2011-2017 Greenhouse Gas Reporting Program
Industrial Profile: Petroleum and Natural Gas Systems

October 2018


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Contents

Introduction	3

Petroleum and Natural Gas Systems in the GHG Reporting Program	4

Reported GHG Emissions from Petroleum and Natural Gas Systems	6

Reported Emissions by Industry Segment	6

Reported Emissions by Greenhouse Gas	7

Reported Combustion and Process Emissions	7

Reported GHG Emissions by Industry Segment and Source	9

Onshore Production	9

Offshore Production	12

Gathering and Boosting	13

Natural Gas Processing	16

Natural Gas Transmission Compression	16

Natural Gas Transmission Pipeline	17

Underground Natural Gas Storage	17

LNG Import/Export	18

LNG Storage	18

Natural Gas Distribution	18

Changes from 2011 to 2017	20

Changes in Number of Facilities	20

Changes in Reported Emissions	20

Additional Information	23

Glossary	23


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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Petroleum and Natural Gas Systems

Introduction

In Fall 2018, the U.S. Environmental Protection Agency
(EPA) released 2017 greenhouse gas (GHG) data for
Petroleum and Natural Gas Systems1 collected under the
Greenhouse Gas Reporting Program (GHGRP). The GHGRP,
which was required by Congress in the Fiscal Year 2008
Consolidated Appropriations Act, requires facilities to
report data from large emission sources across a range of
industry sectors, as well as from suppliers of certain
greenhouse gases and products that would emit GHGs if
released or combusted.

The data show 2017 GHG emissions from 2,253 facilities
conducting Petroleum and Natural Gas Systems activities,
such as production, gathering and boosting, processing,
transmission, and distribution. In total, these facilities
accounted for GHG emissions of 284 million metric tons of
carbon dioxide equivalent (CChe). In 2017, reported GHG emissions from Petroleum and Natural
Gas Systems represented 9.8% of emissions reported to the GHGRP.

When reviewing these data and comparing them to other data sets or published literature, it is
important to understand the GHGRP reporting requirements and the impacts of these requirements
on the reported data. Facilities used uniform methods prescribed by the EPA to calculate GHG
emissions, such as direct measurement, engineering calculations, or emission factors derived from
direct measurement In some cases, facilities had a choice of calculation methods for an emission
source.

Petroleum and Natural Gas Systems is one of the more complex source categories within the GHGRP
because of the number of emission sources covered, technical complexity, variability in the
calculation methods used for a particular emission source, and variability across facilities. It is
expected that there can be differences in reported emissions from one facility to another. As
described in more detail below, there is a reporting threshold, and the reporting requirements do
not cover certain emission sources. Thus the data do not represent the entire universe of emissions
from Petroleum and Natural Gas Systems. Starting with data reported for 2016, facilities reported
emissions from select emission sources in gathering and boosting systems, blowdown emissions
from natural gas transmission pipelines, emissions from oil well completions and workovers with
hydraulic fracturing, and well identification numbers for onshore production wells. While changes
in the total number of reporting facilities can cause changes in total reported emissions from year-
to-year, a number of factors, such as those detailed above, contribute to differences as well. All of
these factors could impact cross-segment, cross-source, or cross-facility comparisons.

There are also considerations to keep in mind when drawing conclusions about the deferred
activity data reported for 2011-2013, as part of the reporting year 2014 submissions. While many
facilities in this sector submitted deferred data, certain facilities might not have reported this

1 The implementing regulations ofthe Petroleum and Natural Gas Systems source category of the GHGRP are located at 40 CFR
Part 98 Subpart W.

All emissions presented here
reflect the most recent
information reported to EPA as of
8/19/2018. The reported
emissions exclude biogenic CO2.
GHG data displayed here in units
of carbon dioxide equivalent
(CC>2e) reflect the global warming
potential (GWP) values from
Table A-l of 40 CFR 98, which is
generally based on the IPCC AR4.
with the addition of GWPs from
the IPCC AR5 for fluorinated
GHGs that did not have GWPs in
the AR4.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

information for legitimate reasons. These include changes in ownership and not having reported to
the GHGRP in a previous year for a valid reason. In addition, the reporting requirements were
significantly revised in 2014, so some activity data reported in 2015 and later reporting years are
not available for previous years. It is important to be aware of these limitations and differences
when using this data, particularly when attempting to draw broad conclusions about emissions and
activities from this sector.

