EPA-450/3-75-076
October 1975
4TMOi i immc
EMISSIONS SURVEY
OF THE SOUR GAS
PROCESSING INDUSTRY
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Air and Waste Management
Office of Air Quality Planning and Standards
Research Triangle Park, North Carolina 27711
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EPA-450/3-75-076
ATMOSPHERIC
EMISSIONS SURVEY
OF THE SOUR GAS
PROCESSING INDUSTRY
by
Ecology Audits, Inc.
11061 Shady Trail
Dallas, Texas 75229
Contract No. 68-02-1865
EPA Project Officer: Harry Butcher
Prepared for
ENVIRONMENTAL PROTECTION AGENCY
Office of Air and Waste Management
Office of Air Quality Planning and Standsrds
Research Triangle Park, North Carolina 27711
October 1975
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This report is issued by the Environmental Protection Agency to report
technical data of interest to a limited number of readers. Copies are
available free of charge to Federal employees, current contractors and
grantees, and nonprofit organizations - as supplies permit - from the
Air Pollution Technical Information Center, Environmental Protection
Agency, Research Triangle Park, North Carolina 27711; or, for a
fee, from the National Technical Information Service, 5285 Port Royal
Road, Springfield, Virginia 22161.
This report was furnished to the Environmental Protection Agency by
Ecology Audits, Inc., Dallas, Texas 75229, in fulfillment of Contract
No. 68-02-1865. The contents of this report are reproduced herein
as received from Ecology Audits, Inc. The opinions, findings, and
conclusions expressed are those of the author and not necessarily those
of the Environmental Protection Agency. Mention of company or product
names is not to be considered as an endorsement by the Environmental
Protection Agency.
Publication No. EPA-450/3-75-076
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TABLE OF CONTENTS
PAGE NO.
Preface iv
Acknowledgments vi
List of Figures vii
List of Tables viii
Summary ix
I. Introduction 1
II. Section for AP-42 27
General 27
Process Description . 29
Emissions 30
References 34
III. Research Leading to the Development of
Emission Factors for Natural Gas Sweetening 35
Introduction 35
Emission Points 35
Sulfur Compound Emissions 36
Other Emissions 36
Development of Emission Factor 37
IV. Source Classification Codes 45
V. List of Gas Processing Plants in the Contiguous
United States that have Sour Gas Resources 48
Glossary 115
Bibliography 118
Appendix A - Data Summary of Sour Gas
Production Used in Table 3 Al
EPA Technical Report Data
111
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PREFACE
The initial objective of Contract 68-02-1865 was to obtain the most
reliable emissions and source test data for each natural gas processing
facility in the United States which produces more than 25 long tons of
sulfur per year. By definition, the survey was to be restricted to those
gas processing plants with sour gas feedstocks, to the exclusion of all
sweet gas processing plants. These data were then to be used to supplement
and refine the information in the National Emissions Data System (NEDS), the
Source Test Data System (SOTDAT), the EPA publication AP-42, "Compilation
of Air Pollutant Emission Factors", and for the proposal of new Source
Classification Codes for the gas processing industry.
However, the contract objectives were reinterpreted at a meeting of
all contract principals held at NADB in Durham on March 26, 1975. At that
meeting it was decided that the development of Source Classification Codes
for gas sweetening plants (for removal of "sour" hydrogen sulfide) should
have first priority, the development of emission factors for gas sweetening
should have second priority, and encoding NEDS and SOTDAT forms should have
last priority. The following contract chronology is presented in order to
describe the progression of work performed on this contract:
January 29, 1975 Contract signed. Due date 1 August 1975.
February 3, 1975 Work commenced.
March 26, 1975 Meeting of contract principals, all materials
to be provided by EPA delivered at conclusion
of meeting.
IV
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Computer printouts of current plants in NEDS
received from EPA.
Sample NEDS forms submitted to EPA for review.
Data gathering trip to Texas Air Control
Board, Austin, Texas.
James Southerland visited Ecology Audits and
reviewed progress.
Sample SOTDAT forms submitted to EPA for review.
Permission requested to visit New Mexico
Environmental Improvement Agency - Air Quality
Division.
Extension of time period for contract requested
by Ecology Audits, Inc.
Preliminary Draft of SCC codes submitted to EPA
for review.
Preliminary Draft of Introduction to section
for AP-42 submitted to EPA for review.
Permission requested to visit state agencies
in Alabama, Arkansas, Louisiana and Oklahoma.
Permission granted to visit New Mexico state
agency.
Modification of contract time period extending
contract due date to 1 September 1975 received.
Revised SCC codes submitted to EPA.
Preliminary Draft of Emissions Factor for
publication AP-42 submitted to EPA.
All SOTDAT forms submitted to EPA.
Project Officer Butcher visited Ecology Audits
and surveyed the rough draft. A conducted tour
of a gas processing plant and sulfur recovery
unit was completed. Draft of final report
submitted to Project Officer for review.
Chapter II of this report is intended for inclusion in EPA publication
AP-42, "Compilation of Air Pollutant Emission Factor", and as such is
presented in the format of that publication rather than in the standard
format of research reports to EPA.
April 12, 1975
May 6, 1975
May 21, 22, 23, 1975
June 2, 1975
June 9, 1975
June 9, 1975
June 11, 1975
June 24, 1975
July 2, 1975
July 22, 1975
July 30, 1975
August 5, 1975
August 8, 1975
August 8, 1975
August 18, 1975
August 26, 1975
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ACKNOWLEDGMENTS
The authors wish to express their appreciation to several persons who
made significant contributions to the success of the survey project: Mr.
Harry Butcher, EPA Project Officer, for his availability and willingness to
work out solutions to problems that were encountered; Mr. James Sdutherland,
EPA National Air Data Branch, for his review comments and answers to many
questions; Mr. Jim Anz, Consulting Engineer with Core Laboratories, Inc.
for his discussion and guidance in our pursuit of the data base and survey
approach; and Dr. Joe Pennington, Chief of Emissions Inventory Section,
Texas Air Control Board, for his generous help in our review of Texas'
Emissions Inventory. Additionally, we wish to thank all the people who
helped us in small ways, but whom are too numerous to mention individually.
VI
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FIGURE TITLES
PAGE NO.
1. Flow Diagram of the Natural Gas Industry 2
A. Flow Diagram for a 3-Stage Wellhead Separation Unit 3
B. Flow Diagram of an Amine Gas Sweetening Plant 5
C. Flow Diagram of a 2-Stage Glaus Sulfur Recovery Plant 6
D. Flow Diagram of a Typical Diethyleneglycol
Dehydration Plant .8
E. Schematic of a Gas Processing Plant 9
2. Flow Diagram of Basic Amine Process for Gas Sweetening 11
3. Flow Diagram of Conventional Hot Carbonate Process 16
4. Flow Diagram of a Typical Water Wash Absorption Unit 21
9.2-1 Flow Diagram of the Natural Gas Industry 28
9.2-2 Flow Diagram of the Amine Process for Gas Sweetening 29
5. Map of AQCRs in 16 States with Sour Gas Resources 43
vn
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TABLE TITLES
PAGE NO.
9.2-1. Emission Factors for Gas Sweetening Plants 31
9.2-2. Average Hydrogen Sulfide Concentrations in
Natural Gas by Air Quality Control Regions 32
1. Hydrocarbon Analysis of a Stack Gas Sample 37
2. Emissions Factors for Gas Sweetening Plants 38
3. Average Hydrogen Sulfide Concentrations in Natural
Gas by Air Quality Control Regions 39
4. List of Gas Processing Plants in 16 States that
have Sour Gas Resources 51
Vlll
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SUMMARY
The natural gas industry is comprised of several discrete activities
including the drilling and completion of wells, separating and dehydrating
the raw natural gas into its constituent parts, removing hydrogen sulfide if
present (called "sweetening" the gas), recovering sulfur from the gas, and
storing and distributing the various forms of natural gas. Natural gas from
the well may contain many compounds including carbon dioxide, carbon disul-
fide, carbonyl sulfide, mercaptans, water vapor, nitrogen and.crude oil.
There are three major sources of emissions to the atmosphere from the
natural gas industry. They are compressor and pump engines, boilers for
process heating and solution regeneration, and gas sweetening. Engine
exhausts and external combustion boilers are each the subject of separate
study in the EPA publication AP-42, "Compilation of Air Pollutant Emission
Factors". The emissions from gas sweetening operations are the combustion prod-
ucts of.the waste acid gases following their removal from the raw natural gas.
Combustion oxidizes the waste acid gases to sulfur dioxide with negligible
emissions of particulates, nitrogen oxides, hydrocarbons and carbon monoxide.
There are four major categories of sweetening processes: 1) amine
solutions 2) carbonate processes 3) physical absorption and 4) solid bed
sweetening, all of which accomplish removal of hydrogen sulfide. Each of 27
different processes are briefly described and references made to their
special applications.
IX
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A major objective of the project was to develop an emissions factor
for natural gas sweetening plants that could be included in the EPA
publication AP-42 "Compilation of Air Pollutant Emission Factors". Towards
this objective, content analysis of the technical literature was performed,
consultations with natural gas engineers and plant personnel, as well as
with air pollution specialists, were pursued in order to develop a data base
for historic emissions and gas plant specifications. The survey was re-
stricted to only those states producing sour gas.
The major waste product from the gas sweetening processes.is an acid
containing HoS and COo'. This acid gas can be used by chemical plants or
sulfur recovery plants for commercial purposes, or it may be disposed of
by burning. The combustion of this acid gas results in emissions of sulfur
dioxide. Assuming the combustion of the acid gas is essentially 100 percent
complete and assuming that the sweetening process removes essentially 100
percent of the f^S present in the feedstock, then the S02 emissions from the
acid gas combustion are directly proportional to the mol percentage of H^S
in the sweetening plant intake stream. Therefore, when the H^S mol percent-
age of intake gas is known, the SC^ emissions of the sweetening plant can
be calculated by multiplying the whole number representing the H^S mol
percent by the factor 1685 to get the pounds of SC>2 emitted per million
cubic feet of intake gas sweetened. The research and development leading
to the factor 1685 is presented.
If the H2S content of the intake gas stream is unknown, the above
direct calculations cannot be made. In order to allow some degree of
calculation of emissions, a geographical survey of sour gas fields was
compiled in order to define an average mol percentage of H2S produced by
various fields in the United States. These data were then presented by
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Air Quality Control Region. Reference to the table of values for H?S by
AQCR will allow one to calculate estimated emissions for a plant within
the geographical region.
Another objective of the research project was to propose a new Source
Classification Code for gas sweetening, as none presently exist. The only
emissions from the gas sweetening process are the acid gas wastes containing
C02 and H2S. This acid gas may be flared or incinerated, thereby generating
sulfur dioxide emissions, and negligible emissions of particulates, nitrogen
oxides, hydrocarbons and carbon monoxide. The acid gas is frequently used
by associated industries as feedstock, and when it is so utilized, there
are no emissions from the gas sweetening process. Five Source Classification
Codes were proposed to reflect the described situations; e.g., gas sweeten-
ing with a flare, with an incinerator, or with an associated industry
utilizing the waste acid gases.
The last objective of the project was to review the contents of the
National Emissions Data System (NEDS) and the Source Test Data System (SOTDAT)
This was done by survey of the NEDS computer printouts from EPA, from plant
and emissions surveys by industry trade associations, and by review of the
research literature. The final result presented was an annotated list of
gas plants by state with comments on their coding status and emissions. The
authors believe the list to be one of the most comprehensive for all gas
plants in the 16 states surveyed, which represents almost all sour gas
production in the United States. Development of processing facilities
/
within the last two years may not have been recorded, but this list should
be current up to 1973.
xi
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I. INTRODUCTION
The natural gas industry comprises several discrete activities
including the drilling and completion of wells, separating and dehydrating
the raw gas, removing hydrogen sulfide (called sweetening the gas), recov-
ering sulfur from gas that is rich in hydrogen sulfide, processing the gas
into its constituent parts, and transmission5 of the produced gas in pipe-
lines. Figure 1 is a diagram showing the activities involved in obtaining
natural gas for consumers. The involved legend for Figure 1 will serve to
explain the various processes and describe how the industry interacts with
the environment.
The three primary activities of preparing natural gas for consumption
are separating-dehydrating, sweetening, and processing. Separators and de-
hydrators themselves have no emissions to the atmosphere as their operation
is only concerned with the physical composition of the gas stream from the
well and all operations occur in a closed system. In case of emergencies,
venting or flaring of the gas may occur.
Similarly, gas processing itself has no emissions to the atmosphere
because the processes involved occur in closed systems. The processes in-
volve changing the physical properties of natural gas and any emission to the
atmosphere is essentially a loss of product. Again, emergencies can cause
venting of gas to the atmosphere, but stringent safeguards are taken against
this occurring.
1
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SIC 1311
SCCs exist
lease
exhaust
(b)
flare
(c)
t
I
Separators
Dehydrators
SIC 1311
sour gas feedstock to chemical plants
reinjection
flare
vent
flare
incinerator
II
sour
Gas Sweetening Flam
I
^incinerator
SIC 1311
SCC 3-06-014-
(proposed)
sweet
gas
III
acid gas
C02-H2S
Sulfur Recov-
ery Plant
SIC 2819
SCCs exist
elemental
sulfur
exhaust
(T)
natural gas
IV
Gas Processing
Plant
SIC 1311
C2)
-*Min
liquified petroleum^
gas (C3 * C4)
higher
hydrocarbons
$». (e) pipeline
(C5 + heavier)
reinjection
if sweet
Figure 1
Flow diagram of the natural gas industry
2
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LEGENDS FOR FIGURE 1
a Flare during well testing and completion, SIC 1311
SCC 3-06-009-01
The flared materials may include water vapor, H2S and/or
CCu, mercaptans, carbon disulfide and/or carbonyl sulfide.
Well-site flares are usually low temperature flames yield-
ing incomplete combustion products including S02 and
hydrocarbons.
I Separators - Dehydrators SIC 1311
Natural gas from gas wells passes through separators at
the well head to remove hydrocarbon condensates and water.
Motive power for the process is either natural pressure
in the well or by pump. Figure 1A is a flow diagram of
a three stage wellhead separation unit.
To Sweetening
Well
H:
Stage
P
gas
\
liquid
. r
ress
Ga..
1st
; Absorber
;h
sure
pC
In
2nd
Stage
teri:
Pres
ediate
sure Lou
Gas ^ ~^^
3rd
Stage
Pr
-C
^a OI
essure
>
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Legends Ccont.)
b Lease exhaust
Exhaust emissions for lease operations are included in
various internal combustion SCC codes: reciprocating
natural gas engines, SCC 2-02-002-02; reciprocating
gasoline engines, SCC 2-02-003-01; or reciprocating
diesel engines, SCC 2-02-004-01.
c Flare, SCC 3-06-009-01
A flare operating on a separator/dehydrator at the well-
head would yield emissions of SC^ and hydrocarbons from
incomplete combustion of water vapor, f^S and/or CC^-
Gas is normally dehydrated either by a di- or tri-
ethylene glycol absorption process or by passage over
solid desiccants such as alumina, silica gel or bauxite.
Other dehydrating processes such as direct cooling,
compression followed by cooling, and chemical reactions
are little used today.
d Reinjection to reservoir, if sweet
In certain cases sweet natural gas is immediately
reinjected into the reservoir to maintain reservoir
pressures rather than marketing the gas. This is
referred to as a gas cycling operation.
e Pipeline SIC 4922 Natural Gas Transmission, 4923
Natural Gas Transmission and Distribution,
4924 Natural Gas Distribution
Sweetened gas must meet rigid specifications before it
will be purchased by pipeline transporters. The generally
required specification for pipeline gas is an l^S content
of "no more than one-quarter grain I^S per 100 standard
cubic feet of gas". This is approximately 4 x 10"^ mole
fraction of t^S, or 4 parts per million by volume, or
6 mg of H^S per normal cubic meter of gas.
f Feedstock to Chemical Plants
Some chemical manufacturing processes use sour gas as a
starting material. The sour gas would be piped to nearby
chemical plants.
II Gas Sweetening Plant - amine process SIC 1311
Proposed SCCs 3-06-014-01 Amine process w/smokeless
flare
3-06-014-02 Amine process w/incinerator
3-06-014-03 Amine process w/Claus plant
3-06-014-04 Amine process w/h^SC^ plant
3-06-014-05 Amine process w/well reinjection
3-06-014-99 Other/Not Classified
Figure IB is a flow diagram of the amine sweetening process.
A detailed description follows in the text.
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Legends (cont.)
Acid gas
Pjirified
cooler.
=rri
(g^reboiler
heat exchanger
Figure IB
Flow diagram
of an amine gas sweetening plant
g Emergency flare
Flare would oxidize sour gas giving SC>2 emissions,
No SCC codes because of unpredictable, nature.
h Reinjection to reservoir
In some cases after sour gas has been sweetened, it is
reinjected to maintain reservoir pressures rather than
being marketed. This optional use of sweet gas is dependent
on plant design and field operation.
i Flare, SCC 3-06-014-01 (proposed)
Flared gas would contain CC^, F^jS and CH^. Some raw
natural gas is usually fed to the flare to increase com-
bustion temperatures; combustion is usually 98 percent
complete and emissions are primarily SC^. Flares are
used only when an associated industry such as a sulfur
recovery plant is not necessary or economically feasible.
Two basic types: (1) ambient condition flare with a
natural gas pilot, and (2) modern smokeless type with
fuel and steam injection.
Vent
No SCC code because venting is not allowed because of
the safety hazard of F^S. Some venting might occur if
a flare were accidentally extinguished by winds.
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Legends (cont.)
Incinerator, SCC 3-06-014-02 (proposed)
A tail gas incinerator is an elaborate flare. An
incinerator is a special combustion chamber with raw
gas and oxygen fed to it to optimize combustion.
Combustion of HoS and CO? is essentially complete
resulting in emissions of SC^.
Ill Sulfur Recovery Plant
SCC 3-01-032-01
3-01-032-02
3-01-032-03
3-01-032-99
SIC 2819
mod-claus 2 stage
mod-claus 3 stage
mod-claus 4 stage
other/not classified
Figure 1C is a flow diagram of a 2 stage claus sulfur
recovery plant.
AC 1C GAS
1 1ST HOT GAS BY-PASS
AIR*-
/"
^
BiRC
1
2ND HOT GiS BY-PASS
n_r - V
j*\ j
TAIL CAS
c
LEGEND
t - BURNER
RC - REACTION CHAMBER
WHB - WASTE HEAT BOILER
Rj - FIRST CATALYTIC CONVERTER
«2 - SECOND CATALYTIC CONVERTER
C, - FIRST CONDENSER
C2 - SECOND CONDENSER
SL . LIQUID SULFUR
SUFFICIENT AIR IS ADDED TO BURN 1/3 OF TOTAL HjS TO SOj AND ALL HYDROCARBON TO C02
Figure 1C
Flow diagram of a two-stage
claus sulfur recovery plant
j Flare, coded as control equipment
Flared gas would contain CC>2 and I^S. Combustion is
usually 98 percent complete and emissions are primarily
SO?. If combustion temperatures are low, then some HC
may be emitted.
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Legends (cont,)
Incinerator, coded as control equipment
An incinerator is a flare with air premixing. An
incinerator is a special combustion chamber with fuel
gas and air fed to it to maintain high combustion
temperatures with the resulting combustion of H2S
and hydrocarbons essentially complete. Emissions are
S02, C02, N2 and H20.
k Elemental sulfur
The sulfur recovery plants burn gas streams rich in
H2S with air over catalysts to convert the H2S to SC>2
and then condense the sulfur out of the gas stream.
The best known and most widely used system is the Glaus
Process, with plants having either 1, 2 or 3 stages of
catalytic converters, depending on the H2S content of
the feed gas and/or the desired efficiency of recovery.
Three stage plants are most efficient, but still yield
minor emissions of S02.
IV Gas Processing Plant - SIC 1311
Most gas wells contain enough natural gas, butane and
propane to warrant processing plants for recovery of
these liquifiable constituents. The natural gas is
then ready for the market unless H2S is present, in
which case the gas goes to a sweetening plant. The
most common method of recovery is a bubble plate column
with a gas-oil as an absorbent. This gas-oil is rich
in light HC, is stripped of propane, butane and natural
gasoline constituents, cooled and returned to the
absorber. Figure ID illustrates dehydration of gas as
it enters a processing plant. Figure IE is a schematic
flow diagram of a large volume gas processing installation.
1 Exhaust
_^
These emissions are from engines which burn both natural
gas and gasoline and diesel fuel. SCC codes 2-02-002-01
2-02-002-02
2-02-003-01
. 2-02-004-01
2-02-004-02
m Natural Gas
The lightest forms of natural gas are methane (CH4) and
ethane (C2-H/J . This gas mixture is the end product
desired for storage and sale to pipelines and consumers.
-------
Legends
wet
gas
inlet
scrubber
liquid
Condenser
Accum-
ulator
Water
Reboiler
Figure ID
Flow diagram of
a typical di-ethylene glyeol dehydration plant
n Liquefied petroleum gas (LPG)
Natural gases with three carbon atoms (propane) and four
carbon atoms (butane) are easily compressed and handled
as liquids. Liquified petroleum gases are stored and
sold to consumers as liquids which then vaporize when used.
o Higher hydrocarbons
Gas processing plants recover small amounts of hydrocarbons
with five or more carbon atoms and if quantities are
great enough, they are pipelined to petroleum refineries.
