Data
0
No Data
No Data
No Data
Nitrogen,
Total
0
No Data
No Data
No Data
1
12.9
12.0
61.0
Oil &
Grease3
15
51.0
ND
293
9
[CBI]
[CBI]
[CBI]
PAH
0
No Data
No Data
No Data
0
No Data
No Data
No Data
Phenol3
17
2.79
ND
33.5
4
7.01
ND
58.4
Phosphorus
0
No Data
No Data
No Data
0
No Data
No Data
No Data
Selenium
17
0.00712
ND
0.081
5
0.0485
ND
0.186
Sulfide3
15
7.03
0.500
27.3
3
11.6
ND
100
TDS
0
No Data
No Data
No Data
1
3320
2080
7820
4 The calculated average, minimum, and maximum concentrations for ammonia, chemical oxygen demand (COD), and oil &
grease based on detailed study data are withheld from this document to protect underlying data claimed as confidential
business information (CBI).
5-4
-------
5 —Study Analyses
Table 5-2. Pollutant Concentrations in WWT System Influent
1 "JS2
11)1)
2019 Dclaik-ri Siuclj
Polliilanl
Ki'lmcrics
Polliilanl ( nniTiilralion (niii/l.)
Refineries
I'olliiliinl ( oniTiilraliun ung/l.)
willi l);il;i
A\ ii
Min
Max
with Dalii
A\ ii
Min
Max
TKN
0
No Data
No Data
No Data
1
8.70
ND
96.3
TOC
15
110
25.0
283
3
150
11.7
738
TSSa
15
91.7
11.0
380
6
rcBii
rcBii
rcBii
Uranium-238
0
No Data
No Data
No Data
0
No Data
No Data
No Data
Zinc
17
0.393
0.00900
1.90
5
0.403
0.0500
1.48
Acronyms: CBI (confidential business information); mg/L (milligrams-per-liter); ND (nondetect).
Note: All pollutant concentrations are rounded to three significant figures,
a - Included in current ELG.
5.2 Baseline Loadings Estimate
The EPA used publicly available data to estimate the discharged quantities of the 26 pollutants of
interest (listed in Table 5-1). These baseline loadings estimates are calculated using flow rate and
pollutant-specific concentrations to determine the amount discharged in pounds per year for each
pollutant of interest. Section 5.2.1 describes the method for estimating pollutant-specific concentrations
and Section 5.2.2 describes how flow rates at each refinery were determined. The results of the EPA's
baseline loadings estimate are discussed in Section 5.2.3.
5.2.1 Effluent Concentrations
The EPA used 2017 Integrated Compliance Information System National Pollutant Discharge
Elimination System (ICIS-NPDES) data, data collected for the 2019 detailed study, and data from
permits to identify outfalls with WWT effluent. Some permits include multiple outfalls, some of which
may discharge various wastestreams (e.g., process wastewater, stormwater, or cooling water, among
others). The EPA used publicly available data to identify the subset of outfalls with treated process
wastewater for this effluent analysis. The EPA identified outfall data containing WWT effluent, or
treated process wastewater, for 91 refineries using the following methods.
• Reviewed WWT diagrams submitted through the Petroleum Refining Data Request and site
visits to identify the specific outfall number corresponding to the effluent from the WWT.
See Section 2.2 for details on the data request and site visits conducted as part of the detailed
study. The EPA matched these outfalls to outfall numbers listed in ICIS-NPDES data to
check that these outfalls included at least those pollutants that are included in the current
petroleum refining ELG (ammonia, BODs, COD, chromium, hexavalent chromium, oil and
grease, phenol, sulfide, and TSS).
• Used the process wastewater discharge and permit information provided by the trade
associations (API, 2019) to identify refineries that were listed as direct discharge only or
direct and indirect discharge and had only one final outfall included in their permit. The EPA
assumed these outfalls contained WWT effluent.
• Identified permits for petroleum refineries that included numeric limits for all pollutants
listed in the current ELG using 2017 DMR data. Where a permit included only one outfall
with limits for all pollutants in the current ELG, the EPA assumed this outfall included
5-5
-------
5 —Study Analyses
process water and represented the WWT effluent. Eight permits included multiple outfalls
with numeric limits for all ELG pollutants; for these, the EPA assumed outfall 1 represented
WWT effluent.
The EPA calculated, using the 2017 outfall-specific annual load and flow date estimated from EPA's
Water Pollutant Loading Tool, a concentration for the pollutants of interest (annual load divided by
annual flow) for 82 refineries with DMR data for outfalls with WWT effluent (ERG, 2019a). These
refinery-specific average concentrations were then used to calculate an average concentration for the
industry, as shown in Table 5-3.
Table 5-3. Average Effluent Concentrations of Pollutants of
Interest at 82 Refineries with DMR Data for Outfalls
Discharging WWT Effluent
Nil in hoi' of Refineries
A\oi':i^o I'olliiliiiil
Polllllillll
willi Diilii
( (incoiilriilion (inii/l.)
Ammonia u;> \
~o
i so
Arsenic
15
0.0179
BODs
79
8.49
BTEX
3
0.000192
Cadmium
11
0
Chromium
65
0.00245
COD
73
76.1
Copper
19
0.00333
Cyanide
15
0.0122
Lead
17
0.000982
Mercury
25
0.0000860
Nickel
12
0.00547
Nitrate-Nitrite
0
No Data
Nitrogen, Total
5
16.9
Oil & Grease
63
2.16
PAHa
0
No Data
Phenol
25
0.00894
Phosphorus
16
0.954
Selenium
26
0.0536
Sulfide
70
0.0296
TDS
7
1440
TKN
8
6.78
TOC
11
11.2
TSS
77
12.9
Uranium-238
0
No Data
Zinc
20
0.0261
Note: All concentrations are rounded to three significant figures,
a - The EPA's analysis includes only data listed as the combined PAH parameter in
ICIS-NPDES. Some refineries may collect samples for individual PAH compounds
that was not included in this analysis. The EPA determined that comparing
concentrations for varying number of individual PAH compounds at different
refineries may not be representative.
5-6
-------
5 —Study Analyses
5.2.2 Wastewater Treatment Effluent Flows
The EPA also estimated WWT-specific effluent flows for all refineries, not just those with DMR data by
taking the following steps.5
1. Eighteen of the 21 refineries responding to the data request discharge all or part of their
WWT effluent to surface water. For each of these 18 refineries, the EPA calculated total
2016 wastewater effluent flow from their WWT to a surface water by (a) assuming that the
daily flow values they reported in their data request responses were average daily values; and
(b) multiplying by 365 days to calculate an annual flow.
2. The EPA then used the 2016 EIA Refinery Capacities Report operating capacity (EIA,
2016) value in barrels per calendar day to calculate an average WWT flow per barrel per
calendar day (data request WWT effluent flow/EIA operating capacity) for these 18
refineries.
3. Finally, the EPA multiplied the average WWT flow per barrel per calendar day from Step 3
by the 2017 EIA operating capacity value in barrels per calendar day to calculate the 2017
WWT effluent flows for all refineries (EIA, 2017).
The EPA calculated the industry-level annual flow rate as the sum of the flow rates of all refineries
included in the petroleum refining population that directly discharge any of their process wastewater or
where the discharge status is unknown. For nine refineries, 2017 EIA capacity data were not available.
For these nine refineries, the EPA assumed an average effluent flow of 1,250 million gallons per year
(MGPY), which is the average of all 2017 WWT effluent flows calculated in Step 3 (see above).The
EPA estimates the industry-level annual discharge of process wastewater from refineries directly to
surface waters at 139,000 MGPY.
5.2.3 Loadings Estimate
For each of the 26 pollutants of interest (see Table 5-1), the EPA estimated the annual load using the
following equation.
Industry-Level Loading (lb/year) = Industry-level Annual Flow Rate x Concentration in mg/L x
(2.20462 lb/106 mg) x (1000 L/264.17 gallons)
Where:
Industry-level Annual Flow Rate = 139,000 MGPY
Concentration in mg/L = Concentrations listed in Table 5-3
The EPA's estimated baseline loadings are presented in Table 5-4. These loadings account for the
following assumptions.
5 Flows reported in DMR represent total outfall flows, which can include wastewaters other than treated WWT effluent. In
order to estimate only the flow of treated effluent from the WWT, the EPA developed this method based on 2018 detailed
study data.
5-7
-------
5 —Study Analyses
• Loadings estimates do not differentiate by types of WWT installed at individual refineries.
With additional data to characterize effluent from treatment systems and data on the types of
treatment at each refinery, the EPA would be able to refine these baseline loadings estimates
of pollutants being discharged by groups of similar WWT systems.
• Loadings estimates do not include the amount of pollutants discharged by refineries that send
all their process wastewater to publicly owned treatment works (POTWs) (i.e., indirect
dischargers).