Petroleum and Natural Gas Systems in the GHG Reporting Program

The Petroleum and Natural Gas Systems source category of the GHGRP (Subpart W) requires
reporting from the following 10 industry segments for 2017:

•	Onshore Production - Production of petroleum and natural gas associated with onshore
production wells and related equipment;

•	Offshore Production - Production of petroleum and natural gas from offshore production
platforms;

•	Gathering and Boosting - Gathering pipelines and other equipment that collect
petroleum/natural gas from onshore production gas or oil wells and then compress,
dehydrate, sweeten, or transport the petroleum and/or natural gas;

•	Natural Gas Processing - Processing of field-quality gas to produce pipeline-quality natural
gas;

•	Natural Gas Transmission Compression - Compressor stations used to transfer natural gas
through transmission pipelines;

•	Natural Gas Transmission Pipeline - A rate-regulated interstate or intrastate pipeline, or a
pipeline that falls under the "Hinshaw Exemption" of the Natural Gas Act;

•	Underground Natural Gas Storage - Facilities that store natural gas in underground
formations;

•	Liquefied Natural Gas (LNG) Import/Export - Liquefied Natural Gas import and export
terminals;

•	LNG Storage - Liquefied Natural Gas storage equipment; and

•	Natural Gas Distribution - Distribution systems that deliver natural gas to customers.

Figure 1 below illustrates the segments of the Petroleum and Natural Gas Systems source category
that were required to report under the GHGRP for 2017.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 1: Petroleum and Natural Gas operations covered by the GHG Reporting Program

Petroleum and Petroleum
Product Suppliers

Large end-user
emissions reported
under relevant subparts
for other industries.

¦MIU

Production & Processing Natural Gas Transmission & Storage

1.	Onshore Petroleum & Natural Gas
Production

2.	Offshore Petroleum & Natural Gas
Production

3.	Total Crude Oil to Refineries

4.	Petroleum Refining

5.	Gathering and Boosting

'Data collection began in RY 2016

6.	Gas Processing Rant

'May contain NGL Fractionation equipment

7.	Natural Gas Liquids (NGL) Supply

8.	Transmission Compressor Stations

9.	Underground Storage

10.	Liquified Natural Gas (LNG) Storage

11.	LNG Import-Export Equipment

12.	Natural Gas Transmission Pipeline
"Data collection began in RY 2016

Distribution

13.	Large End Users

14.	Natural Gas Distribution

15.	Natural Gas & Petroleum Supply
to Small End Users

Subpart W; Emissions from petroleum & natural
gas systems

Subpart Y: Emissions from petroleum refineries

Subpart MM: C02 associated with supplies of
petroleum products

Subpart NN: C02 associated with supplies of
natural gas & natural gas liquids

Not reported under GHGRP

Note: Certain petroleum and/or natural gas operations are covered by subparts of the GHGRP other than
Subpart W or began reporting GHG data starting with the 2016 reporting year.

Other segments of the petroleum and natural gas industry are covered by the GHGRP but not
included in the Petroleum and Natural Gas Systems (Subpart W) source category such as
Petroleum Refineries (Subpart Y), Petrochemical Production (Subpart X), Suppliers of Petroleum
Products (Subpart MM), and Suppliers of Natural Gas and Natural Gas Liquids (Subpart NN}.

As noted above, the GHGRP also includes reporting of stationary fuel combustion emissions from
facilities that are associated with the petroleum and natural gas industry, but that do not report
process emissions from any of the above source categories, such as certain facilities that have a
North American Industry Classification System (NAICS) code beginning with 211 (the general
NAICS for oil and gas extraction). These facilities are referred to as "Other Oil and Gas Combustion"
in this document.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

The GHGRP covers a subset of national emissions from Petroleum and Natural Gas Systems. A
facility in the Petroleum and Natural Gas Systems source category is required to submit annual
reports if total emissions are 25,000 metric tons carbon dioxide equivalent (C02e) or more.