-------
Legends (cont.)
cooler
to storage or
sweet
dry,>
gas
^-^
fH
0)
(H
O
tfl
L^
-
1
^
pipeline
heater
n-^.
s
J cooler
i
-\* 1 1 pan n-i 1 W
r
^) pump
^
i
c
v^
\
OH
P.
>H
Accumulator
water
steam
pump \ ,_/
(1) Separation of natural gas from liquefiable constituents of
natural gas.
Butane
Propane
Fuel Gas
Heavier
Hydrocarbons
to <
Refinery
1 2
Distillation Towers
(2) Processing natural gas liquids into pure components
Figure IE
Schematic of a gas processing plant
e>o
H
v>
H
UH
4J
I/)
T3
'3
H
ii
V)
rt
+J
rt
-------
There are many processes designed to sweeten gas ranging from the very
simple iron sponge process to the more complicated and more expensive
processes such as the amine processes or the Selexol process. Twenty-seven
specific processes have been identified and are discussed in this report.
The bulk of the material is drawn from Maddox (1974), Gas and Liquid
Sweetening.
Of the processes mentioned, eleven can be described as out-dated,
inefficient, or good only for special applications; two others are effective
for H2S removal only when large amounts of CO? are present. The remaining
fourteen processes consist of twelve amine or amine-related methods and two
other effective processes. Although there is no listing of the number of
plants using each type of process, Maddox concurs with other experts in the
gas sweetening industry when he states that amine or amine-related processes
are the most widely used for the commercial removal of h^S from natural gas
streams.
Gas sweetening processes can best be divided into four major categories:
1) amine and amine-type processes; 2) carbonate and other chemical processes;
2) physical absorption methods and 4) solid bed sweetening processes.
AMINE PROCESSES
_^
The amine processes were developed to remove high concentrations of
H_S in large volumes of gas at high pressures. At the present time the
alkanolamines are the most generally accepted and widely used of the many
available solvents for the removal of f^S and (X^. Primarily because of
their reactivity and availability at low cost the alkanolamines have
10
-------
achieved a position of prominence in the gas sweetening industry. (Maddox,
1974, p. 44). The three alkanolamines generally used in gas sweetening
are: monoethanolamine (MEA), diethanolamine (DEA) and triethanolamine
(TEA). Of these three MEA is usually preferred.
A diagram of the flow of a basic amine process system is shown in
Figure 2.
cooler
sweet
gas
sour
gas
acid
gas
amine
solution
rich
amine
solution
cooler
heat
Modified from Maddox 74
exchanger
steam
reboiler
I pump
Figure 2
Flow diagram of basic amine process
for gas sweetening
11
-------
Monoethanolamine
MEA is the strongest base of the three amines and, therefore, reacts
most rapidly with the acid gases. MEA removes both hydrogen sulfide and
carbon dioxide; it is generally considered to be non-selective between
these two acid gases. With the lowest molecular weight of the common
amines, MEA has a greater carrying capacity for acid gases on a unit weight
or volume basis. This generally means less solution circulation is
necessary to remove a given amount of acid gases. In addition, MEA is
chemically stable, which minimizes solution degradation; it can be separated
easily from the acid gas constituents by steam stripping.
MEA reacts irreversibly with carbonyl sulfide and carbon disulfide.
This results in solution loss and in the buildup of reacted solids in the
MEA solution. MEA has a higher vapor pressure than the other amines. This
can result in significant solution losses through vaporization. This
problem usually can be overcome by a simple water wash of the sweetened gas
stream.
The rate of absorption of C02 in MEA is less than that of H2S. The
process is not considered selective, however, because carbon dioxide is
readily absorbed and essentially will be completely removed when treating
natural gas for F^S removal to pipeline specifications.
MEA will easily reduce acid gas concentrations to pipeline specifica-
tions (generally less than 0.25 grains per 100 cu ft). By proper design
and operation, the acid gas content can be reduced as low as 0.05 grains
per 100 cu ft (Maddox 1974, p. 49).
Diethanolamine
The DEA process is similar to the MEA process. The primary difference
is that DEA reacts either very slowly or not at all with carbonyl sulfide
12
-------
and carbon disulfide. This characteristic renders DEA especially useful
for sweetening gas streams where these contaminants are prevalent. DEA is
also non-selective and will remove both l^S and CO^. In some instances,
utilizing the DEA process, it is difficult to reduce h^S concentrations to
pipeline specifications. DEA, however, is much less volatile than MEA and,
therefore, has lower losses of amine solution due to vaporization (Maddox
1974, p. 49).
Triethanolamine
Although TEA was the first commerically-applied amine sweetening
process, it has been largely displaced by MEA and DEA processes. TEA is
less reactive with acid gases and has less acid gas carrying capacity per
volume of solution. The TEA process is unable to reduce H-S content to
general pipeline specifications. The principle advantage of TEA is its
selectivity for ^S. This selectivity is not significant, however, and
today TEA does not have widespread usage as an industrial sweetening agent
(Maddox 1974, p. 50).
Methyldiethanolamine
A fourth alkanolamine process exists utilizing methyldiethanolamine.
It is not commercially competitive with the MEA or DEA processes, but may
have some value in special applications (Maddox 1974, p. 49).
Glycol-Amine
The glycol-amine process utilizes MEA (or occasionally DEA) in combina-
tion with a glycol to simultaneously sweeten and dehydrate the gas stream
(Maddox 1974, p. 48), The solution consists of 10-30% MEA; 45-85% glycol
and 5-25% water by weight. This combined process unit costs less than
separate MEA and glycol units.
13
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The main disadvantages of glycol-amine systems are: a) high vapori-
zation losses of MEA due to high regeneration temperatures; b) intricate
corrosion problems; c) its best application is for gas streams not
requiring low water dewpoint control and d) reclaiming must be by vacuum
distillation.
New Amine-Type Processes
Several variations of amine processes are currently being used for
gas sweetening. Among these are the Shell Sulfinol process, diglycolamine,
and an SNPA-DEA process. Maddox (1974, p. 157) classifies these as new
amine-type processes.
Diglycolamine (PGA)
The treating agent in the DGA process is 2(2-amino-ethoxy) ethanol.
The process is non-selective and will remove both HoS and/or CC>2. DGA has
several advantages over MEA. DGA can be used in concentrations of 50 to 70
percent which results in approximately twice as much acid gas pickup per
gallon as an MEA solution in the 15 to 20 percent range. Use of higher
concentrations results in decreased circulation rates, heat requirements
and horsepower. DGA can be used at lower temperatures without protection of
the exposed solution. This makes it suitable for cold weather areas.
Sulfinol
The Sulfinol process came into commercial use in 1964. It was
patented by Shell Development Company as a replacement for systems using
MEA. Sulfinol is a solvent composed of sulfolane, an alkanolamine, and
water, in varied amounts according to application (Kirk 5 Othmer 1951,
p. 384). Sulfinol is a unique process that involves both a physical sol-
vent and a chemically reactive agent in the sweetening solution, thereby,
14
-------
combining both the chemical and physical absorption methods often used
separately in gas sweetening.
Sulfinol is equivalent to MEA at lower partial pressures, but it is
superior to MEA at high partial pressures. The best application of this
process is in gas streams with relatively high ratios of H2S (H2S to C02
ratios 1:1 or greater). Sulfinol absorbs more hydrocarbons than its MEA
equivalent; it also removes thiols and carbonyl sulfide. Special treatment
for the removal of hydrocarbons from the acid gas stream will be necessary
prior to the sulfur plant if the content is too high for feed to a Glaus
sulfur-recovery operation (Kirk § Othmer 1951, p. 384).
SNPA-DEA
The SNPA-DEA process is similar to a conventional amine process but
utilizes a 20-30 percent by weight of DEA solution. Solution circulation
rate is set at 1.0 to 1.3 moles of DEA per mole of acid gas. Reboiler heat
duty ranges from 0.9 to 1.1 pounds of steam per U.S. gallon of solution.
The higher weight concentration of DEA solution is utilized so that the
number of moles of DEA per gallon of solution is essentially the same as
for a 15-20 percent by weight MEA solution. Because of the lower vapor
pressure of DEA the partial pressure of DEA over the 30 percent by weight
solution is actually less than the partial pressure of MEA over a 15 percent
by weight MEA solution.
The sweetened gas H7S content will normally run from 0.15 to 0.05
grains per 100 scf. This is usually well within pipeline specifications
(0.25 grains per 100 scf). As with MEA units CCU is essentially quanti-
tatively removed. Unlike MEA units carbonyl sulfide is removed without
degradation of the DEA solution (Maddox 1974, p. 179).
15
-------
CARBONATE AND OTHER CHEMICAL PROCESSES
Hot Potassium Carbonate (uncatalyzed)
There are some similarities between process flows for the hot
potassium carbonate process and the amine process, however, in the hot
potassium carbonate system the absorber operates at a high temperature.
This enables a considerable savings in heat exchange and heating equipment.
Use of high temperatures increases the solubility of potassium bicarbonate
in solution. This permits the use of a concentrated I^COs solution and
increases the carrying capacity for acid gases per gallon of solution
(Maddox 1974, p. 99).
The hot potassium carbonate system is very effective where 5 to 8
percent acid gases are present in large quantities. However, if no C02
is present potassium bisulfide is very difficult to regenerate. Therefore,
this process is not suitable for sweetening gas mixtures containing, little
or no C02. The flow diagram for this process is shown in Figure 3.
sweetened
gas
sour
gas
O)
o
CO
cooler
Lean solution
pump
heat
exchanger
Modified from Maddox 74
Rich solution
QJ
Q.
O.
co
V
T
Figure 3-
Flow diagram of conventional
hot carbonate process
acid
gas
steam
reboiler
16
-------
Catacarb Process
This is a variation of the basic hot potassium carbonate process. The
Catacarb Process uses amine borates to increase the activity of the hot
potassium carbonate solution. A potassium carbonate solution is not highly
ionized and has few hydroxyl ions which can react directly with CC^.
Therefore, this process acts on the assumption that CC^ must first react
with water or a hydrate to form carbonic acid. Next, the carbonic acid
reacts with a carbonate ion to form two bicarbonate ions.
These carbonate solutions frequently become contaminated by potassium
formate and potassium sulfate. These contaminants have a negative effect
on solution activity. They can be removed or maintained at a satisfactory
level in the solution, however, to do so is expensive and results in
potassium carbonate losses (Maddox 1974, p. 112).
Benfield Process
This is a hot potassium carbonate process which uses diethanolamine as
the activation agent. The process flow and operating conditions for the
Benfield Process are essentially the same as those for the uncatalyzed hot
potassium carbonate process.
DEA-Carbonate
This process is a combination of the diethanolamine (DEA) and the hot
potassium carbonate processes. The DEA-Carbonate method requires a high
percentage of CCU to operate effectively. In certain applications this
process can save as much as 10 percent in operation costs over the DEA
process alone.
In the DEA-Carbonate process, gas entering the absorber first contacts
the activated potassium carbonate solution. Then it flows to the upper
17
-------
section where it is treated with the DEA solution. This dual method
enables a more complete removal of the acid gases. The amine and carbonate
solutions are segregated in both the absorber and regenerator. Spent DEA
from the absorber is preheated by the carbonate solution before being
introduced to the lower section of the regenerator. Because the potassium-
carbonate solution is cooled before it enters the regenerator, and to
maintain proper stripping steam distribution in the regenerator, both the
potassium carbonate section and the DEA section are reboiled.(Maddox 1974,
p. 116).
Giammarco-Vetrocoke (G-V) Process
The G-V process uses a catalyst to increase the rate of absorption of
CC>2 in alkali carbonate solutions. The G-V process is really a multiple
process which can be used to accomplish three objectives: 1) as a C02
removal process; 2) as a highly selective removal of H2S and 3) as a
process with which modifications enable the removal of C02 and h^S
simultaneously (Maddox 1974, p. 117).
Seaboard Process
This process was developed by the Koppers Company in 1920. It is
essentially a regenerative process without recovery of the product removed.
The Seaboard method uses an aqueous solution with 3.0 to 3.5 percent sodium
carbonate for absorbing F^S in a bubble tray or packed tower. The foul
solution is pumped to a second tower where it is regenerated by blowing air
through it to obtain release of the absorbed ^S, which is emitted to the
atmosphere (Kirk 5 Othmer 1951, p. 384).
18
-------
The Seaboard process was the first regenerative liquid process for
H-S removal used commercially on a large scale. It is no longer of major
industrial significance (Maddox 1975, p. 121).
Vacuum Carbonate Process
This is a modification of the Seaboard process which also used 3.0 to
3.5 percent sodium carbonate as an absorbent. The process is especially
adapted to the recovery of t^S from manufactured gases and is primarily
used for treating coke-oven gases (Kirk £ Othmer 1951).
Phosphate Process
The phosphate process developed by Shell Development Company employs
a solution of potassium orthophosphate for absorbing t^S. Regeneration is
accomplished by steam stripping.
This phosphate method involves a two stage absorption process with the
completely regenerated solution entering the final stage in contact with
effluent gases and partially regenerated solution entering the first stage.
In this way, the saving of steam is accomplished. This is important be-
cause complete reactivation of the solvent is more expensive in this process
than in the amine processes.
Tripotassium Phosphate Process
This process, introduced by Shell Oil, has been largely replaced by the
amine process. However, it does have some advantages for special applica-
tions. The advantages of this method are: 1) tripotassium phosphate is
not volatile; 2) it is insoluble with hydrocarbons and 3) tripotassium
phosphate does not react with carbonyl sulfide (Maddox 1974, p. 124).
19
-------
Sodium Phenolate Process
This process involves a concentrated solution of sodium phenolate in
a heat conversion-heat regenerative flow process. The solution has a high
capacity for ^S but a loiv efficiency for F^S removal. This process seldom
achieves necessary specifications; only about 90 percent of the H?S in sour
gas is removed. For these reasons most sodium phenalate plants have been
replaced by other processes (Maddox 1974, p. 125).
Phenoxide Process
The phenoxide process uses a solution of sodium phenoxide as an absor-
bent. Operating difficulties encountered in this process have caused the
few plants in which this process was utilized to convert to other processes.
Alkacid (Alkazid) Process
This process was developed and used in Germany prior to World War II.
The Alkacid process is not presently used in the United States.
PHYSICAL ABSORPTION METHODS
General
All physical solvents mentioned here have a relatively high solubility
for the heavy hydrocarbons. This is especially true of aromatic and un-
saturated hydrocarbons. For this reason, particular care must be taken in
the regeneration cycle of all of the processes when there are unsaturated or
aromatic hydrocarbons in the sour gas stream being treated. Otherwise, the -
acid gases from the unit will be completely unsuitable for feed gas to a
Glaus sulfur recovery unit (Maddox 1974, p. 155).
Water Absorption
Water is a satisfactory solvent for removing acid gases from sour gas
streams. This is a good process to use as a companion to an amine process.
20
-------
The water wash process followed by an amine process clean-up requires a 12
to. 15 percent lower investment. Additionally, there is approximately a
50 percent savings in operational costs of an equivalent amine unit designed
to do the total sweetening job (Maddox 1974, p. 129). The diagram of a
typical system is shown in Figure 4.
Contactor
Sour
gas
Partially sweetened
gas to amine unit
JOr
COOLER
Acid gas and hydro-
carbons to amine unit
INTERMEOIATE-PRESSU^
FLASH TANK
Lean Solution
Modified from Maddox 74
Power Recovery
Turbines
pump
Figure 4
Flow diagram of a typical water wash
absorption unit
Acid
gas
LOW-PRESSURE
FLASH TANK
pump
21
-------
Fluor Solvent Process
This process originated from an extensive testing and evaluation
program searching for physical absorbents. Four solvents were finally
selected: 1) propylene carbonate 2) glycerol triacetate 3) butoxyl
diethylene glycol acetate 4) methoxy triethylene glycol acetate. These
solvents are primarily intended for the removal of C02 from high pressure
gas streams. There are indications that some of them may have sufficient
selectivity for H2S that they can be used under certain conditions for
preferential removal of H2S from a sour gas stream (Maddox 1974, p. 135).
Selexol Process
The solvent in this process is dimethyl ether of. polyethylene glycol
(DMPEG). DMPEG has significantly greater solubility for H2S than for C02.
This enables some selectivity for PUS to be designed into the system.
Advantages of this process are 1) lower initial plant costs and lower
V
operating costs than MEA or potassium carbonate 2) DMPEG is more selective
for H2S than MEA 3) DMPEG has a better ability to treat for H2S removal
than does hot potassium carbonate.
Rectisol-Purisol Process
The Rectisol process uses a refrigerated solution of methanol as a
solvent. The Rectisol process has been used primarily in the treatment of
synthesis gas for removal of CO,,.
The Purisol process uses a solution of N-methyl-2 pyrrolidone (NMP-
Purisol). This process has a high absorptivity for H2S and indications of
selectivity between H9S and CCU.
£a £*
This process is primarily used for sweetening synthesis gas, but there
are potential applications for it in the natural gas field.
22
-------
Estasolvan Process
The Estasolvan Process utilizes the solvent tri-n-butyl phosphate (TBP).
This process can be used for either sweetening only or sweetening combined
with liquid hydrocarbon recovery. In addition to removing ^S, TBP will
remove mercaptans and other organic sulfur compounds (Maddox 1974, p. 147).
Others
Various other physical solvents can be used in natural gas sweetening.
Any of these solvents might be applicable depending upon plant design and
nature of the gas to be sweetened. Possible solvents include: methyl
cyanoacetate, glutaronitrile, propylene carbonate, trimethylene cyanohydrin,
N-methyl pyrrolidone, dimethyl formamide, DEC dimethyl ether, sulfolane
(Maddox 1974, p. 151).
SOLID BED SWEETENING PROCESSES
General
Solid bed sweetening processes are based on the adsorption of the acid
gases on the surface of the solid sweetening agent or on the reaction with
some component on that surface. These sweetening processes are not as
widely used as the previously discussed liquid processes (Maddox 1974, p. 181)
Solid bed sweetening is usually best applied to gases containing low
to medium concentrations of P^S or mercaptans. Most of the solid processes
are highly selective and do not normally remove significant quantities of
C02- This means the t^S stream from the process is usually of high purity.
Pressure has relatively little effect on the adsorptive capacity of a
sweetening agent. Some solid bed processes are batch type and have low
investment and operating costs (Maddox 1974, p. 181).
23
-------
Iron Oxide (Sponge) Or Dry Box Process
This is one of the oldest known methods for removal of sulfur compounds
from gas streams. The dry box process was introduced in England in the
mid-19th century. It still has a place, today, in areas of special
application.
The simplest process involves contact of the sour gas with hydrated
ferric oxide. This results in the formation of ferric sulfide. When
exposed to the air, ferric sulfide is oxidized to sulfur and ferric oxide.
This can be used to react with additional hydrogen sulfide. The reaction-
regeneration cycle can be repeated several times.
Eventually the sulfur will cover most of the surface of the oxide
particles, thereby causing loss of activity of the adsorbent and excessive
pressure drop through the bed.
Several variations of the iron oxide process exist. These developments
primarily differ in size and design of the vessel to contain the iron oxide.
Molecular Sieves
Crystalline sodium calcium alumino silicates can be used for selective
removal of hUS and other sulfur compounds from natural gas streams. Some
crystalline forms of these materials are found naturally. The common
crystalline forms used in commercial absorption are synthetically manufac-
tured materials. The activated crystalline material is porous. The pore
openings in a given structure are all exactly the same size and are deter-
mined by the molecular structure of the crystal and the size of molecules
present in the crystal. The pores are formed by driving off water of
crystallization that is present during the synthesis process. The exactness
of the pore size and distribution has given rise to the name molecular
sieves, which is used almost universally to describe these materials.
24
-------
These materials are marketed under the name Molecular Sieves by the
Linde Division of Union Carbide Corporation and the Davison Chemical Co.
Division of W. R. Grace and Co.
Molecular sieves have the large surface area typical of any solid
adsorbent. In addition, however, molecular sieves have highly localized
polar charges. These localized charges are the reason for the very strong
adsorption of polar or polarizable compounds on molecular sieves. This
also results in much higher adsorptive capacities for these materials by
molecular sieves than by other adsorbents, particularly in the lower concen-
tration ranges (Maddox 1974, p. 188).
EFCO Process
Engineers and Fabricators Company (EFCO) has developed another
molecular sieve process. In the EFCO process sour gas enters the unit
through a separator and filter which will remove all liquids and entrained
solids. The sour gas then flows downward through two molecular sieve
treating beds and leaves the plant as sweetened gas. A portion of the
sweet gas stream is removed and flows downward through a third bed which
has been regenerated but is still hot. The sweetened gas removes heat from
the bed and flows through a gas-to-gas exchanger before going through the
regeneration heater. Following heating, this gas flows upward through the
bed on regeneration cycle heating it and removing the adsorbed H2S and
sulfur compounds. The gas from the bed then flows through heat exchange
with the sweetened gas to the tower and then through a cooler.