Table 5-4. Estimated 2017 Baseline Loadings
Msliiiiiilod l ondinii
Polliiliini
-------
5 —Study Analyses
5.3.1 Wastewater Treatment Prior to End-of-Pipe Treatment
The Petroleum Refining Data Request collected information on specific unit operations and destinations
of wastewater generated by these units (see Section 3 for more details on the data request). From the
responses to this request, the EPA gathered information from 21 of the 143 refineries on treatment
technologies used in 2016. Treatment systems were used to treat a variety of wastewater streams.
• Crude desalter effluent.
• Catalytic cracking unit (CCU) and associated air pollution control (APC) wastewater.
• Catalytic reforming unit (CRU) regenerator and associated APC wastewater.
• Delayed coking unit (DCU) wastewater.
• Sour water stripper (SWS) effluent.
• Benzene removal unit (BRU) effluent.
The EPA notes the following trends based on responses to the request.
• All surveyed refineries generating CCU APC wastewater operate at least one dedicated CCU
APC wastewater treatment unit. Most refineries then send treated CCU APC wastewater to
end-of-pipe WWT system.
• Dedicated treatment of wastewater from CRU regenerators and associated APCs is not
common among surveyed refineries. Most refineries reported sending this stream directly to
an end-of-pipe WWT system.
5.3.2 Wastewater Treatment Within End-of-Pipe Wastewater Treatment System
To assess end-of-pipe WWT technologies in-place, the EPA used WWT data collected as part of the
data request, site visit reports, and other publicly available data sources, such as 2011 Office of Air and
Radiation (OAR) data, NPDES permit and permit application information, and other publicly available
studies and reports. See Section 3 for a discussion of these data sources. As part of this assessment, the
EPA compared the WWT technologies in place to the technology basis identified as the best available
technology (BAT) in the existing ELGs. The end-of-pipe treatment train identified in the BAT ELGs
includes the following treatment units.
• Equalization and storm water diversion.
• Primary oil and solids removal.
• Secondary oil and solids removal.
• Biological treatment to reduce BOD and COD.
• Filtration or other final polishing steps following biological treatment.
The EPA made the following assumptions as part of this analysis.
• Where multiple data sources provided wastewater treatment information for a facility, the
Agency considered the most current information.
• Technologies were operated in a similar order as the BAT technology basis treatment train.
5-9
-------
5 —Study Analyses
• Biological treatment includes the following types of systems.
- Aerobic impoundment or units.
- Aerated/non-aerated surface impoundments.
- Aerobic fixed film growth.
- Aerobic suspended growth.
- Moving bed bioreactors (MBBR).
- Membrane bioreactor (MBR).
- Tank-based activated sludge.
- ADVENT integral biological system.
- Biological activated filter.
- Biosolids flotation unit.
- Ecoverde.
- Integrated biox system.
• Final polishing includes the following types of systems.
- Polishing pond.
- Chemical oxidation.
- Chemical addition.
- Settling unit.
- Constructed wetland or lagoon.
- Coagulation and flocculation.
The EPA compiled WWT data for 129 of the 143 petroleum refineries. Table 5-5 summarizes the
number of petroleum refineries operating each step of the BAT technology basis. Note that the treatment
technologies identified as the final step are split into filtration and other polishing. Both may fulfill the
BAT technology basis but comprise different groups of technologies. Refineries need to meet the final
effluent limits; they are not required to install the BAT technology basis. Hence, some refineries may be
meeting the ELGs with treatment units other than those identified as the technology basis for the ELG.
Table 5-5. WWT Technologies at 129 Petroleum Refineries
Oil iiiid Solids
Rcino\;il
Scconriiin Oil
iiiid Solids
Kcmo\;il
liiolo^icid
1 iviilmonl
I'llTlui'iil Polishing
lillmlion
Oilier
Polishing
Number of Refineries
Operating Technology
121
88
100
24
9
Percent of Total Refineries
94%
68%
78%
19%
7%
Note: The EPA compiled WWT data for a total of 129 of the 143 current petroleum refineries.
5-10
-------
5 —Study Analyses
Of the 129 refineries with WWT data, the EPA identified 25 refineries that are not subject to the BAT
requirements because they discharge process wastewater indirectly or not at all. The EPA also identified
eight refineries where the type of process wastewater discharge is unknown, the EPA assumed these
refineries are likely subject to the BAT requirements. Therefore, 104 refineries (of the 129 with WWT
data) are likely subject to the BAT requirements. Figure 5-1 shows the treatment technologies operated
by these 104 refineries. The EPA used the following WWT categories.
• Beyond BAT. WWT system includes biological treatment, final polishing (i.e., filtration or
other polishing), and some additional type of treatment before discharge.
• Current BAT. WWT includes biological treatment system and an effluent polishing unit (i.e.,
filtration or other polishing).
• Biological treatment. WWT includes a biological treatment system, but not an effluent
polishing unit. These refineries may or may not operate an oil/water separator.
• Treatment other than biological treatment. WWT includes at least one oil/water separator,
but not biological treatment.
• No treatment information available. WWT information is not available in the sources the
EPA reviewed for these refineries.
Appendix B identifies the WWT data for each refinery that the EPA used to categorize each refinery's
treatment technology.
No Treatment
Information Available
(5 Refineries)
Treatment Other than
Biological Treatments
(10 Refineries)
Beyond BAT
Technology
(5 Refineries)
Current BAT
Technology
(23 Refineries)
Biological Treatment
(61 Refineries)
Figure 5-1. WWT Systems at Refineries Subject to BAT Requirements
Of the 104 refineries likely subject to BAT requirements, five refineries were categorized as beyond
BAT technology. These refineries employ one of the following in addition to BAT.
• Filtration and a polishing unit.
• Selenium reduction plant.
5-11
-------
5 —Study Analyses
• Ion exchange.6
5.4 Permit Limits Analysis
The EPA reviewed publicly available permit limits and discharge monitoring data to determine the
prevalence of limits for the 26 pollutants listed in Table 5-1.
Using 2017 ICIS-NPDES data, the EPA investigated pollutants found in NPDES permits for the
petroleum refining industry that are not already included in the existing ELG for petroleum refining. The
existing petroleum refining ELG includes limits for ammonia, BODs, COD, chromium, hexavalent
chromium, oil and grease, phenol, sulfide, and TSS.
The EPA identified data for external outfalls and effluent monitoring locations using DMR data entry
codes for parameter feature (EXO and SUM) and monitoring location (1, 2, A, B, or SC). The EPA
identified DMR data representing external outfalls or effluent monitoring locations for 106 refineries
(115 permits) (ERG, 2019b). Using this subset of DMR data, the EPA further identified which permits
include a numeric limit or monitoring requirement for the pollutants of interest.
The EPA found requirements for metals, including arsenic, selenium, copper, mercury, lead, and zinc, in
30 or more permits. Table 5-6 lists the pollutants most commonly found in permits, excluding those
pollutants already included in the petroleum ELG. Table 5-7 presents the information by state, with
details for zinc, lead, mercury, copper, selenium, arsenic, phosphorus, and nitrogen.
Table 5-6. Pollutants Found in 10 or More Petroleum Refining Permits
Number of Permits Includinii ;i
Polliiliini
Ri'(|iiimiK'n( in 201n l)MK l);ii;r'
TOC
73
Zinc
47
Lead
45
Mercury
44
Copper
42
Cyanide
40
Benzene
40
Whole effluent toxicity
39
Selenium
39
Arsenic
30
Nickel
29
Phosphorus
26
Cadmium
25
TDS
22
Benz [a] anthracene
21
Bcnzo|a|pvrcnc
21
Naphthalene
20
Fluoranthene
19
Pyrene
18
BTEX combination
18
Anthracene
18
Chrysene
18
6 The EPA does not have details as to the role of this technology within the refinery's WWT system.
5-12
-------
5 —Study Analyses
Table 5-6. Pollutants Found in 10 or More Petroleum Refining Permits
Number of Permits Including ;i
Pulliiliinl
Ki'(|iiimiH'iil in 201n l)MK l);il;r'
Benzo(b)fluoranthene
17
Benzo [kjfluoranthene
17
Chloride
17
Acenaphthene
17
Nitrogen
13
TKN
11
Dibenz [a,h] anthracene
11
Indeno [ 1,2,3 -cd]pyrene
10
Source: ERG, 2019c
a - Permit requirement refers to either a numeric limit or a monitoring requirement for an individual
pollutant.