The EPA has a multi-step data verification process, including automatic checks during data-entry,
statistical analyses on completed reports, and staff review of the reported data.2 Based on the
results of the verification process, the EPA follows up with facilities to resolve mistakes that may
have occurred during the reporting period.

The EPA has made available the optional use of best available monitoring methods (BAMM) for
targeted circumstances where the EPA made recent changes to GHGRP monitoring requirements
for Petroleum and Natural Gas Systems.3 In certain previous reporting years, in order to provide
facilities with time to adjust to the requirements of the GHGRP, the EPA made available the optional
use of BAMM for unique or unusual circumstances. Where a facility used BAMM for any reporting
year, it was required to follow emission calculations specified by the EPA but allowed to use
alternative methods for determining inputs to calculate emissions. Examples of BAMM include
monitoring methods used by the facility that do not meet the specifications of 40 CFR Part 98
Subpart W, supplier data, engineering calculations, and other company records. As of reporting
year 2017, no facilities are approved to use BAMM any longer.

Reported GHG Emissions from Petroleum and Natural Gas Systems

The following section provides information on reported GHG emissions by industry segment,
greenhouse gas, and combustion and process emissions for the 2017 calendar year.

Reported Emissions by Industry Segment

The 2017 calendar year was the seventh year that GHG emissions from Petroleum and Natural Gas
Systems activities were required to be collected. Annual reports were due to the EPA by April 2,
2018. The EPA received reports from 2,253 facilities4 with Petroleum and Natural Gas Systems
activities, with total reported GHG emissions of 284 million metric tons (MMT) C02e.

Table 1 presents number of facilities and reported emissions in 2017 by industry segment. The
largest industry segment in terms of reported GHG emissions was onshore production, with a total
of 94 MMT CC>2e, followed by gathering and boosting, with reported emissions of 75 MMT C02e.
Natural gas processing accounted for 56 MMT CC^e. The next largest segment was natural gas
transmission compression, with reported emissions of 24 MMT C02e. Reported emissions from
natural gas distribution totaled 13 MMT C02e. The remaining segments accounted for total
reported emissions of approximately 22 MMT C02e.

2	Access more information on verification.

3	Access more information on BAMM.

4	In general, a "facility" for purposes of the GHGRP means all co-located emission sources that are commonly owned or
operated. However, the GHGRP has developed specialized facility definitions for onshore production, gathering and boosting
natural gas transmission pipeline, and natural gas distribution. For onshore production, the "facility" includes all emissions
associated with wells owned or operated by a single company in a specific hydrocarbon producing basin (as defined by the
geologic provinces published by the American Association of Petroleum Geologists). For gathering and boosting a "facility"
means all gathering pipelines and other equipment located along those pipelines that are under common ownership or
common control by a gathering and boosting system owner or operator and that are located in a single hydrocarbon basin. For
natural gas transmission pipeline, a "facility" means the total U.S. mileage of natural gas transmission pipelines, owned and
operated by an onshore natural gas transmission pipeline owner or operator. For natural gas distribution, a "facility" is a local
distribution company as regulated by a single state public utility commission.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Table 1: 2017 Reported Emissions by Industry Segment

Industry Segment

Number of Facilities

Reported Emissions
(Million Metric Tons C02e)

Onshore Production

497

94

Offshore Production

141

7

Gathering and Boosting

321

75

Natural Gas Processing

449

56

Natural Gas Transmission Compression

529

24

Natural Gas Transmission Pipeline

33

3

Underground Natural Gas Storage

48

1

LNG Import/Export

6

4

LN G Storage

6

<1

Natural Gas Distribution

169

13

Other Oil and Gas Combustion

79

7

Total

2,253

284

Note: The total number of facilities that reported to the GHGRP for 2017 is smaller than the sum of facilities from
each segment because some facilities reported under multiple segments. A facility is included in the count of
number of facilities if it reported emissions (even if the reported emissions were zero) under a given segment.