Entrained liquids are removed in a separator before the regeneration
stream flows into an absorber where approximately 90 percent of the H^S is
removed by circulating solvent. The regeneration gas is then recycled to
25
-------
the inlet gas stream to the plant. The EFCO process rejects from the gas
stream only the acid gas constituents and burns only the amount of gas
required to provide regeneration heat (Maddox 1974, p. 193).
Tail Gas Conditioning
Tail gas conditioning involves removing trace quantities of sulfur
from gas streams. Usually tail gas processes are a follow-up procedure to
another process, for example, the Glaus process (Maddox 1974) lists six
methods of tail gas conditioning designed to carry the Glaus reaction to
further completion. All of these processes are very efficient and remove
at least 99 percent of the sulfur in the acid gas stream.
26
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II. SECTION FOR EPA PUBLICATION AP-42,
COMPILATION OF AIR POLLUTANT EMISSION FACTORS
9. PETROLEUM INDUSTRY
9.2 NATURAL GAS PROCESSING
9.2.1 GENERAL1
Natural gas from high-pressure wells is usually passed through field
separators to remove hydrocarbon condensate and water at the well. Natural
gasoline, butane and propane are usually present in the gas, and gas proc-
essing plants are required for the recovery of these liquefiable constituents
(see Figure 9.2-1). Natural gas is considered "sour" if hydrogen sulfide is
present in amounts greater than 0.25 grains per 100 standard cubic feet.
The hydrogen sulfide (I^S) must be removed (called "sweetening" the gas)
before the gas can be utilized. If H^S is present, the gas is usually
sweetened by absorption of the H2S in an amine solution. Amine processes
are used for over 95 percent of all gas sweetening in the United States.
Other processes such as carbonate processes, solid bed absorbents and
physical absorption methods comprise approximately five percent of the.
nation's sweetening plants. Emissions data for sweetening processes other
than amine-types are very meager.
The major sources of emissions from the natural gas processing industry
arise from compressor engines and from acid gas wastes from gas sweetening
plants. Compressor engine emissions are discussed in Section 3.3.2, there-
fore, only gas sweetening plant emissions will be discussed.
27
-------
flare
K)
oo
SIC 1311
SCCs exist
lease
exhaust
*i
flare
Separators
Dehydrators
SIC
sour gas feedstock to chemical plants
reinjectjon
flare g Sf^
II
sour
Gas Sweetening Planl
gas
I
vent
^flare
^incinerator
I
I
*, *
flare
incinerator
SIC
SCC 3-06-014-
(proposed)
sweet
gas
acid as
C02-H2S
exhaust
iv
Processing
Plant
SIC 1311
pipeline
reiniection
if sweet
Sulfur Recov-
ery Plant
SIC 2819
SCCs exist
elemental
sulfur
natural gas
(Cj + C2)
liquified petro1eum^
gas (C3 * C4)
higher
hydrocarbons
(Ccj * heavier)
Figure 9.2-1
Flow diagram of the natural gas industry
-------
9.2.2 PROCESS DESCRIPTION2'3
There are many available chemical processes for sweetening natural gas.
However, at present the most widely-used process for H2S removal or gas
sweetening is the amine type process (also known as the Girdler process), -
and utilizing various amine solutions for absorbing H2S. The process is. -
summarized in the following reaction and ..illustrated, in Figure 9.2-2.
2 RNH2 + H2S
(RNH3)2S
R = mono, di, or tri-ethanol
N = nitrogen
H = hydrogen
S = sulfur
Acid gas
cooler
Purified
gas
Sour
gas
Leon a mine
* ' solution
Rich amine
solution
steam reboiler
heat exchanger
Figure 9.2-2 Flow diagram of the amine process
for gas sweetening
The gas is first absorbed in an amine solution (RNH2) in a bubble-tray
tower. The amines form a compound with hydrogen sulfide at low temperatures.
The volitale hydrogen sulfide is separated from the relatively nonvolatile
amine by steam stripping the amine solution. The complete removal of the
hydrogen sulfide from the rich amine solution in turn allows complete puri-
fication of the gas in a counter-current absorber. The recovered hydrogen
sulfide gas stream may be (1) vented, (2) flared in waste gas flares or
modern smokeless flares, (3) incinerated, or (4) utilized for the production
29
-------
of elemental sulfur or other commercial products. If the recovered H2S gas
stream is not to be utilized as a feedstock for commercial usage, the gas is
usually passed to a tail gas incinerator where the F^S is oxidized to sulfur
dioxide and then passed to the atmosphere via a stack.
9.2.3 EMISSIONS4'5
Virtually all of the emissions from gas sweetening plants consist of
sulfur dioxide, resulting from flaring or incinerating the waste gas. It is
very rare, however, for a sweetening plant to exist without a sulfur recovery
plant or other commercial plant nearby. The amount of SC>2 emitted by sweet-
ening plants is directly related to the H^S concentration in the gas sweet-
ening plant intake. Waste gas flares usually burn at temperatures lower
than those necessary to completely oxidize all hydrocarbons and yield minor
emissions of particulates and hydrocarbons. Modern smokeless flares with
fuel gas and steam injection assure complete combustion of all waste gas
constituents. Tail gas incinerators are usually operated at temperatures
ranging from 1000° to 1200°F. Enough excess air and fuel gas are added to
plant tail gas to maintain the above temperature range. At these conditions
the combustion of hUS to SO- is over 98 percent complete. Table 9.2-1 lists
emissions from gas sweetening plants with smokeless flares or incinerators.
Emissions from sweetening plants with adjacent commercial plants such as
sulfur recovery or sulfuric acid manufacturing are treated in Sections 5.18
and 5.17, respectively.
30
-------
Table 9.2-1. EMISSION FACTORS FOR GAS SWEETENING PLANTS 2>4"?
Oxidesa Carbon Nitrogen
Type of Process Particulates (S02) Monoxide Hydrocarbons Oxides
Amine with smokeless
flare or incinerator
lb/106 ft3 gas
processed
kg/103 m3 gas
processed
Neg
Neg
1685 SD Neg
26.98 Sb Neg
Neg
Neg
Neg
Neg
a Emissions are proportional to the mol percent of hydrogen sulfide in gas
sweetening plant intake.
" S is the H2S content in mol percent, of the sour gas entering the gas
sweetening plant. For example; if H^S content is 2 percent, the emissions
factor would be 1685 x 2 = 3370 lbs/106 ft3, gas sweetened. If H2S mol
percent is unknown and cannot be determined, then use AQCR average H2S
value from Table 9.2-2.
H2S concentrations are also reported in grains/100 ft3 and ppm.
Conversion factors to mol percents are listed below.
.01 mol % H2S = 6.264 grains H2S/100 std ft3 @ 60°F 29.92"Hg
1 grain/100 std ft3 = 15.96 ppm (parts per million) of H2S in
natural gas.
31
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Table 9.2-2. AVERAGE HYDROGEN SULFIDE CONCENTRATIONS
IN NATURAL GAS BY. .AIR QUALITY CONTROL REGIONS
State
Alabama
Arizona
Arkansas
California
Colorado
Florida
Kansas
Louisiana
Michigan
Mississippi
Montana
New Mexico
: AQCR Name
Mobile-Pensacola-Panama City-
Southern Mississippi (FL., MS.)
Four Corners (CO., NM., UT.)
Monroe-El Dorado (LA.)
Shreveport-Texarkana-Tyler
'(LA., OK.-, -TX.)
Metropolitan Los Angeles
San Joaquin Valley
South Central Coast
Southeast Desert
Four Corners (AZ., NM., UT.)
Metropolitan Denver
Pawnee
San Isabel
Yampa
Mobile-Pensacola-Panama City-
Southern Mississippi (AL., MS.)
Northwest Kansas
Southwest Kansas
Monroe-El Dorado (AR.)
Shreveport-Texarkana-Tyler
(AR., OK., TX.)
Upper Michigan
Mississippi Delta
Mobile-Pensacola-Panama City-
Southern Mississippi (AL., FL.)
Great Falls
Miles City
Four Corners (AZ . , CO . , UT . )
Pecos-Permian Basin
AQCR
Number
5
14
19
22
24
31
32
33
14
36
37
38
40
5
97
100
19
22
126
134
5
141
143
14
155
Average
H7S mol %
3^30
0.71
0.15
0.55
2^09
0.89
3.66
1.0
0.71
0.1
0.49
0.3
0.31
3.30
0.005
0.02
0.15
0.55
0.5
0.68
3.30
3.93
0.4
0.71
0.83
32
-------
Table 9.2-2 (continued). AVERAGE HYDROGEN SULFIDE CONCENTRATIONS
IN NATURAL GAS BY AIR QUALITY CONTROL REGIONS
State
North Dakota
Oklahoma
Texas
Utah
Wyoming
AQCR Name
North Dakota
Northwestern Oklahoma
Shreveport-Texarkana-Tyler
(AR., LA., TX.)
Southeastern Oklahoma
Abilene-Wichita Falls
Amaril lo- Lubbock
Austin- Waco
Corpus Christi-Victoria
Metropolitan Dallas-Fort Worth
Metropolitan San Antonio
Midland-Odessa-San Angelo
Shreveport-Texarkana-Tyler
(AR., LA., OK.)
Four Corners (AZ., CO., NM.)
Casper
Wyoming (except Park, Bighorn
and Washakie Counties )
AQCR
Number
172
187
22
188
210
211
212
214
215
217
218
22
14
241
243
Average
H2S mol %
1.74a
1.1
0.55
0.3
0.055
0.26
0.57
0.59
2.54
1.41
0.63
0.55
0.71
1.262
2.34
f" Sour gas only reported for Burke, Williams and McKenzie Counties.
Park, Bighorn and Washakie Counties report gas with an average 23 mol
percent FUS content.
33
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REFERENCES FOR SECTION 9.2
1. Katz, D. L., David Cornell, Riki Kobayashi, F. H. Poettmann, J. A. Vary,
J. R. Elenbaas, and C. F. Weinaug. Handbook of Natural Gas Engineering.
McGraw-Hill Book Company, New York. 1959, 802 pp.
2. Maddox, R. N. Gas and Liquid Sweetening. Second edition. Campbell
Petroleum Series, Norman, Oklahoma. 1974, 298 pp.
3. Kirk, Raymond E. and Donald F. Othmer, editors. Encyclopedia of
Chemical Technology. Interscience Encyclopedia, Inc., New York.
1951, Volume 7.
4. Sulfur Compound Emissions of the Petroleum Production Industry. Ecology
Audits, Inc. Report to EPA Control Systems Laboratory NERC, RTP.
December 1974.
5. Unpublished stack test data for gas sweetening plants. Ecology Audits,
Inc., subsidiary of Core Laboratories, Dallas, Texas. 1974.
6. Control Techniques for Hydrocarbon and Organic Solvent Emissions from
Stationary Sources. U.S. DHEW, PHS, EHS, National Air Pollution Control
Administration, Washington, D.C. Publication Number AP-68. March 1970,
p. 3-1 and 4-5.
7. Control Techniques for Nitrogen Oxides from Stationary Sources. U.S.
DHEW, PHS, EHS, National Air Pollution Control Administration,
Washington, D.C. Publication Number AP-67. March 1970, section 7.3".
34
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III. RESEARCH LEADING TO THE DEVELOPMENT
OF EMISSION FACTORS FOR NATURAL GAS SWEETENING
INTRODUCTION
The development of emission factors for the natural gas processing
industry began with an intensive investigation of the industry itself. This
investigation determined the important emission points and types of pollu-
tants emitted from the different facilities and processes associated with
gas processing. After defining the important emission points and the
pollutant types the literature was researched to determine a fundamental
data base arid to suggest an approach for emission factor development. Con-
sultation with gas engineers, plant personnel and air pollution specialists
was utilized to fill gaps in the data base, as well as to improve or check
its accuracy.
EMISSION POINTS
The initial investigation of the gas processing industry determined
that compressor engine exhausts and gas sweetening plant tail gases were
responsible for the major share of the emissions produced by the industry.
Emissions from compressor engines have already been described in AP-42 so
attention was concentrated on the emissions from gas sweetening plants.
Gas sweetening plant tail gases are usually flared or incinerated if
the sulfur is not removed. Flares are usually elevated, smokeless types in
order to safely dissipate the heat and diffuse any emitted vapors. Some
small installations still use waste gas flares which are less efficient
35
-------
than the modern flares. Incinerators utilize air preraixing to insure good
combustion and incinerator gases are usually exhausted to the atmosphere
via a tall stack.
SULFUR COMPOUND EMISSIONS
Sour natural gas contains hydrogen sulfide (t^S) in widely varying con-
centrations, plus trace amounts of organic sulfur compounds such as mercap-
tans, carbonyl sulfide (£05) and carbon disulfide (CS2).. H2S is rarely less
than 95 percent of the total sulfur content. Tail gases from sweetening
plants contain primarily H2S, S02, C02, N2 and H20. Since combustion of
hydrogen sulfide to sulfur dioxide is over 98 percent complete, SO- is con-
sidered the major pollutant emitted by gas sweetening.plants.
OTHER EMISSIONS
Incinerators and flares at gas sweetening plants operate at tempera-
tures ranging from approximately 900° to 1200°F. At these temperatures the
combustion of H-S to SO- is over 98 percent complete. This temperature
range is too low for significant creation of oxides of nitrogen to be a
problem; therefore, NOX was not considered as an emitted pollutant.
Particulates, smoke and hydrocarbons are byproducts of incomplete com-
bustion. Incomplete combustion can result from insufficient fuel value in
the gas mixture, inadequate combustion air or inadequate mixing of fuel and
air. Since it is necessary to insure good combustion of H S to S02, all of
the above factors are considered in incinerator and flare design and
operating procedures. Therefore, smokeless flares and incinerators usually
do not produce significant amounts of visible emissions, particulate material,
or hydrocarbons.
36
-------
However, little information on hydrocarbon emissions from gas sweet-
ening plant tail gases is available. Based on unpublished stack test data,
it was determined that the efficient combustion of sweetening plant tail
gases results in a negligible production of hydrocarbon emissions. A
typical sample hydrocarbon analysis of waste gas as it leaves a gas
sweetening plant is shown in Table 1.
Table 1
HYDROCARBON ANALYSIS OF No. 1 A Acid GAS SAMPLE
COMPONENT MOL PE
Hydrogen 0.
Hydrogen Sulfide 81.
Carbon Dioxide 17.
Nitrogen 0.
Methane . 0.
Ethane 0.
Propane 0.
iso-Butane 0.
n-Butane 0.
iso-Pentane 0.
n-Pentane 0.
Hexanes 0.
Heptanes plus 0«
100.
R CENT G P M
18
95-
31
02
11
06 0.015
07 0.020
01 0.003
02 0.006
01 0.004
01 0.004
05 0.021
20 0.093
00 0.166
DEVELOPMENT OF EMISSION FACTOR
The amount of SC^ emitted by a gas sweetening plant depends upon
several parameters, and in order to develop a valid emission factor, certain
assumptions were made.
The major waste product from gas sweetening is the acid gas stream.
This acid gas, if not utilized for various commercial purposes, is usually
disposed of by burning. Regardless of whether the acid gas is burned in a
flare or incinerator, combustion of H2S to S02 was assumed to be essentially
100 percent complete.
37
-------
Sweetening of a sour gas stream involves reducing H2S in any concen-
tration the sour gas should contain when produced, to a market standard for
sweet gas, usually a maximum of 0.25 grains H2S per 100 standard cubic feet
of gas, or 0.00039 mol percent H2S. For the purpose of determining an
emission factor, it was assumed that essentially 100 percent of the H2S
present in processed sour gas is removed by the sweetening process.
Therefore, if the average mol percent H2S present in the sweetening
plant intake gas stream is known, then the S02 emissions from the plant are
directly proportional to this H-S value. Emissions can, thus, be calculated
from the average H2S mol percent in sweetening plant intake by use of an
emission factor. This factor was derived mathematically and is shown in
Table 2.
Table 2. EMISSIONS FACTORS FOR GAS SWEETENING PLANTS
S02 Emissions3
Amine with smokeless
flare or incinerator
lbs/106 ft3
1685 Sb
Kg/103m3
26.98 Sb
a Emissions are proportional to the mol percent of Hydrogen Sulfide in gas
sweetening plant intake.
b S is the H2S content in mol percent, of the sour gas entering the gas
sweetening plant. For example; if H2S content is 2 percent, the emissions
factor would be 1685 x 2 = 3370 lbs/106 ft3 gas sweetened. If H2S mol
percent is unknown and cannot be determined, then use AQCR average H2S
value from Table 9.2-2.
H2S concentrations are also reported in grains/100 standard ft3
and ppm. Conversion factors to mol percents are listed below:
.01 mol % H2S = 6.264 grains H2S/100 std ft3 @ 60°F 29.92"Hg
1 grain/100 std ft3 = 15.96 ppm (parts per million) of H2S
in natural gas.
38
-------
' Table 3. AVERAGE HYDROGEN SULFIDE CONCENTRATIONS
IN NATURAL GAS 'BY AIR QUALITY CONTROL REGIONS -
State
Alabama
Arizona
Arkansas
California
Colorado
Florida
Kansas
Louisiana
Michigan
Mississippi
Montana
New Mexico
x
:' AQCR Name
Mobile-Pensacola-Panama City-
Southern Mississippi (FL., MS.)
Four Corners (CO., MM., UT.)
Monroe-El Dorado (LA.)
Shreveport-Texarkana-Tyler
'(LA. , OK.-, -TX.)
Metropolitan Los Angeles
San Joaquin Valley
South Central Coast
Southeast Desert
Four Corners (AZ., MM., UT.)
Metropolitan Denver
Pawnee
San Isabel
Yampa
Mobile-Pensacola-Panama City-
Southern Mississippi (AL., MS.)
Northwest Kansas
Southwest Kansas
Monroe-El Dorado (AR.)
Shreveport-Texarkana-Tyler
(AR., OK., TX.)
Upper Michigan
Mississippi Delta
Mobile-Pensacola-Panama City-
Southern Mississippi (AL., FL.)
Great Falls
Miles City
Four Corners (AZ. , CO., UT.)
Pecos-Permian Basin
AQCR
Number
5 v
14
19
22
24
31
32
33
14
36
37
38
40
5
97
100
19
22
126
134
: 5
141
143
14
155
Average
H2S mol %
3.30
0.71
0.15
0.55
2^09
0.89
3.66
1.0
0.71
0.1
0.49
0.3
0.31
3.30
0.005
0.02
0.15
0.55
0.5
0.68
3.30
3.93
0.4
0.71
0.83
39
-------
Table 3 (continued). AVERAGE HYDROGEN SULFIDE CONCENTRATIONS
IN NATURAL GAS BY AIR QUALITY CONTROL REGIONS
State
North Dakota
Oklahoma
Texas
Utah
Wyoming
AQCR Name
North Dakota
Northwestern Oklahoma
Shreveport-Texarkana-Tyler
(AR., LA., TX.)
Southeastern Oklahoma
Abilene-Wichita Falls
Amarillo-Lubbock
Austin-Waco
Corpus Christi-Victoria
Metropolitan Dallas-Fort Worth
Metropolitan San Antonio
Midland-Odessa-San Angelo
Shreveport-Texarkana-Tyler
(AR., LA., OK.)
Four Corners (AZ., CO., NM.)
Casper
Wyoming (except Park, Bighorn
and Washakie Counties )
AQCR
Number
172 '
187
22
188
210
211
212
214
215
217
218 .
22
14
241
243
Average
H?S mol %
1.74a
1.1
0.55
0.3
0.055
0.26
0.57
0.59
2.54
1.41
0.63
0.55
0.71
1.262
2.34
Sour gas only reported for Burke, Williams and McKenzie Counties.
Park, Bighorn and Washakie Counties report gas with an average 23 mol
percent H2S content.
40
-------
The emission factor for S02 was developed as follows:
626.4 grains H2S
1 mol percent H9S = *
r z 100 ft3
Molecular weight of hydrogen sulfide = 34
Molecular weight of sulfur dioxide = 64
7000 grains = 1 pound
6,264,000 grains H2S 64 1 Ib.
1 mol % H?S = x x = 1685 Ibs. S02/
106 ft3 34 7000 106 £t3
grains
Therefore, any mol percent value of H2S in a gas sweetening plant intake
stream times 1685 gives the number of pounds of S02 emitted per million
cubic feet of gas sweetened.
For example: A sweetening plant operates from a gas field of similar
wells. The average mol percent H2S is 1.2, and the plant processes four
million cubic feet per day of sour gas. To determine the plant emissions:
1.2 1685 2022
mol % H2S x Ibs. S02/106 ft3 = Ibs. S02/106 ft3
2022 Ibs. S02 4 x 106 ft3
x = 8088 Ibs. S02/day
1 x 106 ft3 1 day
Thus, the sweetening plant has a total daily emission of 8088 pounds of
sulfur dioxide.
41
-------
If the average mol percentage of H2S in the plant intake is unknown,
then the values in Table 3 may be used to roughly approximate plant
emissions for plants located in certain geographic areas. This table was
developed by researching state agency data, service company data, and
available literature to determine H-S values for sour gas fields. Data
from the analysis of 13,558 gas samples were surveyed in order to determine
the average H2S concentrations for the 29 AQCRs represented in Table 3.