5-13
-------
5 —Study Analyses
Table 5-7. Petroleum Refining Permit Requirement Data by State and EPA Region
I'.PA Region
State
Number of
Refineries in
State
Number of Permits
Included in Anal\sis
Permits with Monitoring Rcuiiircmcnts and/or Numeric Limits
/.inc
Lead
Mercun
Copper
Selenium
Arsenic
Phosphorus
Nitrogen
2
NJ
3
3
1
1
1
1
0
0
1
0
3
DE
1
2
1
1
1
1
0
0
0
0
3
PA
4
5
2
2
0
1
1
0
2
0
3
WV
1
1
1
0
0
1
0
1
0
1
4
AL
3
2
1
1
1
1
0
0
2
0
4
KY
2
3
1
1
0
0
2
0
0
4
MS
4
4
1
0
0
1
0
0
1
1
5
IL
4
4
2
1
3
1
1
1
1
0
5
IN
2
2
1
2
2
1
1
1
1
0
5
MN
2
2
1
0
2
2
0
2
0
5
OH
4
4
1
2
3
1
3
0
3
0
5
WI
1
1
1
1
1
1
1
1
1
0
6
AR
2
2
1
1
1
1
1
0
1
0
6
LA
18
19
3
8
2
3
0
0
3
4
6
OK
5
6
0
1
0
0
1
0
0
0
6
TX
29
25
11
3
3
6
6
2
1
1
7
KS
3
3
3
3
3
3
3
3
2
2
8
CO
1
1
1
1
1
1
1
1
0
0
8
MT
4
4
0
2
2
1
2
3
3
3
8
ND
2
1
0
0
0
0
0
0
0
0
8
UT
5
2
0
0
0
0
0
0
1
0
8
WY
6
1
1
1
1
1
1
1
0
0
9
CA
20
13
10
11
13
12
13
11
0
0
9
HI
2
1
0
0
1
0
0
1
1
1
10
AK
5
1
0
0
1
1
0
0
0
0
10
WA
5
3
3
2
2
3
2
2
0
0
Total
138
115
47
45
44
42
39
30
26
13
Note: Some refineries have more than one permit.
5-14
-------
5 —Study Analyses
5.5 Review of New Technologies or Improved Performance
The EPA's Industrial Wastewater Treatment Technology Database provides technology performance
data from peer-reviewed journals, conference proceedings, and government reports (EPA, 2018). The
EPA used this tool to identify articles and performance data related to treatment of petroleum refining
wastewater for metals and nutrients.7 This section summarizes articles focused on filtration or adsorption
technologies targeting arsenic, selenium, mercury, and nutrients.
5.5.1 Removal of Selenium in Refinery Effluent with Adsorption Media
A study conducted by MAR Systems Inc., a wastewater treatment technology company, provided data
from 2012 on their proprietary adsorbent technology, which uses an activated alumina-based substrate
that was tested on petroleum refining wastewater (Hayes and Sherwood, 2012). The technology,
Sorbster™ media, uses proprietary chemistries to covalently bond metals and remove them from
aqueous streams. Of interest is the media's ability to remove soluble selenium in the form of selenate
and selenite, and other forms such as selenium sulfide and selenosulfate. After use, the proprietary
media passes the EPA toxicity characteristic leaching procedure tests for disposal in non-hazardous
landfills.
The Hayes and Sherwood (2012) study evaluated five refineries, two midwestern and three western
refineries, currently with less than 110 parts per billion (ppb) selenium in their final treated effluent. The
purpose of the testing was to evaluate whether the Sorbster™ media could remove more selenium, to a
concentration of less than 20 ppb. New detection limits for selenium and lower permit limits were cited
as potential reasons for these lower selenium concentrations.
For all bench-scale testing, refinery effluent wastewater flowed through a packed column with a contact
time of 10 minutes to 25 minutes. Each refinery has existing selenium treatment within the WWT.
• Refinery A - In the Midwest, used final WWT effluent for testing. The WWT includes
carbon filtration.
• Refinery B - In the western U.S., used permeate from a fluid bed reactor (FBR)/membrane
treatment unit for testing.
• Refinery C - In the Midwest, used final WWT effluent for testing. The WWT includes iron
coprecipitation targeting selenium.
• Refinery D - In the western U.S., used final WWT effluent for testing. The WWT includes
iron coprecipitation and carbon polishing to target selenium.
• Refinery E - In the western U.S., used final WWT effluent for testing. The WWT includes
iron coprecipitation to target selenium.
7 The EPA used the following search terms to identify articles: Petroleum refining (Industry); Selenium, Mercury, Lead,
Arsenic, Nitrogen, Phosphorus, Phosphate, Nitrogen, Total Kjeldahl (TKN), Ammonia, Chromium, Aluminum, Antimony,
Barium, Beryllium, Cadmium, Copper, Iron, Magnesium, Manganese, Nickel, Silver, Sodium, Strontium, Thallium, Zinc
(Pollutants).
5-15
-------
5 —Study Analyses
Influent and effluent samples from the columns were sampled using the EPA Method 200.7. The
detection limit for selenium is 5 ppb. Table 5-8 presents the influent water quality data from each
refinery for the Sorbster™ media testing.
Table 5-8. Bench-Scale Tests of Influent Water Quality at Five Refineries
Polliiliini
Relinen A
( onceiiI r;i 1 io
Relinen li
is iiiul Spcciiilion ;i
Rel'inen (
1 l-'i\c Refineries
Relinen 1)
Kdincn I!
Selenium
Concentration
22.x
5." ppb
32 ppb
23.U ppb
luy ppb
Se Speciation
Not known
Selenocyanate
then selenite;
minor selenate
Selenate,
selenite
Not known
Mostly selenite,
minor selenate
Source: Hayes and Sherwood, 2012.
a - Units not specified in data source.
The study determined that the Sorbster™ media was able to remove additional selenium from treated
WWT effluent. The study does not include precise selenium concentration data, but, based on the non-
detect and target concentration results, the sorbent technology achieved greater than 80 percent removal
of selenium in all refinery effluent, regardless of upstream selenium treatment technology.
5.5.2 Evaluation of Activated Sludge Microfiltration for Refinery Wastewater Reuse
Coffeyville Resources Refining & Marketing refinery in Coffeyville, Kansas, conducted a pilot test in
2009 to evaluate the performance of side-stream microfiltration for refinery wastewater treatment
(Cabral et al., 2010). The pilot had two main objectives.
• Determine if the technology could be used to reduce the load on the clarifiers within the
WWT system in place.
• Produce a treated effluent with water quality suitable for reuse. The goal of water reuse
would be to reduce river water intake and use treated effluent as reverse osmosis (RO) feed
water.
Coffeyville refinery's WWT system included API separation, equalization, DAF, three conventional mix
activated sludge (CMAS) basins operated in parallel (hydraulic retention time of approximately one
day), two secondary clarifiers operated in parallel, and a final clarifier before discharge.
The piloted microfiltration unit was a modified, immersed MBR, operated without the biological
treatment steps. The microfiltration membranes were polyvinylidene fluoride reinforced hollow fiber
with 0.4-micron pore size. The microfiltration unit treated effluent from the existing CMAS basins.
The study was conducted in three phases, each evaluating different air flow and flux scenarios (e.g., low
air flow and high flux, low air flow and decreased flux, and normal air flow and decreased flux). Table
5-9 presents average influent and effluent concentrations for select pollutants across the entire test
period (about three weeks), as well as the calculated percent removal based on laboratory results.
Influent samples were collected as wastewater exited the DAF but before entering the CMAS basins;
while effluent samples were membrane permeate.
5-16
-------
5 —Study Analyses
The study demonstrated that the microfiltration technology could alleviate the load on the clarifier and
that the microfilter permeate quality can achieve RO feed water requirements. No details on whether the
refinery changed the WWT configuration based on this pilot were included in the study.
Table 5-9. Microfiltration Pilot Study Results
A\or;iiie C ciiicon 1 r;il ion
A\i'r;iuc ( (ineon(r;ilion in
PiimiiH'Icr
in Inl'liii'iil img/l.)
I'HTIiicnl (inii/l.)
IVrconl Ui'in
-------
5 —Study Analyses
(anthracite and sand) for 126 days of the 138-day test period. Table 5-10 presents the granular media
filtration performance data for mercury and TSS. While the effluent TSS concentrations did not meet the
initial target performance goals for the pilot (<4.1 mg/L), mercury removal met the pilot goal of 8.5 ng/L
and the three granular media filtration configurations performed similarly. All three configurations
either achieved or nearly achieved 100 percent of samples with an 8.5 ng/L effluent mercury
concentration (Allen and Loete, 2016).
Table 5-10. Mercury and TSS Performance Data for Tertiary Filtration
Technologies
Ti'chnolo"\
Inl'lui'iil
irriiicni
IVrci'iil of samples lliiil
;ichk'\i'(l
-------
5 —Study Analyses
https://www.eia.gov/petroleum/refinerycapacity/archive/2016/refcap2016.php. (22 June).