Reported Emissions by Greenhouse Gas

Figure 2 presents reported emissions in 2017 by industry segment and greenhouse gas. For all
segments combined, carbon dioxide (CO2) emissions accounted for 196 MMT C02e of reported
emissions and methane (CH4) emissions accounted for 88 MMT C02e of reported emissions. Nitrous
oxide (N2O) emissions accounted for 0.1 MMT C02e of reported emissions.

Figure 2: 2017 Reported Emissions by Greenhouse Gas

Onshore Production
Offshore Production
Gathering and Boosting
Natural Gas Processing
Natural Gas Transmission Compression
Natural Gas Transmission Pipeline
Underground Natural Gas Storage
LNG Import/Export
LNG Storage
Natural Gas Distribution
Other Oil and Gas Combustion

Emissions, MMT C02e

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

20

40

60

80

100

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Reported Combustion and Process Emissions

Each segment of Petroleum and Natural Gas Systems includes a combination of emission sources.
Emissions may result from the combustion of fossil fuels or from process sources that result in
the direct emission of GHGs. Reported combustion emissions in Petroleum and Natural Gas
Systems totaled 158 MMT C02e and reported process emissions totaled 127 MMT C02e. Figures 3
and 4 present reported combustion and process emissions in 2017 by industry segment and
emission source, respectively.

Figure 3: 2017 Reported Combustion and Process

20	40	60

Emissions, MMT C02e

80

100

Note: Segment totals may not equal sum of process and combustion emissions due to independent rounding.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 4: 2017 Reported Process Emission Sources

Pneumatic Devices
Misc Equipment Leaks
Acid Gas Removal Units
Associated Gas Venting and Flaring
Other Flare Stacks
Atmospheric Storage Tanks
Distribution Mains
Blowdown Vent Stacks
Distribution Services
Reciprocating Compressors
Well Compl. and Work, with HF
De hydra tors
Pneumatic Pumps
Centrifugal Compressors
Liquids Unloading
Offshore Sources
Distribution M-R Stations
Transmission Tanks
Gas Well Compl. and Work, without HF
Well Testing
Enhanced Oil Recovery Liquids
Enhanced Oil Recovery Pumps

IC02 Emissions
ICH4 Emissions
N20 Emissions

10	15	20

Emissions, MMT C02e

25

30

35

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Reported GHG Emissions by Industry Segment and Source

The following section provides information on reported GHG emissions organized by industry
segment. For each segment, the top reported emission sources are presented.

Onshore Production

The EPA received annual reports from 497 facilities in the onshore production segment and
reported emissions totaled 93.8 MMT C02e. Methane emissions totaled 44.0 MMT C02e and carbon
dioxide emissions totaled 49.8 MMT C02e. Combustion equipment (30.7 MMT C02e) and pneumatic
devices (25.5 MMT CChe) were the top reported emission sources, followed by associated gas
venting and flaring (10.5 MMT C02e), miscellaneous equipment leaks (7.8 MMT C02e), atmospheric
tanks (6.8 MMT C02e), and other flare stacks (3.2 MMT C02e). Onshore production emissions by
greenhouse gas from the top reported emission sources are presented in Figure 5 for 2017.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 5: 2017 Onshore Production: Top Reported Emission Sources

Combustion Equipment
Pneumatic Devices
Associated Gas Venting and Flaring
Misc Equipment Leaks
Atmospheric Storage Tanks
Other Flare Stacks
Well Compl. and Work, with HF
Pneumatic Pumps
Liquids Unloading

10	15	20

Emissions, MMT C02e

C02 Emissions
CH4 Emissions
N20 Emissions

35

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 6 shows 2017 onshore production reported emissions by basin.

Range

~

1,000-158,000
150.080-500.000

500,000-1,500,000
1,500,000 - 5,000,000
5,000,000 - 10,000,000
10,000,000 -15,000,000

Basin refers to the geological provinces as published by the American Association of Petroleum Geologists (AAPG).
Data Source: 2017 Greenhouse Gas Reporting Program as of 8/19/2018.