Only 345 of the gas analyses were of sour gas, and these data are summarized
in Appendix A and presented graphically in Figure 5. At first reading the
values in Table 3 appear low. This is largely a factor of being an average
figure for an entire AQCR where there will be wells producing both sweet
and sour gas. When dealing with an individual gas sweetening plant, every
effort should be made to learn the actual H-S concentration in its intake
gas before using the average value in Table 3.
This approach for development of the emission factor was utilized for
several reasons. First, it was known that the S02 emissions were directly
proportional to the H2S concentration in the burned waste gases. Second,
in order to use this relationship the volume of gas must be known as well
as the H2S concentration. Data on sales gas is usually available, but for
many plants information on the amount of hydrogen sulfide in the incoming
gas stream is not available. Therefore, a method of approximating H2S con-
centrations in sweetening plant intake gas streams had to be devised. Since
information on plant location is known, a method of relating geographic
location to the emission factor was sought, and resulted in analysis of gas
field H2S concentration. Although the natural gas bearing geologic forma-
tions produced in different areas and at different depths have widely
42
-------
3.6
Numbers shown =
average H2S mol percent
of gas produced in each
AQCR.
Figure 5
Map of Air Quality Control Regions in sixteen states
with sour gas resources
-------
divergent H2S values, in general, areas of sour gas production have
reasonably consistent H2S values. In other words, although the difference
between the maximum H-S concentration and the minimum H2S concentration may
be large, most samples fall close to the mean value. This indicates that
in a large percentage of cases emission prediction accuracy will be good.
For example: A sweetening plant is located in West Texas in Ector
County. The plant processes ten million cubic feet of gas daily.
'Ector County is located in Air Quality Control Region 218. In Table 3
the average mol percent H2S listed for AQCR 218 is 0.63. Therefore,
(0.63) x C1685) x (10) = 10,615 Ibs S02/day
mol % H2S S02 Emission Daily Plant emitted
Factor Intake
106 ft3
44
-------
IV. SOURCE CLASSIFICATION CODES
The only emissions from gas sweetening plants are the acid gas streams.
This acid gas may be vented, flared, incinerated, or used by an associated
industry as a feedstock. Most sour gas fields usually have sulfur recovery
plants associated with the gas sweetening plants. Such an associated
industry serves two functions: (1) it serves as a control device by
lowering emission of sulfur oxides to allowable levels and (2) it produces
economic benefits from the sale of the recovered product. Some isolated
fields or individual wells may have small sweetening process units, without
an associated industry to utilize the produced acid gas stream. In these
cases the acid gas is usually flared. Some large volume gas sweetening
plants also operate without marketing their acid gas stream, but normally
these plants are processing gas that is only slightly sour.
Acid gas emitted from sweetening plants is very corrosive and, there-
fore, it is rarely transported by pipeline. In some cases the rich amine
solution from a sweetening plant may be piped for short distances to chemical
manufacturers for commercial production. Therefore, associated industries,
such as sulfur recovery plants or sulfuric acid plants, are usually con-
structed close by sweetening plants to utilize the acid gas supply. When
this is the case, then the proper Chemical Manufacturing source classifica-
tion code should be used to indicate the associated industry as the emission
45
-------
source. This is necessary to demonstrate that the emissions resulting from
a sulfur recovery plant operating on an acid gas supply from a sweetening
plant should be attributed to the sulfur recovery plant and not the gas
sweetening plant. The proper SCC will show the sweetening plant to have no
emissions. Source Classification Codes already exist for the associated
industries listed and emission estimates should be made according to the
Source Classification Codes for the proper emission source. SCCs do not
exist for gas processing as a process separate from gas sweetening, but it
is not necessary to have an SCC for gas processing because there are no
emissions from normal operations of gas processing facilities. Only amine
process flares or incinerators should have emissions attributed to gas
sweetening plants directly.
The Source Classification Codes and emission factors for natural gas
sweetening are listed below:
46
-------
Industrial Process-Natural Gas Industry
****************** ********************
Gas Sweetening
3-06-014-01 Amine process w/smokeless
flare
3-06-014-02 Amine process w/incinerator
3-06-014-03 Amine process w/Claus planta
3-06-014-04 Amine process w/P^SC^ plant**
3-06-014-05 Amine process w/ well
reinjection
3-06-014-99 Other/not classified
Pounds Emitted Per Unit
Part. SOY NOY HC CO
Units
Negc
Neg
0
0
1685 Neg
1685 Neg
0
0
0
0
0 0
Neg Neg MMCF Gas
Neg Neg Processed
0
0
0
0
Pounds Emitted Per Unit
a Sulfur (elemental)
3-01-032-01 MOD-Claus 2Stage
3-01-032-02 MOD-Claus 3Stage
3-01-032-03 MOD-Claus 4Stage
3-01-032-99 Other/Not Clasifd.
" SuIf uric acid
1. H2S04 - Chamber
3-01-022-01 General
Part. SOX NOX HC CO
280.
189.
146.
2. H2S04 - Contact
3-01-023-01 99.7 Conversion
3-01-023-04
3-01-023-06
3-01-023-08
3-01-023-10
3-01-023-12
3-01-023-14
3-01-023-16
3-01-023-18
3-01-023-99
99.5 Conversion
99.0 Conversion
98.0 Conversion
97 . 0 Conversion
96.0 Conversion
95.0 Conversion
94.0 Conversion
93.0 Conversion
Other/Not Clasifd.
2.50
2.50
2.50
2.50
2.50
2.50
2.50
2.50
2.50
4.00
7.0.0
14.0
27.0
40.0
55.0
70.0
82.0
96.0
Units
Tons product
Tons product
Tons product
Tons product
Tons pure acid
produced
Tons " produced
Tons " produced
Tons " produced
Tons " produced
Tons
Tons
Tons " produced
Tons " produced
Tons " produced
Tons produced
" produced
" produced
Negligible emission
47
-------
V. LrST OF GAS PROCESSING PLANTS IN THE CONTIGUOUS
UNITED STATES THAT HAVE SOUR GAS RESOURCES
The following table, Table 4, contains a comprehensive listing of
natural gas plants in the sixteen states known to have significant sour gas
resources. The table is intended to complement the entries in the National
Emissions Data System (NEDS) by comments on how the plant is presently
encoded in NEDS and on other information pertinent to emissions from the
various plants.
Plant identification numbers are presented only for those plants
presently in NEDS, as the authors did not assign new plant identification
numbers for the plants not currently listed. Comments on Standard Indus-
trial Classification codes represent the view of the authors that if a gas
processing plant has an associated industry utilizing the emissions of the
gas processing plant, then it should be coded either as the chemical manu-
facturing facility (2819) or dual coded. The authors hold this view because
emissions from a sulfur recovery plant should be charged to SIC 2819 rather
than from the gas processing plant (SIC 1311) which has a sulfur recovery
unit adjacent to it. The table indicates that all plants presently coded
with SIC 1321 should be recoded 1311.
Comments on SCCs are general because direct knowledge of which specific
processes exist at each plant is not available to the authors. A citation
48
-------
of incorrect SCCs is only made when the existing SCC is obviously wrong for
the kind of facility described by the SIC, plant name and other SCCs for
the facility.
Many publications and various groups and agencies were contacted in an
attempt to compile an accurate listing. Not all of these contacts proved
fruitful. Contacts by phone and mail with many of the state pollution con-
trol offices provided accurate information for those states. A visit to the
Texas Air Control Board (TACB) in Austin yielded a great deal of data for
Texas. Increased activity in the natural gas industry in the last two years
is not reflected in this table. The data are believed current through 1973.
49
-------
Table Explanation
N. D. - No Data
Sources
1 - Texas Air Control Board Data
2 - Mississippi Air Control Board Data
3 - Oil § Gas Journal
4 - Report to EPA "Sulfur Compound Emissions of
the Petroleum Production Industry"
5 - Alabama Air Pollution Control Commission
6 - National Emission Data Systems
Comments
A - New plants to be coded 1311
B - These plants are coded either as gas processing
(1311) or chemical manufacturing (2819) but should
be coded 1311. Dual coding has sometimes occurred.
C - Recede as 1311
D - SIC correctly coded in NEDS
50
-------
Table 4. LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR
AL 001
005
AZ 014
AR 022
CA 024
County
Choctaw
Washington
Escambia
Escambia
Mobile
Apache
Columbia
Lafayette
Lafayette
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Los Angeles
Orange
Orange
Orange
Orange
Company
Placid Oil
Phillips
Exxon
Mallard Exp.
Cities Service Oil
Kerr-McGee Corp.
Ark. -La. Gas Co.
Austral Oil Co.
Phillips Petro.
Getty Oil
Lomita Gas Co.
Lomita Gas Co.
Mobil Oil
Signal Oil $ Gas
Standard Oil
Standard Oil
Sun Oil
Texaco
Union Oil
Union Oil
Union Oil
Signal Oil § Gas
Standard Oil
Standard Oil
Union Oil
Plant/ ID
Womack Hill
Chatora
Flomaton .
. Canoe
Citronelle
Navaho
Hamilton
Lake Erling
Me Kami e
Sesnon Frew
Harbor Plant
Signal Hill
Springs Plant
Inglewood Plant
Inglewood LTS
Torrance
Newhall
Honor Rancho
Bell
Del Valle
Dominguez
.Huntington Beach
Huntington Beach
Murphy-Coyote LTS
Stearns
Source
5
5
4
5
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Comments*
A
A
A
A
A
A
B
B
B
A
B
A
A
A
A
A
A
A
A
A
A
A
A
A
A
\
Dual
Dual
Dual
Dual
All SOX emissions in short tons/year.
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County Company Plant/ID Source Comments*
*
CA 024 Santa Barbara Arco --/44 ' 6 A
2-02-002-02
3-06-001-04
3-06-008-02
3-06-008-04
3-06-008-05
4-03-001-02
Santa Barbara Arco State Lease #308 3 A
Santa Barbara Getty Oil Los Alamos 3 A
Santa Barbara Mobil Oil Los Flores/30 6 A
3-06-008-05
N> 4-03-001-02
Santa Barbara Phillips Petro. Tajiguas/31 6 A
2-02-002-02
3-06-008-02
3-06-003-03
3-06-008-05
Santa Barbara Shell Goleta/32 6 A
' 3-06-008-03
3-06-008-05
3-06-001-04
4-03-001-02
Santa Barbara Shell Oil Molino/34 6,3 A
i 4-03-001-02
3-06-001-04
'2-02-002-02
3-06-008-02
3-06-008-03
3-06-008-04
3-06-008-05
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County Company Plant/ID Source Comments*
s
CA 024 Santa Barbara Standard Oil Carpenteria/35 ' 6,3 A
2-02-002-02
3-06-008-02
3-06-008-04
3-06-008-05
3-06-001-04
4-03-001-02
Ventura Arco --/3 6 A
2-02-002-02
Ventura Arco N. Sulfur Mtn./4 6 A
w 2-02-002-02
w . 3-06-008-02
3-06-008-03
3-06-008-04
3-06-008-05
4-03-001-02
4-03-001-04
Ventura Arco Ojai Timber Canyon 3 A
Ventura Chanslor-Western W. Pac. Coast Hwy/5 6 A
2-02-002-02
3-06-008-02
3-06-008-03
3-06-008-04
3-06-008-05
4-01-999-99
Ventura Coline Gas Coline Plant 3 - A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
in
State AQCR County Company
CA 024 Ventura Continental Oil
Ventura Getty
Ventura Getty
Ventura Getty
/
Ventura Getty
Ventura . Getty
Ventura Getty
Ventura Getty
Plant/ID
San Miguelito/8 '
Crocker/68
'
Oxnard Plains
School Canyon/ 18
S; Mtn./19
Tapo/69
Tapo-Simi/70
Temescal-Piru/67
Source Comments*
6 A
2-02-002-02
3-06-008-02;
4-03-001-02;
6 A
3-06-008-03;
4-03-001-02;
6 A
2-02-002-02
3-06-008-02
3-06-008-03;
4-03-001-02;
6 A
3-06-008-02
3-06-008-03;
4-03-001-02
4-03-001-04
4-03-999-99
6 A
3-06-008-02;
4-03-001-02;
6 A
2-02-002-02
( 3-06-008-02;
4-03-001-02;
6 A
3-06-008-03;
4-03-001-02;
6 A
3-06-008-02;
4-03-001-02;
-03;
-04
-05
-04
'
-04;
-04
-04;
-03;
-04
-03;
-04
-05
-04
-03;
-04
-04
-05
-05
-05
-05
-05
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
Company
Plant/ID
Source
Comments*
CA
024
en
in
Ventura
Ventura
Ventura
Ventura
Ventura
Getty
Lloyd Corp.
Ventura
Ventura
Ventura
Mobil
Mobil
Mobil
Mobil
Mobil
Mobil
Ventura/20
Ventura/28
Barnard-Nitten/71
Oxnard/75
Padre Canyon/31
Rincon/30
Rose Lease/73
.Tomson Lease/74
6,3 A^SOX - 6
3-06-008-02; -03; -04; -05
4-03-001-02; -04
2-02-002-02
3-06-001-04
6 A
4-03-001-02; -04S
2-02-999-97
3-06-008-02; -03; -04; -05
6 A
2-02-999-97
3-06-001-02; -03; -04; -05
6 A
4-03-001-02; -03; -04; -07
4-03-001.52
6 A
2-02-002-02
3-06-001-02
3-06-008-02; -03; -04; -05
4-03-001-02; -04
4-03-999-99
6 A
3-06-008-03; -04; -05
6 ! A
3-06-008-02; -03; -04; -05
6 A
3-06-008-03; -05
* All SOX emissions in short tons/year.
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
Company
Plant/ID
Source
Comments*
CA 024
en
Ventura
Ventura
Ventura
Ventura
Ventura
Ventura
Phillips Petro.
Shell Oil
Standard
Standard
Standard
Standard
W. Pacific Coast/33
Ventura/43
Ventura
Ventura
Shell Oil
Shell Oil
Ventura/44
Ventura/ 4 5
Fillmore/47 6
Fillmore Oil Field/50 6
Oxnard/49
W. Montalvo/48
2-02-002-02
3-06-008-02; -03; -04; -05
3-06-009-01
3-06-001-02; -04
4-03-001-02; -04
6,3 A
3-06-008-02; -03; -04; -05
3-06-001-04
4-03-001-02; -04
6 A
3-06-008-02; -03; -04; -05
4-03-001-02; -04
6 A
3-06-001-04
2-02-002-02
3-06-008-02; -03; -04; -05
3-06-007-01
6 A
4-03-001-02; -04
4-04-001-99
A
4-03-001-02
I 4-03-001-04
6 A
-4-03-001-02; -04
6 A
4-03-001-02; -04
4-03-999-99
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
tn
State AQCR County Company Plant/ID Source
CA 024 Ventura Texaco Shiells Canyon/55 6,3
Ventura Texaco S. Mtn. Field/53 6
Ventura Union Oil Bardsdale/60 6
Ventura Union Oil Big Mountain/61 6
Ventura Union Oil Broad Oaks/57 6
Ventura Union Oil Del Valle Absorption
Plant/80 6
Ventura Union Oil Oakridge Field/58 6 \
Ventura Union Oil Santa Paula/56 6
.
Comments*
A
3-06-008-02;
4-03-001-02;
A
4-03-001-02;
3-06-001-04
A
3-06-008-02;
4-03-001-02;
A
4-03-001-02;
2-02-002-02
3-06-001-04
3-06-008-03;
A
4-03-001-02;
A
2-02-002-02
1-02-006-02
3-00-008-05
3-06-008-02;
3-06-007-01
A
3-06-008-02;
4-03-001-02;
A
3-06-008-03;
4-03-001-02;
3-06-001-04
-03; -04; -05
-04
-04
-03; -04; -05
-04
-04
-05
-04
-03; -04
-03; -04; -05
-04
-04; -05
-04
-------
in
00
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 024 Ventura
Ventura
Ventura
Ventura
Ventura
Ventura
025 Monterey
Monterey
Company Plant/ID Source
Union Oil Simi/77 6
Union Oil S. Tapo/79 6
Union Oil West Mountain/81 6
Union Oil Ventura/82 6
Union Oil Torrey Oil Field/59 6
Westates Petro. Telegraph Rd./64 6
Mobil Oil San Ardo/19 6
1
Texaco San Ardo/30 6
.
Comments*
A
2-02-002-02
3-06-008-03;
4-03-001-02;
A
4-03-001-02;
3-06-008-03;
A .
3-06-008-03
3-06-008-05
4-03-001-02;
2-02-002-02
3-06-001-04
A
4-03-002-03
3-06-008-03
A
3-06-008-02;
4-03-001-03;
A
4-03-001-02;
4-03-999-99
A-SOX - 3
1-02-006-01
1-02-999-98
-05
-04
-04
-05
-04
-03; -04; -05
-04
-04
,220
A-SOX - 9160
1-02-006-01
1-02-999-98
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
tn
State AQCR County Company Plant/ ID
CA 030 Contra Costa Allied Chemical --/17
031 Fresno Mobil Helm/65
Fresno Sampson Resources Burrel/51
Fresno ^ S. Pac. Pipeline Fresno/50
Fresno Standard Oil Three-P
Fresno Shell Coalinga/64
Fresno ' Standard Oil Fresno/69
Fresno Standard Oil Kettleman-
Coalinga/70
Source Comments*
6 B Recede Dual
SOX - 7200
3-01-032-01
6 A
3-06-008-05
3-06-008-03
4-03-001-04
4-03-001-02
6 C Recede
3-06-008-05
2-02-002-02
4-03-001-01
6 A
4-03-001-52
4-03-001-07
4-03-002-01
3 A
6 A-S°X " 405
3-06-008-05
3-06-001-03; -04
4-03-001-04; -02
6 A
3-06-008-05
3-06-008-04
3-06-008-03; -02
6 A
3-06-007-01; 2-02-002-02
3-06-008-05; -04; -03; -02
3-06-001-04
4-03-001-04; -02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 031 Fresno
Fresno
Fresno
Fresno
Fresno
Kern
Kern
Kern
Kern
Company
Texaco
Texaco
Union Oil
Union Oil
Union Oil
Arco
Arco
Arco
Arco
PI ant /ID Source
Coalinga/63 ' 6
Raison City/66 6
Coalinga Nose/68 6,3
Guijarral Hills/74 6
Jacalitos Field/73 6
f
North Coles Levee 3
Steam Inj . Boiler/201 6
Steam Inj . Boiler/202 6
Steam Inj . Boiler/203 6
Comments*
A-SOX -
3-06-001-03
4-03-001-04
4-03-001-02
A
3-06-008-05
2-02-002-02
3-06-001-04
4-03-001-04
4-03-001-02
A-SOX -
2-02-002-02
3-06-001-04
4-03-001-04
A
3-06-008-05
4-03-001-04
A
3-06-008-03
4-03-001-04
A
A-SOX -
1-02-004-02
A-SOX -
1-02-006-02
1-02-004-02
A- SO -
1-02-004-02
1-02-006-02
77
; -04
,
^
3
; -02
; -03
; -02
; -02
161
43
69
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Arco
Belridge Oil
Belridge Oil
Berry Holding
Berry Holding
Berry Holding
Berry Holding
Brogden Oil
Chans lor -Western
Chans lor- Western
Chans lor- Western
Chans lor- We stern
Chans lor- Western
Chans lor- Western
Chanslbr- Western
Plant/ID
Stevens-Calidon
McKittrick/204
Belridge/205
/206
--/207
Steam Inj . Boiler/209
Taft/208
McKittrick/210
Fellows/211
/212
--/213
/214
/215
--/216
Steam Inj . Boiler/217
Source
3
6
6,3
6
6
6
6
6
6
6
6
6
6
6
6
Comments*
A
A-SO - 287
1-02-004-02
A-SOX - 102
1-02-004-02; -03
A
1-02-004-02
1-02-006-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A-SOX - 2884
1-02-004-02
A-SOX - 670
1-02-004-02
A-SOX - 201
1-02-004-02
A-SOX - 201
1-02-004-02
A-SOX - 223
1-02-004-02
A-SOX - 223
, 1-02-004-02
A-SOX - 420
1-02-004-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
K)
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Chans lor-Western
Chans lor-Western
Chans lor- Western
Chans lor- Western
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Plant/ID
Steam Inj . Boiler/218
Steam Inj . Boiler/219
Steam Inj. Boiler/220
Steam Inj . Boiler/221
Buena Vista Hills
Cymric/13
Kern Field/223
01 ig Pump St./322
Reed Field/222
Templor Pump Sta./223
/224
/225
/226
--/227
Source
6
6
6
6
3
6,3
6
6
6
6
6
6
6
6
Comments*
A- SO - 603
1-02-004-02
A-SOX - 402
1-02-004-02
A-SOX - 76
1-02-004-02
A-SOY-223
A
1-02-004-02
A
A
2-02-002-02
3-06-008-02; -05; -04; -03
3-06-001-04
A-SOX - 2962
1-02-004-02
A
1-02-006-02
A-SOX - 1643
1-02-004-02
A-SOX - 48
1-02-004-02
A- SO - 3329
1-02-004-02
A-SOX - 1035
1-02-004-02
A-SO - 4360
1-02-004-02
A-SOX - 190
1-02-004-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o\
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
. Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty Oil
Getty. Oil
Plant/ID
~/228
/229
--/230
--/231
--/232
/233
--/234
--/235
--/236
/237
--/238
--/239
--/240
--/241
/242
Source
6
6
6
6
6
6
6
6
6
6
6
6
6
6
6
Comments*
A-SOX - 3088
1-02-004-02
A-SOX - 309
1-02-004-02
A-SOX - 95
1-02-004-02
A-SOX - 95
1-02-004-02
A-SOX - 6774 ^
1-02-004-02
A-SOX - 3047
1-02-004-02
A-SOX - 107
1-02-004-02
A-SO - 107
1-02-004-02
A-SO - 107
1-02-004-02
~A-SOX - 115
1-02-004-02
A-SO - 115
1-02-004-02
A-SOX - 209
1-02-004-02
A-SOX - 30
.1-02-004-02
A-SOX - 143
1-02-004-02
A-SOX - 179
1-02-004-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Getty Oil
Gulf Oil
Marathon Oil
McCulloch Oil
McFarland Energy
Mobil
Mobil
Mobil
Mobil
Mobil
Mobil
Mobil
Mobil
Mobil
North Kern Front
Enterprises
Occidental Petro.