DCN PR00154.
6. EIA. 2017. U.S. Energy Information Administration. Refinery Capacity Report Archives
With Data as of January 1, 2017. Available online at:
https://www.eia.gov/petroleum/refinerycapacitv/archive/2016/refcap2016.php. June).
DCN PR000166.
7. EPA. 2018. U.S. Environmental Protection Agency. Industrial Wastewater Treatment
Technology Database (IWTT). Available online at: https://www.epa.gov/eg/industrial-
wastewater-treatment-technology-database-iwtt.
8. ERG. 2019a. Eastern Research Group, Inc. Water Pollutant Loading Tool and ICIS/NPDES
Data. (22 May). DCN PR00140.
9. ERG. 2019b. Eastern Research Group, Inc. Average Concentration and Flow Data by
Refinery. (3 July). DCNPR00141.
10. Hawthorne, S.B., D.J. Miller, and J.P. Kreitinger. 2005. Measurement of total polycyclic
aromatic hydrocarbon concentrations in sediments and toxic units used for estimating risk
to benthic invertebrates at manufactured gas plant sites. Environmental Toxicology and
Chemistry. 25, pp 287-296. (7 July). DCNPR00171.
11. Hayes, M., and N. Sherwood. 2012. Removal of Selenium in Refinery Effluent with
Adsorption Media. Paper presented at Water Environment Federation Technical Exhibition
and Conference. New Orleans, LA, USA. pp. 193-204. EPA-HQ-OW-2015-0665-0423.
12. Li, C., L. Fu, J. Stafford, M. Belosevic, and M.G. El-Din. 2017. The toxicity of oil sands
process-affected water (OSPW): A critical review. Science of the Total Environment. 601-
602, pp 1785-1802. (11 June). DCNPR00172.
13. Misiti, T.M. 2012. Fate and effect of naphthenic acids in biological systems. Ph.D.
dissertation presented to Georgia Institute of Technology. (31 December). DCN PR00173.
14. Misiti, T., U. Tezel, and S.P. Pavlostathis. 2012. Fate and effect of naphthenic acids on oil
refinery activated sludge wastewater treatment systems. Journal of Water Research. 47, pp
449-460. (29 October). DCNPR00174.
15. Purdue-Argonne. 2012b. Argonne National Laboratory and Purdue University Calumet
Water Institute. Emerging Technologies and Approaches to Minimize Discharges into Lake
Michigan. Purdue-Argonne Phase 2, Module 4 Report. (March). DCN PR00168.
16. Syvret, T.M., and S.A. Lordo. 2014. Understanding the contaminants in unconventional
crudes and managing their impact on the refinery wastewater treatment plant. Water
Environment Federation 2014 Technical Exhibition & Conference (2568). (October)
DCN PR00175.
5-19
-------
Appendix A -
U.S. Refinery Population
-------
THIS PAGE INTENTIONALLY LEFT BLANK
-------
U.S. Refinery Population
2018 EIA Refinery Atmospheric Crude Distillation
Refinery ID
Refinery Name
City
State
Operating Company
NPDES Permit(s)
Discharge Status
ELGs Subcategory
Capacity
(barrels per calendar day)
1 Arctic Slope Regional - North Pole
North Pole
AK
Petro Star Inc
Unknown
19,700
2 Arctic Slope Regional -Valdez
Valdez
AK
Petro Star Inc
Unknown
55,000
3
BP - Prudhoe Bay
Prudhoe Bay
AK
BP
Indirect
6,000
4 ConocoPhillips - Prudhoe Bay
Prudhoe Bay
AK
ConocoPhillips
Unknown
15,000
5 Kenai Refinery
Kenai
AK
Marathon Petroleum Corporation
AK0000841
Direct and Indirect
62,700
6 Good way Refining
Atmore
AL
Good way Refining LLC
Unknown
4,100
7
Hunt Refining-Tuscaloosa
Tuscaloosa
AL
Hunt Refining Company
AL0000973
Direct B
46,000
8
Shell Chemical Mobile Site
Sara land
AL
Shell Oil Products US
AL0055859
Direct
A
91,575
9
Lion Oil
El Dorado
AR
Delek US Holdings
AR0000647
Direct
83,000
10
Martin Operating
Smackover
AR
Martin Midstream Partners
AR0000591
Direct
7,500
11 Alon - Bakersfield
Bakersfield
CA
Alon USA Energy, Inc.
Direct
12 Los Angeles Refinery - Carson
Carson
CA
Marathon Petroleum Corporation
CA0000680, CAS000001
Indirect B
243,800
13 Los Angeles Refinery - Wilmington
Wilmington
CA
Marathon Petroleum Corporation
CA0003778
Indirect B
97,500
14 Chevron - Richmond Refinery
Richmond
CA
Chevron Corporation
CA0005134
Direct E
245,271
15
Chevron - El Segundo Refinery
El Segundo
CA
Chevron Corporation
CA0000337
Direct and Indirect B
269,000
16
Phillips - SF Refinery Rodeo
Rodeo
CA
Phillips 66
CA0005053
Direct B
120,200
17 Phillips - SF Refinery Arroyo Grande
Arroyo Grande
CA
Phillips 66
CA0000051
Direct B
18 Phillips - LA Refinery Carson
Carson
CA
Phillips 66
CA0063185
Indirect B
1
19 Phillips - LA Refinery Wilmington
Wilmington
CA
Phillips 66
CA0000035, CA0064611
Indirect B
139,000
201Torrance Refinery
Torrance
CA
PBF Energy
CA0055387
Indirect B
160,000
21
Greka
Santa Maria
CA
Greka Integrated
Unknown
9,500
22 Kern Refining
Bakersfield
CA
Kern Oil & Refining Company
CAU000200, CAZ458176
Unknown
26,000
23 South Gate Refinery
South Gate
CA
World Oil Company (d.b.a. World Oil Refining)
CAPO00078, CAZ189100
Indirect
8,500
24 Paramount Refinery
Paramount
CA
Alon USA Energy, Inc.
CA0056065
Indirect B
25 San Joaquin Refinery
Bakersfield
CA
San Joaquin Refining Co., Inc.
CAZ456330
Indirect
15,000
26 Shell - Martinez Refinery
Martinez
CA
Shell Oil Products US
CA0005789
Direct B
156,400
27 Martinez Refinery
Martinez
CA
Marathon Petroleum Corporation
CA0004961
Direct B
166,000
28 Valero - Wilmington Refinery
Wilmington
CA
Valero Energy Corporation
Indirect
85,000
29
Benicia Refinery
Benicia
CA
Valero Energy Corporation
CA0005550
Direct B
145,000
30 Wilmington Asphalt Plant
Wilmington
CA
Valero Energy Corporation
Indirect
6,300
31 Commerce City Refinery
Commerce City
CO
Suncor
C00001147
Direct B
103,000
32 Delaware City Refinery
Delaware City
DE
PBF Energy
DE0000256, DE0050601
Direct
182,200
33 Kapolei Refinery
Kapolei
HI
Par Pacific Holdings, Inc.
H10000329
Direct
54,000
34 Hawaii Refinery
Kapolei
HI
Par Petroleum Corporation
Indirect B
93,500
35 Lemont Refinery
Lemont
IL
Citgo Petroleum Corporation
IL0001589
Direct B
179,265
36 Joliet Refinery
Channahon
IL
ExxonMobil
IL0002861
Direct B
238,600
37
Marathon - Illinois Refinery
Robinson
IL
Marathon Petroleum Corporation
IL0004073
Direct and Indirect B
245,000
38 Wood River Refinery
Roxana
IL
Phillips 66
IL0000205
Direct
314,000
39
BP Whiting Refinery
Whiting
IN
BP
IN0000108
Direct B
413,500
40
Country Mark Refinery
Mt Vernon
IN
CountryMark
IN0002470
Direct
28,800
41 Coffeyvi 11 e Refi ne ry
Coffeyville
KS
CVR Refining, LP
KS0000248
Direct
132,000
42 El Dorado Refinery
El Dorado
KS
HollyFrontier Corporation
KS0000761
Direct
160,000
43 National CO-OP Refinery
McPherson
KS
CHS Inc
KS0000337
Indirect
97,920
44
Catlettsburg Refinery
Cat letts burg
KY
Marathon Petroleum Corporation
KY0000388, KY0070718
Direct E
277,000
45 Somerset Refinery
Somerset
KY
Continental Refining Company
KY0003476
Direct
5,500
46 Krotz Springs Refinery
Krotz Springs
LA
Alon USA Energy, Inc.
