EPA-600/2-77-023b
February 1977
Environmental Protection Technology Series
INDUSTRIAL PROCESS PROFILES FOR
ENVIRONMENTAL USE: Chapter 2.
Oil and Gas Production
Industry
Industrial Environmental Research Laboratory
Office of Research and Development
U.S. Environmental Protection Agency
Cincinnati, Ohio 45268
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RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into five series. These five broad
categories were established to facilitate further development and application of
environmental technology. Elimination of traditional grouping was consciously
planned to foster technology transfer and a maximum interface in related fields.
The five series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
This report has been assigned to the ENVIRONMENTAL PROTECTION
TECHNOLOGY series. This series describes research performed to develop and
demonstrate instrumentation, equipment, and methodology to repair or prevent
environmental degradation from point and non-point sources of pollution. This
work provides the new or improved technology required for the control and
treatment of pollution sources to meet environmental quality standards.
This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
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EPA-600/2-77-023b
February 1977
INDUSTRIAL PROCESS PROFILES
FOR ENVIRONMENTAL USE
CHAPTER 2
OIL AND GAS PRODUCTION INDUSTRY
by
Glynda E. Wilkins
Radian Corporation
Austin, Texas 78766
Contract NO. 68-02-1319
Project Officer
Alfred B. Craig
Metals and Inorganic Chemicals Branch
Industrial Environmental Research Laboratory
Cincinnati, Ohio 45268
INDUSTRIAL ENVIRONMENTAL RESEARCH LABORATORY
OFFICE OF RESEARCH AND DEVELOPMENT
U.S. ENVIRONMENTAL PROTECTION AGENCY
CINCINNATI, OHIO 45268
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DISCLAIMER
This report has been reviewed by the Industrial Environmental Research
Laboratory - Cincinnati, U.S. Environmental Protection Agency, and approved
for publication. Approval does not signify that the contents necessarily
reflect the views and policies of the U.S. Environmental Protection Agency,
nor does mention of trade names or commercial products constitute endorsement
or recommendation for use.
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ACKNOWLEDGEMENTS
This chapter was prepared for EPA by Radian Corporation under Contract
No. 68-02-1319, Task 42. Glynda E. Wilkins was the author. Significant
contributions were also made by Tommy D. Raye, Larry D. Short, and
Teresa Sipes. Program administration was directed by Eugene C. Cavanaugh,
Helpful review comments from James H. Gary were received and incorporated
into this chapter.
ill
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TABLE OF CONTENTS
CHAPTER 2
Page
INDUSTRY DESCRIPTION. .... 1
Products 3
Companies 3
Environmental Impact 4
Bibliography 5
INDUSTRY ANALYSIS ..... 6
Exploration and Site Preparation. . 7
Process No. 1. Exploration ..... 8
Process No. 2. Site Preparation 10
Well Drilling and Completion 12
Process No. 3. Drilling 13
Process No. 4. Mud Circulation 16
Process No. 5. Format Evaluation 19
Process No. 6. Well Completion 21
Crude Processing 24
Process No. 7. Water Removal 25
Process No. 8. Gas-Oil Separation 28
Process No. 9. Crude Storage 30
Natural Gas Processing 32
Process No. 10. Liquid Hydrocarbon Recovery 34
Process No. 11. Acid Gas Removal 37
Process No. 12. Sulfur Recovery 39
Process No. 13. Dehydration 41
Process No. 14. Production Separation 43
Process No. 15. LPG Storage 46
Process No. 16. Gasoline Storage 48
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TABLE OF CONTENTS (Cont.)
Page
Secondary and Tertiary Recovery Techniques . . 50
Process No. 17. Displacement 51
Process No. 18. Fracturing 53
Process No. 19. Acid Treatment . 55
Process No. 20. Thermal Treatment 57
Appendix A - Characteristics of U. S. Crude Oils 59
Appendix B - Geographical Location of Oil and Gas Production
Activities 79
Appendix C - Partial Listing of Domestic Producers 99
Appendix D - Materials for Drilling Fluid Systems 115
vi
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LIST OF FIGURES
CHAPTER 2
1 The Oil and Gas Production Industry ............ 2
2 Crude Processing ................ 24
3 Natural Gas Processing ............... 33
vi i
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LIST OF TABLES
CHAPTER 2
Tab1e Page
1 Yearly Volumes of Acids Used for Well Treatment 22
2 Disposition of Waste Brine 26
3 Hydrocarbon Emission Factors for Crude Storage 30
4 Hydrocarbon Emission Factors for Gasoline Storage 48
A-l Properties of United States Crude Oils . . 60
A-2 Trace Element Content of United States Crude Oils. ..... 67
A-3 Sulfur and Nitrogen Content of the Giant U. S. Oil Fields. . 72
B-l Production of Crude Oil and Lease Condensate by
States, 1973 30
B-2 Production of Natural Gas by States, 1973 82
B-3 Location of Large Domestic Oilfields 84
B-4 Natural Gas Processing Plants in the United States,
January, 1972 90
B-5 Wells Drilled in the U. S 97
C-l Partial Listing of Domestic Producers 100
D-l Materials for Drilling Fluid Systems .... 116
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OIL AND GAS PRODUCTION INDUSTRY
INDUSTRY DESCRIPTION
The oil and gas production industry is involved in locating and retrieving
oil and gas from underground formations and preparing the well streams for
use by consumers or refiners. Production activities begin with exploration
and end with storage or sales.
