Technical Support Document
Industry Overview and Current Reporting
Requirements for Petroleum Refining and
Petroleum Imports
Proposed Rule for Mandatory Reporting of
Greenhouse Gases
Office of Air and Radiation
U.S. Environmental Protection Agency
January 30, 2009
-------
Petroleum Product Suppliers Technical Support Document
Table of Contents
Page
1.0. Introduction 1
1.1. Purpose 1
1.2. Organization of this Report 1
2.0. Overview of the Petroleum Industry 2
2.1. The Role of Petroleum in the Economy 2
2.2. Structure of the Petroleum Industry 7
3a.0. Industry Federal Reporting Requirements 17
3a. 1. Refineries 18
3a.2. Imports 21
3a.3. Exports 25
3a.4. Others 25
3b.0. Data Gaps and Quality 26
3b. 1. Reporting Gaps in Industry Coverage 27
3b.2. Data Sensitivity 27
3b.3. Quality Assurance and Control 28
4.0. Analysis Supporting the Rule 28
4.1. Default Carbon Content Factors 28
4.1.1 Default Petroleum Product Carbon Content Factor Uncertainties .. 28
4.1.2. Petroleum Products 33
4.1.3. Natural Gas Liquids 42
4.1.4. Biomass Feedstock and Products 44
4.2. Direct Measurement Methods for Establishing Carbon Content 48
4.2.1. Direct Density Measurements 48
4.2.2. Direct Carbon Share Measurements 49
4.3. Threshold Calculations 49
4.3.1. Refineries 49
4.3.2. Importers 67
4.3.3. Exporters 74
4.4. Monitoring Method Costs 74
January 28, 2009
-------
Petroleum Product Suppliers Technical Support Document
List of Exhibits
Page
Exhibit 1: 2006 Petroleum Share of Primary Energy Consumption 4
Exhibit 2: Refinery Numbers and Operating Capacity 4
Exhibit 3: Crude Oil Imports into the United States by API Gravity 5
Exhibit 4: Imports of Products into the United States, February 2008 5
Exhibit 5: Flow Diagram of the Petroleum Industry 6
Exhibit 6: Twenty Largest Producers of Crude Oil in the United States in 2006 7
Exhibit 7: Refinery Capacity in the Top 5 States 9
Exhibit 8: Refinery Capacity of the Top 10 Refining Companies 9
Exhibit 9: Quantity of Crude Oil imported by PADD 12
Exhibit 10: Crude Oil imports by Top 5 Countries of Origin and by PADD 13
Exhibit 11: Imports of Finished Products by PADD 15
Exhibit 12: Consumption of Petroleum Products for Non-Energy Uses 16
Exhibit 13: 2006 Non-Energy use Petroleum Product Consumption, Storage and
Emissions 17
Exhibit 14: Calculation of Default Values for all Refined and Semi Refined Petroleum
Products 34
Exhibit 15: Emission Factors for Natural Gas Liquids 43
Exhibit 16: Renewable Diesel Co-processing By Thermal Depolymerization 44
Exhibit 17: Emission Factors for the Bio Portion of Renewable Diesel 45
Exhibit 18: Composition of Animal Fat and Vegetable Oil 46
Exhibit 19: Refinery Blending of Biodiesel with Fossil Diesel 47
Exhibit 20: Finished Motor Gasoline Produced per Refinery 51
Exhibit 21: Calculated C02 Emission Factor 62
Exhibit 22: Calculated C02 Emissions per Refinery 63
Exhibit 23: Estimated National C02 Emissions from Refineries 67
Exhibit 24: Calculated C02 Emission Factor 68
Exhibit 25: Calculated C02 (tonnes/year) Emissions per Importer 68
Exhibit 26: Threshold Analysis for Importers 74
Exhibit 27: Refinery Monitoring and Reporting Costs 75
Exhibit 28: Refinery Unit Cost for Monitoring and Reporting 76
January 28, 2009
ii
-------
Petroleum Product Suppliers Technical Support Document
1.0. Introduction
1.1. Purpose
This document provides an overview of the petroleum industry and identifies the current
federal reporting requirements of fuel suppliers, namely suppliers of petroleum products,
whether refiners or importers. The analysis here is part of a larger effort to develop
guidelines for mandatory reporting requirements for greenhouse gases (GHGs). In
December 2007, Congress enacted an omnibus appropriations bill that directs EPA to
develop and publish a rule requiring measurement and reporting of GHG emissions
above appropriate thresholds in all sectors of the economy. The bill mandates that EPA
publish a proposed rule within nine months and a final rule within 18 months.
Understanding the information that fuel suppliers already generate and report to federal
agencies is a first step in developing mandatory GHG reporting requirements.
This document focuses on firms in the petroleum industry, particularly petroleum
refiners, and the various players that import petroleum products. The emphasis is on the
generation of reports about volumes of petroleum products produced at U.S. refineries
and petroleum product imports. The report also addresses the level of detail of data,
facility definitions and boundaries, frequency of reporting, validation of reported data,
and how data gaps are managed. The report presents information on the coverage of
the data that are reported, key gaps in the data, business sensitivity of the data, and
questions about data verification and quality assurance and control. Finally, the report
discusses a number of relevant and critical aspects of the rule making such as the
carbon content of petroleum products, the question of threshold, and the costs
associated with monitoring and/or measuring the carbon content of products and
provides information on the calculations and assumptions underlying these aspects of
the rule.
Throughout the document petroleum refineries and corporate entities are mentioned by
name. All data and all name references are drawn from data and reports in the public
domain. While a number of sources are used the main source is the web site of the
Energy Information Administration (EIA) of the U.S. Department of Energy.
1.2. Organization of this Report
To provide context for the reporting requirements of the petroleum sector, section 2
provides an overview of the industry and the role that petroleum plays in the total energy
consumption of the United States. The focus is on the petroleum refining portion of the
industry and on petroleum imports but summary information about other major players in
the industry: producers, pipelines/terminals, and distributors is also provided. The
survey of the industry begins with a statistical summary of refineries, their capacity, and
their concentration, both geographic and economic. This is followed by a discussion of
the petroleum industry participants, with brief discussions of each, focusing on the types
of information generated in both the natural course of business as well as information
developed for and reported to federal government agencies. The information typically
reported to state government agencies is also identified. Included in this section is a
brief description of the non-energy petroleum products such as petrochemical
feedstocks, asphalt and road oil, among others.
January 28, 2009
1
-------
Petroleum Product Suppliers Technical Support Document
Section 3a is where the current reporting requirements of the industry are described. It
is divided into three subsections. The first address petroleum refineries, the second
imports/exports, and the final subsection briefly discusses other federal sources of data.
In Section 3b, conclusions about overall gaps in the reporting requirements are reported,
as well as other issues relevant to data coverage. Quality control and reliability of the
data reported are also briefly addressed. Also included is a section on the data that the
industry considers most sensitive. Finally Section 4 includes a discussion on the carbon
factors for petroleum products natural gas liquids, and biomass and presents the default
table of carbon factors along with the calculations, the sources and the methodology.
The calculations supporting the rule in the area of threshold analysis are presented next,
and the estimated costs.
2.0. Overview of the Petroleum Industry
2.1. The Role of Petroleum in the Economy
The United States is currently the third largest producer of crude oil in the world following
Saudi Arabia and Russia. In 2006 the United States produced 8,330 thousand barrels
per day (Mb/d) of total oil and 5,102 Mb/d of crude oil. The difference between the two
numbers represents production of lease condensate and natural gas liquids as well as
refinery gain, which in the United States ranges between six and seven percent on
average. The EIA maintains a historical data set which shows that the long term trend is
a steady decline in volume of production, although there have been some years of
increased production as when Prudhoe Bay came on line and with the advent of the
deepwater Gulf of Mexico production.
Crude oil production is surprisingly widespread and can be found in the majority of the
states. The other notable fact about U.S. production is that of the almost 500,000
producing oil wells (EIA 2007) in the United States over 84 percent are classified as
stripper wells1. However, the main and larger producers are found in PADD2 3 (Texas
and Louisiana) and PADD 5 (California and Alaska).
On the demand side the United States is the world's largest consumer of petroleum,
consuming 20,687 Mb/d in 2006. This amounts to approximately 39.8 quadrillion Btus or
Quads. The difference between the consumption and the production number, even
taking into account refinery gain3 is an indication of the degree of U.S. dependence on
imports. Another important fact is that of the petroleum products consumed in the
1 Stripper wells are defined as marginal wells reaching the end of their economic life and producing
between 5 to 15 barrels per day. (EIA)
2 PADD =Petroleum Administration for Defense District, the administrative divisions of the country by
which most petroleum data are reported. PADD 1 is the East Coast, PADD 2 is the Midwest, PADD 3 is
the Gulf Coast, PADD 4 is the Rockies, and PADD 5 is the West Coast. There is also a PADD 6 which
consists of the U.S. Virgin Islands and Puerto Rico, and a PADD 7 which consists of the Pacific Territories.
A map of the main 5 PADDs is attached at the end of this document.
3 Refinery gain is the volumetric increase in the total amount of product produced at a refinery compared to
the inputs. Thus for 1 barrel of inputs output is 1.06 barrels. The level of the gain varies with the
complexity of the refinery ranging from 1 percent at a topping plant to about 10 percent at a highly
complex refinery.
January 28, 2009
2
-------
Petroleum Product Suppliers Technical Support Document
United States over 71 percent are transportation fuels of various types (gasolines, on-
road diesels, marine and locomotive diesels, aviation fuels, and bunkers).
Petroleum accounts for almost 40 percent of United States primary energy consumption,
still by far the largest of the energy forms (EIA, 2006). Exhibit 1 shows the breakdown of
primary energy consumption by energy form.
There are currently 1504 active petroleum refineries in the United States sited in all 5
PADDs but the bulk of them are situated in the Gulf Coast and on the West Coast, the
main producing areas. Looking back to the 1970s there were then over 300 refineries.
However, many of those were small inefficient refineries that were opened largely
because of various subsidies and crude oil price controls. The 1980s and 1990s saw a
long period of refinery closings and consolidations as subsidies were ended and price
controls lifted. This elimination of small, simple, and inefficient refineries and its effect is
reflected by the fact that although the number of refineries has declined markedly, the
atmospheric distillation capacity of the remaining U.S. refineries has steadily increased
(See Exhibit 2). Petroleum refineries are extremely capital intensive, technologically
sophisticated facilities with very strong economies of scale. However, small refineries
can still function well in the United States if they have a captive market or produce high
value added products.
The increasing complexity of the product specifications and the increasing deterioration
of the world crude oil slate5 have led to major investment in equipment that has made
U.S. refineries among the most complex in the world and able to deal effectively with the
worst types of crude oils (which are also the cheapest). The down side of this is that
these refineries have more intensive processing, use more energy, and thus have higher
emissions.
4 As of January 1, 2008, EIA
5 Over the past decade the global crude oil slate has become increasingly heavier and higher in sulfur which
requires more intense processing to produce the clean fuels required in many countries. This is a long term
trend although there are periods in which it has been temporarily reversed such as from the growth of
Angolan crude oil which is generally light and low in sulfur.
January 28, 2009
3
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 1: 2006 Petroleum Share of Primary Energy Consumption
8.2%
22.4%
¦ Petroleum
Natural Gas
¦ Coal
Renewable Energy
Nuclear Electric Power
Source: Energy Information Administration (EIA), Annual Energy Review 2006 - U.S. Primary
Energy Consumption by Source and Sector, 2006
Exhibit 2: Refinery Numbers and Operating Capacity
Mb/d
2003
2004
2005
2006
2007
PADD 1
1,571
1,663
1,638
1,627
1,658
13
14
13
13
13
PADD 2
3,518
3,526
3,569
3,583
3,582
26
26
26
26
25
PADD 3
7,708
7,881
8,068
7,464
7,990
54
54
53
52
55
PADD 4
578
582
588
596
598
16
16
16
16
16
PADD 5
3,109
3,107
3,144
3,152
3,171
36
36
36
35
36
U.S. Total
16,484
16,759
17,006
16,421
16,998
145
146
144
142
145
Source: www.eia.doe.aov/oil aas/Detroleum/info alance/Detroleum.html
Exhibit 3 shows some of the range of crude oil imports into the United States by API
gravity. As the exhibit shows the largest percentage of crude oil types that are imported
into the United States fall into the heavy oil category, (<25 API gravity). At the other end
of the scale, a small amount of Algerian condensate is imported into Louisiana for a few
specialized refineries.
January 28, 2009
4
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 3: Crude Oil Imports into the United States by API Gravity
Percentage of Total Crude oil Imports
API Gravity
August
07
September
07
October 07
November
07
December
07
January 08
20.0 or less
13.26
13.56
12.83
10.01
13.38
13.41
20.1 -25.0
20.84
19.83
21.3
26.17
23.38
29.05
25.1 -30.0
13.06
14.31
13.26
11.7
7.22
10.86
30.1 -35.0
26.58
28.44
28.04
30.17
30.08
25.03
35.1 -40.0
17.47
18.05
18.8
15.67
15.84
15.93
40.1 -45.0
6.48
5.37
4.08
4.56
6.54
4.24
45.1 or greater
2.29
0.44
1.69
1.73
3.56
1.48
Source: http://tonto.eia.doe.aov/nav/Det/Det move iDct k m.h
tm
The United States imports refined products and blending products: the number has
hovered around 2 MMb/d for many years, sometime more, sometimes less. However,
product imports are expected to climb over the next decade. Exhibit 4 lists imported
finished products and imported gasoline blending components for a representative
month, February 2008. The import portfolio includes a full range of finished products;
however it is biased towards transportation fuels as the latter approximates 45 percent.6
Transportation fuels are broken out into a number of categories. Gasoline imports are
distinguished by whether they are reformulated or conventional and then they are further
distinguished by any additives such as an oxygenate. Distillate fuel oil and residual fuel
oil are reported by sulphur category. Petrochemicals are reported by whether they are
naphtha based or otherwise.
Exhibit 4: Imports of Products into the United States, February 2008,
Mb/d
Finished Motor Gasoline (5 categories)
354
Aviation Fuels (3 categories)
101
Kerosene
2
Distillate Fuel Oil (4 categories)
248
Residual Fuel Oil (3 categories)
308
Petrochemical Feedstocks (2 categories)
171
Special Naphthas
14
Lubricants
27
Waxes
3
Petroleum Coke (Marketable)
11
Asphalt and Road Oil
34
Total
1273
Motor Gasoline Blending Components (6
categories)
657
Source: EIA, Petroleum Supply Monthly, April 2008
Exhibit 5 is a flow diagram of the petroleum industry focused around refining. The
diagram shows something of the complexity of the movements and the interrelationship
with other sectors.
6 Finished Motor Gasoline 354 Mb/d, Aviation Fuels 101 Mb/d, and that portion of the Distillates
that is ULSD 124 Mb/d.
January 28, 2009 5
-------
Exhibit 5: Flow Diagram of the Petroleum Industry
'etroleum Flow Diagram
5006 Annual Volumes in Thousand Barrels
EIA 820
EIA 812
E1A 810
Calculated Values
E1A 810
Crude Oil Exports
E1A814
Crude Oil Imports 3,693,081
5,546,341
5,563,354
Natural Gas Liquids
179,916
Pentanes Plus
66,875
Liquefied Petroleum Gases
113,041
Other Liquids
-632,581
Other Hydrocarbons/Oxygenates
46,836
Unfinished Oils (net)
241,381
Motor Gasoline Blending Components (net)
-920,832
RBOBwith Ether
-5,246
RBOB with Alcohol
-753,798
CBOB
-147,094
GTAB Reformulated
0
GTAB Conventional
1,014
All Other
-15,708
Aviation Gasoline Blending Components (net)
34
Purchased
Fuel Inputs
Natural Gas
Coal
Electricity
Steam
697,593 million cubic feet
34 thousand short tons
39,353 million kWh
70,769 million pounds
Total Refinery Products
Petrochemical Feedstocks
Naptha
Other Feedstocks
Special Naphthas
Petroleum Coke
Marketable
Catalyst
Finished Motor Gasoline
Reformulated
Blended with Ether
Blended with Alcohol
Non Oxygenated
Conventional
Blended with Alcohol
Other Conventional
Finished Aviation Gasoline
Kerosene-Type Jet Fuel
Commercial
Military
Kerosene
Distillate Fuel Oil
15 ppm Sulfur and Under
>15 ppm to 500 ppm Sulfur
> 500 ppm Sulfur
Residual Fuel Oil
Liquefied Refinery Gases
Ethane/Ethylene
Ethane
Ethylene
Propan e/Propylene
Propane
Propylene
Normal Butane/Butylene
Normal Butane
Butylene
Isobutane/I sobutylene
Isobutane
Isobutylene
Asphalt and Road Oil
Miscellaneous Products
Fuel Use
Nonfuel Use
143,859
71,548
72,311
309,431
219,398
90,033
1,965,341
125,678
82,350
24,665
18,663
1,839,663
15,309
1,824,354
6,578
1,474,741
555,524
575,708
343,509
231,888
228,960
6,775
5,170
1,605
198,190
110,110
-1,791
-312
-926
25,819
626
25,193
Natural Gas Liquids
Other Liquids
Finished Petroleum Products
24,769
29,108
417,686
Exports 471,563
E1A810
Notes
1. Negative values represent drawdown from stock
2. Solid box denotes that all commodities contained in the the box go where the attached arrow points;
dotted box donotes that some of the commodites contained in the box go where the attached arrow points
Net
Products
Produced
Source: EIA Petroleum Supply Annual 2006
lanuary 28, 2009
6
Petroleum Product
Suppliers Technical
Support
Documen
E1A 810
E1A 811
E1A812
E1A813
E1A814
E1A816
E1A817
Total Products Produced
Natural Gas Liquids and LPGs
Pentanes Plus
Liquefied Petroleum Gases
_ Ethan f/EthyJen_e
i Propane/Propvlene
i Normal Butane/Butylene
Isobutan e/l so buty I en e
Other Liquids
Other Hydrocarbons/Oxygenates
Unfinished Oils
Motor Gasoline Blend. Comp.
Reformulated
Conventional
Aviation Gasoline Blend. Comp.
Products
Produced
Finished Petroleum Products
Finished Motor Gasoline
Reformulated
Conventional
Finished Aviation Gasoline
Kerosene-Type Jet Fuel
Kerosene
Distillate Fuel Oil
15 ppm and under Sulfur
Greater than 15 to 500 ppm Sulfur
Greater than 500 ppm Sulfur
Residual Fuel Oil
Petrochemical Feedstocks
Naphtha for Petro. Feed. Use
Other Oils for Petro. Feed Use
Special Naphthas
Lu bricants
Waxes
Petroleum Coke
Marketable
Catalyst
Asphalt and Road Oil
Still Gas |-
Miscellaneous Products
10,005,018
7,550,907
779,452
30,326
749,126
258,108
443,415
42,209
5,394
6,759,253
3,377,174
1,132,518
2,244,656
6,626
596,011
19,594
1,521,730
520,689
650,979
350,062
251,429
255,559
119,827
135,732
13,348
50,040
4,722
190,608
100,575
90,033
190,049
258,893
23,470
i Natural Gas Liquids | 131,227
1 Other Liquids ~| 517,931
Finished Petroleum Products 660,843
Imports 5,003,082
E1A 856
E1A 804
E1A 814
Recycled to
Refinery
Feedstocks
to Other
Industries
E1A821
FERC6
End Use
Total Products
Distillate
Residential
Commercial
Industrial
Oil Company
Farm
Electric Power
Railroad
Vessel Bunkering
On-Highway
Military
Off-Highway
All Other
Residual Oil
Commercial
Industrial
Oil Company
Electric Power
Vessel Bunkering
Military
All Other
Kerosene
Residential
Commercial
Industrial
Farm
All Other
1,744,968
73,288,647 thousand gallons
62,192,026 thousand gallons
4,984,826
2,808,786
2,463,676
636,788
3,261,345
656,355
3,552,430
1,903,138
39,118,301
327,827
2,478,554
10,273,631 thousand gallons
479,124
1,451,730
65,247
2,505,724
5,753,592
12,005
6,209
822,990 thousand gallons
491,508
112,392
202,590
15,064
1,435
-------
Petroleum Product Suppliers Technical Support Document
2.2. Structure of the Petroleum Industry
This section describes the operating components of the petroleum industry.
Producers. These are the companies that explore, drill, and produce petroleum, and in
many cases, natural gas in the United States. There were approximately 13,820
operators of 497,403 oil wells in 2006. These operators range from large integrated
producers with worldwide operations and interests in all segments of the oil and gas
industry, to large independents, to small one or two person operations that may only
have partial interest in a single well. The twenty largest producers in 2006 are shown in
Exhibit 6. The 10 largest producers accounted for 2,669 Mb/d in 2006 or 53 percent of
total crude oil production while the largest 20 producers accounted for 62 percent. The
top 50 producers accounted for 75 percent. The remaining 13,770 accounted for the last
25 percent of crude oil production (EIA, 2006). Attached at the end of this paper is a list
of the top 200 producers.
The three largest producing states are Texas (21 %), Alaska (15 %), and California (12
%). In addition, 25 percent of U.S. production comes from the Federal offshore in the
Gulf of Mexico.
Exhibit 6: Twenty Largest Producers of Crude Oil in the United States in 2006
Rank
Company Name
Volume (Mb/d)
1
BP Pic
586
2
Chevron Corporation
450
3
ConocoPhillips Co
401
4
Shell Oil Co
305
5
Occidental Petroleum Corporation
285
6
Aera Energy LLC
188
7
Anadarko Petroleum Corporation
183
8
ExxonMobil Corporation
131
9
Apache Corporation
81
10
Plains Exploration & Production Co
59
Total
2,669
Percentage of U.S.
Total
53%
11
Kinder Morgan Energy Partners
57
12
Amerada Hess Corporation
57
13
Dominion Resources Inc.
54
14
Noble Energy Inc.
52
15
Marathon Oil Co.
47
16
Merit Energy Co
46
17
Murphy Oil Corporation
43
18
XTO Energy Inc
40
19
Devon Energy Corporation
38
20
EOG Resources Inc
37
Total
3,140
Percentage of U.S.
Total
62 %
Source; EIA 2006
January 28, 2009
7
-------
Petroleum Product Suppliers Technical Support Document
Producers create and maintain extensive and accurate records on petroleum production
in the normal course of business. Particular attention is paid to the lease meter,
because it is at that point that royalty payments are calculated. Royalty payments must
be made to landowners and other well partners. State severance taxes require the
submission to state agencies of production data and sales. Federal royalty payments
are made to the land management agencies and to the Minerals Management Service
for offshore outer continental shelf production. At the same time, producers are excused
from having to file data regularly with the Energy Information Administration (EIA). ElA's
reports on production come from data collected from state agencies. State agencies are
the central repositories for production data. EIA does collect sample data from
producers in EIA-231 and EIA-23S, Annual Survey of Domestic Oil & Gas Reserves.
EIA-231 is sent to a sample of large and mid size operators who report data on the field
level, while EIA-23S is sent to a sample of small operators who report data on the state
or geographic level. Although the focus of the forms is on reserves the survey recipients
are required to report on oil, gas, and lease condensate production for the appropriate
year.
Gathering Pipelines. These are pipelines that collect petroleum from wellheads in a
branch and trunk system and deliver the crude oil into either a refinery or a trunk line that
then moves the crude oil to a refinery. There are about 14,9117 miles of crude oil
gathering pipelines in the United States. They may be owned by the producer or the
processing plant, or the affiliate of a trunk line or an independent gathering business.
They charge a fee for the service where fees are negotiated between the producer and
the gathering pipeline.
Gathering pipelines measure the crude oil they transport and thus have extensive
records on current levels of throughput. However, only if they move over 1,000 barrels
are they required to file their data with EIA in EIA-813 Monthly Crude Oil Report. They
also must file reports with the Department of Transportation (DOT), Pipeline and
Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS).
These are relative to siting, routing, and safety issues. Gathering systems may also
report to federal land management agencies and state land use agencies.
Petroleum Refiners. There are currently 150 operating petroleum refineries in the
United States with a capacity of 17,000 Mb/d. As Exhibit 2 above shows capacity has
been steadily increasing both at the national and at the PADD level. A new refinery has
not been built in the United States for over 30 years and U.S. refiners have responded
by expanding existing refineries, which is still difficult but has proved easier in terms of
local permits.
A distinct characteristic of the refining sector is the high level of concentration, both
geographic and economic. The geographic concentration is historic and relates to the
pattern of crude oil production in the country. The economic concentration relates in part
to the high capital costs and the economies of scale in refining technology. As an
example unless an individual refinery has a captive market a hydrocracker would not be
installed in a refinery of less than 100,000 b/d capacity.
Exhibit 7 shows the geographic concentration of refining and Exhibit 8 shows the
economic concentration.
7 Oil & Gas Journal, Volume 10633, September 1, 2008
January 28, 2009
8
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 7: Refinery Capacity in the Top 5 States
Mb/d
2003
2004
2005
2006
2007
1. Texas
4,329
4,468
4,628
4,241
4,337
2. Louisiana
2,719
2,753
2,773
2,534
2,971
3. California
1,990
1,984
2,005
2,005
2,022
4. Illinois
878
878
896
904
904
5.