LA0051942
Direct
C
80,000
47
Calcasieu Refinery
Lake Charles
LA
Calcasieu Refining Company
LA0052370
Direct
A
125,000
48
Calumet - Shreveport Lubricant and Waxes
Shreveport
LA
Calumet Specialty Products Partners LP
LA0032417
Direct
D
57,000
49
Calumet - Princeton Lubricants
Princeton
LA
Calumet Specialty Products Partners LP
LAO 08 85 52
Indirect
8,300
50
Calumet - Cotton Valley Lubricants
Cotton Valley
LA
Calumet Specialty Products Partners LP
LA0005312
Direct
A
13,020
51 Citgo - Lake Charles Refinery
Lake Charles
LA
Citgo Petroleum Corporation
LA0005941
Direct
D
418,000
52
Phillips - Lake Charles Refinery
West lake
LA
Phillips 66
LA0003026, LA0104469
Direct
D
260,000
53 Alliance Refinery
Belle Chasse
LA
Phillips 66
LA0003115
Direct B
249,700
54 Convent Refinery
Convent
LA
Shell Oil Products US
LA0006041
Direct B
209,787
55
Shell - Saint Rose Refinery
Saint Rose
LA
Shell Oil Products US
LA0054216
Direct
A
56
Baton Rouge Refinery
Baton Rouge
LA
ExxonMobil
LA0005584
Direct E
502,500
57 Chalmette Refinery
Chalmette
LA
PBF Energy
LA0004260
Direct B
190,000
58
Garyville Refinery
Garyville
LA
Marathon Petroleum Corporation
LA0045683
Direct B
556,000
59 Norco Refinery
Norco
LA
Shell Oil Products US
LAO003522, LA0005762
Direct
C
218,200
60
Pelican - Lake Charles Refinery
Lake Charles
LA
Pelican Refining Company, LLC
LA0054399
Direct
61
Placid - Port Allen Refinery
Port Allen
LA
Placid Refining Company, LLC
LA0039390
Direct B
75,000
62 Valero - New Orleans Refinery
Norco
LA
Valero Energy Corporation
LA0052051, LAG535403
Direct B
215,000
63 Meraux Refinery
Meraux
LA
Valero Energy Corporation
LA0003646
Direct B
125,000
64 Michigan Refinery
Detroit
Ml
Marathon Petroleum Corporation
Indirect B
139,000
65 Pine Bend Refinery
Rosemount
MN
Flint Hills Resources
MN0000418
Direct and Indirect
310,000
66
St Paul Refinery
Saint Paul Park
MN
Marathon Petroleum Corporation
MN0000256
Direct
98,515
67 Pascagoula Refinery
Pascagoula
MS
Chevron Corporation
MS0001481
Direct
352,000
68
Ergon Refinery
Vicksburg
MS
Ergon Inc.
MS0034711
Direct
26,500
69
Southland Refinery
Sandersville
MS
Hunt Refining Company
MS0001686
Direct
11,000
70
Vicksburg Petroleum Products
Vicksburg
MS
Vicksburg Petroleum Products
MS0060976
Direct
71
Laurel Refinery
Laurel
MT
CHS Inc
MT0000264
Direct
59,600
721 Phillips - Billings Refinery
Billings
MT
Phillips 66
MT0000256
Direct and Indirect
60,000
73
Exxon - Billings Refinery
Billings
MT
ExxonMobil
MT0000477, MT0028321
Direct
61,500
74 Montana Refinery
Great Falls
MT
Calumet Specialty Products Partners LP
MTPU00118, MTR000556
Indirect
24,000
75 Dakota Refinery
Dickinson
ND
Marathon Petroleum Corporation
NDR050776
Indirect
A
19,500
76 Mandan Refinery
Mandan
ND
Marathon Petroleum Corporation
NDO000248
Direct B
73,800
77 Bay way Refinery
Linden
NJ
Phillips 66
NJ0001511, NJ0026662, NJ0026671
Direct B
258,000
78 Axeon - Paulsboro
Paulsboro
NJ
Axeon Specialty Products
NJ0064921
Direct
79
PBF-Paulsboro
Paulsboro
NJ
PBF Energy
NJ0005029
Direct B
160,000
A-l
-------
U.S. Refinery Population
2018 EIA Refinery Atmospheric Crude Distillation
Refinery ID
Refinery Name
City
State
Operating Company
NPDES Permit(s)
Discharge Status
ELGs Subcategory
Capacity
(barrels per calendar day)
80
Navajo Refinery
Artesia
NM
HollyFrontier Corporation
Indirect and Injection
110,000
81 Gallup Refinery
Jamestown
NM
Marathon Petroleum Corporation
NM0031071, NMR053168
Unknown
26,600
82 Foreland Refinery
Ely
NV
Foreland Refining Corp
Unknown
2,000
83 Toledo Refinery
Oregon
OH
BP and Husky Energy (Joint Venture)
OH0002461
Direct
B
155,000
84 Lima Refinery
Lima
OH
Husky Energy
OH0002623
Direct
177,000
85 Ohio Refinery
Canton
OH
Marathon Petroleum Corporation
OH0005657
Direct
93,000
86
Toledo Refinery
Oregon
OH
PBF Energy
OH0002763
Direct
172,800
87 Ponca City Refinery
Ponca City
OK
Phillips 66
OK0000256
Direct
B
206,000
88
Tulsa East Refinery
Tulsa
OK
HollyFrontier Corporation
OK0001309
Direct and Indirect
70,300
89
Tulsa West Refinery
Tulsa
OK
HollyFrontier Corporation
OK0000876
Direct
85,000
90 Ardmore Refinery
Ardmore
OK
Valero Energy Corporation
OK0001295
Direct
B
86,000
91 Wynne wood Refinery
Wynne wood
OK
CVR Refining, LP
OK0000825, OK0046027
Direct
74,500
92 American Refining
Bradford
PA
American Refining Group Inc.
PA0002674
Direct
11,000
93 Trainer Refinery
Trainer
PA
Delta Airlines, Inc.
PA0012637
Direct
190,000
94
Philadelphia Refinery
Philadelphia
PA
Philadelphia Energy Solutions Refining and Marketing LLC
PA0011533, PA0012629
Direct and Indirect
335,000
95
United Refining
Warren
PA
United Refining Company
PA0005304
Direct
65,000
96 Tennessee Refinery
Memphis
TN
Valero Energy Corporation
TNG670074, TNR056522, 5-NN1-029
Indirect
B
180,000
97
Calumet - San Antonio
San Antonio
TX
Calumet Specialty Products Partners LP
TXG670214
Unknown
20,000
98
Big Springs Refinery
Big Spring
TX
Alon USA Energy, Inc.
TX0104515
Direct
73,000
99
Borger Refinery
Borger
TX
Phillips 66 and Cenovus (Joint Venture)
TX0009148
Direct
B
146,000
100 Sweeny Complex
Brazoria
TX
Phillips 66
TX0007536
Direct
c
256,000
101 Citgo - Corpus Christi Refinery
Corpus Christi
TX
Citgo Petroleum Corporation
TX0006211
Direct
157,500
102
Tyler Refinery
Tyler
TX
Delek US Holdings
TX0001449
Indirect
75,000
103
McKee Plant
Sunray
TX
Valero Energy Corporation
TX0115851
Indirect
B
195,000
104 Beaumont Refinery
Beaumont
TX
ExxonMobil
TX0118737
Direct
D
365,644
105 Baytown Refinery
Baytown
TX
ExxonMobil
TX0006271
Direct
E
560,500
106
Flint Hills - Corpus Christi East Refinery
Corpus Christi
TX
Flint Hills Resources
TX0006599
Direct
B
319,000
107
Flint Hills - Corpus Christi West Refinery
Corpus Christi
TX
Flint Hills Resources
TX0006289
Direct
C
b
108
LyondellBasell - Houston Refinery
Houston
TX
LyondellBasell
TX0003247
Direct and Indirect
E
263,776
109 Galena Park Crude & Condensate
Galena Park
TX
Kinder Morgan
TX0135640
Indirect
84,000
110 Lazarus Refinery
Nixon
TX
Blue Dolphin Energy Company
Unknown
13,765
111
Marathon - Galveston Bay Refinery
Texas City
TX
Marathon Petroleum Corporation
TX0003522
Direct
B
571,000
112
Marathon - Texas City Refinery
Texas City
TX
Marathon Petroleum Corporation
TX0003697
Direct
B
113 Pasadena Refinery
Pasadena
TX
Brazilian Petroleum Corporation - Petrobras
TX0004626
Indirect
E
112,229
114
Motiva- Port Arthur Refinery
Port Arthur
TX
Motiva Enterprises - Divested to Saudi Aramco (Q2 2017)
TX0005835
Direct
c
603,000
115 Valero - Port Arthur Refinery
Port Arthur
TX
Valero Energy Corporation
TX0005991
Direct
B
335,000
116 Deer Park Refinery
Deer Park
TX
Shell Oil Products US and Pemex (Joint Venture)
TX0004871,TX0004863
Direct
B
275,000
117 Si Is bee Refinery
Silsbee
TX
Texas Oil & Chemical Co
TX0003204
Direct
B
118 Total Petrochemicals - Port Arthur Refinery
Port Arthur
TX
Total Petrochemicals and Refining USA, Inc.