Plant/ID
/243
Paloma
South Coles Levee
Bakersfield/245
/255
Bakersfield/247
Bakersfield/248
Bakersfield/319
Steam Inj . Boiler/249
Steam Inj. Boiler/250
Steam Inj . Boiler/251
Steam Inj . Boiler/252
Steam Inj . Boiler/253
Steam Inj . Boiler/254
Steam Inj . Boiler/323
Steam Inj. Boiler/244
Source
6
3
3
6
6
6
6
6
6
6
6
6
6
6
6
6
Comments*
A-SO - 190
1-02-004-02
A
A
A-SOX - 40
1-02-004-02; -03
A
0-00-000-00 Recode
A-SO - 612
1-02-004-02
A-SOX - 1266
1-02-004-02
A
3-06-001-04
A-SO - 1497
1-02-004-02
A-SO - 875
1-02-004-02
A-SOX - 593
1-02-004-02
A-SO - 409
1-02-004-02
A-SO - 220
1-02-004-02
A-SOX - 168
1-02-004-02
A-SOX - 137
1-02-004-02
A
1-02-004-02
-------
in
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Reserve Oil § Gas
Shell Oil
Shell Oil
Shell Oil
Shell Oil
Shell Oil
Signal Oil § Gas
Standard Oil
. Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Plant/ID
Reserve Standard
Bakersfield Pump
Sta./318
Mid Pump Sta./315
Petrol Rd/313
Ten Section
Wasco/314
Maricopa
Bitterwater Pump
Sta./310
Kern Pump Sta./309
Lokern Pump Sta./311
Lost Hills
McKittrick
Oildale/260
Source
3
6
6
6
3
6
3
6
6
6
3
3
6
Comments*
A
A-SOX - 48 .
3-06-001-02
1-02-004-02
A-SOX - 48
1-02-004-02
A-SOX - 48 '
1-02-004-02
1-02-006-02; -03; -04
A
A-SO - 48
1-02-004-02
A
A
1-02-004-03
A
1-02-004-03
1-02-006-03
A
1-02-006-03
1-02-004-03
A
A
A-SO - 170
1-02-004-02
Kern
Standard Oil
Oildale/261
A-SOX - 340
1-02-004-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
ON
ON
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Standard Oil
Plant/ID
Oildale/262
Oildale/263
Oildale/264
Oildale/265
Oildale/266
Oildale/267
Oildale/268
One-C
Rio Bravo Pump
Thirty-two Z
/2S7
--/258
Source
6
6
6
6
6
6
6
3
Sta./312 6
3
6 '
6
Comments*
A-SO - 170
1-02-004-02
A-SOX - 170
1-02-004-02
A-SOX - 170
1-02-006-02
1-02-004-02
A-SOX - 340
1-02-006-02
1-02-004-02
A-SOX - 170
1-02-006-02
A-SO - 170
1-02-006-02
1-02-004-02
A-SOX - 340
1-02-004-02
1-02-006-02
A
A
1-02-004-03
1-02-006-03
A
A-SO - 136
1-02-008-02
1-02-004-02
A-SO - 952
1-02-004-02
1-02-006-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Standard Oil
Sun Oil
Sun Oil
Superior Oil
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
.
Tenneco
Plant/ID
/259
Newhal 1/269
Newhall/271
Rio Bravo
Bakersfield/279
Bakersfield/280
Bakersfield/281
Bakersfield/282
Bakersfield/283
Bakersfield/284
Bakersfield/285
Bakersfield/286
Bakersfield/287
Bakersfield/288
Bakersfield/289
Source
6
6
6
3
6
6
6
6
6
6
6
6
6
6
6
Comments*
A-SOX - 262
1-02-004-02
1-02-006-02
A
1-02-004-02
A
1-02-004-02
A
A-SOX - 103
1-02-004-02
A-SO - 307
1-02-004-02
A-SOX - 154
1-02-004-02
A-SOX - 1475
1-02-004-02
A-SO - 1390
1-02-004-02
A-SO - 957
1-02-00^-02
A-SOX - 31
1-02-004-02
A-SOX - 487
1-02-004-02
A-SOY - 784
JN.
1-02-004-02
A-SOX - 180
1-02-004-02
A-SO - 81
1-02-004-02
-------
00
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES .
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Company
Texaco
Texaco
Texaco
Texaco
Texaco
Texaco
Texfel Petro.
Union Oil
Union Oil
Union Oil
Union Oil
Union Oil
Union Oil
Victory Oil
.
Plant/ID
Bakersfield/293
Bakersfield/294
Bakersfield/295
Bakersfield/296
Bakersfield/297
Bakersfield/298
--/291
Antelope Pump Sta
Bakersfield/299
Bakersfield/300
Bakersfield/301
Junction Pump Sta
Middlewater Pump
McKitrick/302
Source
6
6
6
6
6
6
6
./307 6
6
6
6
./306 6
Sta/308 6
6
Comments*
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A-SOX - 41
1-02-004-02
A
3-06-001-03
A
1-02-004-02
A-SO - 120
1-02-004-02
A-SO - 138
1-02-004-02
A
3-06-001-03
A
3-06-001-01
A
1-02-004-02
3-06-001-03
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o\
State AQCR County
CA 031 Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
Kern
032 Santa Barbara
Company
Victory Oil
Victory Oil
Victory Oil
Westates Petro.
M. H. Whittier
M. H. Whittier
M. H. Whittier
M. H. Whittier
M. H. Whittier
M. H. Whittier
M. H. Whittier
Arco
Plant/ID
McKitrick/303
McKitrick/304
McKitrick/305
Bakersfield/290
Fellows/272
Fellows/273
Fellows/274
Fellows/275
Fellows/276
Fellows/277
Fellows/278
--/45
Source
6
6
6
6
6
6
6
6
6
6
6
6
Comments*
A
1-02-004-02
3-06-001-03
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
1-02-004-02
A
2-02-002-02
3-06-008-02
3-06-008-04; -05
3-06-001-04
4-03-001-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
Company
Plant/ID
Source
Comments*
CA 032 Santa Barbara Arco
Santa Barbara Getty Oil
Santa Barbara Getty Oil
Santa Barbara Shell
Santa Barbara Texaco
Santa Barbara Union Oil
Cayama Valley/43
Canyon Field
Zaca Field/29
Santa Barbara/33
E. Cat Canyon/36
Casmalia/41
A
4-03-
4-03-
3-06-
A-
3-06-
3-06-
2-02-
4-03-
A-
3-06-
4-03-
3-06-
A
3-06-
3-06-
4-03-
A
3-06-
3-06-
4-03-
A
2-02-
2-02-
3-06-
3-06-
4-03-
001-02
001-04
008-05
SOX - 16
001-04
008-05
002-02
001-02; -04
SO - 8
001-04
001-02
008-05
008-02; -03; -04; -05
001-04
001-02
001-04
008-03; -04; -05
001-02
002-02
004-01
008-03; -04; -05
001-04
001-02
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
CA 032 Santa Barbara
-
Santa Barbara
Santa Barbara
Santa Barbara
CO 014 La Plata
035 Mesa
036 Adams
Adams
Adams
Adams
Arapahoe
037 Logan
Morgan
Company
Union Oil
Union Oil
Union Oil
Union Oil
Northwest
Pipeline
Continental Oil
Amoco Production
Koch Oil
Vessels Gas Proc.
Vessels Gas Proc.
Amoco Production
Excelsion Oil
Union Oil
Plant/ID
Cat Canyon/ 38
Lompoc Field/39
Orcutt Station/40
Santa Maria/42
Ignacio
Fruita
Third Creek
Third Creek
Bennett
Irondale
Peoria
Yenter
Adena
Source
6
6
6
6,3
3
3
3 .
3
3
3
3
3
3
Comments*
A
2-02-002-02
2-02-004-01
3-06-008-03; -04; -05
4-03-001-02
3-06-001-04
A
2-02-002-02
3-06-008-03
3-06-008-04; -05
A
4-03-001-02
3-06-008-03
A
2-02-002-02
2-02-004-01
3-06-008-03; -04; -05
3-06-001-04
4-03-001-02
A
A
A
A
A
A
A
A
A
-------
N)
FL 049
KS 096
097
099
100
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State
CO
AQCR
037
040
County
Morgan
Morgan
Weld
Rio Blanco
Rio Blanco
Rio Blanco
Rio Blanco
Company
Vallery Corp.
Vessels Gas Proc.
Amoco Production
Chevron Oil
Matrix Land
Sun Oil
Texaco
Plant/ID
Vallery
Round Up
Spindle
Range ley Hagood
Piceance Creek
Dragon Trail
Wilson Creek
Source
3
3
3
3
3
3
3
Comments*
A
A
A
A
A
A
A
Bradford
Ellsworth
Ellsworth
Rush
Harper
Florida Hydrocar-
bons
Northern Gas
Products
Northern Helex
Kansas Refined
Helium
Cities Service Oil
Bradford
Otis '
Spivey Gas/17
Harvey
Kingman
Kingman
Reno
Sedgwick
Barber
Ford
Peoples Natural Gas Burrton
Cities Service Oil Cheney
Cities Service Oil
Cities Service Oil
Cities Service Oil
Skelly Oil
Skelly Oil .
Midway
Hutchinson
Wichita
Medicine Lodge
Minneola
3
3
3
3
3
3
3
3
3
A
A
1-02-006-02
2-02-002-02
2-02-002-01
5-03-005-99
A
A
A
A
A
A
A
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
in
State AQCR County
KS 100 Grant
^
Grant
Grant
Grant
Kearney
Morton
Morton
Morton
Morton
Pratt
Seward
Seward
Seward
Seward
Scott
Stanton
Company
Amoco Production
Cities Service Oil
Mesa Petroleum
Mobil Oil
Colo. Interstate
Gas
Alamo Chemical
Anadarko Prod.
Cities Service
Colo. Interstate
Gas
Kathol Natural Gas
Anadarko Prod.
National Helium
Anadarko Prod.
Northern Natural
Gas
Cities Service
Peoples Natural Gas
Plant/ID
Ulysses Gas/3
Jayhawk
Mesa Ulysses
Hickok Gas
Lakin
Elkhart/1
Interstate
Wilburton
Morton County
Rattlesnake Creek
Woods
NH
Cimarron
Holcomb
Sunflower
Johnson
Source
6
3
3
6
3
6
3
3
3
3 ,
3
3
3
3
3
3
Comments*
C Recede
2-02-002-02
1-02-006-02
3-06-001-04
2-01-999-97
A
A
C Recede
2-02-002-02
2-01-999-97
1-02-006-03
1-02-006-02
A
C Recede
5-03-001-01
1-02-006-02
2-02-002-02
3-01-999-99
A
A
A
A
A
A
A .
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
LA 019 Ouachita
Morehouse
Rich land
" Tensas
022 Bossier
Bossier
Bossier
Bossier
Caddo
Claiborne
Claiborne
Lincoln
Lincoln
Lincoln
Nachitoches
Webster
Webster
Webster
Webster
Webster
106 Allen
Acadia
Acadia
Acadia
Acadia
Acadia
Acadia
Company
Ark- La Gas
Miss. River
Transmission
Sun Oil
Horner § Smith
Amoco
Ark-La Gas
Sun Oil
Union Tx. Petro.
United Gas Pipe-
line
Tenneco Oil
Claiborne Gas
Ark- La Gas
Chevron Oil
Kerr-McGee
Placid Oil
Amoco Prod.
Ark- La Gas
Ark -La Gas
Beacon Gas
Cotton Valley
Operators Comm.
Hunt Petro .
Cities Service
Continental Oil
LaGloria Oil § Gas
Shell Oil .
Union Tx. Petro.
Union Tx. Petro.
Plant/ID
Calhoun
Kenmore
Delhi
Locust Ridge
Sentell
Sligo
S. Sarepta
Sligo
Greenwood
Stephens
Claiborne
North Ruston
Hico Knowles
Dubach
Black Lake
Minden
Bistineau
Minden
cvoc
Kinder
Crowley
Acadia
Rayne
Mermentau
Eunice
Rayne
Source
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-A .
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
On
State AQCR County
LA 106 Ascension
Ascension
Ascension
- Assumption
Assumption
Assumption
Beauregard
Calcasieu
Calcasieu
Calcasieu
Calcasieu
Calcasieu
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Cameron
Company
Mobil
Shell
Uniroyal Chemical
Liquid Products
Recovery
Liquid Products
Recovery
Wanda Petro.
Sohio Petro.
Amoco
Cities Service
Continental Oil
Koch Oil
Sohio Petro.
. Amoco Prod.
Amoco Prod.
Austral Oil
Chevron
Continental Oil
Crystal Oil
Liquid Prod.
Recovery
Mobil Oil
Shell Oil
Shell Oil
.Shell Oil
Shell Oil
Skelly Oil'
Sohio Petro.
Plant/ID
Riverside
Tebone
Geismar/12
Napoleonville #1
Napoleonville #2
Napoleonville
South Fields
South Manchester
Lake Charles
Gillis
Manchester
Holmwood
Big Lake
South Pecan Lake
Holly Beach
West Cameron
Grand Chenier
Kings Bayou 5 Hog
S. Grand Chenier
Cameron
Black Bayou #1
Black Bayou #2
Chalkey
Kings Bayou
Cameron
Grand Chenier
Source
3
3
6
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Bayou 3
3
3
3
3
3
3
3
3
Comments*
A
A
B-SOX - 93 Dual
3-01-032-99
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
. A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
LA 106 , Cameron
Cameron
East Baton
Rouge
Evangeline
Evangeline
Iberia
Iberia
Iberia
Iberville
Jefferson
Jefferson
Jefferson
Davis
Jefferson
Davis
Jefferson
Davis
Jefferson
Davis
Jefferson
Davis
Lafayette
Lafourche
Lafourche
Lafourche
Plaquemines
Plaquemines
Plaquemines
Plaquemines
Company
Superior Oil
Warren Petro.
Mull ins § Prichard
S. La. Production
S. La. Production
Exxon
Koch Oil
Shell Oil
Shell Oil
Exxon
Texaco
Amoco
Amoco
Phillips Petro.
Shell Oil
. -
Texaco
Sun Oil
Amoco Production
Exxon
Liquid Prod. Rec.
Chevron
Exxon
Getty Oil
Getty Oil
Plant/ID
Lowry
Johnson Bayou
Bartville
Cocodrie
St . Landry
Avery Island
Bayou Postillion
Weeks Island
Bayou
Grand Isle
Lafitte
South Jennings
S. Thornwell
Rollover
Iowa
South Lake Arthur
Maurice
Lake Boeuf
Thibodaux
Bourg
Romere Pass
Delta
Bastian Bay
Venice
Source
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3 ,
3
3
' 3 >
3 .
3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A .
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
LA 106 Plaquemines
Plaquemines
Plaquemines
Plaquemines
Pointe Coupee
Pointe Coupee
Pointe Coupee
Rapides
St . Bernard
St. Bernard
St. Bernard
St . Bernard
St. Charles
St. Charles
St. James
St. James
St. James
St. James
St. James
St . Landry .
St . Landry
St . Landry
St . Landry
St . Landry
St. Martin
St. Martin
St. Mary
St. Martin
Company
Getty
Gulf Oil
Gulf Oil
Texaco
Anchor Gasoline
Sun Oil
Texaco
Cities Service
Shell Oil
Shell Oil
Southern Natural
Gas
Union Tx. Petro.
Shell Oil
Texaco
Cities Service
Exxon
Liquid Prod.
Recovery
Mid-La. Gas
Shell Oil
Exxon
Getty
Gulf Oil
Mobil
Sohio
Exxon
Kerr-McGee
Exxon
Shell Oil
Plant/ID
West Bastian Bay
SE Bastian Bay
Venice
Venice
Krotz Springs
Fordoche
Fordpche
Big Island
Toca
Yscloskey
Toca
Toca
Norco
Par ad is
St. Amelia
College Point
Vacherie
Kenmore
LaPice
Opelousas
Opelousas
Krotz Springs
Opelousas
Washington
Duck Lake
Bayou Crook Chene
Garden City
West Lake Verret
Source
3
3
3
3
3
3
3
3
3
3
3 .
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
oo
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
X
LA 106 St. Martin
St. Martin
St. Martin
St. Mary
St. Mary
St. Mary
St. Mary
St. Mary
St. Mary
.St. Mary
Terrebonne
Terrebonne
Terrebonne
Terrebonne
Terrebonne
Terrebonne
Terrebonne
Terrebonne
. Terrebonne
Terrebonne
Vermilion
Vermilion
Vermilion
Vermilion
Vermilion
Vermilion
Company
Southeastern
Public Service
Wanda Petro.
Wanda Petro.
Arco
Placid Oil
Shell
Sun Oil
Sun Oil
Texaco
Wanda Petro.
Exxon
Exxon
Getty
La. Land §
Exploration
Placid Oil
Superior Oil
Superior Oil
Shell
Shell
Union Oil
Amoco
Mobil
Phillips Petro.
Superior Oil
Texaco
Texaco
Plant/ID
South Section
Breaux Bridge
Cypress
Bayou Sale
Patterson
Calumet
Bayou Sale
Belle Isle
Floodway
Eugene Isle
Lirette
Lirette - 2
Hollywood
Pointe aux Chene
Lapeyrouse
Bayou Penchant
Four Isle Dome
N. Terrebonne
Timbalier Bay
Houma
TSMA
Cow Island
Vermilion
Gueydan
Henry
Sea Robin
Source
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
to
State AQCR County
MI 122 Osceola
125 Hillsdale
Ingham
1 26 Crawford
MS 005 Adams
Clarke
Clarke
Clarke .
Clarke
Clarke
Clarke
Clarke
Jasper
Marion
Marion
- Pike
Rank in
Smith
Wayne
Wayne
Wayne
ND ND
ND
Company
Mich-Wis. Pipeline
Marathon Oil
Mobil Oil
Dow Chemical
Sun Oil
Continental Oil
Continental Oil
Getty Oil
Getty Oil
Shell Oil
Tx. Oil § Gas
Tonkawa Gas
Processing
Skelly Oil
, Exxon
Exxon
Sun Oil
Shell Oil
Shell Oil
Amerada-Hess
Amerada-Hess
Mobil
Amoco Oil
Amoco Production
Plant/ID
Loreed
Scipio
Aure 1 iun
Dow
Mercer
Pachuta Creek
West Nancy
East Nancy
West Nancy
Goodwater
Harmony
Paulding/31
Bay Springs/ 13
Hub
Sandy Hook
McComb/33
Thomasville
.Tallahala
Cypress Creek
Quitman
S. Cypress Field
Prairie Branch
Lake Utopia
Source
3
3
3
3
3
2,4
2,4
2,4
2,4
2,3,4
2,4
6
6
3
3
6
2,3,4'
2,3,4
2,4
2,4
2,4
2
2
Comments*
A
A
A
A
A
A- SO - 8
A-SOX - 240"
A-SOX - 0.43
A-SOX - 4
B-SOX - 1000
A
C
2-02-002-02
3-06-001-02
C
1-02-006-03
2-02-002-02
A
A
C
2-02-002-02
3-06-001-02 .
B-SOX - 49
B-SOX - 444
A
A
A-SOx - 587
A-SO - 234
A-SOX - 149
Dual
Recede
Recede
Recede
Dual
Dual
-------
oo
o
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
MS ND ND
ND
ND
ND
ND
ND
ND
ND
ND '
ND
ND
ND
MT 140 Yellowstone
141. Glacier
143 Fallen
Richland
Roosevelt
NM 014 Rio Arriba
Rio Arriba
San Juan
Company
Arco
Getty Oil
Getty Oil
Getty Oil
Hess Pipeline
Hess Pipeline
Hess Pipeline
Shell
Shell
Shell
Texaco
Amoco Production
Montana Sulfur §
Chemical
Thunderbird
Resources
Union Tx. Petro.
McCulloch Gas
McCulloch Coas.
Proc .
El Paso Nat. Gas
Southern Union
Prod .