Pennsylvania
760
760
770
770
773
Total
10,676
10,843
11,072
10,454
11,007
Percentage of
U.S. Total
65%
65%
65%
64%
65%
Source: EIA
As Exhibit 7 shows 65 percent of the refining capacity in the United States is
concentrated in 5 states, all of which constitute the historic production centres of the
country.
Exhibit 8: Refinery Capacity of the Top 10 Refining Companies
Mb/d
2003
2004
2005
2006
2007
1
ExxonMobil
ConocoPhillips
ConocoPhillips
Valero
Valero
1,808 11%
2,186 13%
2,198 13%
2,195 13%
2,219 13%
O
Phillips
ExxonMobil
Valero
ConocoPhillips
ExxonMobil
1,711 10%
1,844 11%
2,108 12%
1,983 12%
1,862 11%
'i
BP
Valero
ExxonMobil
ExxonMobil
ConocoPhillips
1,502 9%
1,696 10%
1,847 11%
1,860 11%
1,779 10%
A
Valero
BP
BP
BP
BP
1,317 8%
1,505 9%
1,505 9%
1,039 6%
1,249 7%
Chevron
Chevron
Chevron
Chevron
Chevron
999 6%
1,007 6%
1,007 6%
1,012 6%
1012 6%
Marathon
Marathon
Marathon
Marathon
Marathon
935 6%
935 6%
948 6%
974 6%
974 6%
Motiva
Motiva
Sunoco
Sunoco
Sunoco
880 5%
887 5%
900 5%
900 5%
903 5%
8
Sunoco
Sunoco
Koch Industries
PDV America
Koch Industries
730 4%
740 4%
763 4%
785 5%
777 5%
9
Shell
PDV America
Motiva
Koch Industries
Motiva
669 4%
640 4%
747 4%
777 5%
762 4%
10
Conoco
Shell
PDV America
Motiva
PDV America
566 3%
574 3%
640 4%
747 5%
753 4%
Source: EIA
The top ten refining companies currently control 72 percent of the refining capacity in the
country. For the last two years the list has been topped by the large independent,
Valero, which is a refining company only.
As the flow diagram (Exhibit 5) shows, refineries sit between production and
consumption, but also, to some extent between natural gas processing plants and
consumption. They are among the largest of the industrial energy users, using their own
products, including still gas, as well as purchased natural gas and, in some places coal.
Refinery consumption of electricity, steam and hydrogen is somewhat more complicated
as they both purchase these products from outside the fence and self generate them.
January 28, 2009
9
-------
Petroleum Product Suppliers Technical Support Document
Traditionally their purchased natural gas was used both for energy and as a feedstock
for the hydrogen plant. However, Air Liquide has now built a large pipe ring in Houston
through which it provides hydrogen to the Houston refineries that have, in most cases,
closed down their own hydrogen plants. Trade Journals have been discussing the
possibility of a similar effort by Air Liquide on the West Coast.
Increasingly refineries are also integrating with petrochemical plants. In many cases the
ethylene cracker is now built among the refinery processing units so that the feedstock
can swing from natural gas to naphtha to gasoil depending on the relative prices.
Refineries are among the industrial facilities that have to provide the most data to federal
and state officials. They are also closely monitored for safety by both OSHA and the
relevant state agencies and are closely monitored for criteria pollutants and toxic
emissions. Depending on their location (whether or not a residential area has grown up
around them) they may or may not continuously monitor all emissions going over the
fence. Refineries provide detailed information to EIA on a monthly and annual basis
largely in EIA-810 Monthly Refinery Report and EIA-820 Annual Refinery Report. These
reports are mandatory and required from every refinery in the country with no
exceptions. There are a plethora of other reports that they file related to their imports, to
their sales, and to their stocks which are discussed in Section 3. Refineries are also
required to report detailed information to state agencies. California and Texas in
particular maintain substantial data on refineries.
Trunk Pipelines. These are the large diameter systems that move crude oil from
producing regions to refineries or from import terminals to refineries. Not all crude oil
moves through these lines as this is dependent on the location of the refinery vis-a-vis
the source of crude oil. For example there are refineries in the coastal regions that
receive their imported crude oil directly from tankers that off load at the refinery's own
docks.
These pipelines are also the large diameter product lines that move refinery products to
consumers or product imports to final consumers. Crude oil lines and product lines are
completely separate. There is one line in the country that occasionally batches crude oil
and products but it is the exception. Both the crude and the product lines can be
intrastate or interstate.
As of 2007 there were 46,658 miles of crude oil trunk lines in the United States and
about 85,666s miles of product lines. Major pipeline companies include Colonial Pipeline
Co., Enbridge Energy LP, Marathon Pipeline LLC and Explorer Pipeline Co. Each of
these companies owns several major interstate pipelines and are the top four petroleum
lines in terms of trunkline traffic9.
The major components of pipelines include the receipt and delivery meters, pump
stations, and the pipe itself. Product pipelines in particular can have many receipt point
meters where products are loaded up into the pipeline directly from refineries. The
delivery point meters measure deliveries to other pipelines, storage, and large end
users. Pipelines must operate to maintain a balance between receipts and deliveries on
8 Ibid
9 Oil & Gas Journal, September 3, 2007
January 28, 2009
10
-------
Petroleum Product Suppliers Technical Support Document
a daily, monthly, and annual basis. Shippers' bills are based on these meter readings
and over the course of a year are reasonably accurate
Both crude and product pipelines submit information to EIA. The crude lines report on
EIA-813 Monthly Crude Oil Report and all the product lines report on EIA-812 Product
Pipeline Report. Product pipelines also report to EIA weekly on EIA 802-Weekly Product
Pipelines Report. However, the product pipelines reports apply ONLY to movements
between PADDS. As mentioned above crude oil lines are only obliged to file if they
move more than 1,000 barrels. Both product and crude oil interstate lines are required
to report to the Federal Energy Regulatory Commission (FERC) annually, U.S. FERC
Form 6: Annual Report of Oil Pipeline Companies. Intrastate lines are required to report
to their relevant state agency.
Marine Companies. A substantial amount of crude oil, unfinished oils and products
moves around by tanker and barge. There is considerable inter refinery trading of crude
oil and unfinished oils particularly in the U.S. Gulf that moves by barge on the
intercoastal waterway. It is not uncommon during non-scheduled events such as
accidents or mechanical problems or scheduled events such as annual maintenance
turnarounds for refiners to trade excess unfinished product.10 Unfinished oils can also
be traded if there is an imbalance between the atmospheric distillation tower and some
of the downstream processing units. For example, if the refinery is producing more
naphtha than it can process the option facing it are to either sell the naphtha on the open
market or to trade it to another refinery - the decision will be made based on the relative
prices. Inter-company shipments from one refinery to another have to be reported to
EIA on the Monthly Refinery Report (EIA-810) and the Annual Refinery Report (EIA-
820).
On the East coast, imports from overseas and domestic products from the south
converge on New York City and are then distributed to New England and the Mid
Atlantic by barge along the East Coast Inland waterway. During part of the year
substantial volumes of products move up the Mississippi by barge. All inter-PADD
movements by water are required to be reported to EIA in EIA-817 Monthly Tanker and
Barge Movements between PADDs. In addition, all marine movements and details on
the type and volume of cargo are tracked and reported by the Army Corps of Engineers
on Forms ENG Form 3935 and ENG Form 3925B (Shallow draft barge and tow boat
operators) unless the trip is under one mile. However, it is unlikely that inter refinery
trades would be less than a mile.
Terminal Operators. There are a number of different terminal groupings. There are
crude oil terminals which are usually owned by refining companies and serve as a way
station for crude oil that is imported or brought long distances for their refineries. In
terms of petroleum products there are terminals that are owned by refineries and a large
number of independent terminals that store both domestic and imported products
depending on their location. There are also at least 280 terminals at which additives,
blending stock and biofuels are blended with gasolines.
10 This trading goes on on a regular basis. For example the Hovensa refinery in the U.S. Virgin Islands
sends large volumes of unfinished oils to a plant in Port Reading, New Jersey which does not have an
atmospheric distillation tower but does have a vacuum distillation tower and other processing units.
January 28, 2009
11
-------
Petroleum Product Suppliers Technical Support Document
There are two sets of reports that terminal operators have to make to EIA, Bulk
Terminals must report weekly on EIA-801 Weekly Bulk Terminal Report and monthly on
EIA-811 Monthly Bulk Terminal Report. Specialized terminals, where gasoline blending
takes place, report weekly on EIA-805 Weekly Terminal Blenders Report and monthly on
EIA-815 Monthly Terminal Blenders Report. In addition, all bulk terminals and bulk
carriers (pipeline and marine) are required to file information on their product volumes
and movements to the IRS under the Excise Summary Terminal Reporting System
(ExSTARS) program. This is a program that tracks all products that come into and out
of bulk terminals and also tracks the destination of the products once they leave the
terminal.
Importers. Substantial volumes of petroleum imports reach the United States. There is,
however, a difference in both the pattern and players between crude oil imports and
product imports. Most crude oil imports (and unfinished oils) are imported by the oil
companies, with an occasional trader making an appearance. The crude oil comes in
either directly to the refiner's marine terminal or to the terminals of the major crude oil
pipelines such as Capline. Canadian crude oil enters the northern tier of the United
States by pipeline, with Eastern Canadian offshore crude oil moving to the East Coast
refiners by tanker. Crude oil is only used by refiners. Finished products on the other
hand, can come in wherever there is a terminal with the offloading and tankage
requirements. The universe of importers is different as well. Year to year it can vary
considerable. The marketing arms of the oil companies import products, as do traders,
petrochemical/chemical companies, propane distributors, ethanol companies, utilities on
the East Coast, and there have even been times in the past during bad winters when
states and local governments have directly imported heating oil.
There is a good deal more information about the origin of the crude oil that is imported
into the United States than is known about refined products imports. Exhibit 9 shows the
quantity of foreign crude oil imported into the 5 PADDs and Exhibit 10 shows the top 5
countries of origin. Exhibit 11 shows imports of products into the 5 PADDs.
Exhibit 9: Quantity of Crude Oil imported by PADD
Million barrels and % of Total Crude Used
2003
2004
2005
2006
2007
PADD 1
579
567
586
547
543
98.9%
99.2%
99.1%
98.9%
99.2%
PADD 2
349
391
367
412
410
68.9%
71.9%
70.4%
71.9%
71.1%
PADD 3
2,156
2,284
2,236
2,187
2,164
65.0%
67.4%
68.6%
67.9%
67.5%
PADD 4
120
111
121
119
120
53.3%
49.7%
49.5%
47.8%
47.9%
PADD 5
323
339
386
428
419
33.7%
36.1%
40.3%
45.2%
45.2%
U.S.
Total
3,528
3,692
3,696
3,693
3,656
63.0%
65.2%
66.3%
66.6%
66.4%
Source: EIA
January 28, 2009
12
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 10: Crude Oil imports by Top 5 Countries of Origin and by PADD
MMBbls
PADD 1
2003
2004
2005
2006
2007
1
Nigeria
127
Nigeria
159
Nigeria
172
Nigeria
162
Nigeria
145
2
Angola
82
Canada
72
Canada
78
Canada
77
Canada
93
3
Saudi Arabia
78
Saudi Arabia
63
Saudi Arabia
68
Saudi Arabia
67
Saudi Arabia
60
4
Canada
77
Angola
58
Venezuela
57
Venezuela
56
Venezuela
54
5
United Kingdom
45
Venezuela
43
Angola
53
Angola
54
Angola
38
PADD 2
2003
2004
2005
2006
2007
1
Canada
331
Canada
369
Canada
358
Canada
411
Canada
409
2
Nigeria
9
Nigeria
14
Angola
3
3
United Kingdom
2
Colombia
3
Colombia
2
4
Saudi Arabia
2
Angola
2
Nigeria
2
5
Norway
2
United Kingdom
1
Norway
1
PADD 3
2003
2004
2005
2006
2007
1
Mexico
538
Mexico
555
Mexico
540
Mexico
553
Mexico
498
2
Saudi Arabia
458
Venezuela
430
Venezuela
392
Venezuela
356
Saudi Arabia
373
3
Venezuela
400
Saudi Arabia
390
Saudi Arabia
341
Saudi Arabia
345
Venezuela
360
4
Nigeria
167
Nigeria
221
Nigeria
217
Nigeria
215
Nigeria
244
5
Iraq
132
Iraq
182
Iraq
152
Iraq
142
Algeria
131
PADD 4
2003
2004
2005
2006
2007
1
Canada
120
Canada
111
Canada
121
Canada
118
Canada
120
PADD 5
2003
2004
2005
2006
2007
1
Saudi Arabia
92
Saudi Arabia
93
Saudi Arabia
115
Saudi Arabia
105
Saudi Arabia
93
2
Ecuador
39
Iraq
57
Ecuador
69
Ecuador
72
Iraq
60
3
Iraq
38
Ecuador
51
Iraq
39
Iraq
59
Ecuador
56
4
Canada
24
Canada
32
Canada
32
Canada
38
Canada
46
5
Argentina
20
Argentina
19
Mexico
20
Angola
24
Angola
33
U.S. Total
2003
2004
2005
2006
2007
1
Saudi Arabia
630
Canada
591
Canada
596
Canada
655
Canada
679
2
Mexico
573
Mexico
585
Mexico
567
Mexico
576
Saudi Arabia
526
3
Canada
566
Saudi Arabia
547
Saudi Arabia
525
Saudi Arabia
517
Mexico
514
4
Venezuela
432
Venezuela
475
Venezuela
451
Venezuela
417
Venezuela
419
5
Nigeria
304
Nigeria
395
Nigeria
393
Nigeria
379
Nigeria
395
Source: EIA
January 28, 2009
13
-------
Petroleum Product Suppliers Technical Support Document
Importers of foreign crude oil and products file a number of different reports with EIA:
• EIA 814 Monthly Imports Report- crude oil and products
• EIA 804 Weekly Imports Report- crude oil and products
• EIA 856 Monthly Foreign Crude Oil Acquisition Report—companies importing
more than 500 MB per month
• EIA 14 - Refiner's Monthly Cost Report- crude oil only.
EIA also puts the raw import data on its website (Company Imports from EIA-814).
Crude oil imports are reported by batch, by volume, by sulphur content and API gravity,
by country of origin, by importing refinery, and by using refinery should that be different.
Using this data one can determine what crude oils are being imported by what refinery.
However, in terms of the quality a certain amount of care must be exercised. Many
countries export what they call an "export blend" which is composed of a combined
stream of crude oils. The component crude oils and their proportions can change over
time, thus changing the quality of the crude imported.
Product imports are reported by country of origin and in a few cases (for motor gasoline
blending components and unfinished oils) the user and the place of use are reported.
However, in most cases all that is known is the port of entry and the port of origin. In
many cases there is no way of further tracing the product. Product may be drawn down
from stocks in Rotterdam and, if the product is fungible, be mixed with similar products
from numerous sources.
Note that refiners that export products are required to file Form 7525-V Shipper's Export
Declaration with the Department of Commerce.
January 28, 2009
14
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 11: Imports of Finished Products by PADD
MMBbls
PADD 1
2003
2004
2005
2006
2007
All gasoline (including blending components)
285.3
306.6
337.6
355.9
354.5
Distillate fuel oil, <= 15 ppm sulfur
0.0
7.9
0.6
30.4
46.9
Distillate fuel oil, > 15 ppm <= 500 ppm sulfur
42.1
33.5
45.4
19.9
2.1
Distillate fuel oil, > 500 ppm sulfur
70.8
61.0
60.2
58.9
35.6
Kerosene and kerosene-type jet fuel
26.2
18.6
39.0
34.8
36.6
Residual fuel oil, < 0.31% sulfur
14.7
24.6
28.4
6.3
12.0
Residual fuel oil, 0.31-1.00% sulfur
30.7
42.9
48.9
21.4
14.6
Residual fuel oil, > 1.00% sulfur
50.0
54.6
69.9
60.5
51.3
Petrochemical feedstocks
3.9
2.7
1.4
1.3
1.6
All other petroleum products
62.7
92.2
99.2
118.6
114.1
PADD 2
2003
2004
2005
2006
2007
All gasoline (including blending components)
0.7
0.7
1.0
0.3
0.8
Distillate fuel oil, <= 15 ppm sulfur
0.0
0.0
0.0
0.2
1.3
Distillate fuel oil, > 15 ppm <= 500 ppm sulfur
2.1
1.8
1.1
1.7
0.6
Distillate fuel oil, > 500 ppm sulfur
0.6
0.7
0.4
0.4
0.3
Kerosene and kerosene-type jet fuel
0.2
0.4
0.1
0.0
0.0
Residual fuel oil, < 0.31% sulfur
0.1
0.0
0.0
0.0
0.0
Residual fuel oil, 0.31-1.00% sulfur
0.6
0.8
1.1
0.8
1.4
Residual fuel oil, > 1.00% sulfur
0.5
0.8
1.0
1.2
1.2
Petrochemical feedstocks
0.4
0.5
1.3
2.6
2.0
All other petroleum products
34.5
40.6
44.0
44.6
38.4
PADD 3
2003
2004
2005
2006
2007
All gasoline (including blending components)
17.4
16.2
46.3
40.7
32.3
Distillate fuel oil, <= 15 ppm sulfur
0.0
1.1
0.0
3.6
2.7
Distillate fuel oil, > 15 ppm <= 500 ppm sulfur
0.3
0.9
3.5
1.0
0.2
Distillate fuel oil, > 500 ppm sulfur
0.6
2.0
0.6
2.0
6.0
Kerosene and kerosene-type jet fuel
0.3
0.2
6.1
2.6
1.4
Residual fuel oil, < 0.31% sulfur
1.8
5.4
2.9
2.2
4.2
Residual fuel oil, 0.31-1.00% sulfur
3.7
6.4
12.6
5.0
15.0
Residual fuel oil, > 1.00% sulfur
4.2
7.8
13.0
13.3
23.2
Petrochemical feedstocks
80.8
103.1
110.4
107.0
84.6
All other petroleum products
136.7
183.6
230.4
251.1
222.8
PADD 4
2003
2004
2005
2006
2007
All gasoline (including blending components)
0.2
0.2
0.1
0.0
0.0
Distillate fuel oil, <= 15 ppm sulfur
0.0
0.0
0.0
0.4
2.0
Distillate fuel oil, > 15 ppm <= 500 ppm sulfur
2.7
3.4
2.1
2.3
0.8
Distillate fuel oil, > 500 ppm sulfur
0.2
0.5
0.2
0.3
0.2
Kerosene and kerosene-type jet fuel
0.1
0.2
0.2
0.2
0.1
Residual fuel oil, < 0.31% sulfur
0.0
0.0
0.0
0.0
0.0
Residual fuel oil, 0.31-1.00% sulfur
0.0
0.0
0.0
0.0
0.0
Residual fuel oil, > 1.00% sulfur
0.0
0.0
0.0
0.0
0.0
Petrochemical feedstocks
0.0
0.3
0.0
0.0
0.0
All other petroleum products
3.3
4.2
3.9
5.4
5.0
PADD 5
2003
2004
2005
2006
2007
All gasoline (including blending components)
19.5
22.9
22.0
21.0
35.0
Distillate fuel oil, <= 15 ppm sulfur
0.0
1.6
0.9
6.2
9.6
Distillate fuel oil, > 15 ppm <= 500 ppm sulfur
2.1
4.0
3.2
3.1
1.3
Distillate fuel oil, > 500 ppm sulfur
0.2
0.6
1.9
2.6
0.5
Kerosene and kerosene-type jet fuel
15.2
27.9
26.6
31.7
42.2
Residual fuel oil, < 0.31% sulfur
1.6
2.5
2.6
3.1
0.5
Residual fuel oil, 0.31-1.00% sulfur
1.4
1.3
1.2
1.6
1.6
Residual fuel oil, > 1.00% sulfur
10.2
9.0
11.7
12.5
10.4
Petrochemical feedstocks
0.2
0.0
0.1
0.8
0.6
All other petroleum products
19.7
22.7
26.7
30.4
31.6
Source: EIA
January 28, 2009
15
-------
Petroleum Product Suppliers Technical Support Document
Marketers. Petroleum marketers purchase products either directly from refiners or
indirectly from terminal operators. There are approximately 8,000 independent
petroleum marketers in the country. Like all other sectors of the industry the last decade
has brought increasing consolidation in this sector as well. The independent marketers
do not submit reports to EIA. They are indirectly tracked through the refinery marketing
reports in which refiners are required to report sales of products directly to end users
and their sales to other marketers.
Non-Energy Use of Petroleum Products. The largest volume of petroleum products
are combusted for energy, either as transportation fuels or as furnace or boiler fuels.
Some products are consumed for non-energy uses. ICF has conducted an intensive
study for non-energy uses for EPA's Inventory of Greenhouse Gases and S/'n/cs.11 The
petroleum products consumed for non-energy use are shown in Exhibit 12.
Exhibit 12: Consumption of Petroleum Products for Non-Energy Uses
TBtu
2003
2004
2005
2006
Asphalt & Road Oil
1,219.5
1,303.8
1,323.2
1,225.6
Distillate Fuel Oil
11.7
11.7
11.7
11.7
LPG
1,437.8
1,436.7
1,442.0
1,491.8
Lubricants
159.0
161.0
160.2
130.6
Pentanes Plus
158.3
156.5
146.0
105.1
Naphtha (<401 F)
573.4
687.9
678.6
592.9
Other Oil (>401 F)
501.0
547.8
518.7
573.4
Still Gas
59.0
63.5
67.7
122.3
Petroleum Coke
76.9
161.3
145.0
178.7
Special Naphtha
75.7
47.2
60.9
68.7
Waxes
31.0
30.8
31.4
25.2
Miscellaneous Products
126.0
113.4
112.8
133.2
C02 emissions occur from non-energy uses via several pathways. When a product is
manufactured emissions may occur when producing plastics or rubber from petroleum
derived feedstocks, for example. Emissions may also arise when a product is used,
such as solvent use. Overall, looking at all non-energy uses of petroleum feedstocks
about 62 percent of the carbon contained in the non-energy petroleum feedstocks is
stored in the products with the remaining 38 percent emitted at various stages. Exhibit
13 shows the estimated carbon stored and C02 emissions for 2006 of non-energy use of
petroleum products in the United States. These emissions constituted less than 2
percent of overall fossil fuel emissions, a percentage that has not appreciably changed
since 1990.
Summary. In every sector of the petroleum industry the flow of crude oil and petroleum
is closely monitored since it is the source of revenue. Some of the data are reported to
federal government and some to state governments. In every case, however, data are
routinely collected, aggregated, and verified as the basis for executing sales and billing
customers.
11 http://www.epa.gov/climatechanae/emissions/usinventorvreport.html
January 28, 2009
16
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 13: 2006 Non-Energy use Petroleum Product Consumption, Storage and
Emissions
Non-
Carbon Stored
Carbon
Carbon
Energy
(Tg C)
Emissions
Emissions
Use
(TBtu)
(Tg C)
(Tg co2)
Asphalt & Road Oil
1,225.6
25.3
0.0
0.0
Distillate Fuel Oil
11.7
0.1
0.1
0.4
LPG
1,491.8
15.4
9.6
35.3
Lubricants
130.6
0.2
2.4
8.8
Pentanes Plus
105.1
1.2
0.7
2.7
Naphtha (<401 F)
592.9
6.6
4.1
15.2
Other Oil (>401 F)
573.4
7.0
4.4
16.1
Still Gas
122.3
1.3
0.8
3.0
Petroleum Coke
178.7
2.5
2.5
9.1
Special Naphtha
68.7
0.8
0.5
1.9
Waxes
25.2
0.3
0.2
0.8
Miscellaneous Products
133.2
0.0
2.7
9.9
3a. 0. Industry Federal Reporting Requirements
This section focuses on sectors identified as points of monitoring of petroleum: refining,
imports, and exports. The following discussion is based on information gathered on
current reporting requirements and presents a discussion of the reporting matrix
spreadsheets compiled as background for the rule and attached at the end of the
document. The discussion is focused on the reporting requirements most relevant to the
determination of an accurate accounting of the flow of commodities through the nation's
petroleum infrastructure.
Each sector is structured in a similar fashion: the key reporting obligations by agency
and reporting form are discussed; the key questions EPA has identified for evaluating
the suitability of the reporting requirement as a basis for the Agency's mandatory
monitoring system are then discussed. These questions include:
• What is reported?
• Is the reporting tied to a facility or entity at a facility?
• What is the threshold for reporting?
• What is the frequency of reporting?
• How is the data developed?
• What are the verification/certification, QA/QC methods?
• How public is the information?
• Where are the gaps in sector coverage that would lead to un-accounted for
volumes?
The summary matrices are included in the Appendix.
January 28, 2009
17
-------
Petroleum Product Suppliers Technical Support Document
3a.1. Refineries
Energy Information Administration
EPA receives reports from refineries related to the specifications of transportation fuels,
but the EIA is the only federal agency that receives extensive physical and financial
information reports from refineries. Monthly and annual reports are required for all
refineries, while weekly reports are required for a subset of refineries selected by the
EIA; sampling procedure assures coverage of 90 percent of the data. The weekly report
(EIA-800) includes only quantities and ending stocks for inputs and products. The
monthly report (EIA-810) includes information on refinery input and capacity, sulfur
content and API gravity of crude oil, and detailed stock information on a comprehensive
list of inputs and products. It should be noted that for the weekly and monthly reports,
stocks in the custody of the refinery are reported regardless of ownership and quantities
must be at least 500 barrels to be reported (rounded to 1 whole-number thousand-barrel
unit).