GHGRP, 2017

Emissions by Basin

Onshore Petroleum and Natural Gas

Production

(metric tons CChe)

Figure 6: 2017 Onshore Production Reported Emissions (COze) by Basin

tors

Starting with data reported for 2016, onshore production facilities reported well identification
numbers and certain emission source types associated with wells. A well identification number is
either the US Well Number (formerly referred to as the API Well Number, or API Number), or the
unique well number assigned by its permitting authority if the well does not have a US Well
Number.5 Figure 7 shows 2017 well count by county for onshore production facilities.

8 Professional Petroleum Data Management Association. The US Well Number Standard: An Identifier for Petroleum Industry
Wells in the USA. Version 2013 rev 1, published June 19, 2014.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 7: 2017 Onshore Production Weil Count by County







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(wells)

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50-200

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1,000-2,000

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Data Source: 2017 Greenhouse Gas Reporting Program as of 8/19/2018; image updated Sept. 2019.

Offshore Production

The EPA received annual reports from 141 facilities in the offshore production segment that totaled
7.0 MMT CChe. For offshore production, facilities calculate process emissions using requirements
that were established by the Bureau of Ocean Energy Management (BOEM). In addition, the GHGRP
collects data on combustion emissions. While the full list of process emission sources is extensive, it
can generally be categorized into vented emissions, flaring, and equipment leaks. The top reported
source of emissions for offshore production was from combustion (5 MMT CC^e), followed by
venting (1 MMT CC^e). See Figure 8 below for offshore emissions by emission source category.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 8: 2017 Offshore Production: Top Reported Emission Sources

Combustion
Venting

Equipment Leaks	C02 Emissions

¦ CH4 Emissions

Flanng	"N20 Emissions

2	3	4

Emissions, MMT C02e

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Figure 9 shows 2017 facility locations and reported emissions (C02e) for offshore production
facilities.

Figure 9: 2017 Offshore Production Facility Locations and Reported Emissions (C02e)





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Offshore Production
(metric tons C02e)

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2017 emissions
(metric tons C02e)

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Data Source: 2017 Greenhouse Gas Reporting Program as of 8/19/2018.

Gathering and Boosting

The gathering and boosting segment was first reported in 2016. In 2017, the EPA received annual
reports from 321 facilities in the gathering and boosting segment and reported emissions totaled

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

75.0 MMT C02e. Methane emissions totaled 19.3 MMT C02e and carbon dioxide emissions totaled
55.7 MMT C02e. Combustion equipment (52.5 MMT C02e) was the top reported emission source,
followed by miscellaneous equipment leaks (6.2 MMT C02e), pneumatic devices (4.9 MMT C02e),
and atmospheric tanks (2.9 MMT C02e). See Figure 10 below for gathering and boosting emissions
by greenhouse gas for the top reported emission sources in 2017.

Figure 10: 2017 Gathering and Boosting: Top Reported Emission Sources

Combustion Equipment
Misc Equipment Leaks
Pneumatic Devices
Atmospheric Storage Tanks
Other Flare Stacks
Blowdown Vent Stacks
Dehydrators
Centrifugal Compressors
Pneumatic Pumps
Acid Gas Removal Units

Reciprocating Compressors

IC02 Emissions
ICH4 Emissions
N20 Emissions

10	20	30	40

Emissions, MMT C02e

-r-

50

60

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Figure 11 shows 2017 gathering and boosting reported emissions by basin.

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2011-2017 GHGRP Industrial Profile	Petroleum and Natural Gas Systems

1.000-150,000
150.060-500.000

500,000 -1,500,000
1,500,000-5,000,000
5,000,000 -10,000,000
10,000,000 - 15,000,000

Data Source: 2017 Greenhouse Gas Reporting Program as of 8/19/2018.

Figure 11: 2017 Gathering arid Boosting Reported Emissions (C02e) by Basin

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GHGRP, 2017
Emissions by Basin
Onshore Petroleum and Natural
Gas

Gathering & Boosting
(metric tons (C02e)

Range

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Natural Gas Processing

The EPA received annual reports from 449 facilities in the natural gas processing segment, and
reported emissions totaled 55.8 MMT C02e. Methane emissions totaled 3.1 MMT C02e, and carbon
dioxide emissions totaled 52.7 MMT CChe. As presented in Figure 12, the top reported emission
sources were combustion equipment (37.6 MMT C02e), acid gas removal units (11.3 MMT C02e),
and other flare stacks (4.1 MMT C02e).