Arco
Plant/ID
Pachuta Creek Field
E. Paulding Field
Vossburg
W. Paulding Field
Eucutta Station A
Eucutta Station 'B
Hiwannee Storage
Pachuta Creek
Stafford Springs Field
W. Pachuta
W. Pachuta Creek
N. Nancy Field
Billings/14
Westco Refining
Glendive
Fairview
Tule
Lindrith Sta./3
Lybrook
Four Corners/4
Source
2
2
2,4
2
2
2
2
2
2
2
2
2
6
3
3
3
3
6
3
6
Comments*
A-SO - 17
A-SOX - 38
A-SOX - 0.3
A-SOX - 1
A-SOX - 496
A-SOX - 1094
A
A-SOX - 88
A-SO - 14
A- SO* - 3
A-SOX - 0.4
A-SOV - 1106
A.
B-SOX - 82 Dual
3-01-999-99
A
A
A
A
A
2-02-002-02
3-06-001-04
A
A
4-03-001-02; -04
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
00
State AQCR County Company Plant /ID Source
NM 014 San Juan El Paso Nat. Gas Blanco Station/8 6
t
San Juan El Paso Nat . Gas Chaco Station/9 6
San Juan El Paso Nat. Gas Chaco Station/14 6
San Juan El Paso Nat. Gas Kutz Station/16 6
San Juan El -Paso Nat. Gas San Juan River . 6
Sta./lO
San Juan El Paso Nat. Gas San Juan Sta./17 6
San Juan El Paso Nat. Gas Station No. 3B-1/15 6
San Juan Southern Union . Kutz Gasoline/26 6
Products
Comments*
C
4-03-001-02; -03;
1-02-007-02
2-02-002-02
2-02-999-97
3-06-001-04
4-90-999-99
C
4-03-001-03
1-02-007-02
2-02-002-02
3-06-001-04
2-02-999-97
3-06-999-99
C
2-02-002-02
C
2-02-002-02
C-SOX - 6304
4-03-001-01; -03
1-02-007-01
2-02-002-02
.3-06-009-01; -99
C
2-02-002-02; -01
C
2-02-002-02
C
2-02-002-02
3-06-001-04
Recede
-04
Recode
Recede
Recode
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
00
State AQCR County
NM 155 Chaves
Eddy
Eddy
Eddy
Eddy
Eddy
Eddy
Eddy
Eddy
Company
Cities Service
Amoco Production
Amoco Production
El Paso Nat. Gas
Marathon Oil
Marathon Oil
Phillips Petro.
Southern Union Gas
Southern Union Gas
Plant/ID
Cato/2
Empire Abo
Hobbs/2
Wingate
Indian Basin
Midland/8
Artesia/11
Aval on
Indian Hills/6
Source Comments*
6 A
2-02-002-02
3,4 B
6 C-SOx " 120°
1-02-006-03
2-02-002-02
3-01-032-02
4-03-001-01
4-03-001-03
3 A
3,4 B
6 C-SO - 128
3-01-032-01
2-02-002-02; -01
4-03-001-01; -03
6 G-SOX' 1343°
2-02-002-02
1-02-006-02
3-06-001-02
3-06-009-01
3-01-900-99
3-01-090-99
4-03-001-01
3 A
6 A-S°X " 59°
4-03-001-01; -03
3-06-001-04
2-02-002-02
3-06-009-99
Dual
Recode
Dual
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
00
OJ
State AQCR County
s
NM 155 Lea
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Company
Arco
Climax Chemical
Continental Oil
El Paso Natural
Gas
El Paso Natural
Gas
El Paso Natural
Gas
El Paso Natural
Gas
El Paso Natural
Gas
El Paso Natural
Gas
Marathon
Plant/ID Source
Pecos -Permian Basin 6
Monument/3 6
Maljamar 3,4
Eunice/5 6
Jal #1/6 6
Jal #2/7 6
Jal #3/8 6
Jal #4/9 6
Monument Sta./10 6
.
/29 6
Comments*
A
4-03-001-02; -04-
4-03-002-03: -04
B-SOX - 720
3-01-032-01
B
C-SO - 15,800
2-02-002-02
3-01-090-99
C-SOX - 4350
3-01-090-99
C-SO - 6
3-06-001-04
C-SO - 6184
1-02-006-03; -02
3-06-001-02
3-06-009-99; -01
2-02-002-01
C-SO - 15,515
1-02-006-02
2-02-002-02
3-06-009-01
C-SO - 21,606
1-02-006-02
2-01-999-97
2-02-002-02
3-06-009-99
A-SOX - 24
3-01-090-99
4-03-001-01; -02
Dual
Dual
Recede
Recode
Recede
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
oo
State AQCR County
s
NM 155 Lea
.
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Lea
Company
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Perry Gas
Processors
Phillips Petro.
Plant/ID
--/35
Block 12/37
Block 19/38
Eunice Station/36
Hobbs Gathering #1/39
Hobbs Gathering #2/40
Hobbs/41
Hobbs Refrigeration/42
Antelope Ridge/43
Eunice Station/44
Source
6
6
6
6
6
6
6
6
6
6
Comments*
C
3-06-001-02
1-02-006-02
2-02-002-02
4-03-001-01
C
2-02-002-02
C-SO - 11 '
2-02-00^-02
C
2-02-002-02
C-SOX - 18
2-02-002-02
C-SOX - 56
2-02-002-02
C
2-02-002-02
C
2-02-002-02
C-SO - 467
3-06-009-99
C-SO - 6309
2-02-002-02
1-02-006-02
3-06-009-01
3-01-009-99
4-03-001-01
Recode
Recede
Recode
Recode
Recode
Recode
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
00
in
State AQCR County Company
NM 155 Lea Phillips Petro.
Lea Phillips Petro.
Lea Phillips Petro.
Lea Phillips Petro.
-
Lea ' Phillips Petro.
Lea Skelly Oil
Lea Texaco
Lea Tipperary
Lea Warren Petro.
Plant/ID
Hobbs/45
Lee/46
Lovington/47
Lusk/48
Wilson
Eunice #1-2
Buckeye
Denton
Eunice #161/60
Source Comments*
6 C-SOX - 1308
1-02-006-02
2-02-002-02
3-06-009-01
3-01-009-99
6 C-SOX - 2146
1-02-006-03; -02
3-06-001-02
2-02-002-02
3-01-009-99
3-06-009-01
6 C-SO - 433
1-02-006-03
2-02-002-02
3-01-009-99
4-03-001-03
6 C-SOX - 5320
3-06-001-02
2-02-002-02
4-03-001-03
3-06-009-99
3 A
3 A
3 A
3 A
6 C-SO - 1710
3-06-OOT-02
1-02-006-02
2-02-002-02
J:8i:88?:8?
Recede
Recede
Recede
Recede
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
oo
State AQCR County
*
NM 155 Lea
Lea
Lea
Lea
Lea
Roosevelt
Roosevelt
Roosevelt
ND 172 - Burke
Burke
McKenzie
Williams
Williams
Company
Warren Petro.
Warren Petro.
Warren Petro.
Warren Petro.
Warren Petro.
Cities Service
Cities Service
. Cities Service
Hunt Industries
Texaco
True Oil
Hunt Industries
Signal Gas .
Plant/ID
Monument/ 65
Saunders
Tatum/62
Tatum/66
Vada #139/64
Chaverog Sta./2
E. Bluitt Sta./3
Todd/155
McGregor/ 2
Lignite/71
Red Wing Creek
N. Tioga
Tioga/4
Source
6
3
6,8
6
6
6
6,8
6
6
6
3
6
6
Comments*
A
2-02-002-02
A
A-SOX - 2400
2-02-002-02
3-01-090-99
4-03-001-01; -02
3-06-009-99
A
2-02-002-02
C
2-02-002-02
4-03-001-02
A
2-02-002-02
A
2-02-002-02
A
2-02-002-02
C-SO - 370
3-06-999-99
C
3-06-999-99; -98
A
C
3-06-999-99
C-SOX - 4550
3-06-999-99
1-02-006-02
' 3_06-qgq-qR
Recede
Recede
Recede
Recede
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
oo
State AQCR County
OK 184 Canadian
Cleveland
Cleveland
Dewey
Grady
Grady
Grady
Grady
Kingfisher
Kingfisher
Kingfisher
Kingfisher
Kingfisher
Lincoln
Lincoln
Logan
McClain
McClain
Oklahoma
Company
Mustang Fuel
Continental Oil
Sun Oil
Shell Oil
Mobil Oil
Phillips Petro.
Phillips Petro.
Warren Petro.
Amoco Production
Cities Service
Continental Oil
Exxon
Humble Oil § Ref.
Eufaula Enterp.
Sun Oil
Eason Oil
Sohio Petro.
Sun Oil
Champ 1 in Petro.
Plant/ID
Calumet
Short Junction
Moore/ 2
Selling
Chitwood/1
Brad ley/ 3
Norge
Knox
N . Okarche
Rodman-Basin-Choate/2
Hennessey
Dover - Henne s s ey
Hennessey/ 1
Sue Davenport
Carney/ 3
#3
Norman
Dibble/4
Witcher
Source
3
3
3,6
3
3,6
3,6
3
3
3
3,6
3
3
6
3
3,6
3
3
3,6
3
Comments*
A
A
C
2-02-002-02
3-06-001-04
A
C
3-06-001-04
C
1-02-006-02
2-02-002-02
3-06-009-01
A
A
A
C
1-02-006-03
A
A
C
1-02-006-01
A
C
3-06-001-04
A
A
C
2-02-002-02
3-06-001-04
A
Recede
Recede
*
Recede
Recede
Recede
Recede
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
oo
00
State AQCR County
OK 184 Oklahoma
Oklahoma
Oklahoma
Oklahoma
185 Garfield
Garfield
Garfield
Grant
- Grant
Grant
Kay
,
Company
Phillips Petro.
Phillips Petro.
Phillips Petro.
Phillips Petro.
Arco
Champ 1 in Petro.
Cities Service
Continental Oil
CRA, Inc.
Sun Oil
Cities Service
Plant/ID
Edmond/3
Katz Booster/7
Oklahoma City/6
Oklahoma Gas/8
Covington
Enid/4
Rodman/ 2
Medford
Lament
Wakita/1
Ambrose/ 1
Source Comments*
3,6 C
1-02-006-03
2-02-002-02
3-06-005-02
6 C
2-02-002-02
6 C
3-06-005-02
2-02-002-02
3,6 C
1-02-006-02
2-02-002-02
3-06-005-02
3 A
3,6 C
3-06-001-04
3,6 C
1-02-006-02
2-02-002-02
3 A
3 " A
3,6 C
.2-02-002-02 .
3-05-001-04
3,6 C
1-02-006-02
3-06-001-04
2-02-002-02
3-06-007-01
3-06-005-02
Recode
Recode
Recode
^
Recode
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
00
State AQCR County
*
OK 185 Kay
Kay
Kay
186 Creek
Creek
187 Alfalfa
Alfalfa
Beaver
Beaver
Beaver
Beaver
Beaver
. Beaver
Beaver
Elaine
Elaine
Cimarron
Custer
Custer
Company
Cities Service
Eufaula Enterp.
Sun Oil
Arco
Kerr-McGee
Champlin Petro.
Signal Oil § Gas
Amoco Production
Cabot
El Paso Natural
Gas
Northern Natural
Gas
Texaco
Warren Petro.
Warren Petro.
Amoco Prod.
Amoco Prod.
Colorado Inter-
state Gas
Mobil Oil
Tx. Oil § Gas
Plant/ID
Garrett
Marli
Tonkawa
Covington
Mi If ay/ 2
-11
Aline/1
Elmwood
Beaver/2
Beaver
Cabot-Highland
Camrick
Forgan/1
Mocane
Hitchcock
Star-Lacey
Keyes/1
Thomas/3
Custer
Source
3
3
3
3
3,6
6
3,6
3
3,6
3
3
3
6
3
3
3
3,6
6
3
Comments*
A
A
A
A
C
1-01-006-03
2-01-002-01
A
4-03-002-04
C
2-02-002-02
A
C
1-02-006-03
2-02-002-02
A
A
A
' C
3-06-001-02
A
A
A
C
2-02-002-02
C
2-02-002-02
A
Recede
s
Recede
Recede
Recode
Recede
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
s
OK 187 Dewey
Dewey
Dewey
Dewey
Dewey
Dewey
Dewey
Ellis
Harper
Harper
Major
Major
- Ma j or
Ma j or
Major
Texas
Texas
Texas
Texas
Company
Exxon
Humble
Mobil
Mobil
Mobil
Mobil
Signal Oil £ Gas
Tx. Oil $ Gas
Sun Oil
Sun Oil
Phillips Petro.
Pioneer Gas Prod.
Tenneco
Tx. Oil $ Gas
Union Tx. Petro.
Anadarko Prod.
Cities Service
Dorchester Gas
Dorchester Gas
Plant/ID
Camargo
Camargo/1
Northeast Trail
Putnam Oswego
Taloga/2
W. Putnam
Taloga/3
, S. Bishop
Laverne/1
Lovedale/2
Sooner #1
Ringwood/1
Ames
Jeffries
Chancy Dell
N. Richland Center
.Murdock/7
Hooker/ 1
Panoma
Source
3
6
3
3
6
3
6
3
3,6
6
3
3,6
3
3
3
3 .
3,6
6
3
Comments*
A
C
2-02-002-02
3-06-001-04
A
A
C
2-02-002-02
A
C
2-02-002-02
A
C-SOX - 4
3-06-001-04
C
2-02-002-02
A
C-SO - 2
2-02-00^-02
3-06-001-04
" A
A
A
A
C-SOX - 4
3-06-001-04
C-SOX - 3
1-01-006-02
3-06-001-04
A.I'
Recede
Recede
Recode
Recode
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
OK 187 Texas
Texas
Texas
Texas
Woodward
Woodward
Woodward
188 Carter
Carter
Carter
Garvin
Garvin
- Garvin
Garvin
Garvin
Garvin
Love
Company
Excelsior Oil
Map co
Mobil
Mobil
Amoco Prod.
Mobil
Phillips Petro. .
Signal Oil
Signal Oil
Union Oil
Warren Petro.
Warren Petro.
Lone Star Gas
Lone Star Gas
Sohio Petro.
Warren Petro.
Chevron Oil
Plant/ID
Tyrone
Tyrone/ 2
Guymon/4
Postle Hough
Moor el and
Seiling
Cimarron
Duncan/ 2
Fox
Caddo
Antioch/6
Lindsay/5
Katie
Wallville
Elmore/2
Maysville/4
Marietta
Source
3
3,6
6
3
3
3
3
6
3
3
6
6
3
3
3,6
3,6
3
Comments*
A
C-SOX - 3
2-02-002-02
3-06-001-04
C
3-06-001-04
2-02-002-02
A
A
A
A
C
2-02-002-02
1-02-006-02
A
A
C
2-02-002-02
C
2-02-002-02
A
A
C
1-02-006-02
2-02-002-02
' C
1-02-006-01
2-02-002-02
A
Recode
Recode
t,
Recode
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
K>
State AQCR County
OK 188 Love
Marshall
Okfuskee
Pontotoc/Coal
Pontotoc
Seminole
189 Beckman
Caddo
Stephens
Stephens
- Stephens
Stephens
Stephens
Company
Texaco
Pioneer Gas
Grimes, Otha
Koch Oil
Sun Oil
Arco
Shell Oil
Texaco
Mobil
Skelly Oil
Skelly Oil
Skelly Oil
Warren Petro.
Plant/ID
Enville
Madill/1
Grimes
Fitts
Steedman
Seminole
Elk City/1
Apache
Sholem Alechem/6
E. Velma Middle
Block/4
Mar low/ 3
Stephens/8
Marlow/5
Source
3
3,6
3
3
3
3
3,6
3
3,6
3,6
3,6
6
6
Comments*
A
C
1-02-006-02
2-02-002-02
A
A
A
A
C
1-02-006-02
2-02-002-02
A
C
2-02-002-02
3-06-001-04
C
1-02-006-02
2-02-002-02
3-06-001-04
3-06-009-01
" C-SOX - 22
2-02-002-02
3-06-001-04
C
2-02-002-02
1-02-006-01
4-90-999-99
C
1-02-006-03
3-06-001-04
9_n?_nn?_n?
. Recede
1
Recede
Recede
Recede
Recede
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 022 Anderson
Anderson
Camp :
Cass
Cass
Cherokee
Cherokee
Franklin
Franklin
Gregg
Gregg
Gregg
Gregg
Gregg
Harrison
Harrison
Harrison
Harrison
Henderson
Henderson
Henderson
Hopkins
Hopkins
Hopkins
* All SOX emissions in short
Company Plant/ ID
Getty Oil Cayuga
Texas Oil $ Gas Slocum
Delhi Gas Pipeline Gilmer
Breckenridge Lodi
Gasoline
Shell Bryans Mill
Exxon Neches
Exxon Reklaw
Delhi Gas Pipeline Chitsey
Getty Oil New Hope
Atlantic-Richfield Longview
Cities Service Oil East Texas
United Gas Willow Springs
Pipeline
Warren Petroleum Gladewater
Warren Petroleum Spear
Ark -La Gas N. Lansing
Ark- La Gas Waskam
Dorchester Woodlawn
United Gas Blocker
Piepline
Hunt Oil Fairway
Lone Star Gas Trinidad
Lone Star Opelika
Producing
Schneider, Corey Nelta
£ Josey
Signal Oil § Gas Birthright
Warren Petroleum Como
tons/year.
Source
1
1,3
1
1,3
1,3
1,3
3
1
1,3
1,3
1,3
3
1,3
1,3
3
1,3
1,3
3
1,3
1,3
1,3
1
1,3
1,3
Comments*
A
A
C-SOX - 8621
A
B-SOX - 6015
A
A
C-SOX - 1463
A
A
C-SO - 845
A
A
A
A
A
A
A
A
A
A
A
B
B-SOX - 3650
Recede
Dual
Recede
Recode
Dual
Dual
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 022 Panola
Panola
Panola
Panola
Rusk
Rusk
Rusk
Smith
Smith
Upshur
Van Zandt
Van Zandt
Van Zandt
Van Zandt
Wood
Wood
Wood
Wood
Wood
Wood
Marion
Marion
106 Hardin
Hardin
Hardin
Houston
Howard
Company Plant/ ID
Champlin Petroleum East Texas
Champlin Petroleum San Jacinto Gas
Cities Service Oil Panola
United Gas Carthage
Pipeline
Atlantic-Richfield Price
Exxon East Texas
Parade Giles
Etexas Producers Chapel Hill
Gas
Sun Oil Shamburger
Ark- La Gas Gilmer
Amoco Products Edgewood
Cities Service Oil Myrtle Springs
Cities Service Oil Welch
Union Oil Van
Amoco Production West Yantic
Ark- La Gas Manziel
.CRA, Inc. Caska
CRA, Inc. Quitman
Exxon Hawkins
Wanda Petroleum Hainesville
Ark- La Gas , Jefferson
Texas 0 § G East Texas
Atlantic-Richfield Silsbee
Atlantic-Richfield S. Hampton
HNG Petro. Chem. Pavey
Union Oil Ft. Trinidad
Skelly E. Vealmoor
Source
1,3
1
1,3
1,3
1,3
1,3
1,3
1,3
3
1
1,3
1,3
1
1,3
1,3
3
1
1,3
3
3
3
3
1,3
1,3
1,8
1,3
1,3
Comments*
A
A
A
A
A
A
A
A
A
C-SO - 614
B-SOX - 14321
B-SOX - 9839
A-SOX - 251
A
B-SOX - 2413
A
A
A
A
A
B
A
A
A
A
A
C-SO - 1668
Recede
Dual
Dual
Dual
Dual
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
<£>
01
State AQCR County
TX 106 Jefferson
Jefferson
Jefferson
Jefferson
Jefferson
Jefferson
Jefferson
210 Archer
Callahan
Coleman
Commanche
East land
Eastland
East land
Eastland
Eastland
Eastland
Fisher
Fisher
Hardemann
Nolan
Nolan
Nolan
Nolan
Company
Continental Oil
Exxon
Exxon
Petroleum Gas
Producing
Union Texas
Petroleum
Union Texas
Petroleum
Warren Petroleum
Gas Systems
Martix Land
Valera Oil
Trumter Petroleum
Lone Star Gas
Lone Star Gas
Lone Star
Producing
. Mobil Oil
West Centex Gas
West Centex Gas
Continental Oil
Tipperary
Shell Oil
Amoco Production
Champ 1 in Petroleum
El Paso Natural
Gas
Otha H. Grimes
Plant/ID
Port
Amelia
Love 11 Lake
--
Marrs -McLean
Dryex
Winnie
Fannett
McGregor
Box-Elmdale
Duncan
Comp . Sta .
Hill Lake
Pueblo
Ranger 108
Desdemona
Pioneer
Ranger
Hamlin
Claytonville
Conley
White Flat
North Dora
West lake
North Dora
Source
1,3
3
3
3
3
3
3
1
3
1
1
1
1,3
1,3
1,3
1
1 .
1,3
1,3
1,3
1,3
1
1,3
1,3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
C-SOV - 135 Recede
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 210 Nolan
Nolan
Scurry
Scurry
Scurry
Scurry
Scurry
Shackelford
Shackelford
Shackelford
Shackelford
Stephens
Stephens
Stephens
Stephens
Stephens
Stonewall
Throckmorton
Wichita
Wilbarger
Young
Young
Young
Jack
Company
Hylton Gas
Pronto Gas
Chevron Oil
Monsanto
Monsanto
Sun Oil
Texaco, Inc.