The industry has been divided into five segments for consideration.
(1) Exploration and Site Preparation - This segment includes
those operations necessary for selection and preparation
of a drilling site.
(2) Drilling - The drilling segment is comprised of all
operations involved in digging a well and preparing
it for production.
(3) Crude Processing - Several process modules are described
for preparing crude for refinery use.
(4) Natural Gas Processing - This segment includes widely
used processes for preparing natural gas for sales.
(5) Secondary or Tertiary Recovery - Methods for stimulating
well production are included in this segment.
Figure 1 is a schematic representation of the industry segments and their
i nterrelationshi ps.
Process descriptions have been prepared for all necessary operations
involved in each segment, but flowsheets were deemed appropriate in only
two segments: Crude Processing and Natural Gas Processing.
The petroleum production industry is very large and diverse. On December
31, 1973, there were 497,378 producing oil wells and 124,168 producing gas
wells in the U.S. Industry figures indicated that 1,460,000 cubic meters
(9,209,000 barrels) of crude and lease condensate and 1,867 million cubic
meters (65,940 million cubic feet) of natural gas were produced daily. The
drilling segment of the industry completed 33,373 oil wells, gas wells, dry
holes, and service wells in 1974. The entire industry employed 291,900
people in 1974.
Crude oil and natural gas are produced in 32 states-of the U.S., but
Louisiana, Texas, California, and Oklahoma accounted for 79 percent of the
domestic crude production in 1973. Of the domestic gas production for 1973,
Louisiana and Texas accounted for 74 percent. Drilling activities in 1974
were centered in California, Louisiana, Kansas, Oklahoma, and Texas with 64
percent of the total wells drilled in those states. Appendix B contains
several correlations of production data with geographical location. Included
are tables of production by state; gas plants, locations and throughput;
locations of the largest oil fields in the U.S.; and drilling data presented
by state.
1
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EXPLORATION
AND
SITE PREPARATION
DRILLING
CRUDE
PROCESSING
i
SECONDARY
OR
TERTIARY
RECOVERY
I
NATURAL GAS
PROCESSING
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The high growth trends established by the petroleum industry in the late
1960's and early 1970's have been interrupted and are still fluctuating.
Although predicting the future at this time is a difficult task, it appears
that for the near future U. S. crude production will be declining 2 to 3%
yearly while domestic petroleum demands and refining capacity will be
increasing 2 to 3%. Natural gas production became almost constant in the
1970's, and the trend in gas processing has been toward fewer processing
facilities with larger capacities. Despite staggering costs involved in
drilling wells, drilling operations have seen a sharp increase since 1971.
The limiting factor in drilling activities in the next few years is expected
to be the availability of rotary rigs.
Products
Crude oil is composed chiefly of hydrocarbons (paraffins, naphthenes, and
aromatics) in a typical carbon to hydrogen ratio between 6 and 8 together
with small amounts of trace elements and organic compounds containing sulfur,
nitrogen, and oxygen. The appearance and consistency of crude is determined
by the molecular types and sizes of hydrocarbon present. Common colors are
green, brown, black, and occasionally light yellow. Specific gravities are
usually 0.80 to 0.95; viscosities of most crudes range from 0.023 to 0.23
stokes at 38°C. Appendix A contains chemical analyses and physical proper-
ties of some domestic crude productions. A typical domestic crude contains
83-85% carbon, 11-14% hydrogen, 0.05-2% sulfur, 0.1-2% nitrogen and 0.2%
oxygen.
Natural gas is about 95% saturated hydrocarbons. The principal hydrocarbon
is methane. Also present, in decreasing proportions, are ethane, propane,
butanes, pentanes, hexanes, and heptanes. The remaining 5% is usually
nitrogen, carbon dioxide, and sometimes hydrogen sulfide and helium. After
being processed to remove the natural gas liquids, the natural gas becomes
dry natural gas and consists chiefly of methane. The heavier hydrocarbons
are separated and/or liquefied to become ethane, propane (LPG), butanes,
and natural gasoline.