TX0004201
Direct
225,500
119 Valero - Texas City Refinery
Texas City
TX
Valero Energy Corporation
TX0006009, TXG670007
Direct
B
225,000
120
Valero - Houston Refinery
Houston
TX
Valero Energy Corporation
TX0002976
Direct
199,000
121 Valero - Corpus Christi East Refinery
Corpus Christi
TX
Valero Energy Corporation
TX0006904
Direct
275,000
122 Valero - Corpus Christi West Refinery
Corpus Christi
TX
Valero Energy Corporation
TX0063355
Direct
123 Three Rivers Refinery
Three Rivers
TX
Valero Energy Corporation
TX0088331
Direct
89,000
124 Western Refinery
El Paso
TX
Marathon Petroleum Corporation
Indirect
135,000
125
Big West Oil Refinery
North Salt Lake
UT
Big West Oil LLC
Unknown
30,500
126 Chevron - Salt Lake City Refinery
Salt Lake City
UT
Chevron Corporation
UT0000175
Direct and Indirect
53,200
127 HollyFrontier-Wood Cross Refinery
Woods Cross
UT
HollyFrontier Corporation
UTG070092, UTR000514
Indirect
39,330
128 Silver Eagle - Wood Cross Refinery
Woods Cross
UT
Silver Eagle Refining
UTR000132, UTR000449
Indirect
15,000
129 Salt Lake City Refinery
Salt Lake City
UT
Marathon Petroleum Corporation
Indirect
58,500
130 Cherry Point Refinery
Blaine
WA
BP
WA0022900
Direct
B
227,000
131 Ferndale Refinery
Ferndale
WA
Phillips 66
WA0002984
Direct
105,000
132
Puget Sound Refinery
Anacortes
WA
Shell Oil Products US
WA0002941
Direct
B
145,000
133 Anacortes Refinery
Anacortes
WA
Marathon Petroleum Corporation
WA0000761
Direct
B
120,000
134 Tacoma Refinery
Tacoma
WA
US Oil & Refining Company
WA0001783, WAR307424
Direct
40,700
135
Superior Refinery
Superior
Wl
Calumet Specialty Products Partners LP
WI0003085
Direct
38,000
136 Ergon West Virginia Refinery
Newell
WV
Ergon Inc.
WV0004626
Direct
22,300
137 Antelope Refining
Douglas
WY
Antelope Refining LLC
Indirect
138
Frontier Refining
Cheyenne
WY
HollyFrontier Corporation
WY0000442
Indirect
48,000
139 Evanston Refinery
Evanston
WY
Silver Eagle Refining
Zero Discharge
3,000
140
Casper Refinery
Casper
WY
Sinclair Oil Corporation
Indirect
24,500
141
Sinclair Refinery
Sinclair
WY
Sinclair Oil Corporation
Zero Discharge
75,000
Hermes Consolidated Refinery (d.b.a. Wyoming
142
Refining Company)
Newcastle
WY
Par Pacific Holdings, Inc.
Unknown
18,000
143
BTB Refining LLC
Corpus Christi
TX
Buckeye Partners LP
TX0096474
Direct
60,000
a - The Phillips - LA Refinery Carson Refinery and Phillips - LA Refinery Wilmington Refinery are reflected as one facility in the 2018 EIA Annual Refinery Report. For the purposes of this analysis, the 2018 atmospheric crude distillation capacity for both refineries is listed for Phillips - LA Refinery Wilmington Refinery only,
b - The Flint Hills - Corpus Christi West Refinery and Flint Hills - Corpus Christi East Refinery are reflected as one facility in the 2018 EIA Annual Refinery Report. For the purposes of this analysis, the 2018 atmospheric crude distillation capacity for both refineries is listed for Flint Hills - Corpus Christi East Refinery only.
A-2
-------
Appendix B -
Wastewater Treatment in Place at Petroleum Refineries
-------
THIS PAGE INTENTIONALLY LEFT BLANK
-------
Wastewater Treatment in Place at Petroleum Refineries
EPA used WWT data collected as part of the data request, site visit reports, and other publicly available data sources, such as 2011 Office of Air and Radiation (OAR) data, NPDES permit and permit application information, and other publicly
available studies and reports to assess end-of-pipe WWT technologies in-place.
Data Source
Refinery ID
Indirect or Direct'
State
NPDES ID(s)
Oil/water
Oil/water
Separation
Unit
Biological
Treatment
Filtration
Effluent
Description of Effluent
Polishing Unit
Data Request
for 2016 Data
Site Visit
2011 OAR
Information
Collection
Other Sources
Categorized by ERG for Petroleum Refining
Detailed Study Report
Technologies Identified as
"Beyond BAT Technologies"
1
Arctic Slope Regional - North Pole
Unknown
North Pole
AK
No Data
No Data
No Data
No Data
No Data
No Data
No Data
2
Arctic Slope Regional - Valdez
Unknown
Valdez
AK
No Data
No Data
No Data
No Data
No Data
No Data
No Data
3
BP - Prudhoe Bay
Indirect
Prudhoe Bay
AK
No Data
No Data
No Data
No Data
No Data
No Data
No Data
4
ConocoPhillips - Prudhoe Bay
Unknown
Prudhoe Bay
AK
No Data
No Data
No Data
No Data
No Data
No Data
No Data
5
Kenai Refinery
Direct and Indirect
Kenai
AK
AK0000841
X
X
X
X
Biological Treatment
6
Goodway Refining
Unknown
Atmore
AL
X
No Treatment Information Available
7
Hunt Refining - Tuscaloosa
D
red
Tuscaloosa
AL
AL0000973
X
X
X
X
X
Biological Treatment
8
Shell Chemical Mobile Site
D
red
Saraland
AL
AL0055859
X
X
x
x"
Biological Treatment
9
Lion Oil
D
red
El Dorado
AR
AR0000647
X
X
X
X
X
X
Current BAT Technology
10
Martin Operating
D
red
Smack over
AR
AR0000591
X
X
Treatment Otherthan Biological Treatment
11
Alon - Bakersfield
D
red
Bakersfield
CA
X
X
X
Treatment Otherthan Biological Treatment
12
Tesoro Los Angeles Refinery - Carson Operations
Indirect
Carson
CA
CA0000680; CAS000001
X
X
X
Treatment Otherthan Biological Treatment
13
Tesoro - LA Refinery Wilmington
Indirect
Wilmington
CA
CA0003778
X
X
X
X
Treatment Otherthan Biological Treatment
14
Chevron - Richmond Refinery
Direct
Richmond
CA
CA0005134
X
X
X
X
Construded wetlands
X
Beyond BATTechnology
Filtration and Polishing
15
Chevron - El Segundo Refinery
Direct and Indirect
El Segundo
CA
CA0000337
X
X
X
X
Biological Treatment
16
Phillips - SF Refinery Rodeo
Direct
Rodeo
CA
CA0005053
X
X
X
X
X
Beyond BATTechnology
Selenium Redudion Plant
17
Phillips - SF Refinery Arroyo Grande
Direct
Arroyo Grande
CA
CA0000051
X
X
X
X
X
Biological Treatment
18
Phillips - LA Refinery Carson
Indirect
Carson
CA
CA0063185
X
X
X
X
Treatment Otherthan Biological Treatment
19
Phillips - LA Refinery Wilmington
Indirect
Wilmington
CA
CA0000035; CA0064611
X
X
X
Treatment Otherthan Biological Treatment
20
Exxon -Torrance Refinery
Indirect
Torrance
CA
CA0055387
X
X
X
X
X
Current BAT Technology
21
Greka
Unknown
Santa Maria
CA
X
X