Figure 12: 2017 Natural Gas Processing: Top Reported Emission Sources

Combustion Equipment
Acid Gas Removal Units
Other Flare Stacks
Reciprocating Compressors
Blowdown Vent Stacks
Centrifugal Compressors
Dehydrators
Misc Equipment Leaks

0	5	10	15	20	25	30	35	40

Emissions, MMT C02e

r

i

IC02 Emissions
ICH4 Emissions
N20 Emissions

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Natural Gas Transmission Compression

The EPA received annual reports from 529 facilities in the natural gas transmission compression
segment, and reported emissions totaled 24.2 MMT C02e. Methane emissions totaled 3.8 MMT C02e
and carbon dioxide emissions totaled 20.3 MMT CO2. Combustion emissions (20.3 MMT C02e) were
larger than process emissions. Following combustion equipment, the top reported emission sources
were reciprocating compressors (1.5 MMT CChe) and blowdown vent stacks (1.3 MMT C02e). See
Figure 13 for natural gas transmission emissions by greenhouse gas for the top reported emission
sources in 2017.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 13: 2017 Natural Gas Transmission Compression: Top Reported

Emission Sources

~i	

Combustion Equipment
Reciprocating Compressors
Blowdown Vent Stacks
Centrifugal Compressors
Misc Equipment Leaks
Pneumatic Devices
Transmission Tanks
Other Flare Stacks

IC02 Emissions
ICH4 Emissions
N20 Emissions

10	15

Emissions, MMT C02e

20

25

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Natural Gas Transmission Pipeline

GHG emissions from the natural gas transmission pipeline segment were first reported in 2016. The
segment contains one reported emission source, blowdown vent stacks. In 2017, the EPA received
annual reports from 33 facilities in the natural gas transmission pipeline segment and reported
emissions totaled 2.6 MMT C02e. Methane emissions totaled 2.6 MMT C02e and carbon dioxide
emissions totaled less than 0.01 MMT C02e.

Underground Natural Gas Storage

The EPA received annual reports from 48 facilities in the underground natural gas storage segment
and reported emissions totaled 1.5 MMT C02e. Methane emissions totaled 0.7 MMT C02e and
carbon dioxide emissions totaled 0.8 MMT C02e. As presented in Figure 14, combustion equipment
(0.8 MMT CC>2e) was the top reported source of emissions for underground natural gas storage,
followed by reciprocating compressors (0.5 MMT CChe).

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 14: 2017 Underground Natural Gas Storage: Top Reported

Emission Sources

Combustion Equipment
Reciprocating Compressors
Pneumatic Devices
Misc Equipment Leaks
Centrifugal Compressors
Other Flare Stacks

IC02 Emissions
ICH4 Emissions
N20 Emissions

0.0

0.2	0.4	0.6

Emissions, MMT C02e

0.8

1.0

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.
LNG Import/Export

The EPA received emission reports from six LNG import/export terminals and reported emissions
totaled 3.8 MMT CChe. Methane emissions totaled 0.04 MMT C02e and carbon dioxide emissions
totaled 3.7 MMT C02e. The top reported source of emissions was combustion equipment (3.4 MMT
C02e).

LNG Storage

The EPA received emission reports from six LNG storage facilities. Total reported emissions from
LNG storage were less than 0.01 MMT CChe.

Natural Gas Distribution

The EPA received annual reports from 169 facilities in the natural gas distribution segment, and
reported emissions totaled 13.5 MMT C02e. Methane emissions totaled 13.3 MMT C02e and carbon
dioxide emissions totaled 0.2 MMT C02e. Figure 15 presents natural gas distribution emissions by
source.

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Figure 15: 2017 Natural Gas Distribution: Top Reported Emission Sources

Distribution Mains

Distribution Services

Distribution M-R Stations

Combustion Equipment

Misc Equipment Leaks

0	2	4	6	8	10

Emissions, MMT C02e

¦	C02 Emissions

¦	CH4 Emissions
is N20 Emissions

Note: Segment totals may not equal sum of individual GHGs due to independent rounding.