Companies
Some of the companies involved in oil production engage in only one facet of
the industry and are known as nonintegrated companies. Those companies that
are involved in all phases of the petroleum industry are called integrated
companies. In between are the semi-integrated companies that engage in two
or more types of operation.
Another often used classification system is division into two classes:
majors and independents. The differentiation is rather vague, so that a
strict definition is impossible. Most independents are of modest resources
and are nonintegrated. There are some integrated companies with large
international holdings that consider themselves independents, however.
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The independents are extremely important to oil and gas production, as they
are responsible for drilling nearly 80 percent of the producing, domestic wells.
A list of oil and gas producers proved unavailable and impractical, as there
are over 9,000 crude oil producers alone. To add to the problem, the produc-
tion industry is very fluid; companies appear and disappear rapidly due to
mergers and acquisitions. Appendix C contains a listing of integrated companies
and some of the large independents in the U. S. with production data (when
available) and office locations.
Environmental Impact
The major waste streams encountered in the oil and gas production industry
contain hydrocarbons, oily brine, sulfides and other sulfur compounds and
glycols.
Blowouts during drilling operations may cause hydrocarbon emissions to air,
land, and water. Offshore operations also contend with the danger of storms
and shipping accidents causing uncontrolled flow from producing wells Tech-
nology is constantly improving the situation, however, and is decreasing the
potential threat of uncontrolled flow or blowouts.
Gaseous hydrocarbon emissions are significant environmental problems in the
industry. Storage tank breathing and filling losses; fugitive leaks in valves
vents, pumps, pipes, and vessels; and vented natural gas in remote locations
contribute to the emission problem. However, the increased prices of hydro-
carbons are making prevention of their loss more economically attractive, and
this pollution problem should be decreasing in the near future.
Atmospheric emissions of gases other than hydrocarbon gases are also encountered
in oil and gas production. In producing sour crudes or gases hydrogen sulfide
emissions may occur from fugitive sources, and other sulfur compounds may be
emitted in the tail gas from sulfur recovery units or from flaring sulfide
gases. The quantities of sulfur emitted as sulfides or as oxides of sulfur
are not well defined at this time. The problem is addressed in Reference 12,
but the variability of sulfur concentrations in the well productions and the
inconsistencies in reporting procedures seem to have prevented any reliable
estimates of nationwide emissions. Large steam or waste water streams con-
taminated with glycols are also encountered in the natural gas processing
segments. s
A huge waste water stream is a by-product of oil and gas production. Disposal
of large quantities of brines produced with oil and gas presents a problem of
great magnitude. The brine presents a threat to fresh water supplies, and
the associated oil presents a threat to water, land, and air. References 7
and 8 are EPA funded documents which treat the problem of brine disposal in
the oil industry in depth.
Another source of environmental concern is the contamination of aquifer zones
by drilling fluids, brines, or hydrocarbons in secondary recovery and drilling
operations.
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Bibliography
(3)
Inc., 1969.
Annual Statistical Review. Petroleum Industry Statistics. 1965-1974.
Washington, D. C., American Petroleum Institute, 1975.
(2) "Forecast/Review, An Oil and Gas Journal Special Report", Oil and
Gas_Jouni. 71 (4), 103-118 (1975).
Chilingar, George V. and Carrol M. Beeson, eds., Surface Operations
in Petroleum Production, New York, American Elsevier Publishing Co ,
Inc., 1969.
An Appraisal of the Petroleum Industry of the United States. PB188865,
Washington, D. C., United States Department of the Interior, 1965.
(5) Environmental Conservation, Vol. II, Washington, D. C., The National
Petroleum Council, 1972.
(6) Radian Corporation, Study on Control of Hydrocarbon Emissions from
Petroleum Liquids. EPA Contract No. 68-02-1319, Task 12, Austin
Texas, 1975.
(7) Reid, George W., et al., Brine Disposal Treatment Practices
Relating to the Oil Production Industry, EPA 660/2-74-037
Norman, Oklahoma, 1974.
(8) Reid, George W. and Leale E. Streebin, Evaluation of Waste Waters
from Petroleum and Coal Processing. EPA R2-72-001, Ada, Oklahoma,
(9) "Independents Widen Lead in U. S. Oil and Gas Search", Oil and Gas
Journal, 72 (26), 11-15 (1974). '
(10) Kantor, Richard H., Trace Pollutants from Petroleum and Natural Gas
Processing, EPA Contract No. 68-02-1308, I ask 8, Houston, Texas, 1974.
(11) Bland, William F. and Robert L. Davidson, eds., Petroleum Processing
Handbook, New York, McGraw-Hill, 1967.