Report Name: EIA-810 Monthly Refinery Report
What is reported
Input and capacity (thousand barrel), crude quality, production
and stock information (thousand barrel)
Who is reporting
All refinery operators
What is the threshold for reporting
No minimum; quantities at least 500 barrels due to rounding
What is the reporting frequency
Monthly
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Throughout refinery, refinery gate
What are the verification/certification &
QA/QC methods
Some of the data could be reconciled against the weekly report;
sanctions for failure to comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
The annual refinery form (EIA-820) reports on an almost entirely different set of
information. In addition to atmospheric crude oil distillation capacity, which is also
reported on a monthly basis, the annual form requires the quantity of fuel purchased and
consumed at the refinery, receipts of crude oil by method of transportation, downstream
charge capacity, production capacity, and storage capacity.
Report Name: EIA-820 Annual Refinery Report
What is reported
Purchased fuel, crude oil receipts (thousand barrel)
Who is reporting
All refinery operators
What is the threshold for reporting
No minimum
What is the reporting frequency
Annual
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Throughout refinery, refinery gate
What are the verification/certification &
QA/QC methods
Some of the data could be reconciled against the monthly
report; sanctions for failure to comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
January 28, 2009
18
-------
Petroleum Product Suppliers Technical Support Document
Atmospheric crude oil distillation capacity and downstream charge capacities for
individual refineries as well as other information in aggregated form are publicly available
at the Refinery Capacity Report page on the EIA website.
Refineries that produce oxygenates as part of their product mix are required to submit a
monthly oxygenate report (EIA-819), which is mandatory for all facilities that produce
oxygenates and not limited to refineries. The form reports production and stock
information of various oxygenates, including fuel ethanol, ETBE and MTBE, and motor
gasoline blending components, by PADD with a U.S. total. Like the monthly refinery
report, stocks in the custody of the facility are reported regardless of ownership and the
reporting unit is thousand barrels, so quantities below 500 barrels will not be reported
due to rounding to the nearest whole number.
Report Name: EIA-819 Monthly Oxygenate Report
What is reported
Production and stock information of oxygenates
Who is reporting
Operators of all facilities that produce oxygenates
What is the threshold for reporting
No minimum; quantities at least 500 barrels due to rounding
What is the reporting frequency
Monthly
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Throughout facility
What are the verification/certification &
QA/QC methods
Sanctions for failure to comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
Aggregated data from EIA-819 is publicly available at the Monthly Oxygenate Report
page on the EIA website.
Environmental Protection Agency
EPA has several reporting programs that capture the flow of petroleum transportation
products. Three forms of note are part of the Reformulated Gasoline and Anti-Dumping
Reporting Program; one additional form falls under the Diesel Fuel Reporting Program.
A complete list of reporting programs and forms is available at
www.epa.aov/otaq/reas/fuels/forms.htm.
The Anti-Dumping Program Annual Report (EPA Form 3520-20H) is required for
producers and importers of reformulated gasoline (or RBOB), conventional gasoline or
applicable blendstocks. Despite the criteria for reporting, the only volume reported is for
gasoline.
January 28, 2009
19
-------
Petroleum Product Suppliers Technical Support Document
Report Name: EPA Form 3520-20H Anti-Dumping Program Annual Report
What is reported
Total volume of conventional gasoline (gallon)
Who is reporting
Producers and importers of conventional gasoline
What is the threshold for reporting
No minimum
What is the reporting frequency
Annual
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Refinery gate; pipeline imports: border point; marine imports:
offloading
What are the verification/certification &
QA/QC methods
Sanctions for failure to comply; auditing requirements for
completeness and accuracy of submitted data; random in-
person audit by EPA's enforcement office
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
Additional EPA forms of the Reformulated Gasoline Program Emissions Performance
Averaging reporting subgroup are required for producers and importers of reformulated
gasoline or RBOB only.
Report Name: EPA Form 3520-20L RFG Program NOx Emissions Performance Averaging Report
EPA Form 3520-20M RFG Program VOC Emissions Performance Averaging Report
What is reported
Total volume of reformulated gasoline or RBOB (gallon)
Who is reporting
Producers and importers of reformulated gasoline or RBOB
(except CA)
What is the threshold for reporting
No minimum
What is the reporting frequency
Annual
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Refinery gate; pipeline imports: border point; marine imports:
offloading
What are the verification/certification &
QA/QC methods
Sanctions for failure to comply; auditing requirements for
completeness and accuracy of submitted data; random in-
person audit by EPA's enforcement office; independent
laboratory sampling
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
CA data
In addition to Reformulated Gasoline and Anti-Dumping Reporting, the Diesel Fuel
Reporting Program collects volumetric data on the flow of diesel fuel. The Designate &
Track Total Volume Report is required separately for each facility and for each
designation of fuel. Volumes are reported for diesel fuel received, delivered, produced,
and imported. Stock information is reported in the form of beginning and ending
inventory.
January 28, 2009
20
-------
Petroleum Product Suppliers Technical Support Document
Report Name: EPA Form DSF0600 Designate & Track Total Volume Report
What is reported
Volume of diesel fuel received, delivered, produced, imported
(gallon); beginning and ending inventory (gallon)
Who is reporting
Facilities handling diesel fuel including refiners and importers
(except CA)
What is the threshold for reporting
No minimum
What is the reporting frequency
Annual
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Refinery gate; pipeline imports: border point; marine imports:
offloading
What are the verification/certification &
QA/QC methods
Sanctions for failure to comply; random in-person audit by
EPA's enforcement office
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
CA data
Information submitted to EPA is subject to random in-person audits conducted by EPA's
enforcement office. In addition, there are penalties of up to $32,500 per day per
violation for non-compliance with EPA's fuel regulations, including failure to report and
reporting false information.
Summary
Refinery reporting to the EIA appears to capture the flow of petroleum commodities
through the U.S. refinery system with no apparent gaps in reported data due to
mandatory reporting requirement for all refiners. Inputs to the refinery are reported in
great detail as are the outputs. Products are reported in detail; particularly any product
that by law is sulphur constrained (e.g. diesel < 15ppm, < 500 ppm, etc.). Any products
recycled within the refinery are also reported as is the fuel used within the refinery.
Relevant information reported to EPA is confined to gasoline and diesel volumes only,
though there are no apparent gaps in reporting due to mandatory reporting requirements
for all refiners that the produce the specified fuels. It should be noted however that most
reporting requirements for diesel fuel volumes under the Designate and Track program
will sunset in 2014, leaving significant gaps in diesel volume data.
The annual Worldwide Refinery Survey published by the Oil & Gas Journal (OGJ) is a
potentially useful resource. The OGJ also publishes the Nelson Complexity Factor for all
U.S. refineries. This is actually an evaluation of the capital expenditures at the refineries
for processing units, but it is accepted as a surrogate for the complexity of the individual
refineries. There is also the Solomon Benchmarking Surveys which compare refineries
on the basis of best practices in a number of areas. These are proprietary surveys;
however, the OGJ complexity factor surveys can be purchased.
3a.2. Imports
Energy Information Administration
The EIA is the only federal agency that collects reported data on petroleum imports at a
level of detail beyond that of the general customs import document. (Department of
Homeland Security, U.S. Customs and Border Protection, CBP Form 7501).
January 28, 2009
21
-------
Petroleum Product Suppliers Technical Support Document
The Monthly Imports Report (EIA-814) is required for all importers of record who import
crude or petroleum products into the 50 States and the District of Columbia from foreign
countries, Puerto Rico, the Virgin Islands, and other U.S. possessions. The information
reported is shipment-specific; each entry on the form asks for type of commodity, port of
entry, country of origin, quantity in thousand barrels, sulphur content by weight, API
gravity (crude oil only), and the name and location of the processing company (crude
and unfinished products). Transactions with identical details except quantity may be
combined and reported on one line. All transactions of at least 500 barrels are reported
(as with the refinery forms, due to rounding to the nearest whole-number thousand-
barrel unit). Volumetric data is metered at import points: at the border for imports via
pipeline and at offloading for marine imports.
Report Name: EIA-814 Monthly Imports Report
What is reported
Quantity of imported commodity (thousand barrel), sulphur
content, API gravity (crude only)
Who is reporting
Importers of record
What is the threshold for reporting
Transactions of fewer than 500 barrels not reported due to
rounding; virtually all
What is the reporting frequency
Monthly
How are the reported data developed
Metering and from foreign supplier
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Pipeline, at border; marine, at offloading
What are the verification/certification &
QA/QC methods
Check against CBP Form 7501 for consistency; sanctions for
failure to comply
Is the data public or restricted
Unrestricted
Where are the gaps in the data reported
Transactions of fewer than 500 barrels
"Importers of Record" are defined by Customs as the owner or purchaser of the goods
being imported, or a licensed customs broker designated by the owner or purchaser.
The EIA follows the same rules as the Customs which are defined in the various laws
governing imports in general.
The form captures nearly all volumes imported into the U.S., as transactions of major
products rarely have volumes below the reporting threshold. Data collected on EIA-814
is publicly available at the Company Level Imports page on the EIA website.
Since all importers of crude oil and petroleum products are required to file EIA-814,
which reports shipment-specific information, it would be redundant to review import
records from the U.S. Customs and Border Protection (CBP), which contain the same
set of data points with regards to crude and petroleum products, except in more general
(as opposed to petroleum-specific) terms and at a lower level of detail. Indeed, the EIA
checks its data against that from CBP Form 7501 ("Entry Summary") for consistency and
uses the CBP data to identify companies that are not in the EIA data for reasons
including having imported volumes below the reporting threshold.
The Weekly Imports Report (EIA-804) tracks imports activity by PADD for a list of items
that includes crude oil, various formulations of finished motor gasoline, distillates of
various sulphur content, and blendstocks, as well as crude imports by country of origin.
The EIA-804 is required for selected importers of record who import crude or petroleum
products into the 50 States and the District of Columbia from foreign countries, Puerto
Rico, the Virgin Islands, and other U.S. possessions. As done with the weekly refinery
report, companies are selected into the EIA weekly sample according to a procedure
January 28, 2009
22
-------
Petroleum Product Suppliers Technical Support Document
that assures 90 percent coverage. There is no threshold for reporting for this weekly
form; importers selected into the sample must report regardless of quantity imported.
The information reported on EIA-804 is not publicly available in its reported form, but
essentially all of that data is reported on the monthly EIA-814, which is more
comprehensive and whose data is publicly available as Company Level Imports.
The Monthly Foreign Crude Oil Acquisition Report (EIA-856) is required for all firms
reporting data as of June 1982 and all firms that "acquired more than 500,000 barrels of
foreign crude oil in the report month for importation into the United States." The report
includes summary information (total acquisition and offshore inventories) and
transaction-specific information (country of origin, crude type, gravity, date and port of
loading and landing, vessel or pipeline name, volume, acquisition price, landed cost,
etc.).
Report Name: EIA-856 Monthly Foreign Crude Oil Acquisition Report
What is reported
Crude type, API gravity, volume (bbl)
Who is reporting
Importers of record
What is the threshold for reporting
500,000 barrels of foreign crude acquired for the report month
What is the reporting frequency
Monthly
How are the reported data developed
Metering and from foreign supplier
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Pipeline, at border; marine, at offloading
What are the verification/certification &
QA/QC methods
Check against CBP Form 7501 for consistency; sanctions for
failure to comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
Firms that acquired fewer than 500,000 barrels for importation
for the report month are not required to file
The EIA estimates that 90% of crude imports is accounted for, while the remaining 10%
is not covered by the reporting requirement. The information reported is publicly
available only in aggregated form.
The volume reported on EIA-856 is the volume acquired for importation (and not the
volume imported). The EIA included this clarifying note in the instructions for the form:
Since the EIA-856 is filled on a cargo-specific basis, it is implicit that the reported
acquisitions will have been loaded by the time the report was filed. In cases
where foreign crude oil was acquired but not loaded by the time the report was
filed, those parcels should be reported as soon as cargo-specific data are
available (i.e., presumably when the volumes are loaded).
The Refiners' Monthly Cost Report (EIA-14) collects volumetric data on crude going into
refineries. Mandatory for all refiners, the EIA-14 reports, separately for domestic and
imported crude, total cost and total volume of crude oil acquired by PADD. This
information is available on the EIA website in the form of Refiner Acquisition Cost of
Crude Oil (RAC), which is aggregated from data reported on EIA-14.
Report Name: EIA-14 Refiners' Monthly Cost Report
What is reported
Volume of imported crude oil acquired (thousand barrel)
Who is reporting
Firms that refine crude oil
What is the threshold for reporting
500,000 barrels of foreign crude acquired for the report month
January 28, 2009
23
-------
Petroleum Product Suppliers Technical Support Document
What is the reporting frequency
Monthly
How are the reported data developed
Metering
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Refinery gate
What are the verification/certification &
QA/QC methods
Check against CBP Form 7501 for consistency; sanctions for
failure to comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
Imported volumes reported on EIA-804, EIA-856 and EIA-14 are checked against EIA-
814 for consistency.
Environmental Protection Agency
EPA has several reporting programs that capture the flow of petroleum fuels handled by
refiners and importers. The EPA forms documented in the preceding section
("Refineries") are applicable to both refiners and importers. Please refer to the
preceding section for information on some of those forms.
An additional form in the Reformulated Gasoline and Anti-Dumping Reporting Program
that applies to registered foreign refiners only is the Load Port/Port of Entry Independent
Sampling, Testing and Refinery/Importer Identification Form (EPA Form 3520-27). Data
submitted on this form includes foreign refinery registration information, importer
registration information, vessel information and gasoline volume. The form is required
for each occasion certified foreign refinery gas (FRGAS) is loaded onto a vessel for
transport into the U.S.
report Name: EPA Form 3520-27 Load Port/Port of Entry Independent Sampling, Testing and
Refinery/Importer Identification Form
What is reported
Foreign refinery registration number, importer registration
number and information, vessel information, gasoline volume
(gallon)
Who is reporting
Registered foreign refiners who opt in
What is the threshold for reporting
No minimum
What is the reporting frequency
Per shipment
How are the reported data developed
Metering and operating data
Are reports mandatory or voluntary
Submissions are mandatory for foreign refiners who opt in
What is the facility level of the reporting
At offloading
What are the verification/certification &
QA/QC methods
Sanctions for failure to comply; random in-person audit by
EPA's enforcement office; independent laboratory sampling at
port of entry
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
Information submitted to the EPA is subject to random in-person audits conducted by
EPA's enforcement office. In addition, there are penalties of up to $32,500 per day per
violation for non-compliance with the EPA's fuel regulations, including failure to report
and reporting false information.
Summary
The mandatory reporting of information on imports in the form of EIA-814 appears to
capture the flow of petroleum commodities into the U.S. with gaps only due to rounding.
January 28, 2009
24
-------
Petroleum Product Suppliers Technical Support Document
EIA-856 and EIA-14 are dedicated to capturing the flow and usage of crude oil. These
are potentially good resources in addition to EIA-814 should the focus for monitoring fall
on crude oil.
EPA's information collection mechanisms on imports of gasoline and diesel are largely
shared with those for refiners, and the information collected is generally confined to
volumes only. There are no apparent gaps in reporting due to mandatory reporting
requirements for all refiners. Including foreign refiners who choose to opt in, that produce
the specified fuels.
3a.3. Exports
Federal Energy Regulatory Commission
The EIA does not have reporting forms for petroleum exports and obtains the data that it
publishes from the Census Bureau. The Shipper's Export Declaration (Commerce Form
7525-V) is a general-purpose export form that is required for petroleum exports to most
destinations. Aggregated statistics can be obtained from the Census Bureau's monthly
reports (EM-522 and EM-594), which are not publicly available.
Report Name: Commerce Form 7525-V Shipper's Export Declaration
What is reported
Commodity type (Schedule B number), quantity (bbl)
Who is reporting
Exporters
What is the threshold for reporting
No minimum
What is the reporting frequency
Per shipment
How are the reported data developed
Metering
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Pipeline, at border; marine, at loading
What are the verification/certification &
QA/QC methods
Unknown
Is the data public or restricted
Aggregated data available but not public
Where are the gaps in the data reported
SEDs are not required for exports from the U.S. to U.S.
possessions other than Puerto Rico and the Virgin Islands
3a.4. Others
In this section a variety of federal reporting requirements that shed light on throughputs
in other sectors along the petroleum supply chain are discussed.
Minerals Management Service
MMS-4054A "Oil and Gas Operations Report, Part A - Well Production (OGOR-A)"
reports production volumes by well. The report is filed monthly by all MMS lessees, i.e.,
Federal offshore and Federal/Indian onshore; a separate report must be filed for each
lease. Historical data through January 2008 is available at the MMS website.
MMS-2058 "Production Allocation Schedule Report (PASR)" is required for operators of
facility or measurement point handling production from Federal offshore.
January 28, 2009
25
-------
Petroleum Product Suppliers Technical Support Document
Report Name: MMS-4054A (OGOR-A), MMS-4058 (PASR)
What is reported
Volumes (bbl)
Who is reporting
All MMS lessees (OGOR);
All facilities handling Federal offshore production (PASR)
What is the threshold for reporting
No minimum
What is the reporting frequency
Monthly
How are the reported data developed
Metering
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Lease meters
What are the verification/certification &
QA/QC methods
Compliance Asset Management, a division of MMS, verifies the
volumetric data against those reported for royalty purpose on
MMS-2014.
Is the data public or restricted
Historical OGOR data publicly available; Offshore Minerals
Management (OMM) has complete access to PASR data
Where are the gaps in the data reported
None apparent
Army Corps of Engineers
The Army Corps of Engineers collects data on domestic marine movements. There are
two forms concerning freight carried: Form 3925 is the general form and Form 3925B
may be substituted for shallow draft inland traffic. Neither form is petroleum-specific.
Report Name: ENG Forms 3925 and 3925B Vessel Operation Report
What is reported
Commodity type, quantity (ton)
Who is reporting
All domestic operators engaged in commercial activity on
navigable waters
What is the threshold for reporting
Trips of fewer than one mile are not required to be reported;
virtually all
What is the reporting frequency
Monthly
How are the reported data developed
Metering
Are reports mandatory or voluntary
Submissions are mandatory
What is the facility level of the reporting
Ports
What are the verification/certification &
QA/QC methods
Some reconciliation of dock receipts; sanctions for failure to
comply
Is the data public or restricted
Aggregated data public
Where are the gaps in the data reported
None apparent
Federal Highway Administration
The Federal Highway Administration collects consumption data from state agencies that
collect the motor-fuel tax for their respective states. States are required to submit Form
FHWA-551M on a monthly basis. The volumetric data, which is based on tax record and
submitted in aggregated form, is publicly available.
3b. 0. Data Gaps and Quality
In this section the observed gaps in the reporting requirements are discussed and
suggestions for alternatives for acquiring missing data are presented. Similarly, quality
control of the accuracy of the data that are reported is also discussed.
January 28, 2009
26
-------
Petroleum Product Suppliers Technical Support Document
Based on the review of reporting requirements, the Agency is confident reporting
coverage of petroleum refineries and imports captures these sources of petroleum. That
is, the volumes reported appear to reflect the totals moving though these sectors and the
reporting is at the facility/owner level and is traceable to the facility and owner.
3b.1.Reporting Gaps in Industry Coverage
Refineries and importers report an extensive amount of information on the flows and
volumes of their products. They do not, however, report the actual carbon content of
their products. They also report volumes of products in fairly aggregated categories,
which, in some cases, include fuels with highly variable carbon content. The use of
default carbon content factors for these aggregate categories may result in emissions
estimates that are not sufficiently precise.
In terms of crude oil it might be possible for each refinery to report the carbon content of
the crude oil it uses by separate batch. The EIA forms on crude oil imports contain data
on the origin of the crude oil and its API gravity and sulphur content. There are assays
available on all major crude oils and part of a full assay is the carbon content of the
crude oil. The same is true of domestic crude oil. Some states, particularly California
and Texas, have data on the quality of crude oils on a well by well basis. And refineries
certainly test each batch they receive since refineries are configured to optimally run
within a certain range of quality. However, most refineries use more than one type of
crude oil and mingle their crude oil streams presenting an additional problem.
For the past 70 years the National Institute for Petroleum and Energy Research (NIPER)
at Bartlesville Research Centre in Oklahoma has conducted sampling surveys of
gasoline (winter and summer), aviation fuels, and distillates (on-road diesel, diesel for
farm vehicles, railroads and marine engines and heating oil) known as the Petroleum
Product Surveys (PPS). These surveys are conducted on a nation wide basis and the
results based on laboratory tests conducted at Bartlesville. Gasoline samples are taken
at the gas stations in order to catch the additives and biofuels. Carbon is not reported.
Distillate samples are taken at refineries and only the carbon residue is reported. The
Ramsbottom Carbon Residue Test, ASTM12 Designation D524, is used.
A petroleum product carbon measurement and monitoring system would require
laboratory tests or robust default factors. This is discussed further in Section 4.
3b.2. Data Sensitivity
Much of the data reported to EIA, particularly that reported by refiners, is classified by
law as being proprietary. EIA publications report data in the aggregate in a manner that
precludes the identification of individual facilities, with the exception of details on the
nameplate capacity of the process units and types of process units at each individual
refinery. Import data are also reported by importing facility or by corporate entity. In
some cases it is possible to arrive at information on individual refiners by examining their
web sites and their filings with the SEC. However, this is very variable as some
companies reveal a great deal of information, but others do not. Most refiners are very
careful to not reveal proprietary secrets that bear on economic performance.
12 American Society for Testing and Materials
January 28, 2009
27
-------
Petroleum Product Suppliers Technical Support Document
For refiners the core of their business sensitive data consists of data on "runs and yields"
and economics. "Runs and yields" refer to individual intermediate stream rates from and
between processing units, and through those, the yields of products that they are able to
obtain from the crude oils processed. Data on the physical structure of refineries, and
often on the specific type of processing technologies, is publicly available as is the type
of imported crude oil that each refinery uses. Domestic crude oil use is also often
known. However, utilization, which is measured on the first crude oil processing step,
the atmospheric distillation tower (ADT), and the yields of the individual products are
never available on an individual refinery basis.
Take a case in point: refinery A and refinery B may be using relatively similar crude oils
and have similar downstream processing units. The technology used in the ADT and
secondary units will likely be different resulting in different production results.
Downstream processing units may be the same basic type of technology but the yields
may be different depending on the intensity of the processing, the types of catalysts
used, the maintenance condition of the equipment and a host of other physical and
operating variables, some decided on a day to day basis depending on market and
economic factors. In other words refinery A's more efficient equipment, better technical
knowledge, and quicker business decision-making may result in substantially higher
yields of higher value products, and hence, higher profits than refinery B.
One of the reasons that many refiners subscribe to the Solomon Benchmarking Surveys
is that it allows each refinery to rate itself against the best industry practices of its peers
in a number of areas ranging from energy efficiency to management practices.
3b.3. Quality Assurance and Control
There is very little information on the quality of data reported on the various forms.
There is the presumption that mandatory reports with sanctions for not reporting will be
accurate as far as the reporting requirements go. Some of the ambiguities in reporting
requirements probably have been worked out between the agencies and the reporting
community in the years since these reports have been required.
4.0. Analysis Supporting the Rule
This section discusses default values for the carbon content of refined and semi refined
petroleum products, natural gas liquids, and biomass as well as potential methods for
direct measurement of carbon content. This is followed by a discussion of the threshold
calculations and the cost of the rule.
4.1. Default Carbon Content Factors
4.1.1 Default Petroleum Product Carbon Content Factor Uncertainties
In 1994 the EIA developed new emissions coefficients to replace the coefficients from
the IPCC, which were based on samples from Britain. The EIA 1994 published report,
Emissions of Greenhouse Gases in the United States 1987-1992, cited previous
empirical research from 1929 and 1979 that established a set of derived formulas
between density, energy content per unit weight and volume, and carbon and hydrogen
content. The report compared the emission coefficients calculated on the basis of the
January 28, 2009
28
-------
Petroleum Product Suppliers Technical Support Document
derived formulas with actual emissions coefficients of samples from diverse sources of
crude oils, fuel oils, petroleum products, and pure hydrocarbons. The actual fuel
samples were of a limited number and taken up to 81 years ago. In the absence of more
exact information, this empirical relationship has been used by EIA. In addition, the EIA
adopted the Bureau of Mines thermal conversion factors published up to 58 years ago.
Below is a review of data sources used in the existing carbon emission coefficients
developed by the EIA and used in EPA's annual U.S. GHG Inventory.