Atlantic-Richfield
Coastal States
Gas Producing
Petroleum Corp.
of Texas
Warren Petroleum
Arapaho Petroleum
Breckenridge
Gasoline
Permian
Petroleum Corp.
of Texas
Warren Petroleum
Cities Service Oil
Lewtex 0 § G
Regal Petroleum
Mobil Oil
Lewtex 0 § G
Lone Star Gas
Petroleum Corp.
of Texas
Black Hawk Gas
Plant/ID
..
Sweetwater
Snyder
Diamond M
Sharon Ridge
Snyder
Fuller
Albany
Albany
Ibex
Shackelford
0. Tomlin A § B
Eliasville
Possum Kingdom
Woodson
Breckenridge
Stonewall
Throckmorton
Co-op Plant #1
Electra
Graham
Graham
Plant #3
Sewell Field
Source
1
1
1,3
1
1,3
3
1,3
1
1,3
1,3
1,3
3
1,3
3
1,3
1,3
1,3
1
1
3
1
3
1,3
3
Comments*
A
A
A
C-SOX - 600 Recede
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
<£>
State AQCR County
TX 210 Jack
Jack
Jack
Kent
Montague
211 Carson
Carson
Carson
Carson § Gray
Cochran
Collingsworth
Gray
Gray
Gray
Gray
Gray
Gray
Gray
Gray
Gray
Hale
Hans ford
Hans ford
Hock ley
Hock ley
Hock ley
Hockley
Hockley
Company
Cities Service Oil
Palo Pinto 0 § G
Lone Star Gas
General Crude Oil
Tipperary
Cabot
Dorchester Gas
Prod.
Shell Oil
Skelly
Cities Service Oil
Lone Star Gas
Amarillo Oil
Cities Service Oil
Cities Service Oil
Coltexo
Kerr-McGee
Phillips Petroleum
Phillips Petroleum
Pioneer Natural Gas
Skelly Oil
Amoco Production
Phillips Petroleum
Phillips Petroleum
Amoco Production
Amoco Production
Amoco Production
Amoco Production
Perry Gas
Processing
Plant/ID
Gibtown
Mark ley
Jacksboro
Salt Creek
Bowie
Bryan
Cargray
Bryan
Crawford-Shafer
Lehman
E. Panhandle
Pampa
Lefors
Pampa
Plant 78-1
Pampa
Gray
North Plant
Pampa
Kings Mill
Anton Irish
Hans ford
Sherman
Anton- Irish
Level land
Ropes
Slaughter
Level land
Source
1,3
1,3
1
3
1,3
1
1,3
3
1,3
1,3
3
3
3
1,3
1
1,3
1,3
1,3
1
1
1,3
3
1,3
1
1,3
3
1
3
Comments*
A
A
A
A
A
A
A
\
C-SOX - 159
C-SOX - 1089
B
A
A
A
A
A
A
A
A
A
C-SO - 323
A
A
C-SOX - 1010
C-SOX - 602
C-SOX - 543
A
B-SO - 929
A
Recede
Recede
Dual
Recede
Recede
Recede
Recede
Dual
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
<£>
00
State AQCR County
TX 211 Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Ochiltree
Ochiltree
Potter
Potter
Roberts
Terry
Wheeler
Wheeler
Yoakum
Yoakum
Moore
Moore
Moore
Company
Colorado
Interstate Gas
Mapco, Inc.
Natural Gas
Pipeline
Panhandle Producing
Phillips Petroleum
Phillips Petroleum
Phillips Petroleum
Phillips Petroleum
Skelly
Northern Natural
Gas
Skelly
Amarillo Oil
Amarillo Oil
Transwestern
Pipeline
Amerada-Hess
Gerlane Petroleum
Warren Petroleum
Amoco Production
Shell Oil
Colorado
Interstate Gas
Colorado
Interstate Gas
Diamond Shamrock
0 § G
Plant/ID
Sanford
Westpan 1000
161 Plant
Sanford
Canadian
Pantex
Rock Creek
Sanford
Watkins
. Spearman
Spearman
Fain
Turkey Creek
Cree Flowers
Adair
Mobeetie
McLean
Prentice
Wassom
Bivins
Fourway
McKee
Source
1
1,3
1,3
1,3
1,3
3
1,3
1,3
1
1,3
1,3
1,3
1,3
1
1,3
1,3
1,3
1,3
1,3
1,3
1,3
3
Comments*
A
A
A
A
A
A
A
A
C-SO - 1435
A
A
C-SO - 128
C-SO - 54
A-SOX - 49
C-SO - 1540
A
A
C-SO - 1821
C-SO - 15397
A
A
, B
Recede
Recede
Recede
Recode
Recede
Recode
Dual
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
<£>
State AQCR County
TX 211 Moore
Moore
Moore
Moore
Moore
Moore
Moore
Moore
Moore
212 Freestone
Leon
Limestone
McLennan
Madison
213 Hidalgo
Hidalgo
Hidalgo
Hidalgo
Hidalgo
Hidalgo
Company
El Paso Natural
Gas
Kerr-McGee
Natural Gas
Pipeline
Northern Natural
Gas
Panhandle Eastern
Pipeline
Panhandle Eastern
Pipeline
Panhandle Eastern
Pipeline
Phillips Petroleum
Phillips Petroleum
Getty Oil
Lone Star Gas
Lone Star Gas
Cities Service Oil
Lone Star Gas
Amoco Production
Anchor Gas
Clark Fuel
Producing
Coastal States
Gas Producing
Coastal States
Gas Producing
Products Recovery,
Inc.
Plant/ID
Dumas
Cactus Plant #12
162 Plant
Sunray
Cabot Booster
Sneed
Sunray
Dumas
Sneed
Teas Field
Red Oak
Box Church
Waco
M^idisonville
LaBlanca
Tabasco
Sullivan City
. Hidalgo
Mission
Monte Christo
Source
1
1
1,3
1
1
1
1
1,3
1,3
1
3
1
1,3
3
1,3
1,3
3
i
1,3
1,3
3
Comments*
A
A
A
A
A
A
A
C-SOX - 956
C-SOX - 429
B-SOX - 3853
A
A
A
A
A
A
A
A
A
'A
Recode
Recede
Dual
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
o
State AQCR County
TX 213 Hidalgo
Hidalgo
Starr
Starr
Starr
Starr
Starr
Starr
Starr
Webb
Webb
Willacy
Willacy
Jim Hogg
Jim Hogg
Jim Hogg
214 Aransas
Bee
Bee
Bee
Bee
Brooks
Brooks
Brooks
Brooks
Company
Shell Oil
Tenneco Oil
Clark Fuel
Producing
George H. Coates
Continental Oil
Intrastate
Gathering
W. B. Osborne
Shell Oil
Sun Oil
Coastal States
Gas Producing
Texas 0 & G
Amoco Production
Amoco Production
Atlantic-Richfield
Perry Gas
Sohio Petroleum
Tenneco Oil
Amoco Production
Coastal States
Gas Producing
Getty Oil
HNG Petrochemicals
Exxon
Exxon
Exxon
Exxon
Plant/ID
McAllen
Ward
S. Kelsey
Jay Simmons
Rincon
Rio Grande City
G. P. Cart
North Rincon
Sun
Freer
Laredo
La Sal Vieja
Willamar Miocene
NE. Thompsonville
Thompsonville
Prado
Pearce
Burnell-North Pettus
Pawnee
Normanna
. Tuleta
Kelsey
Pita
Santa Fe
Viboras
Source
1,3
1,3
;3
3
1,3
3
1
.1,3
1,3
1,3
3
1,3
1,3
3
3
3
1,3
3
1
1,3
1,3
1,3
3
1,3
1,3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
C-SOX - 439 Recede
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 214 Brooks
Brooks
Calhoun
Calhoun
Calhoun
Calhoun
DeWitt
DeWitt
Duval
Duval
Duval
Nueces
Nueces
Nueces
Nueces
Nueces
Nueces
Nueces
Nueces
Nueces
Refugio
Refugio
Refugio
Refugio
Refugio
Company
HNG Petrochemicals
Texaco, Inc.
Aluminum Co. of
America
Cities Service Oil
Exxon
Exxon
Coastal States
Gas Producing
Shell Oil
Exxon
Mobil Oil
Trinity
Amoco Production
Champlin Petroleum
Cities Service Oil
Coastal States
Gas Producing
Exxon
HNG Petrochemicals
Sun Oil
Tenneco Oil
United Gas
Pipeline
Amoco Production
Atlantic-Richfield
Exxon
HNG Petrochemicals
HNG Petrochemicals
Plant/ID
Loma Blanco
Encinitas
Alcoa
San Antonio Bay
Heyser
Kellers Bay
Gohlke
Goehlke
NE. Loma Novia
. Hagist
Sejita
Luby
Gulf Plains
Robstown
Corpus Christi
Flour Bluff
Robstown
Luby
Dean
Agua Dulce
LaRosa
Refugio
Tom O'Connor
Refugio
Tivoli
Source
1,3
1,3
3
1,3
1,3
3
1,3
1
1,3
1,3
1
1,3
1,3
1,3
1,3
1,3
1,3
1,3
1,3
3
1,3
3
1,3
1,3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
N>
State AQCR County
TX 214 Refugio
Refugio
San Patricio
San Patricio
San Patricio
San Patricio
San Patricio
San Patricio
San Patricio
San Patricio
Victoria
Victoria
Jackson
Jackson
Jackson
Jim Wells
Jim Wells
Jim Wells
Jim Wells
Jim Wells
Kenedy
Kleberg
Kleberg
Kleberg
Lavaca
Live Oak
Live Oak
Company
Hunt Industries
Interstate
Gathering
Atlantic-Richfield
Cities Service Oil
HNG Petrochemicals
Marathon Oil
Mobil Oil
Sun Oil
Superior Oil
Warren Petroleum
HNG Petrochemicals
Sun Oil
Exxon
Mobil Oil
Sun Oil
Coastal States
Gas Producing
Mobil Oil
Mobil Oil
Sun Oil
Texaco, Inc.
Exxon
Chevron Oil
Cities Service Oil
Exxon
Mobil Oil
Atlantic-Richfield
Exxon
Plant/ID
Zoller
Lambert
Taft
Corpus Bay
Gregory
Welder
White Point
Redfish Bay
Portilla
Encinal
Victoria
Victoria
W. Ranch
Vanderbilt
Carancahua
Falfurrias
La Gloria
Seeligson
Ti j erina-Canales
Tijerina
Sarita
Chevron Field
May
King Ranch
Wilcox
Nueces River
Ramirena
Source
1,3
3
1,3
1,3
1,3
1,3
3
1,3
1,3
1,3
1,3
1,3
3
1,3
1,3
1,3
1,3
1,3
1,3
1,3
1,3
1 ,
1,3
1,3
1,3
1,3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A-
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
OJ
State AQCR County
TX 214 Live Oak
Live Oak
Live Oak
McMullen
McMullen
McMullen
215 Cooke
Cooke
Denton
Denton
Gray son
Gray son
Grayson
Grayson
Navarro
Navarro
Navarro
Navarro
Palo Pinto
Palo Pinto
Palo Pinto
Parker
Company
Mobil Oil
Mobil Oil
Mobil Oil
Atlantic-Richfield
Atlantic-Richfield
Trans . Jefferson
Chem.
Chevron
Union Texas
Petroleum
Southwestern Gas
Pipeline
Texas 0 § G
Chevron Oil
Chevron Oil
Texaco, Inc.
Texaco, Inc.
Gulf Energy §
Development
Highland Resource
Permian
Texas 0 § G
Lone. Star Gas
Southwestern Gas
Pipeline
Southwestern Gas
Pipeline
Lone Star Gas
Plant/ID
Clayton
Karon
Kittie
E. Rhodes Ranch
Roos Field Center
--
Sivells Bend
Walnut Bend
Ponder
Denton
New Mag
Sherman
Handy
Hanoyogas
Powell
Currie Center
Liquid Petroleum
Storage Facility
Currie
Gordon
Lone Camp #1
Mineral Wells #1
Springtown
Source
3
3
1,3
3
3
1
1,3
1,3
3
3
1,3
1,3
3
1
1,3
1
1
3
1,3
3
1,3
1,3
Comments*
A
A
A
A
A
B-SOX - 3387 Dual
A
A
A
A
A
A
A
A
B Dual
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 215 Parker §
Wise
Wise
Wise
Wise
Wise
216 Brazoria
Brazoria
Brazoria
Brazoria
Brazoria
Brazoria
Brazoria
Brazoria
Brazoria
Chambers
Chambers
Chambers
Chambers
Chambers
Chambers
Colorado
Colorado
Colorado
Colorado
Fort Bend
Galveston
Company
LVO Corp.
Cities Service Oil
Cities Service Oil
Warren Petroleum
Upham 0 § G
Amoco Production
Amoco Production
Exxon
HNG Petrochemicals
HNG Petrochemicals
Monsanto
Phillips Petroleum
Phillips Petroleum
Shell Oil
Cities Service Oil
Enterprise Products
Exxon
Getty Oil
Pennzoil
United Texas
Transmission
Liquid Products
Recovery
Shell Oil
Superior Oil
Tenneco Oil
Lone Star Gas
Amoco Gas
Plant/ID
Parker County
Pipeline
Chico
Old East Plant
G'M £ A
--
Hastings
Old Ocean
Pledger
Alvin
Liverpool
Manor Lake
Alvin
Brazoria
Buccaneer
Mont Belvieu
LaMont Belvieu
Anahuac
Umbrella
Galveston Bay
Galveston Bay
E. Ramsey
Houston Central
Ramsey
Chesterville
Needville
Texas City
Source
3
1,3
1
1,3
1
1,3
1,3
1,3
3
3
3
1
1,3
1,3
1,3
1
1,3
3
3
1
3
1,3
1,3
1,3
3
3
Comments*
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
en
State AQCR County
TX 216 Galveston
Galveston
Galveston
Galveston
Harris
Harris
Harris
Harris
Harris
Harris
Waller
Wharton
Wharton
Liberty
Liberty
Liberty
Liberty
Matagorda
Matagorda
Matagorda
Matagorda
Matagorda
Matagorda
Matagorda
Matagorda
Montgomery
Montgomery
Montgomery
Company
Amoco Production
HNG Petrochemicals
Hunt Trust Estate
Pan American Gas
Exxon
Exxon
HNG Petrochemicals
Tenneco Oil
Texaco, Inc.
Wanda Petroleum
Exxon
Getty Oil
Exxon
Atlantic-Richfield
Atlantic-Richfield
Exxon
Liquid Products
Recovery
Amoco Production
Coastal States
Gas Production
Exxon
Marathon Oil
Monsanto
Tenneco Oil
Tenneco Oil
Texaco, Inc.
Champlin Petroleum
Exxon
Superior Oil
Plant/ID
South Gil lock
Lafayette
Alta Loma
Texas City
Clear Lake
Tomball
Bammell
LaPorte
Humble
Pierce Junction
Katy
W. Bernard
Magnet Withers
Dayton
Hull
S. Liberty
Raywood
East Bay City
Bay City
Sugar Valley
Markham
El Maton
Blessing
Leabo
Blessing
Conroe
Conroe
Lake Creek
Source
1,3
3
1,3
1
3
3
1,3
1,3
1,3
1,3
1,3
1,3
3
1,3
1,3
3
3
1,3
1,3
3
1,3
3 ,
1
1,3
3
1,3
1,3
1,3
Comments*
A
A
A
A
A
A
C-SO - 72 Recede
A
A
C-SOX - 29 Recede
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 217 Atascosa
Atascosa
Atascosa
Atascosa
Atascosa
Bexar
Dimmitt
Frio
Gonzales
Karnes
Karnes
Maverick
218 Andrews
Andrews
Andrews
Andrews
Andrews
Andrews
Andrews
Andrews
Andrews
Andrews
Company
Atlantic-Richfield
Elcor Chemical
Exxon
Lone Star
Producing
Warren Petroleum
Coastal States Gas
Producing
Sun Oil
Suburban Propane
Gas
: . HNG Petrochemicals
Coastal States Gas
Producing
Shell Oil
Continental Oil
Amoco Production
Amoco Production
Amoco Production
El Paso Natural
Gas
El Paso Natural
Gas
Northern Natural
Gas
Phillips Petroleum
Phillips Petroleum
Texaco, Inc.
Union Oil of
California
Plant/ID
Fashing
Fashing
Jourdanton
Fashing
Fashing
San Antonio
Big Well #1
Martha F. Berry
DuBose
Hobson Treating
Person
Chittim Ranch
Midland Farms
S. Fullerton
Three Bar
Fullerton
St. Andrews Field
Andrews Station
Andrews
Fullerton
Mabee
Bakke
Source
1,3
1
1,3
1,3
1,3
1,3
1,3
1,3
1
1
1,3
3
1,3
1,3
1
1
1
1
1,3
1,3
1,3
1,3
Comments*
B-SOX -
B-SOX -
C-SOX -
A
B
A
A
A
A
C-SOX -
B-SOX -
A
B-SOX -
B-SOX -
A
c-sox -
A
A
A
c-sox -
c-so -
c-soj -
638
646
5900
4488
1779
192
104
8991
2103
78
1022
Dual
Dual
Recede
Dual
Recede
Dual
Dual
Dual
Recede
Recede
Recede
Recede
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 218 Andrews
Coke
Coke
Coke
Coke
Concho
Crane
Crane
Crane
Crane
Crane
Crane
Crane
Crane
Crane
Crane
Crockett
Crockett
Crockett .-
Crockett
Crockett
Crockett
Crockett
Company Plant/ ID
Union Oil of Dollarhide
California
Exxon Bronte
McCulloch Gas Bronte
Processing
Sun Oil Jameson
Union Texas Perkins
Petroleum
Sun Oil Concho
Atlantic-Richfield Block 31
Atlantic-Richfield Imperial
El Paso Natural McElroy-Crane
Gas
Exxon Sand Hills
Mobil Sand Hills
Mobil Univ. -Waddel -Devon
Perry Gas Imperial
Processors
Phillips Petroleum Crane
Warren Petroleum Sand Hills
Warren Petroleum Waddel 1
Atlantic-Richfield Ozona
Cities Service Oil West World
Delhi Gas Pipeline MPI Plant
Delta Drilling Ozona
El Paso Natural Midway Lane
Gas
Ozona Gas 0. G. Plant
Permian Todd
Source
1,3
1
1,3
1,3
1,3
3
1,3
3
1
3
1
1
1,3
1,3
1,3
1,3
3
1,3
1
3
1
1
3
Comments*
A
A
A
A
A
A
A
A
A-SOX - 1549
B
' A-SOX - 1719
A-SOX - 52
A
B-SOX - 10619
C-SO.. - 5058
B
A
A
A
A
A-SOX - 2078
A
A
Dual
Dual
Recede
Dual
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
00
State AQCR County
TX 218 Crockett
Crockett
Crockett
Crockett
Dawson
Dawson
Ector
Ector .
Ector
Ector
Ector
Ector
Ector and
Midland
Ector
Ector
Ector
Ector
Gaines
Gaines
Irion
Irion
. Irion
Pecos
Pecos
Company
Perry Gas
Processing
Shell Oil
Shell Oil
Texaco, Inc.
Cities Service Oil
Texaco, Inc.
Amarillo Oil
Amarillo Oil
Amoco Production
El Paso Natural
Gas
El Paso Natural
Gas
Getty Oil
Odessa Natural
Corp.
Phillips Petroleum
. Phillips Petroleum
Phillips Petroleum
Shell Oil
Cities Service Oil
Phillips Petroleum
Atlantic-Richfield
CRA, Inc.
J. L. Davis
Coastal States
Gas Producing
Coastal States
Gas Producing
Plant/ID
N. Trippett
N. Ozona
Tippett
Ozona
Welch
Lames a
Andector
E. Goldsmith .
N. Cowden
Goldsmith
TXL
Headlee
Foster
Ector
Goldsmith Gas
Goldsmith Sulfur
TXL
W. Seminole
Seminole Gas
Mertzon
Mertzon
Irion
Gomez
Gray Ranch
Source
1
1,3
1,3
1,3
1,3
1,3
1
1,3
1,3
1
1
1,3
1,3
1,3
1
1,3
1,3
1,3
1
1,3
1
3
1
3
Comments*
A-SOX -
A
A
A
B
A
B-SOX -
A-SOX -
B-SOX -
A-SOX -
A
c-sox -
B-SOX -
A
C-SOX -
B-SOX -
c-sox -
B-SOX -
c-sox -
A
c-sox -
A
c-sox -
A
211
296'
175
5166
924
183
969
2606
14632
7295
3540
3986
144
980
Dual
Dual
Dual
Recede
Dual
.
Recede
Dual
Recede
Dual
Recode
Recede
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
o
«£>
State AQCR County
TX 218 Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Pecos
Company
Coastal States
Gas Producing
Coastal States
Gas Producing
El Paso Natural
Gas
El Paso Natural
Gas
H. L. Hunt
Intratex Gas
Lone Star
Marathon
Mobil Oil
Mobil Oil
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Northern Natural
Gas
Phillips Petroleum
Texas 0 § G
Transwestern
Pipeline.