(12) Ecology Audits, Inc., Sulfur Compound Emissions of the Petroleum
Production Industry, EPA Publication No. 650/2-75-030, Dallas, Texas,
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INDUSTRY ANALYSIS
The oil and gas production industry is discussed in five segments: (1)
Exploration and Site Preparation, (2) Drilling, (3) Crude Processing,
(4) Natural Gas Processing, and.(5) Secondary and Tertiary Recovery. The
discussion of the above five segments includes process descriptions of the
various processing steps used in producing and preparing crude, natural
gas liquids, and natural gas for use by consumers or refineries.
An attempt was made to present the process steps in sequence. The problem
encountered in the Crude Processing and Natural Gas Processing segments was
the diversity of the operations involved. The sequences of processing steps
are not at all the same from place to place; moreover, some processes may
be absent and additional processes present to deal with the local conditions
and composition of the production. This catalog entry cannot be considered
an all-encompassing survey, but only a summary of some of the most commonly
used methods in domestic production.
Within each process description data have been presented on operating para-
meters, utility requirements, input materials, and waste streams when they
were applicable and available. Input materials were confined to chemical
substances added; items such as drill bits and drill pipes were disregarded.
Operating parameters include process variables and do not include such things
as downhole temperatures. Waste streams have been indicated even when no
quantitative data were found. Information and data were taken from authori-
tative sources and are considered reliable and accurate. Process flowsheets
have been provided for Crude Processing and Natural Gas Processing, but were
considered inappropriate for the other segments.
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EXPLORATION AND SITE PREPARATION
Process descriptions for the two modules (1) Exploration and (2) Site
Preparation are presented in this segment. A large portion of the total
oil and gas production budget goes into these acitivites which are becoming
increasingly necessary and more expensive each year as the industry is forced
to produce oil from more remote or inaccessible formations.
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EXPLORATION AND SITE PREPARATION PROCESS NO. 1
Exploration
1. Function - The objective of oil exploration procedures is defining
and describing geological structures which are often associated with
oil accumulation in the earth's crust.
Geological surveys of the surface are made using aerial photographs,
satellite photographs, and mappings of surface outcrops. Offshore
geological surveys include mapping of the bottom using acoustic
sounding methods and bottom sampling. Core sampling is performed
in both onshore and offshore operations.
Subsurface geological surveys are made by geophysical methods.
Seismic methods, the most widely used of the geophysical methods,
yield information about the times required for shock waves to travel
through rock formations. These data help characterize the subsurface
strata with respect to the depth and nature of the formations. The
monitored shock waves are generated by explosive charges set at or
near the surface or by dropping a 2700 kg (6000 Ib.) steel slab 3
meters (nine feet) to the ground (thumping).
Offshore seismic operations generate shock waves to penetrate the
earth's crust in a variety of ways. The traditional source was dynamite,
but today electric discharges, encapsulated explosives, gas guns,
and electromechanical and mechanical transducers are used. In marine
geophysical surveys the sources and receivers are operated over the
side of or close behind a ship.
Gravimetric methods depend on the measurements of slight variations in
the force of gravity on the surface of the earth or ocean floor. Mag-
netic methods measure local variations in the intensity of the earth's
magnetic field. These measurements may give indications of the depth
and nature of subsurface rock formations.
2. Input Materials - Not applicable
3. Operating Parameters - Not applicable
4. Utilities - Very small energy usage
5. Waste Streams - There is a minimal danger of pollution due to a
blowout during core drilling operations when a shallow pocket of
gas or oil is encountered.
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Uncased seismic shot holes can cause pollution of shallow freshwater
streams. Strong shock waves generated offshore by explosives have
resulted in killing fish.
On the whole, this part of the industry has little chance for
pollution.
6. EPA Source Classification Code - None exists
7. References -
0) Environmental Conservation. The Oil and Gas Industries. Vol II
Washington, D. C., The National Petroleum Council, 1972.
(2) The Petroleum Handbook. London, Shell International Petroleum
Company Limited, 1966.
(3) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling. 3rd. ed., Austin, Texas,
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EXPLORATION AND SITE PREPARATION PROCESS NO. 2
Site Preparation
1. Function - Site preparation activites include those operations
necessary to prepare the drilling site and "rig-up" the equipment.
The operations are necessarily different for onshore and offshore
Vocations and will be dictated somewhat by local conditions.
For land operations earth-moving machinery clears, grades, and levels
the site. Earthen pits are dug for circulating fluid and for waste,
and access roads are built and surfaced with a variety of materials
including caliche, oyster shells, or wooden timbers. Water must be
furnished to the site by digging water wells or installing pumps
and water lines. The drilling rig may be transported overland on
skids almost completely assembled, or if the distance is great and/or
the terrain is rough, the rig must be dismantled and hauled to the
site on heavy trucks. Remote drilling locations may require trans-
port of rig pieces by air freight or by helicopter. The derrick is
usually of the cantilevered type and is raised into position after
being assembled horizontally using power from the drawworks. Connec-
tions are made for the pumps, mud tanks, and pipe lines and the crown
block, hoisting line, and travelling block are installed. Auxiliary
equipment is installed and the mouse and rat holes are dug before
drilling can begin.