Motor Gasoline and Motor Gasoline Blending Components
a) The density of motor gasoline is drawn from NIPER's, Motor Gasolines, Summer
(various years) and NIPER's, Motor Gasolines, Winter (various years).
b) The characteristics of reformulated gasoline additives are taken from the American
Petroleum Institute, Alcohols and Ethers: A Technical Assessment of Their
Applications as Fuels and Fuel Components, API 4261.
c) The carbon content of motor gasoline is found in Mark DeLuchi, Emissions of
Greenhouse Gases from the Use of Transportation Fuels and Electricity, Volume 2,
ANL/ESD/TM-22, Vol. 2 (Chicago, IL: Argonne National Laboratory, November
1993), Appendix C, pp. C-1 to C-8 and ultimate analyses of one sample of shale-oil
derived gasoline from Applied Systems Corp., Compilation of Oil Shale Test Results
(Submitted to the Office of Naval Research, April 1976), p. 3-2, three varieties of
gasoline from C.C. Ward, "Petroleum and Other liquid Fuels," in Marks' Standard
Handbook for Mechanical Engineers (New York, NY: McGraw-Hill, 1978), pp. 7-14,
and one sample of gasoline from J.W. Rose and J.R. Cooper, Technical Data on
Fuel, The British National Committee, World Energy Conference, London, England
(1977).
d) EIA adopted the Bureau of Mines thermal conversion factor of 5.253 million Btu per
barrel for conventional gasoline as published by the Texas Eastern Transmission
Corporation in Appendix V of Competition and Growth in American Energy Markets
1947-1985, a 1968 release of historical and projected statistics.
e) The factors for reformulated and oxygenated gasolines, both currently 5.150 million
Btu per barrel, are based on data published in EPA's, Office of Mobile Sources,
National Vehicle and Fuel Emissions Laboratory report EPA 420-F-95-003, Fuel
Economy Impact Analysis of Reformulated Gasoline.
Jet Fuel
The carbon content of naphtha-based jet fuel is from C.R. Martel and L.C. Angello,
"Hydrogen Content as a Measure of the Combustion Performance of Hydrocarbon
Fuels," in Current Research in Petroleum Fuels, Volume I (New York, NY: MSS
Information Company, 1977), p. 116.
The density of naphtha-based jet fuel is from the American Society for Testing and
Materials, ASTM and Other Specifications for Petroleum Products and Lubricants
(Philadelphia, PA, 1985), p. 60
Jet Fuel, Naphtha-Type. EIA adopted the Bureau of Mines thermal conversion factor of
5.355 million Btu per barrel for "Jet Fuel, Military" as published by the Texas Eastern
January 28, 2009
29
-------
Petroleum Product Suppliers Technical Support Document
Transmission Corporation in the report Competition and Growth in American Energy
Markets 1947-1985, a 1968 release of historical and projected statistics.
Carbon content and density for kerosene-based jet fuels is drawn from O.J. Hadaller and
A.M. Momenthy, The Characteristics of Future Fuels, Part 1, "Conventional Heat Fuels"
(Seattle, WA: Boeing Corp., September 1990), pp. 46-50
Jet Fuel, Kerosene-Type. EIA adopted the Bureau of Mines thermal conversion factor of
5.670 million Btu per barrel for "Jet Fuel, Commercial" as published by the Texas
Eastern Transmission Corporation in the report Competition and Growth in American
Energy Markets 1947-1985, a 1968 release of historical and projected statistics.
Distillate Fuel
Carbon content and density were derived from the following:
a) Four samples of distillate from C. T. Hare and R.L. Bradow, "Characterization of
Heavy-Duty Diesel Gaseous and Particulate Emissions, and the Effects of Fuel
Composition," in Society of Automotive Engineers, The Measurement and Control of
Diesel Particulate Emissions (1979), p. 128;
b) Three samples from E.F. Funkenbush, D.G. Leddy, and J.H. Johnson, "The
Organization of the Soluble Organic Fraction of Diesel Particulate Matter," in Society
of Automotive Engineers, The Measurement and Control of Diesel Particulate
Emissions (1979) p. 128;
c) One sample from R.L. Mason, "Developing Prediction Equations for Fuels and
Lubricants," SAE Paper 811218, p.34;
d) One sample from C.T. Hare, K.J. Springer, and R.L. Bradow, "Fuel and Additive
Effects on Diesel Particulate- Development and Demonstration of Methodology," in
Society of Automotive Engineers, The Measurement and Control of Diesel
Particulate Emissions (1979), p. 179; and
e) One Sample from F. Black and L. High, "Methodology for Determining Particulate
and Gaseous Diesel Emissions," in Society of Automotive Engineers, The
Measurement and Control of Diesel Particulate Emissions (1979), p. 128.
EIA adopted the Bureau of Mines thermal conversion factor of 5.825 million Btu per
barrel as reported in a Bureau of Mines internal memorandum, "Bureau of Mines
Standard Average Heating Values of Various Fuels, Adopted January 3, 1950." A
standard heat content was adopted from EIA, Annual Energy Review 2000, Appendix A
(Washington, D.C., July 2001).
Residual Fuel
The carbon content of residual fuel oil is based on the following:
a) Three samples of residual fuel from the Middle East and one sample from Texas in
F. Mosby, G.B. Hoekstra, T.A. Kleinhenz, and J.M. Sokra, "Pilot Plant Proves Resid
Process," in Chemistry of Petroleum Processing and Extraction (MSS Information
Corporation, 1976), p.227;
January 28, 2009
30
-------
Petroleum Product Suppliers Technical Support Document
b) Three samples of heavy fuel oils from J.P. Longwell, "Interface Between Fuels and
Combustion," in Fossil Fuel Combustion: A Sourcebook (New York, NY: John Wiley
& Sons, 1991);
c) Three samples of heavy fuel oils from C.C. Ward, "Petroleum and Other Liquid
Fuels," in Marks Standard Handbook for Mechanical Engineers (New York, NY:
McGraw-Hill, 1978), pp. 7-14;
d) Two samples of heavy fuel oils from, D.A. Vorum, "Fuel and Synthesis Gases from
Gaseous and Liquid Hydrocarbons," in American Gas Association, Gas Engineer's
Handbook (New York, NY: Industrial Press, 1974), p. 3/71; and
e) One sample of heavy fuel oil from W. Rose and J.R. Cooper, Technical Data on
Fuel, The British National Committee, World Energy Conference, London, England
(1977).
The density of residual fuel consumed for electric power generation was from EIA, Cost
and Quality of Fuels (Washington, D.C.).
The density of residual fuel consumed in marine vessels was from EIA, Petroleum
Supply Division, Btu Tax on Finished Petroleum Products, (unpublished manuscript,
April 1993) and the National Institute for Petroleum and Energy Research, Fuel Oil
Surveys (Bartlesville, OK, 1992).
EIA adopted the thermal conversion factor of 6.287 million Btu per barrel as reported in
the Bureau of Mines internal memorandum, "Bureau of Mines Standard Average Heating
Values of Various Fuels, Adopted January 3, 1950."
Liquefied Petroleum Gases (LPG: ethane, propane, isobutane, and n-butane.)
Carbon share, density and heat content of liquefied petroleum gases were adopted from
V.B. Guthrie (ed.), "Characteristics of Compounds", Petroleum Products Handbook,
(New York, NY: Mcgraw-Hill, 1960), p.3-3.
Aviation Gasoline
Fuel characteristics were taken from the American Society for Testing and Materials,
ASTM and Other Specifications for Petroleum Products and Lubricants (Philadelphia,
PA, 1985).
EIA adopted the thermal conversion factor of 5.048 million Btu per barrel as adopted by
the Bureau of Mines from the Texas Eastern Transmission Corporation publication
Competition and Growth in American Energy Markets 1947-1985, a 1968 release of
historical and projected statistics.
Asphalt
Ultimate analyses of twelve samples of asphalts showed an average carbon content of
83.5 percent.
EIA adopted the thermal conversion factor of 6.636 million British thermal units (Btu) per
barrel as estimated by the Bureau of Mines and first published in the Petroleum
Statement, Annual, 1956.
The density of asphalt is from American Society for Testing and Materials, ASTM and
Other Specifications for Petroleum Products and Lubricants (Philadelphia, PA, 1985).
January 28, 2009
31
-------
Petroleum Product Suppliers Technical Support Document
Lubricants
Ultimate analysis of a single sample of motor oil yielded a carbon content of 85.8
percent.
EIA adopted the thermal conversion factor of 6.065 million Btu per barrel as estimated
by the Bureau of Mines and first published in the Petroleum Statement, Annual, 1956.
The density of lubricants was adopted from American Society for Testing and Materials,
ASTM and Other Specifications for Petroleum Products and Lubricants (Philadelphia,
PA, 1985).
Petrochemical Feedstocks
The carbon content and density of naphthas is estimated based on G.H. Unzelman, "A
Sticky Point for Refiners: FCC Gasoline and the Complex Model," Fuel Reformulation
(July/August 1992), p. 29.
EIA adopted the thermal conversion factor of 5.248 million Btu per barrel, equal to the
thermal conversion factor for special naphthas.
Kerosene
The average density of 41.4 degrees API and average carbon share of 86.01 percent
was found in five ultimate analyses of No. 1 fuel oil samples
EIA adopted the Bureau of Mines thermal conversion factor of 5.670 million Btu per
barrel as reported in a Bureau of Mines internal memorandum, "Bureau of Mines
Standard Average Heating Values of Various Fuels, Adopted January 3, 1950."
Petroleum Coke
Carbon content for petroleum coke was estimated from two samples from S. W. Martin,
"Petroleum Coke," in Virgil Guthrie (ed.), Petroleum Processing Handbook (New York,
NY: McGraw-Hill, 1960), pp. 14-15.
Density of petroleum coke adopted from American Society for Testing and Materials,
ASTM and Other Specifications for Petroleum Products and Lubricants (Philadelphia,
PA, 1985).
EIA adopted the thermal conversion factor of 6.024 million Btu per barrel as reported in
Btu per short ton in the Bureau of Mines internal memorandum, "Bureau of Mines
Standard Average Heating Values of Various Fuels, Adopted January 3, 1950." The
Bureau of Mines calculated this factor by dividing 30.120 million Btu per short ton, as
given in the referenced Bureau of Mines internal memorandum, by 5.0 barrels per short
ton, as given in the Bureau of Mines Form 6-1300-M and successor EIA forms.
Special Naphtha
EIA adopted the Bureau of Mines thermal conversion factor of 5.248 million Btu per
barrel, which was assumed to be equal to that of the total gasoline (aviation and motor)
factor and was first published in the Petroleum Statement, Annual, 1970.
January 28, 2009
32
-------
Petroleum Product Suppliers Technical Support Document
Density and aromatic contents for special naphthas are from K. Boldt and B.R. Hall,
Significance of Tests for Petroleum Products (Philadelphia, PA: American Society for
Testing and Materials), p. 30.
Petroleum Waxes
The density of paraffin wax is from American Society for Testing and Materials, ASTM
and Other Specifications for Petroleum Products and Lubricants (Philadelphia, PA,
1985). The density of microcrystalline waxes is based on 10 samples found in V. Guthrie
(ed.), Petroleum Products Handbook (New York, NY: McGraw-Hill, 1960).
EIA adopted the thermal conversion factor of 5.537 million Btu per barrel as estimated
by the Bureau of Mines and first published in the Petroleum Statement, Annual, 1956.
Miscellaneous Products
EIA adopted the thermal conversion factor of 5.796 million Btu per barrel as estimated
by the Bureau of Mines and first published in the Petroleum Statement, Annual, 1956.
The carbon content for crude oil was developed from an equation based on 182 crude oil
samples, including 150 samples from U.S. National Research Council, International
Critical Tables of Numerical Data, Physics, Chemistry, and Technology (New York, NY:
McGraw-Hill, 1927).
4.1.2. Petroleum Products
Exhibit 14 shows the full default table provided to reporters in this rule along with
footnotes and sources and a brief description of how certain factors were calculated.
While many of the emission factors are drawn from EIA data sources described in
Section 4.1 of this document, some of them are based on more recent data, and some of
them have been calculated specifically for this table.
In the case of transportation fuels containing some portion of biofuels the carbon share
in the following table relates only to the fossil fuel components.
January 28, 2009
33
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 14: Calculation of Default Values for all Refined and Semi Refined Petroleum
Products.
Refined and
Semi-refined
Petroleum Products
Column A:
Density (API
Gravity)
Column B:
Specific
Gravity
Column C:
Density
(tonnes/bbl)
Column D:
Carbon Share
(% of mass)
Column E:
Computed Emission
Factor (Column C*
Column D/100*
44/12 tonnes
C02/bbl)
Motor Gasoline1
Conventional -
Summer23,4
57.49
0.75
0.12
86.96
0.38
Conventional -
Winter23,4
61.13
0.73
0.12
86.96
0.37
Reformulated -
Summer2,3,5
58.66
0.74
0.12
86.60
0.37
Reformulated -
Winter2,3,5
61.49
0.73
0.12
86.60
0.37
Finished Aviation
Gasoline1
69.00
0.71
0.11
85.00
0.35
Blendstocks
RBOB6,1
0.12
86.60
0.38
CBOB1
59.10
0.74
0.12
85.60
0.37
Others8,9,10
72.98
0.69
0.11
84.00
0.34
Oxygenates
Methanol11,12
47.39
0.79
0.13
37.50
0.17
GTBA13,14
49.91
0.78
0.12
64.90
0.29
t-butanol15,16,14
49.91
0.78
0.12
64.90
0.29
MTBE17
59.10
0.74
0.12
68.20
0.29
ETBE17
59.10
0.74
0.12
70.50
0.30
TAME17
52.80
0.77
0.12
70.50
0.31
DIPE18,19
63.67
0.73
0.12
70.60
0.30
Kerosene-Type Jet
Fuel1
42.00
0.82
0.13
86.30
0.41
Naphtha-Type Jet
Fuel1
49.00
0.78
0.12
85.80
0.39
Kerosene1
41.40
0.82
0.13
86.01
0.41
Distillate Fuel Oil
Diesel No. 120,21
35.50
0.85
0.13
86.40
0.43
Diesel No. 222,21
35.50
0.85
0.13
86.34
0.43
Diesel No. 420,21
23.20
0.91
0.15
86.47
0.46
January 28, 2009
34
-------
Petroleum Product Suppliers Technical Support Document
Fuel Oil No. 124
35.50
0.85
0.13
86.40
0.43
Fuel Oil No. 224
35.50
0.85
0.13
86.34
0.43
Fuel Oil No. 424
23.20
0.91
0.15
86.47
0.46
No. 5 (Navy
Special)25,21
32.65
0.86
0.14
85.81
0.43
No. 6 (a.k.a. Bunker
C)24
11.00
0.99
0.16
85.68
0.40
Petrochemical Feedstocks
Naphthas
(< 401 °F)26,1
61.10
0.73
0.12
84.11
0.36
Other Oils
(> 401 °F)27,1
35.50
0.85
0.13
86.34
0.43
Special Naphthas1
51.20
0.77
0.12
84.76
0.38
Lubricants1
25.60
0.90
0.14
85.80
0.45
Waxes1
43.30
0.81
0.13
85.29
0.40
Petroleum Coke201
0.44
0.07
92.28
0.23
Asphalt and Road
Oil1
5.60
1.03
0.16
83.47
0.50
Still Gas28'29
0.41
0.07
24.40
0.06
Ethane30'31
246.84
0.37
0.06
80.00
0.17
Ethylene32 33
117.62
0.568
0.09
85.71
0.28
Propane31
0.08
81.80
0.24
Propylene3435
0.52
0.08
85.71
0.26
Butane31
0.09
82.80
0.28
Butylene3637
71.51
0.70
0.11
85.71
0.35
Isobutane31
0.09
82.80
0.27
Isobutylene3839
109.19
0.5879
0.09
85.71
0.29
Pentanes Plus1
81.70
0.66
0.11
83.70
0.32
Miscellaneous
Products *1
30.50
0.87
0.14
85.49
0.43
Unfinished Oils1
30.50
0.87
0.14
85.49
0.43
Naphthas40'21
56.80
0.75
0.12
85.70
0.37
Kerosenes40
41.10
0.82
0.13
85.80
0.41
Heavy Gas Oils40
20.90
0.93
0.15
85.80
0.46
Residuum40,21
6.90
1.02
0.16
85.70
0.51
Waste Feedstocks**1
25.60
0.90
0.14
85.71
0.45
January 28, 2009
35
-------
Petroleum Product Suppliers Technical Support Document
Conversion Factors
SG to lb/gal, multiply by
8.32830
g/cm3 to lb/gal, multiply by
8.34568
lb/ft.3 to lb/gal, multiply by
7.480522589
* Includes petrolatum, lube refining byproducts (aromatic extracts and tars), absorption oils, ram-jet fuel, petroleum
rocket fuel, synthetic natural gas feedstocks, specialty oils, and any other product not listed above that leaves the
refinery.
Used plastic, used motor oils, used dry cleaning solvents, etc.
From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007. Table 6-5. Data for
kero- and naphtha-based jet fuel received by personal communication from EIA on 21 August 2008
^ Given the sample data (from the Northrop Grumman Petroleum Product Surveys) of summer and winter API Gravities
for both reformulated and conventional gasoline, a 2 sample t-test was performed to test the null hypothesis that the
winter and summer samples came from the same population. The results showed that there is a statistically significant
difference between the means of the summer and winter API Gravities, thus, a separate emission factor is calculated
for each category.
Dickson, Cheryl. Petroleum Product Study, Northrup Grumman, Gasoline, 2007
Calculated based on the following assumptions:
Conventional gasoline consists Of the following components (from sample regular unleaded gasoline ¦
http://www.marathonpetroleum.com/content/documents/mpc/msds/0127MAR019.pdn:
Weight Percent
Ethanol
Aromatics (assumed
toluene)
Olefins (CnH2n)
Saturated
Hydrocarbons (CnH2n+2)
Benzene
Weight Percent Sum,
Excluding Ethanol
0.1
0.29
0.17
0.43
0.01
0.9000
Carbon
share
(weight %),
based on
molecular
formula
0.52
0.91
0.86
0.845
0.92
A weighted average of the carbon share of these compounds (excluding ethanol) was calculated to get the
weight percent carbon for conventional gasoline.
Calculation of Carbon Share: Column E = ((0.29/0.9)*0.91 + (0.17/0.9)*0.86 + (0.43/0.9)*0.845 + (0.01/0.9)*0.92
Column E = 0.8696*100
Column E = 86.96
'Calculated based on the following assumptions:
January 28, 2009
36
-------
Petroleum Product Suppliers Technical Support Document
Reformulated gasoline consists Of the following components (from sample regular unleaded gasoline with EtOH -
Carbon
share
(weight %),
based on
molecular
Weight Percent formula
Ethanol 0.0575 0.52
Aromatics (assumed
toluene) 0.175 0.91
Olefins (CnH2n) 0.15 0.86
Saturated
Hydrocarbons (CnH2n+2) 0.5425 0.845
Benzene 0.075 0.92
Weight Percent Sum,
Excluding Ethanol 0.9425
A weighted average of the carbon share of these compounds, excluding ethanol, was calculated to get the
weight percent carbon for reformulated gasoline.
Calculation of Carbon Share:
Column E = (0.175/0.9425)*0.91 + (0.15/0.9425)*0.86 + (0.5425/0.9425)*0.845 + (0.075/0.9425)*0.92
Column E = 0.8660*100
Column E = 86.60
6 Source: CITGO MSDS http://www.msds.com/index.asp?open=/protected public/loainsuccessful.asp
At 60°F, avg density = 6.0-6.4 lbs/gal
Assume "Others" = isooctane
9 Isooctane Specific Gravity from: http://msds.chem.ox.ac.Uk/TR/2.2.4-trimethvlpentane.html
10
Carbon content based on molecular formula of isooctane (C8H10).
11 Source: http://avoaadro.chem.iastate.edu/MSDS/methanol.htm
12 Carbon content calculated from molecular formula, CH4Q.
13 Specific gravity from Material Safety Data Sheet: http://www.sciencestuff.com/msds/C1403.html
14
Carbon content calculated from the molecular formula, C4H10O.
15 Same compound as GTBA; see footnote 7.
16 Source (specific gravity'): http://msds.chem.ox.ac.uk/BU/tert-butvl alcohol.html
17 From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007. Table 6-6.
18 Source (specific gravity'): http://www.coleparmer.com/Cataloa/Msds/00803.htm
1Q
Carbon content calculated from the molecular formula, C6H140-
on
Density from: http://www.enaineerinatoolbox.com/fuels-densities-specific-volumes-d 166.html
21 From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007
http://www.eia.doe.aov/oiaf/1605/aarpt/documentation/pdf/0638(2005').pdf
pg. 185: "If one knows nothing about the composition of a particular petroleum product,
assuming that it is 85.7 percent carbon by mass is not an unreasonable first approximation."
Thus, for the products whose carbon content is unknown, Column D is assumed to be 85.7%.
January 28, 2009
37
-------
Petroleum Product Suppliers Technical Support Document
22 Source: Dickson, Cheryl. Petroleum Product Study, Northrup Grumman, Diesel Fuel Oils, 2007
pg. 13, Table 2
National Average was taken, as the difference between densities was determined to NOT be
statistically significant.
24 Source: Table 27-6
Perry's Chemical Engineer's Handbook, 1997 ed., pg. 27-10
25 Source: Wauquier, J.-P., ed. Petroleum Refining, Crude Oil, Petroleum Products and Process Flowsheets
(Editions Technip - Paris, 1995)
| pg.225, Table 5.16
Specific gravity from: Meyers, Handbook of Petroleum Refining Processes, 3rd ed., (New
York, NY: McGraw Hill, 2004), p. 2.10
27 From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007
httpV/www.eia.doe.oov/oiaf/l 605/ogrpt/documentation/pdf/0638(2005').pdf
pg. 186: "Petrochemical Feedstocks with [. . .] boiling points [higher than 401 degrees F] are
assumed to have the same characteristics as distillate fuel."
'iu '
Weighted average calculated based on samples of still gas from EIA (From ElA's Documentation for Emissions of
Greenhouse Gases in the United States. Oct. 2007
http://www.eia.doe.gOv/oiaf/1605/aarpt/documentation/pdf/0638(2005').pdf
Specific Gravity Reference:
http://www.enaineerinatoolbox.com/specific-aravities-gases-
d 334.html
oq
Based on Calculation of carbon content of Sample Data, given both the composition of Still gas (Hydrogen, Methane,
Ethane and Propane), as well as the weight percent of each component.
Source:
From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007
httpV/www.eia.doe.aov/oiaf/l 605/aarpt/documentation/pdf/0638(2005).pdf
Source: V.B. Guthrie (ed.), Characteristics of Compounds, Petroleum Products Handbook,
(New York, NY: McGraw Hill, 1960), p. 3-3
31 Source: From ElA's Documentation for Emissions of Greenhouse Gases in the United States. Oct. 2007. Table 6-7.
httpV/www.eia.doe.gov/oiaf/l 605/ggrpt/documentation/pdf/0638(2005).pdf
32 Source (specific gravity): http://www.rmisonline.com/chemicaldatabase/Viewlnfo1 ,aspx?SID=112
Carbon content calculated from the molecular formula C2H4.
Source: V.B. Guthrie (ed.), Characteristics of Compounds, Petroleum Products Handbook, (New York, NY: McGraw
Hill, 1960), p. 3-3
Carbon content calculated from the molecular formula C3H6.
36 Meyers, Handbook of Petroleum Refining Processes, 3rd ed., (New York, NY: McGraw Hill, 2004), p. 1.45
37 Carbon content calculated from the molecular formula C4H8.
38 Source: http://www.siri.org/msds/f2/clc/clcvz.html
Carbon content calculated from the molecular formula C4H8.
40 Source: www.marscrude.com/mars assavs/iulv99/assav99.xls
January 28, 2009
38
-------
Petroleum Product Suppliers Technical Support Document
As MARS crude is 31 °API, it is representative of the type of crude oil that the average US
refinery runs. Thus, the data for MARS crude is taken to be representative for all crude run in
the US.
Conventional and Reformulated Gasoline
Using conventional and reformulated gasoline sample data from the Northrop Grumman
Petroleum Product Surveys, the API gravities of over 1,400 samples of gasoline from
across the United States were statistically analyzed for a difference in means.
Specifically, a two sample t-test was conducted for summer vs. winter API gravities,
summer reformulated vs. winter reformulated gravities and summer conventional vs.
winter conventional gravities. The t-test was used to test the null hypothesis that the
winter and summer samples came from the same population, which would lead to a
negligible difference in means between the two data sets. From these tests, it was
determined that there is a statistically significant difference between the API gravities of
both summer and winter gasoline, as well as between conventional and reformulated
gasoline. This difference in API gravity leads to a difference in calculated emission
factors. Thus, for the calculation of emission factors, a different mean API gravity for
each subset of finished motor gasoline was used.
The carbon contents of reformulated and conventional gasolines were calculated based
on laboratory data from a gasoline sample.. Conventional gasoline consists of the
following components13:
Carbon share (weight %),
based on molecular
Weight Percent
formula
Ethanol
0.1
0.52
Aromatics (assumed
0.29
0.91
toluene)
Olefins (CnH2n)
0.17
0.86
Saturated
Hydrocarbons
0.43
0.845
(CnH2n+2)
Benzene
0.01
0.92
The average carbon content for conventional gasoline was determined by taking a
weighted average of the carbon shares of each component, excluding ethanol.