Figure 16 shows reported emissions (CC^e) and facility locations for natural gas processing natural
gas transmission and compression, underground natural gas storage, LNG storage, and LNG
import/export facilities.

Figure 16: 2017 Facility Locations and Emissions by Industry Sectors (CChe)



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Subsector

NG Transmission and
Compression

NG Processing

NG Underground Storage

LNG Storage

LNG Import and Export

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2011-2017 GHGRP Industrial Profile

Petroleum and Natural Gas Systems

Changes from

The following section describes the reported data for the 2011 through 2017 calendar years for
Petroleum and Natural Gas Systems.6

Changes in Number of Facilities

Annual reported facility counts from 2011 to 2017 are shown in Table 2. The change in number of
facilities is primarily a result of facilities reporting under two new industry segments in 2016:
gathering and boosting and natural gas transmission pipeline.7 It should also be noted that
emissions can be variable in the Petroleum and Natural Gas Systems sector and it is not unexpected
that emissions for a facility may go above 25,000 metric tons C02e in a given year. Once the
reporting threshold is triggered, facilities must report to the GHGRP until emissions are below the
threshold for a period of time specified in the regulations, or until all emission sources at a facility
cease operation. As a result, the number of facilities reporting to the GHGRP may vary from year-to-
year.

Changes in Reported Emissions

Annual reported emissions values from 2011 to 2017 by industry segment are shown in Table 3.
The largest change in total reported emissions from year to year occurred from 2015 to 2016 and is
generally attributable to the addition of the two new industry segments in 2016. Other changes in
emissions are the result of a number of factors, such as changes in the number of facilities,
operational changes (e.g., increased flaring), calculation changes (e.g., reduced BAMM use), and
changes in the reporting landscape, including the addition of new industry segments and new
emission sources within existing industry segments (e.g., oil well completions and workovers with
hydraulic fracturing). Total reported emissions increased 1.5 percent between 2016 and 2017
while the number of facilities decreased 0.1 percent

6	The EPA received resubmissions of 2011 through 2017 data from certain facilities and this section describes the 2011-2017
time series updated to include the resubmitted data.

7	The decrease in the number of facilities from 2015 to 2016 is mostly due to the addition of the gathering and boosting
segment. For gathering and boosting a "facility" means all gathering pipelines and other equipment located along those
pipelines that are under common ownership or common control by a gathering and boosting system owner or operator and
that are located in a single hydrocarbon basin. Gathering and boosting includes certain stationary and portable fuel
combustion equipment emissions that may have been published for Reporting Years 2011-2015 as Other Petroleum and
Natural Gas Systems and reported using a facility definition referring to all co-located emission sources that are commonly
owned or operated.

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2011-2017 GHGRP Industrial Profiles

Petroleum and Natural Gas Systems

Table 2: Number of Facilities by Industry Segment: 2011 to 2017

Industry Segment1

2011
Number of
Facilities

2012
Number of
Facilities

2013
Number of
Facilities

2014
Number of
Facilities

2015
Number of
Facilities

2016
Number of
Facilities

2017
Number of
Facilities

Onshore Production2

459

507

509

570

535

514

497

Offshore Production

101

108

109

129

133

137

141

Gathering and Boosting3

N/A

N/A

N/A

N/A

N/A

301

321

Natural Gas Processing

374

403

438

479

466

447

449

Natural Gas Transmission Compression

421

458

487

522

520

526

529

Natural Gas Transmission Pipeline3

N/A

N/A

N/A

N/A

N/A

27

33

Underground Natural Gas Storage

49

52

51

54

53

53

48

LNG Import/Export

8

8

8

8

7

6

6

LNG Storage

6

5

5

5

7

6

6

Natural Gas Distribution

183

183

176

181

177

170

169

Other Oil and Gas Combustion4

338

388

419

490

544

91

79

Total

1,921

2,096

2,187

2,419

2,419

2,256

2,253

Notes:

1.	Total number of facilities is smaller than the sum of facilities from each segment because some facilities reported under multiple segments. A facility is included in the count
of number of facilities if it reported emissions (even if the reported emissions were zero] under a given segment.