Preparations for drilling offshore differ widely because of the many
types of rigs available. The drilling rigs may be floating or fixed
in place on the ocean floor. They may be self-contained, or they
may require barge tenders which contain the auxiliary components
necessary to the drilling derrick. In all cases the pumps, pipelines,
and machinery must be connected, and in the case of submersible rigs
the platform must be settled firmly on the bottom. For disassembled
rigs "rigging-up" may require large barges with hoisting capacities
of 450 metric tons (500 tons) to raise the derrick and to prepare the-
rig for drill ing.
2. Input Materials - Not applicable
3. Operating Parameters - Not applicable
4- Utilities - Fuel required for earth-moving and transportation equipment
5. Waste Streams - Top soil may be eroded from land operations where
earth-moving machinery has removed vegetation.
6. EPA Source Classification Code - None exists
10
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7. References -
(1) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling. 3rd. ed., Austin, Texas,
1970.
(2) Environmental Conservation. The Oil and Gas Industries. Vol. II,
Washington, D. C., The National Petroleum Council, 1972.
(3) The Petroleum Handbook, London, Shell International Petroleum
Company Limited, 1966.
11
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WELL DRILLING AND COMPLETION
The segment of the oil industry concerned with drilling and completing an
oil well includes all of those operations necessary to digging the hole and
readying it for production.
There are four main processes involved in this segment. Drilling is the
process of actually cutting through the earth's crust to form a hole. Mud
circulation is a facilitative process which aids in drilling and provides a
safety measure against blowouts. Formation evaluation concerns gathering
data about the formations being penetrated and assessing their commercial
value. Well completion includes those steps necessary to prepare the drilled
hole for production.
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DRILLING PROCESS NO. 3
Drilling
1. Function - Drilling is the process of actually cutting through the
earth's crust to form a well and is accomplished by rotating and
hoisting operations performed at the derrick. The cutting and
grinding through the earth's surface is accomplished by rotating
the drilling string with the required weight on the drill bit affixed
to the end of the drill string. Additional lengths of drill pipe are
attached as the drilling proceeds. When a worn drill bit has to be
replaced, the entire string of pipe must be hoisted. The pipe lengths
are removed as the string is slowly raised until the drill bit is
brought to the surface and changed out. The new bit and the drill
string are slowly lowered, and the lengths of pipe are replaced until
the bottom is reached, at which time rotation begins again.
The rotation equipment consists of a swivel which sustains the weight
of the drilling string, permits rotation, and affords a passageway
for circulation of drilling fluid; the kelly which transmits torque
from the rotary to the drilling string, permits vertical movement
of the string, and transmits drilling fluid down the string; the
rotary table which drives the kelly bushing and accommodates tapered
slips for holding pipe when making or breaking connections. The drill
bit is on the end of the rotating string and is designed to break,
dislodge, or fragment formation material. Different bits are available
for different applications; they may be steel, carbide-tipped, or
diamond tipped.
Hoisting equipment consists of the drawworks, a crown block fixed at
the top of the derrick, and a travelling block to which is attached
a hook. The drawworks is a power hoist provided with a series of
clutches, gearing systems, and braking systems to hoist and lower as
much as 450 metric tons (500 tons) of weight in a controlled manner.
2. Input Materials - Not applicable
3. Operating Parameters - Not applicable
4. Utilities - Heavy duty rigs for deep wells require about 2200 kW
(3000 hp) for rotation, hoisting, and circulation. The power is
routinely supplied by diesel or gas engines.
13
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5. Waste Streams -
. Cuttings - 168 m3 (1059 barrels) of cuttings are generated in
drilling a 4600 m (15,000 foot) hole 22 cm (8% in.) in diameter.
On land the cuttings are separated from the mud and discharged in
waste pits. Offshore the cuttings may be dumped into the ocean
if they are mixed with water-based muds. Those cuttings contam-
inated with oil-based muds or hydrocarbons from a formation may
be treated to separate the oil before disposal in the sea, or the
cuttings may be pumped into a barge for transport to shore when
the waste is treated and discarded.
. Drilling fluid - Excess or contaminated mud is pumped into waste
pits, into the ocean (when water-based mud is used), or into
barges for transport to shore. Earthen mud pits are subject to
a certain amount of leaching which may threaten fresh water zones.
Mud may also escape into porous formations and into fresh water
aquifers during drilling operations. Modern drilling operations
employ techniques to protect fresh water aquifers; oil-based muds
are not used while drilling these formations, and often casing
will be set in that zone.