The average composition of reformulated gasoline is assumed to be the following14:
Carbon share (weight %),
based on molecular
Weight Percent
formula
Ethanol
0.0575
0.52
Aromatics (assumed
toluene)
0.175
0.91
Olefins (CnH2n)
0.15
0.86
13 http://www.marathonpetroleum.com/content/documents/mpc/msds/0127MAR019.pdf
14 http ://www. marathonpetroleum. com/content/documents/mpc/msds/013 0M ARO19. pdf
January 28, 2009 39
-------
Petroleum Product Suppliers Technical Support Document
Saturated
Hydrocarbons
0.5425
0.845
(CnH2n+2)
Benzene
0.075
0.92
The average carbon content of reformulated gasoline was determined by taking a
weighted average of the carbon shares of each component, excluding ethanol.
The omission of ethanol in the determination of carbon content of both conventional and
reformulated gasoline is done to prevent reporters from including in their emissions
calculation any emissions from the combustion of a biomass-based feedstock. In this
rule, potential emissions from the combustion of biomass-based products are accounted
for at the time of feedstock harvest, collection, or disposal, not at the point of fuel
combustion. This is a longstanding accounting convention adopted by the IPCC, the
UNFCCC, the U.S. GHG Inventory, and many other State and regional GHG reporting
programs.
If a refinery produces an ex refinery gate product that has been blended with ethanol, it
should follow the specific calculations provided in the regulation to ensure that the
potential C02 emissions of the petroleum-based portion of the product are not
overestimated.
The samples used in the table above contain ethanol because the only publicly available
compositions of gasoline were gasoline that included ethanol. Ethanol was omitted from
the calculation of total weight percent of gasoline, thus not affecting the final emission
factor.
Finished Aviation Gasoline
The average emission factor (EF) for finished aviation gasoline was calculated from the
API Gravity and carbon content of finished aviation gasoline, as reported in Table 6-5 of
the Energy Information Administration's (EIA) Documentation for Emissions of
Greenhouse Gases in the United States.
Blendstocks
The physical properties for RBOB (Reformulated Blendstock for Oxygenate Blending),
CBOB (Conventional Blendstock for Oxygenate Blending) and GTAB (Gasoline Treated
as Blendstock) were taken as equal to the properties of finished motor gasoline, except
where noted.
Oxygenates
The chemical properties of each oxygenate were taken from references as noted. The
carbon contents were computed from the compounds' molecular formulas.
Kerosene-Type Jet Fuel
The average EF for kerosene-type jet fuel was calculated from the API Gravity and
carbon content of kerosene-type jet fuel, as reported in Table 6-5 of the Energy
Information Administration's (EIA) Documentation for Emissions of Greenhouse Gases
in the United States.
Naptha-Type Jet Fuel
January 28, 2009
40
-------
Petroleum Product Suppliers Technical Support Document
The average EF for naptha-type jet fuel was calculated from the API Gravity and carbon
content of naptha-type jet fuel, as requested, from background documents to the Energy
Information Administration's (EIA) Documentation for Emissions of Greenhouse Gases
in the United States.
Kerosene
The average EF for finished kerosene was calculated from the API Gravity and carbon
content of kerosene, as reported in Table 6-5 of the Energy Information Administration's
(EIA) Documentation for Emissions of Greenhouse Gases in
the United States.
Diesel Fuel Oil No.1 and No.4
The physical and chemical properties of these fuel oils were taken from Perry's
Chemical Engineer's Handbook, 1997 ed. Diesel fuel oil No.1 and No.4 are considered
chemically similar to their fuel oil counterparts.
Diesel Fuel Oil No.2
The national average of API gravity for diesel fuel oil No.2 was taken from the Northrop
Grumman Petroleum Product Survey for Diesel Fuel Oils. Given the samples of diesel
fuel from across the country, a statistical analysis was performed to test whether there
was a significant difference between the means of each region. A statistically significant
difference was not found, thus, the data could be treated as one set and averaged
together for a nation-wide mean API gravity. As with diesel fuel oil Nos. 1 and 4, the
average carbon content of No.2 was taken as the average carbon content of all
petroleum products, due to the difficulty in characterizing the average composition of
diesel fuels.
Fuel Oil Nos. 1, 2, and 4
The physical and chemical properties of these fuel oils were taken from Perry's
Chemical Engineer's Handbook, 1997 ed.
Residual Fuel Oil No.5 (Navy Special)
The physical and chemical properties for fuel oil No.5 were taken from the reference
book, Petroleum Refining, Crude Oil, Petroleum Products and Process Flowsheets. The
average carbon content of No.5 was taken as 80% of the carbon content of Fuel Oil
No.6 and 20% of the carbon content of Fuel Oil No.2.
Residual Fuel Oil No. 6
The physical and chemical properties of fuel oil No.6 was taken from Perry's Chemical
Engineer's Handbook, 1997 ed.
Petrochemical Feedstocks - Naphthas
The specific gravity of naphthas was taken from Handbook of Petroleum Refining
Processes, while carbon content is from Table 6-5 of the ElA's Documentation for
Emissions of Greenhouse Gases in the United States.
Petrochemical Feedstocks - Other Oils
The average emission factor (EF) for other oils was calculated from the API Gravity and
the carbon content of distillate fuels, as reported in Table 6-5 of the ElA's Documentation
for Emissions of Greenhouse Gases in the United States.
January 28, 2009
41
-------
Petroleum Product Suppliers Technical Support Document
Special Naphthas, Lubricants, Waxes, Petroleum Coke, Asphalt and Road Oil,
Pentanes Plus and Miscellaneous Products
The average EFs for the above products were calculated from the API Gravity and the
carbon content of each product, as reported in Table 6-5 of the ElA's Documentation for
Emissions of Greenhouse Gases in the United States, unless otherwise noted.
Still Gas
The carbon content of still gas was calculated using a weighted average of samples
given in the ElA's Documentation for Emissions of Greenhouse Gases in the United
States, using the composition of still gas (hydrogen, methane, ethane and propane), as
well as the weight percent of each component gas.
Ethane, Ethylene, Propane, Propylene, Butane, Butylene, Isobutane, Isobutylene
The chemical properties of each were taken from references as noted. The carbon
contents were computed from the compounds' molecular formulas.
Unfinished Oils
Emission factors for unfinished oils were calculated from the average API gravity of the
oil and the average carbon content of petroleum products, as given in the ElA's
Documentation for Emissions of Greenhouse Gases in the United States. This carbon
content factor was used due to the difficulty in characterizing the average composition of
unfinished oils.
Naphthas, Kerosenes, Heavy Gas Oils and Residuum
The physical and chemical compositions of the above products were taken from the
characterization of MARS crude. As MARS crude is about 31 degrees API gravity, it is
representative of the crude oil that the average US refinery runs. Thus, the data for
MARS crude is taken to be representative for all crude run in the US.
4.1.3. Natural Gas Liquids
When crude oil is produced together with associated gas, the wet gas is separated at the
lease site and then sent to a natural gas processing plant. At this plant the methane is
separated out and sent to the natural gas distribution system. The natural gas liquids
(NGLs) are sent to various end users: petrochemical plants, refineries, and in the case of
pure streams of butane and propane into the market. In the case of refineries the NGLs
are often sent as an undifferentiated stream known as bulk NGLs, that is the C2+ stream
shown in Exhibit 15 below.
The crude oil, which is sent to refineries, usually still retains NGLs and these are then
separated at the refinery and used in various processing steps where they co-mingle
with the NGLs obtained from the natural gas processing plant. Refiners attempting to
estimate the carbon content of feedstocks and products are faced with identifying the
NGLs that come from natural gas processing plants and the NGLs and their derivatives
(propane and propylene) that may come from within the refinery and move out of the
refinery to petrochemical complexes, and with deciding whether or not the carbon
content of the two streams is similar.
In the case of pure streams, such as propane, butane, isobutane the factors in Exhibit 14
can be used. For the heavier products there is some difference and refiners should
decide between the factors in Exhibit 14 and Exhibit 15 depending on what stream of
January 28, 2009
42
-------
Petroleum Product Suppliers Technical Support Document
NGLs they are considering. In all cases, if refiners are unable to determine whether a
feedstock is NGL- or petroleum-based, they must report it as a petroleum product.
Heavier NGLs
The carbon content of naphtha obtained during petroleum refining differs from natural
gasoline, also called "pentane-plus," obtained during natural gas processing. Refinery
naphtha and processing plant natural gasoline contain many of the same hydrocarbons
(typically C5 to C12), but the distribution of these molecules differs. Natural gasoline is
the heavier fraction of natural gas that is separated from crude oil at the wellhead. The
distribution of hydrocarbons in natural gas tails off quickly for heavier molecules such as
C8 and C9. Thus, the natural gasoline composition tends to be skewed toward the lighter
molecules such as pentane and hexane. Naphtha, including "light straight run," is the
distillation fraction that condenses at ambient temperature and atmospheric pressure
from crude oil distillation, hydrocarbons that boil between roughly 100°F and 400°F. The
boiling range of naphtha fractions (whole naphtha, light naphtha, medium naphtha,
heavy naphtha) is decided by each refiner based on its downstream operations and
economics.
As a comparison, natural gasoline is typically 83.7% carbon by weight, slightly higher
than pentane at 83.33%. An equally distributed whole naphtha cut from 95°F to 420°F
(boiling range from pentane to dodecane) is estimated to contain 84.2% carbon by
weight, slightly lower than dodecane at 84.71% and approximately the same as naphtha
reported in this rule. Natural gasoline has lower carbon content because it naturally lies
towards the lighter end of the boiling range, whereas refinery naphtha fractions are more
evenly distributed over the entirety of boiling range.
Exhibit 15: Emission Factors for Natural Gas Liquids
NGL's Used in
Petroleum
Refineries
Column A:
Density (API
Gravity)
Column B:
Specific
Gravity
Column C:
Density
(tonnes/bbl)
Column D:
Carbon Share
(% of mass)
Column E:
Computed Emission
Factor (Column C*
Column D/100*
44/12 tonnes
C02/bbl)
C2+
158.80
0.51
0.08
81.79
0.24
C4+
99.46
0.62
0.10
83.15
0.30
C5+
81.70
0.66
0.11
83.70
0.32
C6+
70.60
0.70
0.11
84.04
0.34
Definitions:
C2+ (also known as bulk NGLs) means the NGL fraction consisting of hydrocarbon
molecules ethane and heavier. The characteristics for this fraction, as reported in
Exhibit 15, are derived from the mixture of 31% ethane and 29% propane as reported in
Exhibit 14, and 41% C4+. These proportions were determined from an example API
E&PTankCalc run on 34°API crude oil from a separator temperature of 100°F and
pressure of 40 psig.
January 28, 2009
43
-------
Petroleum Product Suppliers Technical Support Document
C4+ means the NGL fraction consisting of hydrocarbon molecules butane and heavier.
The characteristics for this fraction, as reported in Exhibit 15, are derived from the
mixture of 39% "pentanes plus" and 61% butane as reported in Exhibit 14. These
proportions were determined from an example API E&PTankCalc run on 34°API crude
oil from a separator temperature of 100°F and pressure of 40 psig.
C5+ refers to "pentanes plus", the characteristics of which can be found in Exhibit 14.
C6+ means the NGL fraction consisting of hydrocarbon molecules hexane and heavier.
The characteristics for this fraction, as reported in Exhibit 15, are derived from the
assumption that "pentane plus", as reported in Exhibit 14, consists of a mixture of 53%
C6+ and 47% pentane. These proportions were determined from an example API
E&PTankCalc run on 34°API crude oil from a separator temperature of 100°F and
pressure of 40 psig.
4.1.4. Biomass Feedstock and Products
Refiners that co-process biomass with petroleum feedstock (e.g. renewable diesel) or
blend biomass-based fuels into petroleum-based fuels (e.g. ethanol blended with
gasoline) must use the biomass emission factors in Table MM-3 in the Rule. This
subsection discusses the major types of biofuels and some of the background
assumptions for the default carbon content factors in Table MM-3.
Renewable Diesel
Renewable diesel fuel can be made through the co-processing, such as thermal
depolymerization, of biological and fossil diesel feedstock. As an example,
ConocoPhillips in an alliance with Tyson pioneered an emerging technology that is
capable of creating renewable diesel fuel from beef, pork, and poultry fat. This
technology uses a thermal depolymerization process to co-process the animal fat with
traditional hydrocarbon feedstock. This process is diagrammed in Exhibit 16 below.
Exhibit 16: Renewable Diesel Co-processing By Thermal Depolymerization
Animal fats
1 ~
Refinery diesel
feedstock
The resulting fuel is chemically equivalent to standard diesel fuel produced from purely
hydrocarbon feedstocks, meets ASTM standards, and can be transported directly
through existing pipelines to distribution terminals. The fuel is approximately equal in
energy content to regular diesel, and has a higher cetane value.
c
o
'•4-»
CO
N
0
E
>>
o
CL
0
~u
ro
E
i_
0
Light fractions
Ultra-low-Sulfur
Renewable diesel blend
January 28, 2009
44
-------
Petroleum Product Suppliers Technical Support Document
The technology was successfully tested at the ConocoPhillips's Whitegate refinery in
Cork, Ireland, in 200615. The companies plan to make as much as 175 million gallons
per year16 of renewable diesel to help supplement the U.S.'s diesel supply.
The portion of biological carbon that is present in renewable diesel and light fractions is
not readily apparent; therefore the Rule requires that refiners report the carbon content
of any biomass that will be co-processed with a petroleum product using default values.
Exhibit 18 below shows the estimated default emission factors for both animal fats and
vegetable oils that can be co-processed within a refinery. The text following the exhibit
lays out the assumptions.
Exhibit 17: Emission Factors for the Bio Portion of Renewable Diesel
Animal Fat and
Vegetable Oil as
Renewable Diesel
Feedstock
Column A:
Density (API
Gravity)
Column B:
Specific
Gravity
Column C:
Density
(tonnes/bbl)
Column D:
Carbon Share
(% of mass)
Column E:
Computed Emission
Factor (Column C*
Column D/100*
44/12 tonnes
C02/bbl)
Animal Fat17
36.95
0.8418
0.13
76.19
0.37
Vegetable Oil3
22.64
0.9219
0.15
76.77
0.41
Assumptions
Animal fat means fats extracted from animals, with 76.19% carbon by weight,
characterized by the composition of fatty acids described in Exhibit 19.
Vegetable oil means oils extracted from vegetation, with 76.77% carbon by weight,
characterized by the composition of fatty acids described in Exhibit 19.
15 ConocoPhillips. Tyson-COP Alliance.
.
1 MSN. ConocoPhillips, Tyson to make diesel from fats. April 16, 2007.
.
17 See Exhibit 19.
18 Griffin Industries. Material Safety Data Sheet, Identity: Chicken Fat. March 19, 2007.
.
January 28, 2009
45
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 18: Composition of Animal Fat and Vegetable Oil
Fatty
Carbon Share
Animal Fat20
Vegetable oil21
acid
(%CFA)
(Xfa)
(Xfa)
14:0
73.7%
1%
0%
16:0
75.0%
24%
9%
16:1
75.6%
5%
0%
18:0
76.1%
8%
6%
18:1
76.6%
44%
27%
18:2
77.1%
17%
51%
18:3
77.7%
1%
7%
Calculations
Using the assumptions displayed in Exhibit 19, the weight percent of carbon for animal
fat and vegetable oil (Column D of Exhibit 18) were calculated using the following
equation:
Carbon Share = ^ [%(, x XFA ]
Where %CFa is the weight percent of carbon of a fatty acid and XFa is the composition
portion of that fatty acid in animal fat or vegetable oil as shown in Exhibit 19.
Biodiesel/Straight Run Diesel Refinery Blending
Biodiesel is blended into refinery straight run diesel at some petroleum refinery racks.
AGE Refining, Inc. was the first petroleum refinery to offer a biodiesel blend to
distributors, blended within the refinery gate22. A diagram of this blending process is
provided in Exhibit 17.
20 Cyberlipid Center. Lipids of Land Animals . Accessed September 9, 2008.
. Estimated by Poultry fat.
21 Erasmus, Udo. Fats That Heal, Fats That Kill: The Complete Guide to Fats, Oils, Cholesterol, and
Human Health. Table accessed from . Estimated by Soy Bean
Oil.
22 Biodiesel Org. Texas Oil Refinery Becomes First to Offer Biodiesel Blend in U.S. May 23,
2005. .
January 28, 2009
46
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 19: Refinery Blending of Biodiesel with Fossil Diesel
Blends come in several varieties that are defined by the percentage of biodiesel present
in the mixture. B2, B5, B10, B20, B30, B50, B95, B99, and B100 denote diesel fuel
blends that are 2%, 5%, 10%, 20%, 30%, 50%, 95%, 99%, and 100% biodiesel
respectively.
The 100% biodiesel factor presented in Table MM-3 in the Rule, 0.40 tonnes C02/barrel,
was derived from Tables IV.A.3-2 and 3-3 in A Comprehensive Analysis of Biodiesel
Impacts on Exhaust Emissions.23
Ethanol
Ethanol is added to gasoline as an oxygenate. Oxygenates are an affective alternative
to aromatics as a gasoline additive to boost octane levels, reduce engine knocking, and
to reduce emissions of pollutants in the engine exhaust.
The emissions factor for combustion of ethanol presented in Table MM-3 in the Rule,
0.23 tonnes C02/barrel, was derived from Chapter 3 of the U.S. EPA's Inventory of U.S.
Greenhouse Gas Emissions and Sinks: 1990 - 200624
23 EPA420-P-02-001 available at www.epa. gov/otaq/models/analvsis/biodsl/p02001 .pdf
24
EPA 430-R-08-005 available at http://epa.gov/climatechange/emissions/downloads/08 CR.pdf
January 28, 2009
47
-------
Petroleum Product Suppliers Technical Support Document
4.2. Direct Measurement Methods for Establishing Carbon Content
4.2.1. Direct Density Measurements
All density measurements of petroleum products can be conducted using appropriate
ASTM standard methodologies. The appropriate methods and the products to which
each applies are detailed in the paragraphs below.
For liquefied petroleum gases (LPG) and other light hydrocarbons ASTM D1657 -
02(2007) Standard Test Method for Density or Relative Density of Light Hydrocarbons
by Pressure Hydrometer can be used. This method covers light hydrocarbons having
Reid vapor pressures exceeding 14.696 psia. The prescribed apparatus should not be
used for materials having vapor pressure higher than 200 psia at the test temperatur
For petroleum products that are low-viscosity, transparent liquids, ASTM D1298 -
99(2005) Standard Test Method for Density, Relative Density (Specific Gravity), or API
Gravity of Crude Petroleum and Liquid Petroleum Products by Hydrometer Method can
be used. This method applies to products having Reid vapor pressures less than 14.969
psia. Values are measured on a hydrometer at either the reference temperature or at
another convenient temperature. If another temperature is chosen, then readings are
corrected to the reference temperature by means of the Petroleum Measurement
Tables.
For petroleum products that may not be transparent liquids, but translucent, or more
viscous, ASTM D4052 -96(2002)e1 Standard Test Method for Density and Relative
Density of Liquids by Digital Density Meter can be used. This test method covers
petroleum distillates and viscous oils that can be handled in a normal fashion as liquids
at test temperatures between 60 and 95 degrees Fahrenheit. Its application is restricted
to liquids with vapor pressures below 14.6 psia and viscosities below about 15,000 cSt
at the temperature of the test. This test method should not be applied to samples so
dark in color that the absence of air bubbles in the sample cell cannot be established
with certainty.
For dark, heavy petroleum products, ASTM D5002 - 99(2005) Standard Test Method for
Density and Relative Density of Crude Oils by Digital Analyzer can be used. This test
method covers crude oils and products that can be handled in a normal fashion as
liquids at test temperatures between 60 and 95 degrees Fahrenheit. It applies to crude
oils and products with high vapor pressures provided appropriate precautions are taken
to prevent vapor loss during the transfer of the sample to the density analyzer. Heavier
crudes can require measurements at higher temperatures to eliminate air bubbles in the
sample.
Petroleum coke requires ASTM D5004 - 89(2004)e1 Standard Test Method for Real
Density of Calcined Petroleum Coke by Xylene Displacement. This test method is
intended for the determination of the real density of calcined petroleum coke, but it is
assumed here that it is also suitable for non-calcined petroleum coke. The density is
obtained when the particle size of the test specimen is smaller than No. 200 sieve.
For all testing and reporting, specific gravity will be converted density using the value for
water at 60 degrees Fahrenheit, 8.32830, as reported from Perry's Chemical
Engineering Handbook for API gravity of 10 degrees.
January 28, 2009
48
-------
Petroleum Product Suppliers Technical Support Document
4.2.2. Direct Carbon Share Measurements25
Carbon content measurement standards are not commonplace. One existing standard
is ASTM D5291 (2007) Standard Test Methods for Instrumental Determination of
Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants. It was
developed mainly for hydrogen and nitrogen but also had the capability to measure
carbon, so that was included as well. The measurement method involves placing a
sample on an absorbent to minimize vaporization and then combusting a sample at
about 1000 degrees Celsius. Combustion products are measured to derive hydrogen,
nitrogen, and carbon content.
ASTM D5291(2007) is suitable for heavier hydrocarbon liquids such as kerosenes,
diesels, fuel oils, residual oils, lubricants and petroleum coke. Volatile hydrocarbon
liquids such as gasoline and other gasoline blend stocks are not recommended for use
with the test method: volatile hydrocarbons may escape before the sample reaches the
combustion zone, avoiding combustion into carbon dioxide and lowering the carbon
share for the measurement. Liquefied petroleum gases (LPG), such as propane and
butane, would be entirely unsuitable for this method.
The ASTM committee did not provide specific published methods for determining carbon
content of fuels but instead offered that gas chromatography is one possibility. ASTM
D6729 - (2004)e1, Standard Test Method for Determination of Individual Components in
Spark Ignition Engine Fuels by 100 Metre Capillary High Resolution Gas
Chromatography is a recommended alternative. Gas chromatography (GC) would be
entirely suitable for LPGs and NGLs as these products have few chemical constituents
easily quantified by GC: ethane, ethylene, propane, propylene, and isomers of
butane/butylenes, pentane/pentenes and hexane/hexenes. GC would also be suitable
for near-pure volatile gasoline blending components such as alcohols and ethers:
methanol, n-butyl alcohol, ETBE, TAME, DIPE, and MTBE. GC is a less practical test
method for determining carbon share in complex volatile mixtures such as gasoline and
gasoline blend-stocks given that it incompletely separates and quantifies the large
number of close-boiling point isomers of individual hydrocarbon species. In the absence
of a specific standard, ASTM D5291 (2007) may be an appropriate surrogate for
determining carbon share in volatile liquid fuels and liquid blending components as long
as its limitations are noted, with ASTM D6729 - (2004)el used for LPG products,
alcohols and ether blending components.
4.3. Threshold Calculations
4.3.1. Refineries
A threshold analysis was conducted on the petroleum products produced by each
refinery to estimate the number of refineries with emissions that surpassed the threshold
limits of 1000, 10,000, 25,000 and 100,000 Mt C02e per year. For this analysis only
those refineries with atmospheric distillation columns were used (140 out of the existing
150 U.S. refineries: EIA 2006). The preliminary threshold analysis was conducted by
estimating emissions from the motor gasoline produced by each refinery. United States
refineries and their 2006 atmospheric distillation capacities were obtained from the EIA
25 Information drawn from a memo from ICF to EPA dated July 2008
January 28, 2009
49
-------
Petroleum Product Suppliers Technical Support Document
for the threshold analysis. The total motor gasoline produced by each state(s) or PADD
district in 2006 was collected from the EIA and was apportioned to each refinery on the
basis of their atmospheric distillation capacity (i.e. the ratio of the atmospheric distillation
capacity of the refinery to the total capacity of the state(s) or PADD district was
multiplied by the total motor gasoline produced by the state(s) or PADD district to obtain
the motor gasoline produced by each refinery). The production numbers obtained from
EIA are adjusted for products that are re-processed to convert into other products (i.e.
reported numbers are net product volumes). However, products shipped between
refineries are not accounted for in the EIA production numbers. Therefore, any product
shipped between refineries is double counted in the estimate.
January 28, 2009
50
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 20: Finished Motor Gasoline Produced per Refinery.
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Valero Energy
Corp.
Delaware City
Delaware
1B
East Coast
170,756
182,200
18,458
Chevron USA Inc.
Perth Amboy
New Jersey
1B
East Coast
170,756
80,000
8,104
Citgo Asphalt
Refining Co
Paulsboro
New Jersey
1B
East Coast
170,756
0
0
ConocoPhillips
Linden
New Jersey
1B
East Coast
170,756
238,000
24,110
Hess Corporation
Port Reading
New Jersey
1B
East Coast
170,756
0
0
Sunoco Inc.
Westville
New Jersey
1B
East Coast
170,756
145,000
14,689
Valero Energy
Corp.
Paulsboro
New Jersey
1B
East Coast
170,756
160,000
16,209
American Refining
Group
Bradford
Pennsylvania
1B
East Coast
170,756
10,000
1,013
ConocoPhillips
Trainer
Pennsylvania
1B
East Coast
170,756
185,000
18,741
Sunoco Inc.