2.	Beginning in Reporting Year 2016, Onshore Production facilities began reporting emissions from oil well completions and workovers with hydraulic fracturing. These
emissions were not reported for prior reporting years.

3.	This industry segment began reporting data for the first time in Reporting Year 2016.

4.	Beginning in Reporting Year 2016, facilities that met the definition of Gathering and Boosting reported emissions for applicable sources. This includes certain stationary
and portable fuel combustion equipment emissions that may have been published for Reporting Years 2011-2015 as Other Petroleum and Natural Gas Systems.

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2011-2017 GHGRP Industrial Profiles

Petroleum and Natural Gas Systems

Table 3: Reported Emissions by Industry Segment: 2011 to 2017

Industry Segment

2011
Reported
Emissions
(MMT C02e}

2012
Reported
Emissions
(MMT C02e}

2013
Reported
Emissions
(MMT C02e}

2014
Reported
Emissions
(MMT C02e}

2015
Reported
Emissions
(MMT C02e)

2016
Reported
Emissions
(MMT C02e)

2017
Reported
Emissions
(MMT C02e)

Onshore Production1

92

93

98

102

101

85

94

Offshore Production

6

7

6

7

7

7

7

Gathering and Boosting2

N/A

N/A

N/A

N/A

N/A

82

75

Natural Gas Processing

59

60

59

60

59

55

56

Natural Gas Transmission
Compression

24

24

23

22

23

22

24

Natural Gas Transmission
Pipeline2

N/A

N/A

N/A

N/A

N/A

3

3

Underground Natural Gas Storage

2

2

2

2

2

1

1

LNG Import/Export

1

1

<1

1

1

2

4

LNG Storage

<1

<1

<1

<1

<1

<1

<1

Natural Gas Distribution

16

15

15

15

14

14

13

Other Oil and Gas Combustion3

23

25

24

28

29

7

7

Total

222

226

228

235

235

280

284

Notes:

1.	Beginning in Reporting Year 2016, Onshore Production facilities began reporting emissions from oil well completions and workovers with hydraulic fracturing. These
emissions were not reported for prior reporting years.

2.	This industry segment began reporting data for the first time in Reporting Year 2016.

3.	Beginning in Reporting Year 2016, facilities that met the definition of Gathering and Boosting reported emissions for applicable sources. This includes certain stationary
and portable fuel combustion equipment emissions that may have been published for Reporting Years 2011 -2015 as Other Petroleum and Natural Gas Systems.

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2011-2017 GHGRP Industrial Profiles

Petroleum and Natural Gas Systems

Additional Information

Access GHGRP data.

Access additional information about Petroleum and Natural Gas Systems in the GHGRP. including
reporting requirements and calculation methods.

Access the GHGRP Petroleum and Natural Gas Systems Data Highlights Page.

Access Facility Level Information on Greenhouse Gases Tool (FLIGHT).

Glossary

IPCC AR4 refers to the Fourth Assessment Report by the Intergovernmental Panel on Climate
Change. Climate Change 2007: The Physical Science Basis. Contribution of Working Group I to the
Fourth Assessment Report of the Intergovernmental Panel on Climate Change [Core Writing Team,
Pachauri, R.K. and Reisinger, A. (eds)]. IPCC, Geneva, Switzerland2007. The AR4 values also can be
found in the current version of Table A-1 in subpart A of 40 CFRpart98.

IPCC AR5 refers to the Fifth Assessment Report by the Intergovernmental Panel on Climate Change.
Climate Change 2013: The Physical Science Basis. Contribution of Working Group I to the Fifth
Assessment Report of the Intergovernmental Panel on Climate Change [Stocker, T.F., D. Qin, G.-K.
Plattner, M. Tignor, S.K. Allen, J. Boschung, A. Nauels, Y. Xia, V. Bex and P.M. Midgley (eds)]. Cambridge
University Press, Cambridge, United Kingdom and New York, NY, USA.

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