. Hydrocarbons - Oil brought to the surface with drilling mud is
separated and disposed of in open pits or pumped into barges for
onshore disposal. Excess oil-based muds are treated in~the same
manner. At any point that the oil is open to the air, atmospheric
emissions result. Hydrocarbon gas brought to the surface with
drilling fluid is separated from the mud and may be vented or
flared at a safe distance from the drilling operation.
Blowouts are considered a very serious hydrocarbon waste stream
which may affect air, land, and water. Blowouts occurred in 106
of 273,000 wells drilled from 1960 through 1970 in "eight states.
Of 9000 wells drilled on the outer continental shelf, blowouts
1n 25 wells occurred. Along with the hydrocarbon emission to the
land, air, and sea, there are dangers of a blowout establishing
communication between the producing formation and a fresh water
aquifer. Blowout prevention measures are practiced routinely
throughout the industry. Drilling rigs are equipped with blowout
preventers which can close a well in 15 seconds. Downhole pres-
sures and mud circulation volumes are constantly monitored during
drilling operations for indications of well fluid entering the
hole. Drilling muds are weighted to keep the downhole pressure
under control.
6. EPA Source Classification Code - None
14
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(7) References -
(1) Environmental Conservation. The Oil and Gas Industries. Vol. II,
Washington, D. C., The National Petroleum Council, 1972.
(2) The Petroleum Handbook, London, Shell International Petroleum
Company Limited, 1966.
(3) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drillings. 3rd. ed., Austin, Texas,
1970.
(4) Rogers, Walter F., Composition and Properties of Oil Well
Drilling Fluids. Houston, Texas, Gulf Publishing Company, 1963.
(5) Collins, Gene, "Oil and Gas Wells-Potential Polluters of the
Environment?", J. of WPCF 43 (12), 2383-93 (1971).
15
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DRILLING PROCESS NO. 4
Mud Circulation
Function - Drilling fluid is pumped through the drill pipe and drill
bit to the bottom of the hole and returned to the surface through
the annul us outside the drill bit during drilling operations. The
purposes of the fluid are to remove cuttings made by the bit, to
cool and lubricate the bit and drill string, to control formation
pressure, to support and protect the wall of the hole, and to facilitate
formation evaluation procedures.
The drilling fluid is pumped under high pressure from a suction tank
or pit, up a standpipe, through the rotary hose and swivel to the
hollow kelly and drilling string. After leaving the drill bit, the
fluid, carrying drilling cuttings, ascends through the space between
the drill string and wall of the borehole. At the surface the fluid
passes through shale shakers, desanders, desilters, and degassers to
remove impurities. The mud then returns to the suction tank for
recycling unless it is contaminated. Contaminated mud is jetted into
reserve pits or barges along with cuttings, excess mud made by the
hole, and other waste streams from the drilling site. In addition to
the basic circulation equipment mentioned there are agitators for the
tanks* mud weight and pit level indicating and recording devices,
chemical testing and treating apparatus, and mud storage and handling
facilities.
The actual composition of the drilling fluid will vary with the forma-
tion being drilled and the activity on the drilling rig. Drilling
fluids include gases, liquids, and solids suspended in liquids. The
solids suspended in liquids type, the most widely used, consists of a
colloidal suspension of clay in water, usually bentonite for fresh
water and attapulgite for salt water. Suspensions of solids in oil
and oil emulsions are also used, especially in drilling through for-
mations that swell and slough in the presence of water. Chemicals
of various types are used to further control the physical and chemical
properties of the drilling fluid. The viscosity is adjusted with
quebracho and tannin; the density is controlled with weighting agents,
usually barite. When drilling through highly permeable formations,
fibrous, flaky, or granular material may be added to stop mud circula-
tion losses. A partial list of the substances used in drilling fluids
includes lignosulfonates, calcium, chromium compounds, acrylonitriles,
sodium salts of phosphoric acids, natural gums, dehydrated phosphates,
subbituminous products, protocatechuic acid, lignins, sugar cane fibers,
lime, ground nutshells, cotton seed hulls, cellophane flakes, corn
starch, salt water, carboxymethyl-cellulose, crude oil, surfactants,
soaps, lecithin, and asbestos. A list of some drilling fluids and
their descriptions is included in Appendix D.
16
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2. Input Materials - A well 2600 to 3500 m (8500 to 11,500 feet) deep
will require 190 to 400 m3 (1200 to 2500 barrels) of mud to circulate
and fill the hole. This does not allow for volumes of chemical addi-
tions made as drilling progresses or for mud lost to porous formations
Chemical additions generally range from 20 to 140 kg (50 to 300 Ib.)
per day, but may go as high as 900 kg (2000 Ib.) per day.