Marcus Hook
Pennsylvania
1B
East Coast
170,756
178,000
18,032
Sunoco Inc.
Philadelphia
Pennsylvania
1B
East Coast
170,756
335,000
33,937
United Refining Co.
Warren
Pennsylvania
1B
East Coast
170,756
65,000
6,585
Citgo Asphalt
Refining Co
Savannah
Georgia
1C
East Coast
170,756
28,000
2,837
Giant Refining
Yorktown
Virginia
1C
East Coast
170,756
59,375
6,015
Ergon-West
Virginia Inc.
Newell
West Virginia
1C
Appalachia
No.1
12,554
20,000
12,554
PDV Midwest
Refining LLC
Lemont
Illinois
2
IN, IL, KY
286,531
167,000
20,373
WRB Refining LLC
Wood River
Illinois
2
IN, IL, KY
286,531
306,000
37,330
January 28, 2009
51
-------
Petroleum Product Suppliers Technical Support Document
Company
Refinery
Location
State
PADD
District
Motor
Gasoline
Sub-PADD
Division
PADD
Finished
Motor
Gasoline
(thousand
b/d)
Refinery
Crude
Capacity (b/d)
Calculated
Finished Motor
Gasoline
(thousand b/d)
ExxonMobil
Refining & Supply
Co.
Joliet
Illinois
2
IN, IL, KY
286,531
238,600
29,108
Marathon
Petroleum Co LLC
Robinson
Illinois
2
IN, IL, KY
286,531
192,000
23,423
BP PLC
Whiting
Indiana
2
IN, IL, KY
286,531
410,000
50,018
Countrymark
Cooperative Inc.
Mount Vernon
Indiana
2
IN, IL, KY
286,531
23,000
2,806
Marathon
Petroleum Co LLC
Catlettsburg
Kentucky
2
IN, IL, KY
286,531
222,000
27,083
Somerset Refinery
Inc.
Somerset
Kentucky
2
IN, IL, KY
286,531
0
0
Valero Energy
Corp.
Memphis
Tennessee
2
IN, IL, KY
286,531
180,000
21,959
Marathon Ashland
Petroleum LLC
Detroit
Michigan
2
IN, IL, KY
286,531
100,000
12,199
BP PLC
Toledo
Ohio
2
IN, IL, KY
286,531
131,000
15,981
Marathon Ashland
Petroleum LLC
Canton
Ohio
2
IN, IL, KY
286,531
73,000
8,906
Sunoco Inc.
Toledo
Ohio
2
IN, IL, KY
286,531
160,000
19,519
Husky Energy
Lima
Ohio
2
IN, IL, KY
286,531
146,120
17,826
Flint Hills
Resources
Rosemount
Minnesota
2
MN, Wl, ND,
SD
40,712
279,300
25,749
Marathon Ashland
Petroleum LLC
St. Paul Park
Minnesota
2
MN, Wl, ND,
SD
40,712
70,000
6,453
Murphy Oil USA
Inc.
Superior
Wisconsin
2
MN, Wl, ND,
SD
40,712
34,300
3,162
January 28, 2009
52
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Tesoro West Coast
MN, Wl, ND,
Co.
Mandan
North Dakota
2
SD
40,712
58,000
5,347
ConocoPhillips
Ponca City
Oklahoma
2
OK, KS, MO
133,048
194,000
32,615
Sinclair Oil Corp.
Tulsa
Oklahoma
2
OK, KS, MO
133,048
70,300
11,819
Sunoco Inc.
Tulsa
Oklahoma
2
OK, KS, MO
133,048
85,000
14,290
Valero Energy
Corp.
Ardmore
Oklahoma
2
OK, KS, MO
133,048
87,400
14,693
Wynnewood
Refining Co.
Wynnewood
Oklahoma
2
OK, KS, MO
133,048
54,000
9,078
Coffeyville
Resources R&M
LLC
Coffeyville
Kansas
2
OK, KS, MO
133,048
112,000
18,829
Frontier El Dorado
Oil Corp.
El Dorado
Kansas
2
OK, KS, MO
133,048
107,500
18,073
National
Cooperative
Refining Assoc.
McPherson
Kansas
2
OK, KS, MO
133,048
81,200
13,651
AGE Refining &
Manufacturing
San Antonio
Texas
3
Texas Inland
111,611
13,000
2,166
Alon USA
Big Spring
Texas
3
Texas Inland
111,611
67,000
11,161
ConocoPhillips
Borger
Texas
3
Texas Inland
111,611
146,000
24,321
Delek Refining LTD
Tyler
Texas
3
Texas Inland
111,611
58,000
9,662
Valero Energy
Corp.
Sunray
Texas
3
Texas Inland
111,611
171,000
28,486
Valero Energy
Corp.
Three Rivers
Texas
3
Texas Inland
111,611
93,000
15,492
January 28, 2009
53
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Western Refining
Inc.
El Paso
Texas
3
Texas Inland
111,611
122,000
20,323
Texas Gulf
BP PLC
Texas City
Texas
3
Coast
479,986
417,000
49,845
Citgo Petroleum
Corp.
Corpus
Christi
Texas
3
Texas Gulf
Coast
479,986
156,000
18,647
Texas Gulf
ConocoPhillips
Sweeny
Texas
3
Coast
479,986
247,000
29,525
ExxonMobil
Refining & Supply
Co.
Baytown
Texas
3
Texas Gulf
Coast
479,986
562,500
67,237
ExxonMobil
Refining & Supply
Co.
Beaumont
Texas
3
Texas Gulf
Coast
479,986
348,500
41,657
Flint Hills
Corpus
Texas Gulf
Resources
Christi
Texas
3
Coast
479,986
288,126
34,440
Houston Refining
Texas Gulf
LLP
Houston
Texas
3
Coast
479,986
270,200
32,298
Marathon Ashland
Texas Gulf
Petroleum LLC
Texas City
Texas
3
Coast
479,986
72,000
8,606
Motiva Enterprises
LLC
Port Arthur
Texas
3
Texas Gulf
Coast
479,986
285,000
34,067
Pasadena Refining
Texas Gulf
System
Pasadena
Texas
3
Coast
479,986
100,000
11,953
South Hampton
Resources Inc
Silsbee
Texas
3
Texas Gulf
Coast
479,986
0
0
January 28, 2009
54
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Deer Park Refining
Texas Gulf
LTD Partnership
Deer Park
Texas
3
Coast
479,986
333,700
39,888
Texas Gulf
Total SA
Port Arthur
Texas
3
Coast
479,986
232,000
27,732
Trigeant LTD
Corpus
Christi
Texas
3
Texas Gulf
Coast
479,986
0
0
Valero Energy
Corp.
Corpus
Christi
Texas
3
Texas Gulf
Coast
479,986
142,000
16,974
Valero Energy
Texas Gulf
Corp.
Houston
Texas
3
Coast
479,986
83,000
9,921
Valero Energy
Texas Gulf
Corp.
Port Arthur
Texas
3
Coast
479,986
260,000
31,078
Valero Energy
Texas Gulf
Corp.
Texas City
Texas
3
Coast
479,986
218,500
26,118
Louisiana
Shell Chemical Co.
Saraland
Alabama
3
Gulf Coast
459,140
80,000
11,020
Gulf Atlantic
Louisiana
Operations LLC
Mobile Bay
Alabama
3
Gulf Coast
459,140
0
0
Calcasieu Refining
Louisiana
Co.
Lake Charles
Louisiana
3
Gulf Coast
459,140
78,000
10,744
Calumet Lubricants
Louisiana
Co.
Cotton Valley
Louisiana
3
Gulf Coast
459,140
13,020
1,793
Calumet Lubricants
Louisiana
Co.
Princeton
Louisiana
3
Gulf Coast
459,140
8,300
1,143
Calumet
Louisiana
Shreveport LLC
Shreveport
Louisiana
3
Gulf Coast
459,140
42,000
5,785
January 28, 2009
55
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Louisiana
Cit-Con Oil Corp.
Lake Charles
Louisiana
3
Gulf Coast
459,140
0
0
Citgo Petroleum
Louisiana
Corp.
Lake Charles
Louisiana
3
Gulf Coast
459,140
429,500
59,163
Louisiana
ConocoPhillips
Belle Chasse
Louisiana
3
Gulf Coast
459,140
247,000
34,024
Louisiana
ConocoPhillips
Westlake
Louisiana
3
Gulf Coast
459,140
239,400
32,977
ExxonMobil
Refining & Supply
Co.
Baton Rouge
Louisiana
3
Louisiana
Gulf Coast
459,140
503,000
69,287
Chalmette Refining
Louisiana
LLC
Chalmette
Louisiana
3
Gulf Coast
459,140
192,760
26,552
Marathon
Louisiana
Petroleum Co LLC
Garyville
Louisiana
3
Gulf Coast
459,140
245,000
33,748
Motiva Enterprises
LLC
Convent
Louisiana
3
Louisiana
Gulf Coast
459,140
235,000
32,371
Motiva Enterprises
LLC
Norco
Louisiana
3
Louisiana
Gulf Coast
459,140
242,200
33,363
Murphy Oil USA
Louisiana
Inc.
Meraux
Louisiana
3
Gulf Coast
459,140
120,000
16,530
Pelican Refining
Louisiana
Company LLC
Lake Charles
Louisiana
3
Gulf Coast
459,140
0
0
Placid Refining Co.
Louisiana
LLC
Port Allen
Louisiana
3
Gulf Coast
459,140
56,000
7,714
Louisiana
Shell Chemical Co.
St. Rose
Louisiana
3
Gulf Coast
459,140
55,000
7,576
January 28, 2009
56
-------
Petroleum Product Suppliers Technical Support Document
Company
Refinery
Location
State
PADD
District
Motor
Gasoline
Sub-PADD
Division
PADD
Finished
Motor
Gasoline
(thousand
b/d)
Refinery
Crude
Capacity (b/d)
Calculated
Finished Motor
Gasoline
(thousand b/d)
Valero Energy
Corp.
Krotz Springs
Louisiana
3
Louisiana
Gulf Coast
459,140
32,000
4,408
Valero Energy
Corp.
Norco
Louisiana
3
Louisiana
Gulf Coast
459,140
185,003
25,484
Chevron USA Inc.
Pascagoula
Mississippi
3
Louisiana
Gulf Coast
459,140
330,000
45,457
Cross Oil &
Refining Co. Inc.
Smackover
Arkansas
3
N. Louisiana,
AR
17,597
7,200
846
Lion Oil Co.
El Dorado
Arkansas
3
N. Louisiana,
AR
17,597
70,000
8,223
Goodway Refining
LLC
Atmore
Alabama
3
N. Louisiana,
AR
17,597
4,100
482
Hunt Refining Co.
Tuscaloosa
Alabama
3
N. Louisiana,
AR
17,597
34,500
4,053
Ergon Refining Inc.
Vicksburg
Mississippi
3
N. Louisiana,
AR
17,597
23,000
2,702
Hunt Southland
Refining Co
Lumberton
Mississippi
3
N. Louisiana,
AR
17,597
0
0
Hunt Southland
Refining Co
Sandersville
Mississippi
3
N. Louisiana,
AR
17,597
11,000
1,292
Giant Refining Co.
Bloomfield
New Mexico
3
New Mexico
16,133
16,800
2,229
Giant Refining Co.
Gallup
New Mexico
3
New Mexico
16,133
20,800
2,760
Navajo Refining
Co.
Artesia
New Mexico
3
New Mexico
16,133
84,000
11,145
Suncor Energy
Products - U
Commerce
City
Colorado
4
Rocky
Mountain
98,287
62,000
10,100
January 28, 2009
57
-------
Petroleum Product Suppliers Technical Support Document
Company
Refinery
Location
State
PADD
District
Motor
Gasoline
Sub-PADD
Division
PADD
Finished
Motor
Gasoline
(thousand
b/d)
Refinery
Crude
Capacity (b/d)
Calculated
Finished Motor
Gasoline
(thousand b/d)
Suncor Energy
Products - U
Denver
Colorado
4
Rocky
Mountain
98,287
32,000
5,213
Cenex Harvest
States
Laurel
Montana
4
Rocky
Mountain
98,287
55,000
8,960
ConocoPhillips
Billings
Montana
4
Rocky
Mountain
98,287
58,000
9,448
ExxonMobil
Refining & Supply
Co.
Billings
Montana
4
Rocky
Mountain
98,287
60,000
9,774
Montana Refining
Co.
Great Falls
Montana
4
Rocky
Mountain
98,287
9,500
1,548
Big West Oil LLC -
B
Salt Lake City
Utah
4
Rocky
Mountain
98,287
29,400
4,789
Chevron USA Inc.
Salt Lake City
Utah
4
Rocky
Mountain
98,287
45,000
7,331
Holly Corp.
Woods Cross
Utah
4
Rocky
Mountain
98,287
24,700
4,024
Silver Eagle
Refining Inc.
Woods Cross
Utah
4
Rocky
Mountain
98,287
10,250
1,670
Tesoro West Coast
Co.
Salt Lake City
Utah
4
Rocky
Mountain
98,287
58,000
9,448
Frontier Refining
Inc.
Cheyenne
Wyoming
4
Rocky
Mountain
98,287
52,000
8,471
Sinclair / Little
America
Casper
Wyoming
4
Rocky
Mountain
98,287
24,500
3,991
Silver Eagle
Refining Inc.
Evanston
Wyoming
4
Rocky
Mountain
98,287
3,000
489
January 28, 2009
58
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Sinclair Oil Corp.
Sinclair
Wyoming
4
Rocky
Mountain
98,287
66,000
10,752
Wyoming Refining
Co.
Newcastle
Wyoming
4
Rocky
Mountain
98,287
14,000
2,281
ConocoPhillips
Alaska
Kuparuk
Alaska
5
West Coast
138,986
15,000
657
BP PLC
Prudhoe Bay
Alaska
5
West Coast
138,986
12,500
547
Flint Hills
Resources
North Pole
Alaska
5
West Coast
138,986
210,000
9,194
Petro Star Inc.
North Pole
Alaska
5
West Coast
138,986
17,500
766
Petro Star Inc.
Valdez
Alaska
5
West Coast
138,986
48,000
2,102
Tesoro Alaska Co.
Kenai
Alaska
5
West Coast
138,986
72,000
3,152
Big West Oil LLC
Bakersfield
California
5
West Coast
138,986
70,000
3,065
BP PLC
Carson (Los
Angeles)
California
5
West Coast
138,986
265,000
11,602
Chevron Corp.
El Segundo
California
5
West Coast
138,986
260,000
11,383
Chevron Corp.
Richmond
California
5
West Coast
138,986
242,901
10,635
ConocoPhillips
Los Angeles
(Carson and
Wilmington)
California
5
West Coast
138,986
139,000
6,086
Rodeo &
ConocoPhillips
Santa Maria
California
5
West Coast
138,986
120,200
5,263
ExxonMobil
Refining & Supply
Co.
Torrance
California
5
West Coast
138,986
149,500
6,545
Greka Energy
Santa Maria
California
5
West Coast
138,986
9,500
416
January 28, 2009
59
-------
Petroleum Product Suppliers Technical Support Document
Company
Refinery
Location
State
PADD
District
Motor
Gasoline
Sub-PADD
Division
PADD
Finished
Motor
Gasoline
(thousand
b/d)
Refinery
Crude
Capacity (b/d)
Calculated
Finished Motor
Gasoline
(thousand b/d)
Kern Oil & Refining
Co.
Bakersfield
California
5
West Coast
138,986
26,000
1,138
Lunday Thagard
Co
South Gate
California
5
West Coast
138,986
8,500
372
Edgington Oil Co
Inc
Long Beach
California
5
West Coast
138,986
18,000
788
Paramount
Petroleum Corp.
Long Beach
California
5
West Coast
138,986
50,000
2,189
San Joaquin
Refining Co. Inc.
Bakersfield
California
5
West Coast
138,986
15,000
657
Shell Oil Products
US
Martinez
California
5
West Coast
138,986
155,600
6,812
Shell Oil Products
US
Wilmington
California
5
West Coast
138,986
97,000
4,247
Tenby Inc
Oxnard
California
5
West Coast
138,986
2,800
123
Tesoro Petroleum
Golden Eagle
California
5
West Coast
138,986
166,000
7,268
Valero Energy
Corp.
Benicia
California
5
West Coast
138,986
144,000
6,305
Valero Energy
Corp.
Wilmington
California
5
West Coast
138,986
80,887
3,541
Valero Refining Co
California
Wilmington
California
5
West Coast
138,986
6,300
276
Chevron USA Inc.
Honolulu
Hawaii
5
West Coast
138,986
54,000
2,364
Tesoro Hawaii
Corp.
Kapolei
Hawaii
5
West Coast
138,986
93,500
4,094
Foreland Refining
Corp
Eagle Springs
Nevada
5
West Coast
138,986
2,000
88
January 28, 2009
60
-------
Petroleum Product Suppliers Technical Support Document
PADD
Finished
Motor
Motor
Calculated
Gasoline
Gasoline
Refinery
Finished Motor
Company
Refinery
Location
State
PADD
District
Sub-PADD
Division
(thousand
b/d)
Crude
Capacity (b/d)
Gasoline
(thousand b/d)
Paramount
Petroleum Corp.
Portland
Oregon
5
West Coast
138,986
0
0
BP PLC
Ferndale
Washington
5
West Coast
138,986
225,000
9,851
ConocoPhillips
Ferndale
Washington
5
West Coast
138,986
96,000
4,203
Shell Oil Products
US
Anacortes
Washington
5
West Coast
138,986
145,000
6,348
Tesoro West Coast
Co.
Anacortes
Washington
5
West Coast
138,986
120,000
5,254
US Oil & Refining
Co.
Tacoma
Washington
5
West Coast
138,986
37,850
1,657
January 28, 2009
61
-------
Petroleum Product Suppliers Technical Support Document
To calculate the C02 emissions per refinery, the carbon emission factors (MMTC/1015
Btu) for motor gasoline and the various petroleum products (finished aviation gasoline,
jet fuel, kerosene, distillate fuel oil, residual fuel oil, petrochemical feedstocks, special
naphthas, lubricants, waxes, petroleum coke, asphalt and road oil, and miscellaneous
products) were obtained from the EIA Emissions ofGHG in the United States 2001, with
the exception of diesel, napthas, and special napthas that were obtained from the API
Compendium of GHG Estimation Methodologies for the Oil and Gas Industry 2004. The
carbon emission factors were converted to C02 emission factors by assuming 100%
oxidation of the fuels with the exception of petrochemical feedstocks, special napthas,
asphalt and road oil, lubricants, and miscellaneous products, which were assumed to
have a 40% oxidation rate. The C02 emission factors (tonnes C02/barrel) were
calculated by multiplying the C02 emission factor (MMTCO2/1015 Btu) with their
corresponding heat content obtained from the EIA Thermal Conversion Factors 2008.
An alternative approach to calculating C02 emission factors for petrochemical
feedstocks, special napthas, asphalt and road oil, lubricants, and miscellaneous
products would be to apply to each product a product-specific oxidation factor instead of
the 40% average rate.
Exhibit 21: Calculated C02 Emission Factor.
Heat
Content
Emission Factor
MMTC/101b
Tonnes CO2/ bbl
Oxidation
Fuel
MMBtu/bbl
BTU
(calculated)
Rate
Motor Gasoline
5.25
19.34
0.37
100%
Diesel
5.61
0.076*
0.43
100%
Petrochemical
Feedstocks
5.69
19.37
0.40
40%
Naphtha/ Reformer
Feed
5.25
0.07*
0.38
100%
Kerosene
5.67
19.72
0.41
100%
Kerosene/Jet Fuel
5.67
19.33
0.40
100%
Aviation Gas
5.05
18.87
0.35
100%
Residual Fuel Oil
6.29
21.49
0.50
100%
Distillate
5.83
19.95
0.43
100%
Lubricants
6.07
20.24
0.45
40%
Asphalt and Road Oil
6.64
20.62
0.50
40%
Wax
5.54
19.81
0.40
40%
Miscellaneous
Products
5.80
19.81
0.42
40%
Petroleum Coke
6.02
27.85
0.62
100%
Special Naphthas
5.25
0.075*
0.39
100%
*These API values are in tonnes C02/MMBtu (average)
The C02 emissions from the refineries were obtained by multiplying the volume of motor
gasoline produced by each refinery with the C02 emission factor (tonnes C02/barrel) for
motor gasoline. The number of refineries with emissions greater than the specified
threshold emission value was identified i.e. for the emission threshold value of 1,000
January 28, 2009
62
-------
Petroleum Product Suppliers Technical Support Document
C02, all refineries possessing total emissions >1,000 C02 were calculated. The total
percent of emissions covered by each threshold limit was calculated by dividing the total
emissions covered by the threshold limit with the total national emissions.
Exhibit 22: Calculated C02 Emissions per Refinery
Motor Gasoline Emissions
Company
Refinery Location
(tonnes C02/Year)
Valero Energy Corp.
Delaware City
2,509,143,269
Chevron USA Inc.
Perth Amboy
1,101,709,449
ConocoPhillips
Linden
3,277,585,610
Sunoco Inc.
Westville
1,996,848,376
Valero Energy Corp.
Paulsboro
2,203,418,897
American Refining Group
Bradford
137,713,681
ConocoPhillips
Trainer
2,547,703,100
Sunoco Inc.
Marcus Hook
2,451,303,523
Sunoco Inc.
Philadelphia
4,613,408,316
United Refining Co.
Warren
895,138,927
Citgo Asphalt Refining Co
Savannah
385,598,307
Giant Refining
Yorktown
817,674,981
Ergon-West Virginia Inc.
Newell
1,706,598,344
PDV Midwest Refining LLC
Lemont
2,769,529,761
WRB Refining LLC
Wood River
5,074,707,226
ExxonMobil Refining &
Supply Co.
Joliet
3,956,944,916
Marathon Petroleum Co LLC
Robinson
3,184,130,024
BP PLC
Whiting
6,799,444,323
Countrymark Cooperative
Inc.
Mount Vernon
381,432,242
Marathon Petroleum Co LLC
Catlettsburg
3,681,650,341
Valero Energy Corp.
Memphis
2,985,121,898
Marathon Ashland
Petroleum LLC
Detroit
1,658,401,054
BP PLC
Toledo
2,172,505,381
Marathon Ashland
Petroleum LLC
Canton
1,210,632,770
Sunoco Inc.
Toledo
2,653,441,687
Husky Energy
Lima
2,423,255,621
Flint Hills Resources
Rosemount
3,500,366,385
Marathon Ashland
Petroleum LLC
St. Paul Park
877,284,808
Murphy Oil USA Inc.
Superior
429,869,556
Tesoro West Coast Co.
Mandan
726,893,127
ConocoPhillips
Ponca City
4,433,668,621
Sinclair Oil Corp.
Tulsa
1,606,633,526
Sunoco Inc.
Tulsa
1,942,586,767
Valero Energy Corp.
Ardmore
1,997,436,276
Wynnewood Refining Co.
Wynnewood
1,234,113,946
January 28, 2009
63
-------
Petroleum Product Suppliers Technical Support Document
Motor Gasoline Emissions
Company
Refinery Location
(tonnes C02/Year)
Coffeyville Resources R&M
LLC
Coffeyville
2,559,643,740
Frontier El Dorado Oil Corp.
El Dorado
2,456,800,911
National Cooperative
Refining Assoc.
McPherson
1,855,741,711
AGE Refining &
Manufacturing
San Antonio
294,391,146
Alon USA
Big Spring
1,517,246,677
ConocoPhillips
Borger
3,306,239,027
Delek Refining LTD
Tyler
1,313,437,422
Valero Energy Corp.
Sunray
3,872,375,847
Valero Energy Corp.
Three Rivers
2,106,028,969
Western Refining Inc.
El Paso
2,762,747,680
BP PLC
Texas City
6,775,968,504
Citgo Petroleum Corp.
Corpus Christi
2,534,894,692
ConocoPhillips
Sweeny
4,013,583,262
ExxonMobil Refining &
Supply Co.
Baytown
9,140,245,284
ExxonMobil Refining &
Supply Co.
Beaumont
5,662,889,745
Flint Hills Resources
Corpus Christi
4,681,853,000
Houston Refining LLP
Houston
4,390,567,601
Marathon Ashland
Petroleum LLC
Texas City
1,169,951,396
Motiva Enterprises LLC
Port Arthur
4,631,057,610
Pasadena Refining System
Pasadena
1,624,932,495
Deer Park Refining LTD
Partnership
Deer Park
5,422,399,735
Total SA
Port Arthur
3,769,843,388
Valero Energy Corp.
Corpus Christi
2,307,404,143
Valero Energy Corp.
Houston
1,348,693,971
Valero Energy Corp.
Port Arthur
4,224,824,487
Valero Energy Corp.
Texas City
3,550,477,501
Shell Chemical Co.
Saraland
1,498,046,017
Calcasieu Refining Co.
Lake Charles
1,460,594,867
Calumet Lubricants Co.
Cotton Valley
243,806,989
Calumet Lubricants Co.
Princeton
155,422,274
Calumet Shreveport LLC
Shreveport
786,474,159
Citgo Petroleum Corp.
