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.

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            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.

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             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
                                          i—i

                                          V)
                                           rt

                                           +J
                                           rt

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     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

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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

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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

-------
     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

-------
                  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

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     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

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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

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'  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

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       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

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            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

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                           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.
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Society of Petroleum Engineers.  Statistics of Oil and Gas Development and
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Southerland, James H. and William M. Vatavuk.  Source Test Data System,
System Sciences, Inc.  National Air Data Branch, Monitoring and Data
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Standard Industrial Classification Manual.  Department of Commerce.
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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
18. DISTRIBUTION STATEMENT
                                              19. SECURITY CLASS (This Report)
                                                   21. NO. OF PAGES
                                              20. SECURITY CLASS (Thispage)
                                                                        22. PRICE
EPA Form 2220-1 (9-73)

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EPA Form 2220-1 (9-73) (Reverse)

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