Biological Treatment
22
Kern Refining
Unknown
Bakersfield
CA
CAU000200; CAZ458176
X
X
Treatment Otherthan Biological Treatment
23
Lunday -Thagard Refinery
Indirect
South Gate
CA
CAP000078; CAZ189100
X
X
X
Treatment Otherthan Biological Treatment
24
Paramount Refinery
Indirect
Paramount
CA
CA0056065
X
X
X
X
X
Treatment Otherthan Biological Treatment
25
San Joaquin Refinery
Indirect
Bakersfield
CA
CAZ456330
X
X
X
Treatment Otherthan Biological Treatment
26
Shell - Martinez Refinery
Direct
Martinez
CA
CA0005789
X
X
X
X
X
Beyond BATTechnology
Selenium Redudion Plant
27
Tesoro - Martinez Refinery
Direct
Martinez
CA
CA0004961
X
X
X
X
X
Current BAT Technology
28
Valero - Wilmington Refinery
Indirect
Wilmington
CA
X
X
Treatment Otherthan Biological Treatment
29
Benicia Refinery
Direct
Benicia
CA
CA0005550
x
x
x
Chemical addition and
settling unit
X
Beyond BATTechnology
Filtration and Polishing
30
Wilmington Asphalt Plant
Indirect
Wilmington
CA
X
X
Treatment Otherthan Biological Treatment
31
Commerce City Refinery
D
red
Commerce City
CO
C00001147
No Data
No Data
No Data
No Data
No Data
No Data
No Data
32
Delaware City Refinery
D
red
Delaware City
DE
DE0000256; DE0050601
X
X
X
X
B
olog
cal Treatment
33
Chevron - Hawaii Refinery
D
red
Kapolei
HI
H10000329
X
X
X
X
B
olog
cal Treatment
34
Tesoro - Hawaii Refinery
Indirect
Kapolei
HI
X
X
X
X
B
olog
cal Treatment
35
Lemont Refinery
Direct
Lemont
IL
IL0001589
X
X
X
X
B
olog
cal Treatment
36
Joliet Refinery
Direct
Channahon
IL
IL0002861
X
X
X
X
Settling unit and aeration
X
Current BAT Technology
37
Marathon - Illinois Refinery
Direct and Indirect
Robinson
IL
IL0004073
X
X
X
X
X
Current BAT Technology
38
Wood River Refinery
D
red
Roxana
IL
IL0000205
X
X
X
X
Biological Treatment
39
BP Whiting Refinery
D
red
Whiting
IN
IN0000108
X
X
X
X
X
Current BAT Technology
40
CountryMark Refinery
D
red
Mt Vernon
IN
IN0002470
X
X
X
x
Biological Treatment
41
Coffeyville Refinery
D
red
Coffeyville
KS
KS0000248
No Data
No Data
No Data
No Data
No Data
No Data
No Data
42
El Dorado Refinery
D
red
El Dorado
KS
KS0000761
X
X
X
X
Biolog
43
National CO-OP Refinery
Indirect
Mcpherson
KS
KS0000337
X
X
X
X
Biolog
44
Catlettsburg Refinery
D
red
Catlettsburg
KY
KY0000388; KY0070718
X
X
X
X
Biolog
45
Somerset Refinery
D
red
Somerset
KY
KY0003476
X
X
Biolog
46
Krotz Springs Refinery
D
red
Krotz Springs
LA
LA0051942
X
X
X
X
X
Biolog
47
Calcasieu Refinery
D
red
Lake Charles
LA
LA0052370
X
X
X
X
X
Biolog
48
Calumet - Shreveport Lubricant and Waxes
D
red
Shreveport
LA
LA0032417
X
X
X
X
X
Biolog
49
Calumet - Princeton Lubricants
Indirect
Princeton
LA
LA0088552
X
X
X
Biolog
50
Calumet - Cotton Valley Lubricants
D
red
Cotton Valley
LA
LA0005312
X
X
X
X
Biolog
51
Citgo - Lake Charles Refinery
D
red
Lake Charles
LA
LA0005941
X
X
X
X
X
Biolog
52
Phillips - Lake Charles Refinery
D
red
Westlake
LA
LA0003026; LA0104469
X
X
X
X
X
Biolog
53
Alliance Refinery
D
red
Belle Chasse
LA
LA0003115
X
X
X
X
Biolog
54
Convent Refinery
D
red
Convent
LA
LA0006041
X
X
X
X
Biolog
55
Shell - Saint Rose Refinery
D
red
Saint Rose
LA
LA0054216
X
X
X
X
X
Current BAT Technology
56
Baton Rouge Refinery
D
red
Baton Rouge
LA
LA0005584
X
X
X
Biological Treatment
57
Chalmette Refinery
D
red
Chalmette
LA
LA0004260
X
X
X
X
X
Biological Treatment
58
Garyville Refinery
D
red
Garyville
LA
LA0045683
X
X
X
X
Effluent settling pond
X
Current BAT Technology
59
Norco Refinery
D
red
Norco
LA
LA0003522; LA0005762
X
X
Clarifier/settling unit
X
Current BAT Technology
60
Pelican - Lake Charles Refinery
D
red
Lake Charles
LA
LA0054399
X
X
X
Biological Treatment
61
Placid - Port Allen Refinery
D
red
Port Allen
LA
LA0039390
X
X
X
X
X
Current BAT Technology
62
Valero - New Orleans Refinery
D
red
Norco
LA
LA0052051; LAG535403
X
X
X
X
Biological Treatment
63
Meraux Refinery
D
red
Meraux
LA
LA0003646
X
X
X
X
X
Current BAT Technology
64
Michigan Refinery
Indirect
Detroit
Ml
X
X
X
X
Biolog
cal Treatment
65
Pine Bend Refinery
Direct and Indirect
Rosemount
MN
MN0000418
X
X
X
X
Biolog
cal Treatment
66
St Paul Refinery
D
red
Saint Paul Park
MN
MN0000256
X
X
X
X
Biolog
cal Treatment
67
Pascagoula Refinery
D
red
Pascagoula
MS
MS0001481
x
x
x
x
x"
Biolog
cal Treatment
68
Ergon Refinery
D
red
Vicksburg
MS
MS0034711
x
x"
No Treatment Information Available
69
Southland Refinery
D
red
Sandersville
MS
MS0001686
x
x
x"
Treatment Otherthan Biological Treatment
70
Vicksburg Petroleum Products
D
red
Vicksburg
MS
MS0060976
X
No Treatment Information Available
71
Laurel Refinery
D
red
Laurel
MT
MT0000264
X
X
X
X
Biological Treatment
72
Phillips - Billings Refinery
Direct and Indirect
Billings
MT
MT0000256
X
X
X
X
Biological Treatment
73
Exxon - Billings Refinery
Direct
Billings
MT
MT0000477; MT0028321
X
X
X
X
No Treatment Information Available
74
Montana Refinery
Indirect
Great Falls
MT
MTPU00118; MTR000556
X
X
X
Treatment Otherthan Biological Treatment
75
Dakota Refinery
Indirect
Dickinson
ND
NDR050776
No Data
No Data
No Data
No Data
No Data
No Data
No Data
76
Mandan Refinery
Direct
Mandan
ND
ND0000248
X
X
X
Biological Treatment
77
Bayway Refinery
D
red
Linden
NJ
NJ0001511; NJ 0026662;
NJ0026671
x
x
X
xb
Biological Treatment
78
Axeon - Paulsboro
D
red
Paulsboro
NJ
NJ0064921
X
X
X
X
Biological Treatment
79
PBF-Paulsboro
D
red
Paulsboro
NJ
NJ0005029
X
X
X
X
X
X
Current BAT Technology
80
Navajo Refinery
Indirect and Injection
Artesia
NM
X
X
X
X
Biolog
ical Treatment
81
Gallup Refinery
Unknown
Jamestown
NM
NM0031071; NMR053168
X
X
X
Biolog
ical Treatment
82
Foreland Refinery
Unknown
Ely
NV
X
X
X
X
Biolog
ical Treatment
B-l
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Wastewater Treatment in Place at Petroleum Refineries
EPA used WWT data collected as part of the data request, site visit reports, and other publicly available data sources, such as 2011 Office of Air and Radiation (OAR) data, NPDES permit and permit application information, and other publicly
available studies and reports to assess end-of-pipe WWT technologies in-place.