Lake Charles
8,042,634,556
ConocoPhillips
Belle Chasse
4,625,217,079
ConocoPhillips
Westlake
4,482,902,707
ExxonMobil Refining &
Supply Co.
Baton Rouge
9,418,964,335
Chalmette Refining LLC
Chalmette
3,609,541,879
Marathon Petroleum Co LLC
Garyville
4,587,765,928
Motiva Enterprises LLC
Convent
4,400,510,176
Motiva Enterprises LLC
Norco
4,535,334,318
January 28, 2009
64
-------
Petroleum Product Suppliers Technical Support Document
Motor Gasoline Emissions
Company
Refinery Location
(tonnes C02/Year)
Murphy Oil USA Inc.
Meraux
2,247,069,026
Placid Refining Co. LLC
Port Allen
1,048,632,212
Shell Chemical Co.
St. Rose
1,029,906,637
Valero Energy Corp.
Krotz Springs
599,218,407
Valero Energy Corp.
Norco
3,464,287,592
Chevron USA Inc.
Pascagoula
6,179,439,822
Cross Oil & Refining Co. Inc.
Smackover
114,976,349
Lion Oil Co.
El Dorado
1,117,825,613
Goodway Refining LLC
Atmore
65,472,643
Hunt Refining Co.
Tuscaloosa
550,928,338
Ergon Refining Inc.
Vicksburg
367,285,558
Hunt Southland Refining Co
Sandersville
175,658,311
Giant Refining Co.
Bloomfield
302,998,191
Giant Refining Co.
Gallup
375,140,618
Navajo Refining Co.
Artesia
1,514,990,957
Suncor Energy Products - U
Commerce City
1,372,990,864
Suncor Energy Products - U
Denver
708,640,446
Cenex Harvest States
Laurel
1,217,975,766
ConocoPhillips
Billings
1,284,410,808
ExxonMobil Refining &
Supply Co.
Billings
1,328,700,836
Montana Refining Co.
Great Falls
210,377,632
Big West Oil LLC - B
Salt Lake City
651,063,410
Chevron USA Inc.
Salt Lake City
996,525,627
Holly Corp.
Woods Cross
546,981,844
Silver Eagle Refining Inc.
Woods Cross
226,986,393
Tesoro West Coast Co.
Salt Lake City
1,284,410,808
Frontier Refining Inc.
Cheyenne
1,151,540,725
Sinclair / Little America
Casper
542,552,841
Silver Eagle Refining Inc.
Evanston
66,435,042
Sinclair Oil Corp.
Sinclair
1,461,570,920
Wyoming Refining Co.
Newcastle
310,030,195
ConocoPhillips Alasks
Kuparuk
89,275,231
BP PLC
Prudhoe Bay
74,396,026
Flint Hills Resources
North Pole
1,249,853,229
Petro Star Inc.
North Pole
104,154,436
Petro Star Inc.
Valdez
285,680,738
Tesoro Alaska Co.
Kenai
428,521,107
Big West Oil LLC
Bakersfield
416,617,743
BP PLC
Carson (Los Angeles)
1,577,195,741
Chevron Corp.
El Segundo
1,547,437,331
Chevron Corp.
Richmond
1,445,669,520
ConocoPhillips
Los Angeles (Carson
and Wilmington)
827,283,804
ConocoPhillips
Rodeo & Santa Maria
715,392,181
ExxonMobil Refining &
Supply Co.
Torrance
889,776,465
January 28, 2009
65
-------
Petroleum Product Suppliers Technical Support Document
Motor Gasoline Emissions
Company
Refinery Location
(tonnes C02/Year)
Greka Energy
Santa Maria
56,540,979
Kern Oil & Refining Co.
Bakersfield
154,743,733
Lunday Thagard Co
South Gate
50,589,297
Edgington Oil Co Inc
Long Beach
107,130,277
Paramount Petroleum Corp.
Long Beach
297,584,102
San Joaquin Refining Co.
Inc.
Bakersfield
89,275,231
Shell Oil Products US
Martinez
926,081,726
Shell Oil Products US
Wilmington
577,313,158
Tenby Inc
Oxnard
16,664,710
Tesoro Petroleum
Golden Eagle
987,979,219
Valero Energy Corp.
Benicia
857,042,214
Valero Energy Corp.
Wilmington
481,413,705
Valero Refining Co California
Wilmington
37,495,597
Chevron USA Inc.
Honolulu
321,390,830
Tesoro Hawaii Corp.
Kapolei
556,482,271
Foreland Refining Corp
Eagle Springs
11,903,364
BP PLC
Ferndale
1,339,128,459
ConocoPhillips
Ferndale
571,361,476
Shell Oil Products US
Anacortes
862,993,896
Tesoro West Coast Co.
Anacortes
714,201,845
US Oil & Refining Co.
Tacoma
225,271,165
All the refineries were found to have emissions greater than the specified thresholds i.e.
1,000, 10,000, 25,000, and 100,000 C02 tonnes/year from motor gasoline produced by
each refinery alone, and as a result the total emissions from all the petroleum products
for the refineries were obtained by multiplying the national production volume for each
product with their respective heating values and C02 emission factors.
Emissions from LPGs and NGLs were not included in our calculation of the total
emissions from all refinery petroleum products. Roughly 75 percent of all LPGs and
NGLs in the country in 2006 were used as non-combustion petrochemical feedstocks as
indicated by the API report - 2006 Sales of Natural Gas Liquids and Liquefied Refinery
Gases. The API report also indicates that about 46.2 percent of propane was used as
combustion fuel, the remaining 53.8 percent being used as petrochemical feedstock, in
year 2006. In addition, 9.7 percent of butane and 2.4 percent of ethane were used for
combustion purposes in 2006. None of the pentanes were used for combustion use.
About 68.6 percent of butane and 67.3 percent of pentanes plus were used as gasoline
blendstock in 2006.
An alternative approach to calculating the total emissions from all refinery petroleum
products would be to include emissions from NGLs and LPGs. This would be
accomplished by multiplying each NGL and LPG product by a product-specific carbon
content default value (see Exhibit 24) and by an oxidation factor - either the 40%
average or a product-specific factor.
January 28, 2009
66
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 23: Estimated National C02 Emissions from Refineries
Net Refinery Production
of Finished Petroleum
Products
Refinery Net Production
(Thousand Barrels per
year)
Refinery Net Production
(Tonnes C02/year)
Finished Motor Gasoline
3,035,705
1,130,618,005
Finished Aviation Gasoline
6570
2,294,294
Kerosene-Type Jet Fuel
540,565
217,197,737
Kerosene
17155
7,031,908
Distillate Fuel Oil
1,477,885
629,610,456
Residual Fuel Oil
231410
114,618,431
Petrochemical Feedstocks
143445
23,187,615
Special Naphthas
13140
5,154,664
Lubricants
66795
12,023,689
Waxes
5475
880,634
Petroleum Coke
309885
190,591,346
Asphalt and Road Oil
184690
37,058,759
Miscellaneous Products
25185
4,240,404
4.3.2. Importers
To conduct a threshold analysis for emissions from petroleum importers, United States
petroleum product importers and their respective petroleum product (asphalt, aviation
gasoline, butylene, distillate, ethane, ethylene, n-butane, isobutane, jet fuel, kerosene,
lubricants, motor gasoline, naphtha, other oils, pentanes plus, petcoke, propane,
residual fuel, and special naphtha) and blendstocks (GTAB, RBOB, and others) imports
were obtained from the EIA Company Reports for the year 2006
To calculate the C02 emissions per importer, the carbon emission factors (MMTC/1015
Btu) for the petroleum products (asphalt, aviation gasoline, distillate, ethane, n-butane,
isobutene, jet fuel, kerosene, lubricants, motor gasoline, other oils, pentanes plus,
petcoke, propane, and residual fuel) were obtained from the EIA, Emissions ofGHG in
the United States 2001 with the exception of naphthas, and special naphthas that were
obtained from the API Compendium ofGHG Estimation Methodologies for the Oil and
Gas Industry 2004. The carbon emission factors for ethylene, and butylene were
assumed to be the same as ethane and butane respectively. The blendstocks (GTAB,
RBOB, and others) were assumed to have the same carbon emission factor as motor
gasoline.
The carbon emission factors were converted to C02 emission factors by assuming 100
percent oxidation of the fuels with the exception of petrochemical feedstocks, waxes,
asphalt and road oil, and lubricants. Asphalt and road oil, waxes, lubricants, and
petrochemical feedstock are reported as NEU (non-energy use) fuels by EPA and emit
January 28, 2009
67
-------
Petroleum Product Suppliers Technical Support Document
an average of 40 percent of their carbon as emissions. As a result these fuels were
assumed to have 40 percent oxidation rate.The C02 emission factors (tonnes
C02/barrel) were calculated by multiplying the C02 emission factor (MMTCO2/1015 Btu)
with their corresponding heat content obtained from the EIA, Thermal Conversion
Factors 2008.
Exhibit 24: Calculated C02 Emission Factor.
Heat
Content
Emission Factor
MMTC/101b
Tonnes CO2/ bbl
Oxidation
Fuel
MMBtu/bbl
BTU
(calculated)
Rate
Motor Gasoline
5.25
19.34
0.37
100%
Petrochemical
Feedstocks
5.69
19.37
0.40
40%
Naphtha/ Reformer
Feed
5.25
0.07*
0.38
100%
Ethane
3.08
16.25
0.18
100%
Propane
3.84
17.2
0.24
100%
Butane
4.33
17.75
0.28
100%
Iso-butane**
3.97
.065*
0.26
100%
Butylene
4.33
17.75
0.28
100%
Ethylene
3.08
16.25
0.18
100%
Pentane Plus
4.62
21.49
0.33
100%
Kerosene
5.67
19.72
0.41
100%
Kerosene/Jet Fuel
5.67
19.33
0.40
100%
Aviation Gas
5.05
18.87
0.35
100%
Residual Fuel Oil
6.29
21.49
0.50
100%
Distillate
5.83
19.95
0.43
100%
Lubricants
6.07
20.24
0.45
40%
Asphalt and Road Oil
6.64
20.62
0.50
40%
Wax
5.54
19.81
0.40
40%
Petroleum Coke
6.02
27.85
0.62
100%
Special Naphthas
5.25
0.075*
0.39
100%
*These API values are in tonnes C02/MMBtu (average)
**lsobutane C02 emission factor is obtained from form EIA-1605, Fuel Emission Factors,
Appendix H
The C02 emissions per importer were estimated by multiplying the volume of petroleum
products and blendstock imported with the corresponding C02 emission factor (tonnes
C02/barrel).
Exhibit 25: Calculated C02 (tonnes/year) Emissions per Importer
Importers
Total Emissions
(tonnes C02/year)
AEROPRES CORP
55,446
AFTON CHEMICAL CORP
9,540
AGGREGATE INDUSTRIES
64,200
January 28, 2009
68
-------
Petroleum Product Suppliers Technical Support Document
Total Emissions
Importers
(tonnes C02/year)
AGRI-MARK INC
11,500
ALBINA ASPHALT
65,400
ALEUT ENTERPRISE LLC
93,850
ALL STATES ASPHALT INC
54,400
ALON USA LP
16,600
ALPAC MARKETING SERV
8,190
AMERICAN AGIP CO INC
513,990
AMERICAN HYDROTECH INC
9,400
AMERICAN REFINING GROUP
5,940
AMERICHEM SALES CORP
2,070
AMERIGAS PROPANE INC
43,055
AMMEX INC
163,940
ANDERES OIL INC
5,160
APEX OIL CO INC
372,680
ASTRA OIL CO LLC
1,418,390
ATLANTIC ENERGY INC
321,700
ATLANTIC TRADING MARKETING
1,635,320
AUTORE OIL CO
12,470
AVFUELCORP
7,370
AXMEN PROPANE INC
9,191
BARR BROTHERS INC
860
BETTER ROAD ASPHALT CORP
105,800
BHREAC PETROLEUM INC
58,800
BIRCHWOOD TRADING INC
25,000
BITUMAR
282,600
BLUE SEAL FEEDS INC
3,000
BLUE WATER OIL TRANSPORT
92,640
BOGNAR EJ INC
52,700
BOMINFLOT ATLANTIC LLC
582,000
BP CANADA ENERGY MKTG CORP
3,273,172
BP PRODUCTS N AMERICA INC
33,648,580
BP WEST COAST PRODUCTS LLC
100,400
BULK TRADING & TRANSP CO
17,000
BURLINGTON NORTHERN RR
361,200
B-V ASSOC INC
2,160
CAPEX INDUSTRIAL LTD
2,337,400
CARBON PRCSG RECLAMATION
LLC
207,500
CARGILL INC
246,050
CARIBBEAN PETROLEUM
1,359,220
CASS CITY OIL & GAS CO
55,470
CASTROL N AMER AUTOMOTIVE
INC
34,380
CAVALIER GAS CO
484
CENTENNIAL ENERGY LLC
258,736
CENTER OIL CO
181,890
January 28, 2009
69
-------
Petroleum Product Suppliers Technical Support Document
Total Emissions
Importers
(tonnes C02/year)
CHEMOIL CORP
6,731,500
CHEVRON PHILLIPS CHEM PR
CORE
28,080
CHEVRON PUERTO RICO LLC
22,200
CHEVRON USA INC
8,927,056
CHS INC
113,502
CM CARBON LLC
742,140
CIRCLE LUBRICANTS INC
3,780
CITGO ASPHALT REFINING CO
1,339,800
CITGO PETROLEUM CORP
20,899,760
CITY SERVICE VALCON
388,825
CLARK OIL TRADING CO
92,880
COCHIN PL LTD
2,275,847
COLEMAN OIL CO
46,220
COLONIAL OIL INDUSTRIES INC
20,387,430
CONOCOPHILLIPS CO
15,310,698
CONSUMERS ENERGY CO
69,000
CONTINENTAL MATERIALS INC
16,000
D & C TRANSPORTATION INC
7,498
DAIGLE OIL CO
2,580
DEAD RIVER CO
82,481
DELTA WESTERN INC
335,300
DOMTAR INDUSTRIES INC
131,000
DOW CHEMICALS CO THE
648,759
DOW HYDROCARBONS & RESRCS
INC
6,796,160
EASTERN AVIATION FUELS INC
14,250
EASTERN ENVIRONMENTAL
SERVICES
3,420
EMERALD KALAMA CHEMICAL LLC
162,640
ENTERPRISE CO INC
7,926,859
EQIUSTAR CHEMICALS LP
4,876,160
EQUITABLE OIL PURCHASING
83,420
EXXONMOBIL CHEMICAL
419,840
EXXONMOBIL OIL CORP
8,213,980
FARSTAD OIL INC
53,992
FERRELL NORTH AMERICA
37,975
FLINT HILLS RESOURCES LP
483,600
FORMOSA PLASTICS CORP USA
2,200,580
FUEL & MARINE MARKETING LLC
1,666,500
GAS CO THE
32,412
GAS SUPPLY RESOURCES INC
456,669
GAS SUPPLY RESOURCES LLC
581,721
GEORGIA PACIFIC CORP
678,280
GETTY PETROLEUM MARKETING
INC
162,060
January 28, 2009
70
-------
Petroleum Product Suppliers Technical Support Document
Total Emissions
Importers
(tonnes C02/year)
GIANT YORKTOWN INC
233,470
GLENCORE LTD
12,684,180
GLOBAL CO LLC
4,186,980
GOETZENERGY
112,010
GREAT LAKES CARBON LLC
2,379,560
GRIFFITH ENERGY DBA SEIMAX
163,994
GRIFFITH OIL CO INC
80,520
GULF OIL LP
50,310
HARBOR BUNKERING CORP
457,830
HAWAII FUELING FACILITIES CORP
928,800
HELM US CHEMICAL CORP
27,690
HERMAN OIL INC
27,090
HESS CORP
30,483,590
HOVENSA LLC
1,491,760
HUDSON LIQ ASPHALT INC
83,800
ICC CHEMICAL CORP
69,420
IDAHO ASPHALT SUPPLY INC
59,600
IDEMITSU LUBR AMERICA CORP
40,500
INERGY PROPANE LLC
49,343
INFINEUM USA LP
22,500
INTALCO ALUM CORP
112,220
IPC USA INC
810,780
IRVING OIL CORP
24,809,541
IRVING OIL TRANSPORTATION CO
325,600
ISLAND COUNTY PUBLIC WORKS
1,000
ISO BUNKERS LLC
6,500
JACKSON ENERGY AUTHORITY
2,310,740
JARON CORP
13,000
JENSEN NORMAN G INC
131,585
JET GAS INC
2,661
KATAHDIN PAPER CO LLC
217,500
KILDAIR SERVICE LTEE
327,000
KINETIC RESOURCES USA
120,214
KOCH SUPPLY & TRADING CO
1,761,940
KOLMAR AMERICAS INC
598,630
LAKES GAS CO
2,661
LANE CONSTR CORP
12,000
LAXFUEL CORP
5,650,800
LIQUID GAS CO
2,419
LOUIS DREYFUS ENERGY SVCS
LP
548,510
LUKOIL PAN-AMERICAS LLC
5,494,000
LUND OIL INC
14,835
MAGRABAR CHEMICAL CORP
540
MAINE PROPANE DSTR
29,267
MARATHON PETROLEUM CO LLC
4,244,131
January 28, 2009
71
-------
Petroleum Product Suppliers Technical Support Document
Total Emissions
Importers
(tonnes C02/year)
MATCON TRADING CORP
31,000
MCCAIN FOODS
11,000
MICHIGAN PETROLEUM TECH
71,810
MIDLAND ASPHALT INC
1,200
MIECO INC
244,750
MOORE OIL INC
2,150
MORGAN STANLEY CAPITAL GRP
INC
15,481,090
MOTIVA ENTERPRISES LLC
50,000
MX PETROLEUM CORP
98,040
NECO DSTR
274,250
NESTE OIL USA LLC
0
NEXT PETROLEUM LTD
115,950
NOBLE AMERICAS CORP
494,280
NOCO ENERGY CORP
150,913
NORTHERN ENERGY INC
161,576
NORTHLAND PRODUCTS CO
1,980
NORTHVILLE INDUSTRIES CORP
1,917,050
NORTHWEST PETROLEUM CO
67,940
NOVA CHEMICAL CORP
832,304
NRG ENERGY MARKETING
251,500
NYNAS USA INC
56,880
OWENS CORNING
27,000
PARAMOUNT PETOLEUM CORP
59,800
PARAMOUNT PETROLEUM CORP
12,400
PARKERS PROPANE GAS CO
89,737
PECKHAM INDUSTRIES INC
66,200
PENNZOIL QUAKER STATE CO
66,600
PETROBRAS AMERICA INC
3,393,370
PETRO-CANADA CHEMICAL INC
367,380
PETROLEUM DIAMOND INC
144,710
PETROLEUM MARINE SERVICE
161,690
PETROSOL INTL
69,419
PHILLIPS COIL CO
65,360
PIKE INDUSTRIAL INC
40,600
PLAINS MARKETING LP
377,625
PMI TRADING LTD
3,860,990
PONDEROSA PETROLEUM CO
17,500
PRSI TRADING LP
113,590
QUADRA ENERGY TRADING INC
88,528
RECOCHEM INC
12,720
RICH ENERGY INC
4,838
RIO ENERGY INTL
95,500
SABIC MARKETING AMERICAS INC
292,780
SAFETY-KLEEN CANADA INC
85,860
SALMON RESOURCES LTD
114,097
January 28, 2009
72
-------
Petroleum Product Suppliers Technical Support Document
Total Emissions
Importers
(tonnes C02/year)
SAMSUNG AMERICA INC
202,540
SARGEANT MARINE INC
68,800
SEA 3 INC
950,829
SEA 3 OF FLORIDA INC
714,029
SEMMATERIALS
107,400
SEMPRA ENERGY TRADING CORP
1,388,000
SEMSTREAM LP
625,017
SENECA PETROLEUM CO INC
27,000
SHELL CO PUERTO RICO LTD
5,000
SHELL GUAM INC
2,263,100
SHELL OIL PRODUCTS US PUGET
SOUND
16,000
SHELL US TRADING CO
7,406,470
SIMONS PETROLEUM INC
430
SK E & P CO
256,860
SONNEBORNINC
5,400
SPRAGUE ENERGY CORP
526,640
STATOIL MKTG & TRDG US INC
4,099,970
SUBURBAN PROPANE GAS CO
52,246
SUIT-KOTE CORP
25,000
SUNOCO INC
1,426,041
SWANSTON EQUIPMENT CO
16,800
TARGA MIDSTREAM SERVICES LP
2,622,810
TAUBER OIL CO
104,520
TAUBER PETROCHEMICAL CO
68,780
TESORO HAWAII CORP
135,590
TESORO PETROLEUM CORP
1,838,570
TEXAS PETROCHEMICALS LP
877,715
TEXPAR ENERGY LLC
393,680
TIDAL ENERGY MARKETING INC
163,606
TRAFIGURA AG
9,652,636
TRAMMOCHEM DIV OF
TRANSAMMONIA INC
131,430
TRANSMONTAIGNE PRODT SVCS
INC
312,500
TRIGEANT LTD
52,000
TRIPLE CLEAN OIL CO
39,500
ULTRAMAR ENERGY INC
2,339,570
UPS SUPPLY SERVICES
75,225
VALERO MARKETING & SUPPLY
CO
990,250
VITOL SA INC
31,932,359
WARNER PETROLEUM CORP
257,500
WARREN GE
14,725,500
WESTERN PETROLEUM CO
725,090
WESTPORT PETROLEUM INC
6,588,360
January 28, 2009
73
-------
Petroleum Product Suppliers Technical Support Document
Importers
Total Emissions
(tonnes C02/year)
WHATCOM BUILDERS INC
5,400
WHITE MOUNTAIN OIL CO INC
2,419
WILLIAMS OLEFINS LLC
171,009
The number of importers with emissions greater than the specified threshold emission
value was identified i.e. for the emission threshold value of 1,000 C02, and all importers
possessing total emissions >1000 C02were calculated. The total percent of emissions
covered by each threshold limit was calculated by dividing the total emissions covered
by the threshold limit with the total national emissions.
Exhibit 26: Threshold Analysis for Importers
Threshold (tonnes
C02/year)
1000
10,000
25,000
100,000
Emissions covered
(tonnes C02/year)
387,150,951
387,029,025
386,720,250
383,492,083
Percentage of
Emissions covered
100%
100%
99.89%
99.05%
Importers covered
218
192
173
119
Percentage of
importers covered
97%
86%
77%
53%
4.3.3. Exporters
According to the Rule both importers and exporters are to report volumes and emissions
at the company level. Import data is available on the EIA website. However, the
individual forms that have to be submitted by Exporters to the Department of Commerce
are only available for analysis under the FOIA. Consequently, no threshold analysis was
performed for Exporters.
4.4. Monitoring Method Costs
Monitoring costs were estimated for each refinery to perform the tests with their in-house
laboratories. Test methods for analyzing the carbon content of petroleum products
include ASTM D5291 (2007), ASTM D6730-01(2006)e1 and ASTM D6733-01(2006).
Alternatively refineries and importers can send the samples to an external lab for testing,
the cost of which will be dependant upon specific contract terms unique to each
company.
January 28, 2009
74
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 27: Refinery Monitoring and Reporting Costs
Annualized Capital Cost (2006$)
Operating & Maintenance Costs (includes
fixed and variable) - 2006$ (See O&M Tab)
Total Reporting Unit/ Facility Cost (Labor +
Capital + O&M)- 2006$
Respondent
Activity
Respondent Activity
Description
First Year
Second Year
First Year
Second Year
First Year
Second Year
First
Reporting
Period - First
Year
Subsequent
Reporting
Period -
First Year
Subsequent
Reporting
Period -
Second Year
First
Reporting
Period - First
Year
Subsequent
Reporting
Period - First
Year
Subsequent
Reporting
Period -
Second Year
First
Reporting
Period - First
Year
Subsequent
Reporting
Period -
First Year
Subsequent
Reporting
Period -
Second Year
Review of regulation
requirements, required data
and reporting process - (gap
analysis)
$-
$-
$-
$-
$-
$-
$ 5,235
$563
$664
Registration
Advice from legal counsel
and/ or outside consultants
$-
$-
$-
$-
$-
$-
$825
$261
$261
Register with EPA; provide
facility details, operation
parameters, etc.