3. Operating Parameters - The minimum critical velocity is usually 37
to 55 meters per minute (120 to 180 feet per minute).
4. Utilities - A typical 41 cm (16 in.) mud pump for a heavy duty rig
is driven by 750 kW (1000 hp). With an efficiency of 0.36 the pump
requires 0.025 m3 (6.50 gallons) of diesel per hour. Additional
power 1s required for various smaller motors, pumps, and agitators
involved in the mud circulation system.
5. wast6 Streams -
Drilling fluid - Excess or contaminated mud is pumped into
waste pits, into the ocean (when water-based mud is used), or
into barges for transport to shore. Drilling mud may threaten
fresh water zones by leaching from earthen pits and by escap-
ing into porous formations during drilling operations. Modern
drilling operations include practices to protect fresh water
zones. Oil-based muds are not used while drilling these for-
mations, and often casing will be set in that zone.
Hydrocarbons - Oil brought to the surface with drilling mud
is separated and disposed of in open pits or pumped into
barges for disposal onshore. Excess oil-based muds are
treated in the same manner. At any point that the oil is
open to the air, atmospheric emissions result.
Hydrocarbon gas brought to the surface with drilling fluid
is separated from the mud and may be vented or flared at a
safe distance from the drilling operations.
6. EPA Source Classification Code - None
7. References -
(1) Petroleum Handbook, London, Shell International
Petroleum Company Limited, 1966.
(2) Petroleum Extension Service Industrial and Business
Training Bureau, A Primer of Oil Well Drilling, 3rd.
ed., Austin, Texas, 1970.
(3) Environmental Conservation. The Oil and Gas Industries,
Vol. II, Washington, D. C., The National Petroleum Council,
1972.
17
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(4) Lynch, Edward J., Formation Evaluation. New York, Harper and
Row, 1962.
(5) Rogers, Walter F., Composition and Properties of Oil Well
Drilling Fluids, Houston, Texas, Gulf Publishing Company, 1963,
(6) Collins, Gene, "Oil and Gas Wells-Potential Polluters of the
Environment?", J. of WPCF 43 (12), 2383-93 (1971).
13
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DRILLING PROCESS NO. 5
Formation Evaluation
1. Function - Formation evaluation involves the use of tools and methods
that are capable of locating producing formations and evaluating
their commercial significance. There are two broad categories of
formation evaluation methods: those used while drilling is in pro-
gress and those used after drilling or a portion of the drilling is
completed. Core analysis and evaluation of drilling fluid and drill
cuttings are in the first group, while wireline logging methods such
as electric logging, radioactivity logging, and acoustic velocity
logging are in the second category. Drill stem testing may be used
in either classification.
In coring the drill bit is replaced by a core barrel and a core head
by means of which a cylinder of the formation being penetrated passes
through the core head and into the core barrel where it is retained
and brought to the surface. Sidewall coring is accomplished by
shooting several hollow cylinders into the walls of the uncased hole.
The cylinders are then pulled to the surface by steel wires attached
to the carrier. The core samples are analyzed for porosity, per-
meability, and the saturation of oil, water, and gas.
Evaluation of the drill cuttings and the drilling fluid involves
continuous monitoring of these streams for traces of oil, gas, or
saltwater.
Wireline logging methods require that various special tools run into
the well on multi-conductor wireline are placed in the well to study
and evaluate the formation. These special devices may measure the
electrical, magnetic, radioactive, or acoustic properties of the
formations. The measured information is displayed continuously as
a function of depth on a strip chart.
If a formation looks promising, a drill stem test is made. Drill
stem testing seeks to reproduce conditions existent in a producing
well. A simplified description of the process is that a producing
formation is sealed off with packers, and the formation is opened
to the surface. Formation fluid then enters the drill pipe and is
brought to the surface for evaluation.
The data gathered from the formation evaluation processes will
determine whether the casing is set and the well completed or plugged.
2. Input Materials - Not applicable
19
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3. Operating Parameters - Not applicable
4. Utilities - The amount of power required is small compared to the power
required for other drilling operations.
5. Waste Streams - None
6. EPA Source Classification Code - None exists
7. References -
(1) Lynch, Edward 0., Formation Evaluation, New York, Harper
and Row, 1962.
(2) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling, 3rd. ed., Austin,
Texas, 1970.
(3) Environmental Conservation. The Oil and Gas Industries, Vol.
II, Washington, D. C., The National Petroleum Council, 1972.
(4) The Petroleum Handbook, London, Shell International Petroleum
Company Limited, 1966.
20
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DRILLING PROCESS NO. 6
Well Completion
Function - Well completion encompasses all of those activities
required in preparing the drilled hole for production.