Transwestern
Pipeline
Plant/ID
Petco
W. Gomez
Puckett
Santa Rosa
Pecos Valley
Gomez
Pikes Peak
Yates
Coyanosa
Waha
Gomez
Jasper
Mitchell
Dates
Pikes Peak
Puckett
Coyanosa
Chinot-Putnam
Puckett
Source
1
1
1,3
1,3
3
1
1
1,3
1,3
1,3
1
1,3
1
1
1
1,3
1,3
Treating 1
1
Comments*
A-SOY -
X
A-SO -
X
A
A
A
C-SOY -
A X
A
B-SOY -
c-so* -
A-SOY -
A
A-SOX -
A
V
A
A-SOV -
X
A
A-SO -
A-SO* -
X
A
921
313
313
3878
130
407
373
33
11543
42
Recede
Dual
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 218 Reagan
Reagan
Reagan
Reagan
Reagan
Reeves
Reeves
Reeves
Reeves
Reeves
Schleicher
Sutton
Sutton
Terrell
Terrell
Tom Green
Tom Green
Tom Green,
Mason and
Perry
Tom Green
Upton
Company Plant/ID
Dorchester Texon
El Paso Natural Barnhart
Gas
El Paso Natural Midkiff
Gas
Pecos Co. Barnhart
Southwest Forest Rocker B
Gas Gathering
Coastal States Greasewood
Gas Producing
Continental Oil Ramsey
El Paso Natural Waha
Gas
Phillips Petroleum Tunstill
Texaco, Inc. Knight
Atlantic-Richfield Eldorado
HNG Petrochemicals Sonora
HNG Petrochemicals Sutton
Creole Production Terrell
Service
El Paso Natural Terrell
Gas
Beacon Gasoline Beacon 5 Strawn
CRA, Inc. Mertzon
Lone Star Gas Carlsbad
Marathon Oil Markham
Atlantic-Richfield Crane
Source
1,3
1
1,3
3
3
1
1,3
1
1,3
1
1,3
3
3
1
1
Plant 1,3
1,3
3
1,3
1,3
Comments*
B-SO - 655
A
A
A
A
A-SOX - 2794
C-SOX - 37
A-SOx - 4064
A
A
C-SOX - 38
A
A
A
k
A
C-SOX - 106
A
A
A
C-SOX - 172
Dual
Recode
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 218 Upton
Upton
Upton
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Ward
Company
El Paso Natural
Gas
El Paso Natural
Gas
Phillips Petroleum
Cabot
Coastal States
Gas Producing
Coastal States
Gas Producing
Coastal States
Gas Producing
El Paso Natural
Gas
Exxon
Natural Gas
Pipeline
Northern Natural
" Gas
Northern Natural
Gas
Northern Natural
Gas
Perry Gas
Perry Gas
Perry Gas
Texaco, Inc.
Transwestern
Pipeline
Plant/ID
Jack Herbert
Wilshire
Benedum
Estes
Block 21
Mivada
Pyote
Sealy Smith
Pyote
160 Plant
Blair
Lockridge
Ward Co. #1 .
Pyote Devonian
Pyote Ellenberger
S. Bar stow
Lockridge
Estes
Source
3
1,3
1,3
1,3
1
1
1
1,3
3
1
1
1
1
3
3
3
1,3
1
Comments*
A
C Recede
A
C-SO - 1110 Recede
A-SOX - 2541
A-SOX - 7208
A-SOX - 2841
A
A
A
A
. A
A
A
A
A
A
A-SO - 1511
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
K)
State AQCR County
TX 218 Ward
Ward
Upton
Winkler
Winkler
Winkler
Winkler .
Winkler
Winkler
Winkler
Winkler
Winkler
Winkler
Winkler
Winkler '
Winkler
Winkler
Winkler
Martin
Company
Transwestern
Pipeline
Warren Petroleum
Union Texas
Petroleum
Amoco Production
Perry R. Bass
Cabot
Chevron Oil
El Paso Natural
Gas
Natural Gas
Pipeline
Northern Natural
Gas
Northern Natural
Gas
Norther Natural
"Gas
Sid Richardson Gas
Texaco, Inc.
Transwestern
Pipeline
Transwestern
Pipeline
Transwestern
Pipeline
Transwestern
Pipeline
Adobe Oil
Plant/ID
Pyote
Monohans
Benedum
Monohans
Hal ley
Walton
Kermit
Keystone M/L Plant
164 Plant
Bravo
Hal ley Dehyd.
S. Kermit
Keystone
S. Kermit
Halley
Kermit
Keystone Treating
Walton
Sale Ranch
Source
1
1,3
3
1,3
1,3
1,3
1,3
1
1
1
1
1
1,3
1,3
1
1
Plant 1
1
3
Comments*
A-SOX
c-sox
A
A-SOX
A-SOX
c-sox
A
A
c-sox
A
A
c-sox
C-SOY
A
A-SOX
A-SOX
A-SOX
A-SOV
X
A
- 3910
- 3925
- 270
- 187s
- 1982
- 2520
- 2275
- 41
- 3528
- 687
- 4926
- 1572
-
Recode
Recede
Recode
Recode
Recode
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
TX 218 Martin
Martin
Midland
Midland
Midland
Midland
Midland
Midland
Midland
Midland
Midland
Company Plant/ ID
Northern Gas Jasper
Products
Northern Natural Spraberry
Gas
Amarillo Oil Ranchland
Atlantic-Richfield Midland
Cities Service Oil Roberts Ranch
El Paso Natural Driver
Gas
El Paso Natural Tex. -Harvey
Gas
Mobil Oil Pegasus
Northern Natural Spraberry
Gas
Phillips Petroleum Spraberry
Warren Petroleum Azalea
Source
1,3
3
3
1,3
1,3
1
1
1,3
1
1,3
1,3
Comments*
A
A
A
A
A
A
A
A
A
A
A
-------
Table 4 (continued). LIST OF GAS PROCESSING PLANTS IN
SIXTEEN STATES THAT HAVE SOUR GAS RESOURCES
State AQCR County
s
WY 241 Converse
Fremont
Fremont
Natrone
243 Campbell
Campbell
Campbell
Campbell
Campbell
Campbell
Campbell
Campbell
Campbell
Carbon
Carbon
Johnson
Lincoln
' Park
Park
Park
Sublette
Sweetwater
Sweetwater
Sweetwater
Uinta
Washakie
Company
Phillips Petro.
Amoco
Arco
Kansas -Nebraska
Natural Gas
Arco
Apexco
CRA, Inc.
Ginther, N.C.
Ginther, N.C.
McCulloch
McCulloch
McCulloch
McCulloch
Colo. Interstate
Gas
Marathon Oil
Continental Oil
Northwest
Pipeline
Amoco
Husky Oil
Ralston Proc.
Chevron Oil
Champlin Petro.
Colorado Oil
Pasco, Inc.
Mountain Fuel
Union Oil
Plant/ID
Douglas
Beaver Creek
Riverton Dome
Caspar
Gillette
Recluse
Gillette
Rozet
Springen
Jamison Prong
Hilight
Oedekoven
Ute
Raw 1 ins
McFadden
Sussex
Opal
Elk Basin
Ralston
Oregon Basin
Birch Creek
Patrick Draw
Patrick Draw
Bairoil
Church Buttes
Worland
Source
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
Comments*
A
B
B
A
A
A
A
A
A
A
A
A
A
A
A
A
A
V
B
B
A
A
A
A
A
A
A
Dual
Dual
Dual
Dual
-------
GLOSSARY
Acid Gas
A blend of hydrogen sulfide (H2S) and carbon dioxide (C02) that is
separated by the amine process from raw natural gas. Most plants
meter their total acid gas.
Amine Process
A process using one of the amines in which raw natural gas is bubbled
through the solution which absorbs essentially all C02 and PUS (acid
gas). The solution is regenerated by boiling and the acid gas sent
on for further processing.
Lean Amine - Amine solution after H2S is removed by steam stripping.
Rich Amine - Amine solution with H2S in solution.
Condensate
Known sometimes as distillate. Basically, they are heavier hydro-
carbons occurring in the vapor phase at initial reservoir pressure and
temperature but condensing into a liquid as confining pressure is
reduced.
Cycling Plant
A plant that removes the heavier components from the gas and then
reinjects the gas into the formation to maintain reservoir pressure
and increase ultimate recovery. The produced gas is often sweetened
prior to reinjection.
Field
A single well or group of wells that penetrate and produce from one
or more petroleum-bearing formations.
Flare Stack
One common way to dispose of acid gas is to mix it with some raw
natural gas and burn it at the end of a flare stack which is simply
a tall stack with a burner at its top. The burner is continuously
fed with natural gas which serves to ignite all waste gases that come
to it from the plant.
115
-------
Formation
A strata or series of associated earth materials having similar
conditions of origin. A gas field will often produce from several
formations in a vertical sequence, and the gas found in each may
be significantly different chemically.
Grains per 100 std. cu. ft. (Gr./lOO ft.5)
Standard term for reporting H2S concentration in natural gas.
1 Gr./lOO ft.3 is equivalent to 16 ppm (parts per million) of H2S
in natural gas.
Incinerator
A device utilizing air premixing to efficiently burn waste gases
having sufficient heating value to burn without added fuel.
Lease
Contract between landowner and another granting the latter right
to search for and produce oil or mineral substances upon payment
of an agreed rental, bonus, and/or royalty.
Mol Percent
One mol percent of any gas = 10,000 ppm
Sour Gas
Natural gas containing hydrogen sulfide in concentrations of 4 to
16 ppm or greater.
Sulfur Recovery Plants
A plant which recovers elemental sulfur from a charge gas stream
composed principally of a mixture of H2S and C02- Where the acid
gas stream is sufficient, an operator will elect to install a sulfur
recovery plant.
Sweet Gas
Natural gas whose hydrogen sulfide content is less than
approximately 4 ppm.
116
-------
Sweetening Plant
A plant which processes a sour natural gas charge stream, recovers
the HoS and CC^ content and yields a sweet natural gas stream and
an acid gas (^S and CO^,) stream as products.
117
-------
BIBLIOGRAPHY
Abrassart, C. P. (ed.). Oil and Gas Fields of Montana 1958. Billings
Geological Society. Billings, Montana. 1959. Looseleaf, unpaged.
Air Pollution Aspects of Emission Sources: Petroleum Refineries - A
Bibliography with Abstracts. Environmental Protection Agency, Research
Triangle Park, N. C. Publication Number AP-110. July 1972. 53 pp.
American Geological Institute. Dictionary of Geological^ Terms. Doubleday
and Co., Inc. 1962. 545 pp.
Atmospheric Emissions From Sulfuric Acid Manufacturing Processes. HEW.
Public Health Service. Cincinnati, Ohio. Publication Number 999-AP-13.
1965. 127 pp.
Beers, W. D. Characterization of Glaus Plant Emissions. Environmental
Protection Agency. Publication Number 220-376. April 1973. 132 pp.
Boone, W. J., Jr. Helium-Bearing Natural Gases of the United States.
Analysis and Analytical Methods. Bureau of Mines. Bulletin 576. 1958.
117 pp.
Cardwell, L. E. and L. F. Benton. Analyses of Natural Gases, 1968. Bureau
of Mines. 1C 8443. 1969. 169 pp.
Cardwell, L. E. and L. F. Benton. Analyses of Natural Gases, 1971. Bureau
of Mines. 1C 8554. 1972. 163 pp.
Cardwell, L. E. and L. F. Benton. Analyses of Natural Gases, 1972. Bureau
of Mines. Amarillo, Texas. 1C 8607. 1973. 104 pp.
Cramer, Richard D., Leroy Gatlin and H. G. Wessman. Oil and Gas Fields of
Oklahoma. Volume I. Oklahoma City Geological Society. "Oklahoma City,
Oklahoma. 1963. Looseleaf, unpaged.
Control Techniques for Hydrocarbons and Organic Solvent Emissions from
Stationary Sources. HEW. Publication Number AP-68. March 1970. Unpaged.
Development Document for Effluent Limitations Guidelines and New Source
Performance Standards for the_ Petroleum Refining Point Source Category.
Environmental Protection Agency. Washington, D. C~.EPA 440/1-74-014-2.
April 1974. 195 pp.
Ecology Audits, Inc. Sulfur Compound Emissions of the Petroleum Production
Industry. Environmental Protection Agency. Contract 68-02-1308. Task No. 26.
Research Triangle Park, N.C. December 1974. 93 pp. plus appendices.
Federal Air Quality Control Regions. Office of Air Programs, Environmental
Protection Agency. Rockville, Maryland. AP-102. January 1972. 199 pp.
118
-------
Gas Processing and Refining Worldwide Directory, 1974-75. Oil and Gas
Journal. Annual Publication. 1974. 326 pp.
Jensen, Fred S., Henry H. R. Sharkey, Daniel S. Turner (editors). Oil and
Gas Fields of Colorado, 1954. Rocky Mountain Association of Geologists.
Denver. 1955. 302 pp.
Katz, D. L., David Cornell, Riki Kobayashi, F. H. Poettmann, J. A. Vary,
J. R. Elenbaas and C. F. Weinang. Handbook of Natural Gas Engineering.
McGraw-Hill Book Co. New York. 1959. 802 pp.
Kirk, Raymond E. and Donald F. Othmer (editors). Encyclopedia of Chemical
Technology. Interscience Encyclopedia, Inc. New York. 1951. Vol. 7,
Vol. 13, Vol. 19.
Maddox, R. N. Gas and Liquid Sweetening. Campbell Petroleum Series.
Norman, Oklahoma. 1974. 298 pp.
Miller, R. D. and G. P. Norrell. Analyses of Natural Gases of the United
States, 1961. Bureau of Mines. 1C 8221. 1964. 148pp.
Miller, R. D. and G. P. Norrell. Analyses of Natural Gases of the United
States, 1962. Bureau of Mines. 1C 8239. 1964. 120 pp.
Miller, R. D. and G. P. Norrell. Analyses of Natural Gases of the United
States, 1963. Bureau of Mines. 1C 8241. 1964. 120 pp.
Monitoring and Air Quality Trends Report, 1973. Environmental Protection
Agency, Research Triangle Park, N. C. Report Number 450/1-74-007. October
1974. 130 pp.
Moore, B. J., R. D. Miller, and R. D. Shrewsbury. Analyses of Natural Gases
in the United States, 1964. Bureau of Mines. 1C 8302. 1966. 144 pp.
Moore, B. J. and R. D. Shrewsbury. Analyses of Natural Gases of the United
States, 1965. Bureau of Mines. 1C 8316. 1966. 181 pp.
Moore, B. J. and R. D. Shrewsbury. Analyses of Natural Gases, 1966. Bureau
of Mines. 1C 8356. 1967. 130pp.
Moore, B. J. and R. D. Shrewsbury. Analyses of Natural Gases, 1967. Bureau
of Mines. 1C 8395. 1968. 187pp.
Munnerlyn, R. D. and R. D. Miller. Helium-Bearing Natural Gases of the
United States: Analyses. Bureau of Mines. Bulletin 617. 1963. 93 pp.
Oil and Gas Fields of Southeastern New Mexico; 1966 Supplement: A
symposium. Roswell Geological Society. Roswell, New Mexico. 1967. 185 pp.
Parker, J. M. (ed.). Oil and Gas Field Volume; Colorado-Nebraska, 1961.
Rocky Mountain Association of.Geol. Denver. 1962. Unpaged.
119
-------
Preston, Don (editor). A Symposium of the Oil and Gas Fields of Utah,
Intermountain Association of Petroleum Geologists. Salt Lake City. 1961.
unpaged.
Princeton Chemical Research. Removal of Sulfur Dioxide from Waste Gases
by Reduction to Elemental Sulfur. United States Department of Commerce.
PB 200-071. July 1969. 295 pp.
Snider, L. C. Petroleum and Natural Gas in Oklahoma. Harlow-Ratliff Co.
Oklahoma City, Oklahoma. 1913. 196 pp.
Society of Petroleum Engineers. Statistics of Oil and Gas Development and
Production. American Inst. of Mining. Metallurgical and Petroleum Engineers.
1958. Vol. 13.
Southerland, James H. and William M. Vatavuk. Source Test Data System,
System Sciences, Inc. National Air Data Branch, Monitoring and Data
Analyses Division. August 1973. Unpaged.
Standard Industrial Classification Manual. Department of Commerce.
Washington, D. C. 1972.
Stephenson, Eugene A. Natural Gas. University of Kansas. 1956. Pages 15-20.
Symposium on Michigan Oil arid Gas Fields. Michigan Basin Geological Society.
Lansing, Michigan. 1968. 199 pp.
Tyler, Charles D. and Robert S. George (editors). Oil and Gas Fields of
North Dakota. North Dakota Geological Society Symposium Committee. Bismarck,
North Dakota. 1962. 220 pp.
Vatavuk, William M. National Emissions Data System (NEDS) Control Device
Workbook. Environmental Protection Agency. Research Triangle Park, N. C.
Publication Number APTD-1570. July 1973. Unpaged.
Wagner, C. Richard (editor). Oil and Gas Fields of the Texas and Oklahoma
Panhandles. Panhandle Geological Society. Amarillo, Texas. 1961. 264 pp.
Wyoming Oil and Gas Fields Symposium. Wyoming Geological Association. N.P.
1957. 484 pp.
120
-------
Appendix A
Data Summary of Sour Gas Production for Table 3
Al
-------
Appendix A
Data Summary of Sour Gas Production for Table 3
AQCR Number
H2S mol Percent
Maximum Minimum Mean
T, ft
Number of Samples
24
32
31
33
211
210
215
212
214
218
217
155
5
22
188
187
126
143
141
243
241
40
38
36
37
14
172
19
134
7.5
5.3
1.6
1.0
0.74
0.057
2.66
0.89
0.72
8.0
2.28
17.48
15.0
2.77
0.3
1.1
0.5
0.4
8.0
11.7
5.4
1.4
0.3
0.1
2.0
1.9
3.7
0.25
0.69
0;08
0.5
0.6
ll'.O
0.0145
0.053
2.3
0.25
0.45
0.004
0.75
0.023
0.02
0.02
0.3
1.1
0.5
0.4
0.1
0.1
0.1
0.1
0.3
0.1
0.1
0.09
0.5
0.04
0.67
2.09
3.66
0.89
1.0
0.26
0.055
2.54
0.57
0.59
0.63
1.41
0.83
3.30
0.55
0.3
1.1
0.5
0.4
3.93
2.34
1.26
0.31
0.3
0.1
0.49
0.71
1.74
0.15
0.68
23
5
24
1
16
2
3
2
3
71
7
28
25
15
1
1
1
1
3
21
12
11
1
2
11
46
5
2
2
aLow number of samples indicates fhat only a small amount of sour gas is
produced in the area. Single samples are used in this table to indicate
sour gas H2S content because they are the only records for the AQCR.
A2
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT NO.
2.
3. RECIPIENT'S ACCESSION-NO.
4. TITLE AND SUBTITLE
Atmospheric Emissions Survey of the Gas Processing
Industry
5. REPORT DATE
September 1975 fsubmittedl
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
Billy J. Mullins, Jr.; Dehn E. Solomon; Gary L. Austin;
Linda M. Kacmarcik
8. PERFORMING ORGANIZATION REPORT NO.
757-01
9. PERFORMING ORGANIZATION NAME AND ADDRESS
10. PROGRAM ELEMENT NO.
Ecology Audits, Inc.
11061 Shady Trail
Dallas, Texas 75229
11. CONTRACT/GRANT NO.
68-02-1865
Modification 1
12. SPONSORING AGENCY NAME AND ADDRESS
Environmental Protection Agency
National Air Data Branch
Research Triangle Park, North Carolina 27711
13. TYPE OF REPORT AND PERIOD COVERED
Final
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
Atmospheric emissions from the gas processing industry originate from compressor
and pump engines, boilers for process heating and solution regeneration, and gas
"sweetening", the removal of hydrogen sulfide from the natural gas. This research
effort concerned itself only with emissions from gas sweetening processes, primarily
the amine type processes because of the widespread use of amine processes to the
exclusion of other sweetening processes. Emissions from gas sweetening are the
combustion products of the acid waste gases following their removal from the raw
natural gas, and include sulfur dioxide with negligible emissions of particulates,
nitrogen oxides, hydrocarbons and carbon monoxide.
An emissions factor for SC>2 was developed. SC^ emissions from gas sweetening
are directly proportional to the mol percentage of H2S in the intake gas to the
sweetening plant. Emissions are calculated by multiplying the whole number repre-
senting mol percent H2S by the factor 1685 to get pounds of S02 per million cubic
feet of intake gas sweetened. When the concentration of H2S is not known, a table
is presented giving average H2S concentrations in gas produced in Air Quality Control
Regions.
New Source Classification Codes are proposed for the industry. A list of over
1,000 gas processing plants is presented with notes on their emissions.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.IDENTIFIERS/OPEN ENDED TERMS C. COS AT I Field/Group
Acid Gas
Sour Gas
Sweet Gas
Amine Process
Hydrogen Sulfide
Flare Stack
Incinerator
Cycling Plant
Sulfur Dioxide
Raw Natural Gas
Sour Gas Processing
Sulfur Recovery Plant
Sweetening Plant
Emissions
Emission Factor
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