$-
$-
$-
$-
$-
$-
$ 2,263
$231
$332
Identify the method and
frequency for monitoring
each input and output
$-
$-
$-
$-
$-
$-
$ 5,885
$462
$373
Monitoring
Monitoring OPTION 1: Use
existing data from other
reporting requirements or
internal company practices
(ex. EIA, FERC)
$-
$-
$-
$-
$-
$-
$-
$-
$-
Monitoring OPTION 2: Fuel
quantity measurement and
composition analysis from
in-house labs
$ 7,119
$21,357
$ 28,476
$ 12,500
$ 37,500
$ 50,000
$ 23,373
$ 59,533
$ 78,706
Monitoring OPTION 3: Fuel
quantity measurement and
third party composition
analysis
$-
$-
$-
$-
$-
$-
$-
$-
$-
Reporting
Data documentation and
report submission
$-
$-
$-
$-
$-
$-
$ 1,694
$535
$ 160
Archiving
Time required to file data
(hard copy and electronic)
$-
$-
$-
$-
$-
$-
$373
$373
$373
Auditing
Auditing assistance to EPA
audit
$-
$-
$-
$-
$-
$-
$-
$-
$842
January 28, 2009
75
-------
Petroleum Product Suppliers Technical Support Document
Exhibit 28: Refinery Unit Cost for Monitoring and Reporting
Monitoring
Option or
Fuels
Calculation
Method
Cost of Monitoring Instruments
Monitoring Costs ($/year)
Other Annual Costs -
(registration, reporting,
archiving, and auditing $/year)
Total Annual
Unit Cost -
Average
($/year)
Capital
Cost ($)
Equipment
Lifetime
(years)
Annualized
Capital Cost
($/year)
O&M Costs
($/year)
First Year
Second
Year
First Year
Second Year
Option 2
$ 200,000
10
$28,476
$50,000
$89,253
$ 79,079
$12,351
$2,631
$91,658
January 28, 2009
76
-------
Petroleum Product Suppliers Technical Support Document
Appendix
Source-specific Summary
Reporting Program/Guidance
Source Category
(or Fuel)
Coverage (Gases or
Fuels)
Coverage (Emissions
Types)
Coverage
(Threshold)
Level of Reporting
(e.g., facility, unit)
Points of Monitoring
Monitoring Methods for
Source/Fuel
Purpose of Method
(e.g, mandatory
reporting, voluntary
reDortina. etc)
Supplemental Data
Reported (e.g.,
production, capacity,
waste-in-olace)
Quality
Assu rance/Qual ity
Control Procedures
EIA reporting for Refineries
Petroleum
Refineries
Petroleum
N/A
Varied
Refinery
Throughout refinery
Meters
Mandatory Reporting
N/A
800, 810, 820 data
reconciled against
one another for
consistency
EPA reporting for Refineries
Petroleum
Refineries
Petroleum
NOx, VOC
No threshold
Refinery
Throughout refinery
Meters
Mandatory Reporting
N/A
Internal and random
in-person auditing
EIA reporting for Imports
Petroleum Imports
Petroleum
N/A
Varied
Importer
Pipeline - at border
Marine - at offload
Meters
Mandatory Reporting
N/A
Weekly and monthly
data reconciled
against each other for
consistency
EPA reporting for Imports
Petroleum Imports
Petroleum
NOx, VOC
No threshold
Importer
Pipeline - at border
Marine - at offload
Meters
Mandatory Reporting
N/A
Internal and random
in-person auditing
FERC reporting for Exports
Petroleum Exports
Petroleum
N/A
Based on revenue
Pipeline
At border
Meters
Mandatory Reporting
N/A
None currently
MMS reporting for Upstream
Production
Petroleum Others
Petroleum
N/A
No threshold
Federal land lessee
Lease meter
Meters
Mandatory Reporting
N/A
Royalty information
from OGOR and
PASR compared
FHWA reporting for Consumption
Petroleum Others
Petroleum
N/A
N/A
State agency
responsible for
collection of motor
fuel tax
Pump sales
Meters
Mandatory Reporting
N/A
None
Army Corps of Engineers reporting for
Marine Movements
Petroleum Others
Petroleum
N/A
Trips less than 1 mile
not required to be
reported
Domestic commercial
operator
Ports
Meters
Mandatory Reporting
N/A
Reconciliation with
dock receipts
Oil & Gas Journal
Worldwide Refinery Survey
Petroleum
Refineries
Petroleum
N/A
Refinery
None
January 28, 2009
77
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Refineries
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Energy
Information
Administration
EIA-800 Weekly Refinery
and Fractionator Report
Operators of all petroleum
refineries and fractionators
selected by the El A
90% (per weekly sample
selection procedure)
Input, production, stocks
(1000 bbl)
Refinery;
Stocks in custody of
refinery reported
regardless of ownership
Quantities of at least 500
barrels are reported
Weekly
Operating
information
Yes
No
800, 810 and 820
reconciled against
one another for
consistency
Report does not contain information on
carbon content of fuel
Energy
Information
Administration
EIA-810 Monthly Refinery
Report
Operators of all operating
and idle petroleum
refineries located in the 50
States, District of
Columbia, Puerto Rico, the
Virgin Islands, Guam, and
other U.S. possessions
All
Refinery input (1000 bbl),
Operable capacity of
atmospheric crude oil
distillation units on the
first day of the month
(barrels per calendar
day),
Weighted average sulfur
content of crude oil,
Weighted average API
gravity of crude oil,
Refinery operations:
beginning stocks,
receipts, inputs,
production, shipments,
fuel uses & losses,
ending stocks reported
for each product except
where field is shaded
Refinery;
Stocks in custody of
refinery reported
regardless of ownership
Quantities of at least 500
barrels are reported
Monthly
Operating
information
Yes
No
800, 810 and 820
reconciled against
one another for
consistency
Report does not contain information on
carbon content of fuel
Energy
Information
Administration
EIA-820 Annual Refinery
Report
All operating and idle
petroleum refineries
(including new refineries
under construction) and
refineries shutdown during
the previous year, located
in the 50 States, the District
of Columbia, Puerto Rico,
the Virgin Islands, Guam,
and other U.S. possessions
All
Quantity of natural gas
and coal purchased for
used as a fuel;
Quantity of electricity and
steam purchased for all
uses;
Receipts of crude oil
(domestic and foreign) by
method of transportation;
Operable capacity of
atmospheric crude oil
distillation units on the
first day of the year
(barrels per calendar day
and barrels per stream
day),
Downstream charge
capacity;
Production capacity
(barrels per stream day);
Storage capacity (1000
bbl)
Refinery
None
Annual
Operating
information
Yes
Operable
atmospheric crude oil
distillation capacity
available by refinery;
Other aggregated
data (by PADD and
state) available:
httD://www. eia. doe. a
800, 810 and 820
reconciled against
one another for
consistency
Report does not contain information on
carbon content of fuel
ov/oi l_gas/petroleum/
data_publ ications/ref i
nery_capacity_data/r
efcapacity.html
January 28, 2009
78
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Refineries (continued)
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Energy
Information
Administration
EIA-819 Monthly
Oxygenate Report
Operators of all facilities
that produce (manufacture
or distill) oxygenates
(including MTBE plants,
petrochemical plants, and
refineries that produce
oxygenates as part of their
operations located in the 50
States and the District of
Columbia
All
Production and stocks of
oxygenate products
(1000 bbl)
Stocks in custody of
refinery reported
regardless of ownership
500 barrels
Monthly
Operating
information
Yes
No
None
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20H Anti-
Dumping Program Annual
Report
Producers and importers of
reformulated gasoline (or
RBOB), conventional
gasoline, or applicable
blendstocks
All
Company ID,
Facilities represented,
Total volume of
conventional gasoline
produced or imported
(gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for
failure to comply;
internal auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20L
Reformulated Gasoline
Program NOx Emissions
Performance Averaging
Report
Producers and importers of
reformulated gasoline or
RBOB
All
Company ID,
Facility ID,
Total volume of averaged
reformulated gasoline or
RBOB (gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for
failure to comply;
internal auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20M
Reformulated Gasoline
Program VOC Emissions
Performance Averaging
Report
Producers and importers of
reformulated gasoline or
RBOB
All
Company ID,
Facility ID,
Total volume of averaged
reformulated gasoline or
RBOB (gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for
failure to comply;
internal auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
January 28, 2009
79
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Refineries (continued)
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Environmental
Protection
Agency
EPA Form DSF0600
Designate & Track Total
Volume Report
Facilities handling diesel
fuel including refiners and
importers
All
Company ID,
Facility ID,
Tax/dye/marker status,
Product type,
Received (gallon),
Delivered (gallon),
Produced (gallon),
Imported (gallon),
Beginning inventory
(gallon),
Ending inventory (gallon)
Fuel in custody of facility
reported regardless of
ownership
None
Annual
(Quarterly for truck
loading terminals)
Operating
information
Yes
No
Sanctions for
failure to comply;
internal auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Oil &Gas
Journal
Worldwide Refinery Survey
httD://oai research, stores, va
Country;
Location;
City;
State;
Number of plants;
Crude capacities;
Charge capacity for
vacuum dist.;
Thermal operations;
Catalytic reforming,
hydroc racking,
hydrorefining,
hydrotreating, and
cracking;
Production capacity for
alkylation;
Polymerization;
Aromatics;
Isomerization;
Lubes;
Oxygenates;
Asphalt;
Hydrogen;
Coke;
Sulfur
Annual
None
hoo. net/worrefsurlat. html
January 28, 2009
80
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Imports
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Energy
Information
Administration
EIA-814 Monthly Imports
Report
Company level imports
data available here:
httD://www. eia. doe. aov/oi I
gas/petroleum/data_publica
tions/companyjevelj mpor
ts/cli.html
All importers of record who
import crude or petroleum
products into the 50 States
and D.C. from foreign
countries, Puerto Rico, the
Virgin Islands, and other
U.S. possessions
Nearly all (transactions of
major products rarely have
volumes below reporting
threshold)
Importer information,
Type of commodity,
Port of entry,
Country of origin,
Quantity (1000 bbl),
Sulfur percent by weight
API gravity (crude only),
Name and location of
processing company
(crude and unfinished
products)
Importer of record
All transactions of at least
500 barrels are reported
Monthly
From foreign
supplier
Yes
Yes
Frame check
against Customs
Form 7501, try to
match companies
that are not in EIA
data
Report does not contain information on
carbon content of fuel
Energy
Information
Administration
EIA-804 Weekly Imports
Report
Selected importers of
record who import crude or
petroleum products into the
50 States and D.C. from
foreign countries, Puerto
Rico, the Virgin Islands,
and other U.S.
possessions;
Companies selected into
weekly sample must report
each week even if there
were zero imports
90% (per weekly sample
selection procedure)
Importer information,
Imports volume by
destination (entry port)
PADD,
Total crude oil imports by
country of origin
Importer of record
None
Weekly
T ransaction-
specific
information
Firms have raw
information but may
not compute these
specific numbers
without the reporting
requirement
No
Imported volumes
verified by ElA-814
Report does not contain information on
carbon content of fuel
Energy
Information
Administration
EIA-856 Monthly Foreign
Crude Oil Acquisition
Report
All firms reporting as of
June 1982 and all firms that
imported more than
500,000 bbl of foreign
crude for the report month
-90% (don't know how much
is "under the radar")
Importer information,
Country of origin,
API gravity,
Port of loading,
Port of destination,
Vessel or pipeline,
Terms and location of
acquisition,
Volume (bbl),
Price ($/bbl),
Landed cost ($/bbl),
Name of vendor
Importer
500,000 barrels of foreign
crude acquired
Monthly
At loading;
transaction-
specific
information
Yes
Aggregated data
Imported volumes
verified by El A-814
Carbon content could be derived from
raw data reported on crude imports
and crude oil assay data
Energy
Information
Administration
EIA-14 Refiners' Monthly
Cost Report
All refiners (except
independent natural gas
processors)
All
Refiner information,
Imported crude cost
($1000),
Imported crude volume
(1000 bbl)
Refiner
None
Monthly
Summary
information
Firms have raw
information but may
not compute these
specific numbers
without the reporting
reauirement
Aggregated data
Imported volumes
verified by El A-814
Report does not contain information on
carbon content of fuel
January 28, 2009
81
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Imports (continued)
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Environmental
Protection
Agency
EPA Form 3520-27 Load
Port/Port of Entry
Independent Sampling,
Testing and
Refi nery/l mporter
Identification Form
Importers of gasoline
All
Foreign refinery
registration number,
Importer registration
number and information,
Vessel information,
Gasoline volume
(gallons)
Importer
None
Per shipment
Operating
information
Yes
No
Sanctions for failure
to comply; internal
auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20H Anti-
Dumping Program Annual
Report
Producers and importers of
reformulated gasoline (or
RBOB), conventional
gasoline, or applicable
blendstocks
All
Company ID,
Facilities represented,
Total volume of
conventional gasoline
produced or imported
(gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for failure
to comply; internal
auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20L
Reformulated Gasoline
Program NQx Emissions
Performance Averaging
Report
Producers and importers of
reformulated gasoline or
RBOB
All
Company ID,
Facility ID,
Total volume of averaged
reformulated gasoline or
RBOB (gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for failure
to comply; internal
auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form 3520-20M
Reformulated Gasoline
Program VOC Emissions
Performance Averaging
Report
Producers and importers of
reformulated gasoline or
RBOB
All
Company ID,
Facility ID,
Total volume of averaged
reformulated gasoline or
RBOB (gallons)
Refiner / Importer
None
Annual
Operating
information
Gasoline volume: yes;
Compliance
calculations: no
No
Sanctions for failure
to comply; internal
auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
Environmental
Protection
Agency
EPA Form DSF0600
Designate & Track Total
Volume Report
Facilities including refiners
and importers of diesel fuel
All
Company ID,
Facility ID,
Tax/dye/marker status,
Product type,
Received (gallon),
Delivered (gallon),
Produced (gallon),
Imported (gallon),
Beginning inventory
(gallon),
Ending inventory (gallon)
Fuel in custody of facility
reported regardless of
ownership
None
Annual
(Quarterly for truck
loading terminals)
Operating
information
Yes
No
Sanctions for failure
to comply; internal
auditing for
completeness and
accuracy of
submitted data;
random in-person
audit by EPA's
enforcement office
Report does not contain information on
carbon content of fuel
January 28, 2009
82
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Exports
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Department of
Commerce
Commerce Form 7525-V
Shipper's Export
Declaration
Generally required for
shipment from the U.S. and
U.S. possessions to foreign
countries
All
Quantity (bbl),
Weight (kg)
N/A
N/A
Per shipment
T ransaction-
specific
information
Yes, operating
information
Aggregated export
statistics available
from Census Bureau
(EM-522, EM-594)
Unknown
Report does not contain information on
carbon content of fuel
January 28, 2009
83
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Others
Agency
Reporting Form Full
Official Title
Who must file the report?
What percent of facilities
and fuel flow does the report
capture? (i.e., what is the
coverage of the industry?)
What is Reported
(product and units?)
How is ownership of
the fuel throughput
treated in the report
form?
What is the threshold for
reporting, i.e., minimum
level of throughput or
facility size?
What is the frequency
of Reporting?
How does the
facility collect the
data reported?
Would the facility
need this
information without
the reporting
requirement?
Is the information
reported publicly
available? Any
restrictions?
What are the
Agency's QA/QC
requirements?
Summary Comments: How good is
this report for gaining an accurate
accounting of fuel and carbon?
Minerals
Management
Service
MMS-4054A Oil and Gas
Operations Report (OGOR)
Part A - Well Production
Federal offshore and
Federal/Indian onshore
MMS lessees
All MMS lessees
MMS lease/agreement
number;
Production month;
Operator information;
Operator well number;
Well status code;
Days produced;
Production volume (bbl
for oil);
Injection volume
Depends on the point of
royalty determination
None
Monthly, 45 days
following the reporting
month
Operating
information
Yes
Historical data
available:
httD://www. aomr. mm
s. gov/homepg/pubinf
o/freeasci/product/fre
eprod.html
Compliance asset
management
compares to
royalty on the MMS
2014
Report does not contain information on
carbon content of fuel
Minerals
Management
Service
M MS-4058 Production
Allocation Schedule Report
(PASR)
Operators of
facility/measurement point
handling production from
Federal offshore
Required for Federal offshore
only
Production number;
API gravity;
Operator information;
Operator/area/block;
Injector (oil/gas/both);
Metering point;
MMS lease/agreement
number;
Sales/transfers volume
Depends on the point of
royalty determination
None
Monthly, 45 days
following the reporting
month
Operating
information
Yes
No; Offshore
Minerals
Management (OMM)
has complete access
Compliance asset
management
compares royalty
information on
OGOR and PASR
Report does not contain information on
carbon content of fuel
Federal Highway
Administration
FHWA-551M Monthly
Motor-Fuel Consumption
State agencies that collect
the motor-fuel tax for their
respective states
All
State name,
Year and month of sale
or transfer,
Volumes (gallons or
liters)
N/A
N/A
Monthly
Tax record
Yes
Yes
None
Report does not contain information on
carbon content of fuel
Army Corps of
Engineers
ENG Form 3925 Vessel
Operation Report,
Statement of Freight and
Passengers Carried
All domestic operators
engaged in commercial
activity on navigable waters
Not all - 3925-B and 3925-P
may be submitted in lieu of this
form
Loading and discharge
information;
Cargo data: commodity,
quantity, unit, weight per
unit, net tons;
Shipper information
N/A
Trips less than 1 mile not
required to be reported
Monthly
Operating
information
Yes
Aggregated data
Data submissions
taken at face value
in general;
Some dock
receipts to
reconcile
Report does not contain information on
carbon content of fuel
Army Corps of
Engineers
ENG Form 3925B Vessel
Operation Report,
Statement of Freight and
Passengers Carried
(Shallow Draft Inland
T raffic)
Shallow draft barge and
tow boat operators
All
Vessel information;
Origin and destination
information;
Cargo data: commodity,
tons
N/A
Trips less than 1 mile not
required to be reported
Monthly
Operating
information
Yes
Aggregated data
Data submissions
taken at face value
in general;
Some dock
receipts to
reconcile
Report does not contain information on
carbon content of fuel
January 28, 2009
84
-------
Petroleum Product Suppliers Technical Support Document
Petroleum Administration
for Defense Districts
PADD
West
AK,
January 28, 2009
85
-------
Petroleum Product Suppliers Technical Support Document
Oil & Gas Journal 200, 2006
2006 Worldwide
2006 U.S. Liquids
Company
Liquids Production
Production (Million
(Million Bbl)
Bbl)
BP
213.89
ExxonMobil Corp.
832.00
116.00
ConocoPhillips
534.00
162.00
Chevron Corp.
632.00
169.00
Anadarko Petroleum Corp.
86.00
54.00
Devon Energy Corp.
78.00
38.00
Occidental Petroleum Corp.
142.00
98.00
Marathon Oil Corp.
86.00
28.00
El Paso Corp.
7.69
7.44
Chesapeake Energy Corp.
6.76
6.76
Apache Corp.
86.25
27.31
Amerada Hess Corp.
94.00
17.00
Dominion Exploration & Production
24.95
9.75
XTO Energy Inc.
20.80
20.80
Noble Energy Inc.
27.34
16.72
EOG Resources, Inc.
13.65
10.68
Williams Cos. Inc.
NA
NA
Murphy Oil Corp.
27.70
7.70
Pioneer Natural Resources Co.
17.82
14.09
Pogo Producing Co.
13.48
8.11
Newfield Exploration Co.
9.00
7.80
Questar Corp.
2.60
2.60
Cimarex Energy Co.
0.27
0.27
Helix Energy Solutions Group Inc.
3.40
3.40
Petrohawk Energy Corp.
1.56
1.56
Forest Oil Corp.
8.03
6.89
Range Resources Corp.
4.25
4.25
W&T Offshore Inc.
6.46
6.46
Cheniere Energy Inc.
0.00
0.00
Whiting Petroleum Corp.
0.67
6.70
Plains Exploration & Production Co.
18.98
18.98
Southwestern Energy Co.
0.70
0.70
Denbury Resources Inc.
8.37
8.37
Stone Energy Corp.
5.59
5.59
Encore Acquisition Co.
7.34
7.34
St. Mary Land & Exploration Co.
6.06
6.06
Quicksilver Resources Inc.
1.33
1.33
Comstock Resources Inc.
2.30
2.30
Unit Corp.
1.45
1.45
Kinder Morgan C02 Co. LP
15.63
15.63
Cabot Oil & Gas Corp.
1.42
1.42
Energen Resources Corp.
3.65
3.65
Equitable Supply
0.11
0.11
Houston Exploration Co.
0.94
0.94
Penn Virginia Corp.
0.38
0.38
Swift Energy Co.
7.90
7.18
ATP Oil & Gas Corp.
3.27
3.25
Ultra Petroleum
2.20
0.59
Rosetta Resources Inc.
0.58
0.58
Seneca Resources Corp.
3.61
3.34
Berry Petroleum Co.
7.18
7.18
Bill Barrett Corp.
0.70
0.70
Fidelity Exploration & Production Co.
2.10
2.10
CNX Gas Corp.
Energy Partners Ltd.
3.01
3.01
Delta Petroleum Corp.
1.35
1.35
Petroleum Development Corp.
0.63
0.63
Clayton Williams Energy Inc.
2.37
2.37
Belden & Blake Corp.
0.37
0.37
Callon Petroleum Co.
1.63
1.63
DTE Gas & Oil Co.
NA
NA
January 28, 2009
86
-------
Petroleum Product Suppliers Technical Support Document
Peoples Energy Production
0.35
0.35
Brigham Exploration Co.
0.44
0.44
PetroQuest Energy Inc.
0.70
0.70
Carrizo Oil & Gas
0.26
0.26
Goodrich Petroleum Corp.
0.47
0.47
Meridian Resource Corp.
0.86
0.86
Quest Resources Inc.
0.01
0.01
Parallel Petroleum Corp.
1.15
1.15
McMoran Exploration Co.
1.55
1.55
Black Hills Corp.
0.40
0.40
Atlas America Inc.
0.15
0.15
Warren Resources
0.46
0.46
Edge Petroleum Corp.
0.57
0.57
Toreador Resources Corp.
0.58
0.06
Prime Energy Corp.
0.38
0.38
Legacy Reserves LP
0.75
0.75
Aurora Oil & Gas Corp.
0.02
0.02
GMX Resources Inc.
0.07
0.07
Challenger Minerals, Inc.
0.54
0.10
Gulfport Energy Corp.
0.87
0.87
NGAS Resources Inc.
0.04
0.04
Arena Resources Inc.
0.90
0.90
Dorchester Mineral Ltd.
0.34
0.34
Gasco Energy Inc.
0.02
0.02
Cano Petroleum Inc.
0.19
0.19
Exploration Co.
0.79
0.79
Harken Energy Corp.
0.17
0.17
Abraxas Petroleum Corp.
0.20
0.20
Contango Oil & Gas Co.
0.04
0.04
Crimson Exploration Inc.
0.18
0.18
Panhandle Royalty Co.
0.10
0.10
American Oil & Gas Inc.
0.04
0.04
New Century Energy Corp.
0.12
0.12
Double Eagle Petroleum Co.
0.01
0.01
Hallador Petroleum Co.
Infinity Inc.
0.08
0.08
Dune Energy Inc.
0.04
0.04
PRB Energy Inc.
Evolution Petroleum Corp.
0.05
0.05
Galaxy Energy Corp.
Credo Petroleum Corp.
0.04
0.04
Teton Energy Corp.
FX Energy Inc.
0.09
0.09
Petrol Oil & Gas Inc.
0.02
0.02
Westside Energy Corp.
0.02
0.02
Royale Energy Inc.
0.02
0.02
New Frontier Energy Inc.
Tri-Valley Corp.
0.01
0.01
Tengasco Inc.
0.19
0.19
San Juan Basin Royalty Trust
0.04
0.04
Adams Resources & Energy Inc.
0.08
0.08
Cross Timbers Royalty Trust
0.14
0.14
Houston American Energy Corp.
0.05
0.02
EnDevCo Inc.
0.03
0.03
Aspen Exploration Corp.
Daleco Resources Corp.
0.01
0.01
VTEX Energy Inc.
0.00
0.00
Reserve Petroleum Co.
0.03
0.03
GeoResources Inc.
0.13
0.13
United Heritage Corp.
0.01
0.01
Cubic Energy Inc.
0.00
0.00
Spindletop Oil & Gas Co.
0.03
0.03
Blue Dolphin Energy Co.
0.00
0.00
Basic Earth Science Systems Inc.
0.10
0.10
Petro Resources Corp.
0.00
0.00
Fieldpoint Petroleum Corp.
0.05
0.05
John D. Oil and Gas Co.
0.00
0.00
January 28, 2009
87
-------
Petroleum Product Suppliers Technical Support Document
Permian Basin Royalty Trust
0.75
0.75
Sabine Royalty Trust
0.46
0.46
Miller Petroleum Inc.
0.01
0.01
GSV Inc.
0.00
0.00
LL&E Royalty Trust
0.04
0.04
Bayou City Exploration Inc.
0.00
0.00
Ness Energy International Inc.
0.00
0.00
Lucas Energy Inc.
0.01
0.01
Capco Energy Inc.
NA
NA
Empiric Energy Inc.
NA
NA
Petrol Industries Inc.
NA
NA
Shell Exploration and Production Company
Companies listed in OGJ 2005 but not in 2006
Altex Industries Inc.
Blue Ridge Energy Inc.
Burlington Resources Inc.
Cadence Resources Corp.
EnCana
Hunt Oil Company
KCS Energy Inc.
Kerr-McGee Corp.
Kestrel Energy Inc.
Natural Gas Systems Inc.
Oneok Inc.
Remington Oil & Gas Corp.
Resource America, Inc.
Torch Energy Services
TotalFinaElf
Trek Resources Inc.
Unocal Corp.
Venoco
W & T Offshore, Inc.
Western Gas Resources
Westside Energy Corp.
Whittier Energy Corp.
January 28, 2009
88
------- |