acil'ity Information
i'iM \\k m il'iH M
Data Source
Refinery ID
State
NPDES ID(s)
Oil/water
Separation
Oil/water
Separation
Unit
Biological
Treatment
Filtration
Effluent
Polishing
Description of Effluent
Polishing Unit
Data Request
for 2016 Data
Site Visit
2011 OAR 1
Other Sources
Categorized by ERG for Petroleum Refining
Detailed Study Report
Technologies Identified as
"Beyond BATTechnologies"
Refinery Name
Indirect or Direct'
aty
Information
Collection
Request
83 | Toledo Refinery
D
red
Oregon
OH
OH0002461
X
X
X
X
X
x
Current BAT Technology
84 Lima Refinery
D
red
Lima
OH
OH0002623
X
X
X
X
Biological Treatment
85 1 Ohio Refinery
D
red
Canton
OH
OH0005657
x
x
x
x
Biological Treatment
86 Toledo Refinery
D
red
Oregon
OH
OH0002763
x
No Treatment Information Available
87 | Ponca City Refinery
D
red
Ponca City
OK
OK0000256
x
x
X
Biolog
cal Treatment
88 Tulsa East Refinery
Direct and Indirect
Tulsa
OK
OK0001309
x
x
x
Biolog
cal Treatment
89 Tulsa West Refinery
D
red
Tulsa
OK
OK0000876
x
x
x
x
Biolog
cal Treatment
90 Urdmore Refinery
D
red
Ardmore
OK
OK0001295
x
x
X
Biolog
cal Treatment
91 | Wynnewood Refinery
D
red
Wynnewood
OK
OK0000825; OK0046027
x
No Treatment Information Available
92 American Refining
D
red
Bradford
PA
PA0002674
x
x
x
x
Biolog
cal Treatment
93 | Trainer Refinery
D
red
Trainer
PA
PA0012637
x
x
x
x
x"
Biolog
cal Treatment
94 Philadelphia Refinery
Direct and Indirect
Philadelphia
PA
PA0011533; PA0012629
x
x
x
xb
Biolog
cal Treatment
95 United Refining
Direct
Warren
PA
PA0005304
x
x
x
x
Biolog
cal Treatment
96 Tennessee Refinery
Indirect
Memphis
TN
MG670074; TNR056522; 5-NN1-0;
x
x
x
Treatment Otherthan Biological Treatment
97 | Calumet - San Antonio
Unknown
San Antonio
TX
TXG670214
x
x
Treatment Otherthan Biological Treatment
98 Big Springs Refinery
Direct
Big Spring
TX
TX0104515
x
x
x
x
x
x
Current BAT Technology
99 | Borger Refinery
Direct
Borger
TX
TX0009148
x
x
x
x
x
x
XC,"
Beyond BATTechnology
Ion Exchange
100 Sweeny Complex
Direct
Brazoria
TX
TX0007536
x
x
x
x
Brine tank (coagulation and
flocculation)
x
Current BAT Technology
101 | Citgo - Corpus Christi Refinery
Direct
Corpus Christi
TX
TX0006211
x
x
x
x
Biological Treatment
102 1 Tyler Refinery
Indirect
Tyler
TX
TX0001449
x
x
x
Biological Treatment
103 McKee Plant
Indirect
Sunray
TX
TX0115851
x
x
x
x
x
x
Current BAT Technology
104 | Beaumont Refinery
D
red
Beaumont
TX
TX0118737
x
x
x
x
Treatment Otherthan Biological Treatment
105 Baytown Refinery
D
red
Baytown
TX
TX0006271
x
x
x
X
Chemical oxidation
x
x
Current BAT Technology
106 1 Flint Hills - Corpus Christi East Refinery
D
red
Corpus Christi
TX
TX0006599
x
x
x
x
x
x
Current BAT Technology
107 1 Flint H ills - Corpus Christi West Refinery
D
red
Corpus Christi
TX
TX0006289
x
x
x
x
x
Current BAT Technology
108 LyondellBasell - Houston Refinery
Direct a
nd indired
Galena Park
TX
TX0003247
x
x
x
Treatment Otherthan Biological Treatment
109 G alena Park Crude & Condensate
In
TX
TX0135640
No Data
No Data
No Data
No Data
No Data
No Data
No Data
110 Lazarus Refinery
Unknown
Nixon
TX
No Data
No Data
No Data
No Data
No Data
No Data
No Data
111 Marathon - Galveston Bay Refinery
Direct
Texas City
TX
TX0003522
X
X
X
X
x
x
Current BAT Technology
112 | Marathon-Texas City Refinery
Direct
Texas City
TX
TX0003697
X
X
X
X
x
Current BAT Technology
113 Pasadena Refinery
Indirect
Pasadena
TX
TX0004626
X
x
x
Treatment Otherthan Biological Treatment
114 Motiva - Port Arthur Refinery
D
red
Port Arthur
TX
TX0005835
X
X
X
x
x
Biolog
115 Valero - Port Arthur Refinery
D
red
Port Arthur
TX
TX0005991
X
X
X
x
x
Biolog
116 | Deer Park Refinery
D
red
Deer Park
TX
TX0004871; TX0004863
X
X
x
x
Biolog
117 1 Silsbee Refinery
D
red
Silsbee
TX
TX0003204
X
X
x
Biolog
118 Total Petrochemicals - Port Arthur Refinery
D
red
Port Arthur
TX
TX0004201
X
X
X
x
x
119 1 Valero-Texas City Refinery
D
red
Texas City
TX
TX0006009; TXG670007
X
X
X
X
x
Current BAT Technology
120 1 Valero - Houston Refinery
D
red
Houston
TX
TX0002976
X
X
X
x
x
Biological Treatment
121 | Valero - Corpus Christi East Refinery
D
red
Corpus Christi
TX
TX0006904
X
x
Treatment Otherthan Biological Treatment
122 Valero - Corpus Christi West Refinery
D
red
Corpus Christi
TX
TX0063355
X
x
xb
Treatment Otherthan Biological Treatment
123 Three Rivers Refinery
D
red
Three Rivers
TX
TX0088331
X
X
X
X
x
x
Current BAT Technology
124 1 Western Refinery
Indirect
El Paso
TX
X
x
Treatment Otherthan Biological Treatment
125 Big West Oil Refinery
Unknown
North Salt Lake
UT
X
X
x
Treatment Otherthan Biological Treatment
126 | Chevron - Salt Lake City Refinery
Direct and Indirect
Salt Lake City
UT
UT0000175
X
X
x
Biological Treatment
127 | H oily Frontier - Wood Cross Refinery
Indirect
Woods Cross
UT
UTG070092; UTR000514
X
X
X
x
Biological Treatment
128 | Silver Eagle - Wood Cross Refinery
Indirect
Woods Cross
UT
UTR000132; UTR000449
X
X
x
Biological Treatment
129 1 Salt Lake City Refinery
Indirect
Salt Lake City
UT
No Data
No Data
No Data
No Data
No Data
No Data
No Data
130 | Cherry Point Refinery
Direct
Blaine
WA
WA0022900
X
X
X
x
x
Biological Treatment
131 Ferndale Refinery
Direct
Ferndale
WA
WA0002984
X
X
X
x
xc
Biological Treatment
132 | Puget Sound Refinery
D
re[.
Anacortes
w.
WA0002941
x
x
x
x
Final pond (chemical
addition and settling)
x
Current BAT Technology
133 Anacortes Refinery
D
red
Anacortes
WA0000761
X
X
X
X
Settling pond
x
Current BAT Technology
134 |Tacoma Refinery
D
red
Tacoma |
WA
WA0001783; WAR307424
X
X
X
x
Biological Treatment
135 | Superior Refinery
D
red
Superior
Wl
Wl0003085
X
X
X
x
Biological Treatment
136 | Ergon West Virginia Refinery
D
red
Newell |
WV
WV0004626
X
X
X
X
Biological Treatment
137 | Antelope Refining
Indirect
Douglas
WY
No Data
No Data
No Data
No Data
No Data
No Data
No Data
138 | Frontier Refining
Indirect
Cheyenne
WY
WY0000442
X
X
X
x
XC'B
Biological Treatment
139 | Evanston Refinery
Zero Discharge |
Evanston
WY
X
x
Treatment Otherthan Biological Treatment
140 | Casper Refinery
Indirect
Casper ~|
WY
No Data
No Data
No Data
No Data
No Data
No Data
No Data
141 | Sinclair Refinery
Zero Discharge |
Sinclair
WY
No Data
No Data
No Data
No Data
No Data
No Data
No Data
142 | Wyoming Refinery
Unknown
Newcastle |
WY
X
X
X
Biological Treatment
143 BTB Refining LLC
Direct
Corpus Christi
TX
TX0096474
No Data
No Data
No Data
No Data
No Data
No Data
No Data
Note: ERG collected available data about p re-treatment technologies in place at petroleum refineries, including stripping units (e.g., sour water stripper), benzene recovery units, and brine treatment units. Refineries may consider these units part of the refining process and may not report
Note: The technology field is populated in the table if the wastewater treatment technology is incorporated anywhere in the system. For this analysis, if the facility has the technologies associated with BAT bases, ERG assumed they were in the expected order.
Note: ERG presented information based solely on survey or site visit data where available,
a - ERG did not verify if the oil/water separators are operated in series.
b - Although there was permit data for this refinery in the permit database, the permit database did not list any treatment technologies for this refinery. Therefore, the data presented for the refinery are solely based on the 2011 OAR data,
c - Identified treatment in place from the BP and Purdue/Argonne Studies (see Section 7 for list of studies)
d - Identified treatment in place from 2009 report titled Lessons Learned on Long-Term Operation ofMBBRfor Refineiy WWT (Cabral, 2009).
e - Identified treatment in place from report titled Enhancing Nitrification in an Oil Refinery WWTP with IFAS (Flournoy, 2008).
f -The data sources used to identify direct or indirect discharge of wastewater is presented and discussed in the Industry Profile Memo.
B-2
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