According to the nature of the producing formation, different
completion methods are used, but a string of casing is always
run into the hole and cemented, at least as far as the top of the
producing layer. When the producing formation is firm, the casing
may be cemented immediately above it, leaving the producing zone
unsupported. If the producing formation is judged to be in danger
of caving or sloughing, it must be supported. The most common way
of completing a well with a structurally weak production zone is by
perforating (comprising 95% of well completions). Casing is run
through the producing layer to the bottom and cemented, after which
holes are shot through the casing and cement in the producing layer
with a perforator. Perforators either contain charges which fire
steel bullets, or they employ small shaped charges that blow holes
through the casing and cement. An alternative to perforating is the
practice of hanging a small perforated pipe (liner) from the bottom
of the set casing. The presence of sand formations may necessitate
the use of a mesh liner or fine gravel to prevent abrasive particles
from entering the production fluid.
After the cement has hardened, a relatively small diameter production
tubing is installed inside the casing. Multiple production zones
require multiple strings of production tubing to produce several
zones simultaneously but separately.
There are various things that may be done to encourage the fluid from
the formation to enter the production tubing and travel to the sur-
face. If the producing formation is carbonate rock and has low
permeability, acid is pumped under pressure down the tubing and
into the formation to open it and allow production fluid to enter
the tubing (see Process 19). If the producing formation is sandstone
of low permeability, fracturing may be used to increase the perme-
ability and to encourage production. Fracturing is accomplished by
forcing a sand and fluid suspension into the formation and literally
cracking it open (see Process 18). Additionally, the well may be
swabbed by lowering a rubber-faced hollow cylinder into the hole and
withdrawing it, creating a vacuum and pulling oil to the surface.
The last step of completing a well is the installation of a Christmas
tree (a series of valves) for freely flowing wells or a pump to bring
the production to the surface.
21
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2. Input Materials - See Processes 18 and 19.
3. Operating Parameters - See Processes 18 and 19.
4. Uti1 i ti es - Power is required for (1) the draw works and (2) pumping
solutions and cement into the hole.
5. Haste Streams -
. Acid - Treating formations with acid results in salt-enriched
acid solutions which present a disposal problem because of
their low pH and high solids content. The amount of acid
used for well treatment procedures is summarized in Table 1.
Table 1. YEARLY VOLUMES OF ACIDS USED FOR WELL TREATMENT
Volume
Acid Gal/Yr. mVYr. '
Hydrochloric 8.7 x 107 3.3 x 10s
Formic 2.0 x 105 7.6 x 102
Acetic 1.0 x 105 3.8 x 102
An additional possibility for pollution exists in the corrosive
nature of the acid solutions toward pipe in the well. When
corrosion causes pipe failure, adjacent strata (which may be
aquifers) are contaminated.
6. EPA Source Classification Code - None exists
7. References -
(1) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling. 3rd. ed., Austin, Texas, 1970,
(2) Environmental Conservation. The Oil and Gas Industries. Vol. II,
Washington, D. C., The National Petroleum Council, 1972.
(3) The Petroleum Handbook. London, Shell International Petroleum
Company Limited, 1966.
(4) Lynch, Edward J., Formation Evaluation. New York, Harper and
Row, 1962.
(5) Rogers, Walter F., Composition and Properties of Oil Well
Drilling Fluids, Houston, Texas, Gulf Publishing Company, 1963.
(6) Collins, Gene, "Oil and Gas Wells - Potential Polluters of the
Environment?", J. of WPCF 43 (12), 2383-93 (1971).
22
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CRUDE PROCESSING
The distinction between oil wells and gas wells is rather arbitrary. There
are very few wells producing oil or gas alone; most produce both. In addition
most wells produce a certain amount of water or brine. The well is often
called an oil well when crude is the major volume of production or when
crude is the production of interest such as in locations very distantly
located from a gas plant or refinery.
This segment of the industry is concerned with the operations necessary in
preparing the crude oil for refinery use. Figure 2 is a representative
flowsheet for crude processing which includes water removal by "knock-out"
and emulsion breaking, gas removal by two or three phase separation, and
storage. These process descriptions are presented sequentially, but the
oil production industry is very diverse, and the process steps may be
altered to suit specific location and production needs. Most of the crude
processing steps take place in the field, at the well head, or at a central
gathering station. In offshore operations, the entire production (gas, oil,
water) may be shipped ashore by barge or pipeline for processing. Alter-
natively, a centralized processing platform may serve several wells in the
same area.
A major liquid waste stream in this segment is production water or oily
brine. There are also hydrocarbon and acid gas emissions from gases
entrained in the crude which may escape upon exposure to air. If sour
gases from separators are flared, an emission of SO also results.
/\
23
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["FROM OIL WELL! ^
ro
TO GAS PROCESSING
pro REFINERYj
TO WASTEWATER
TREATMENT
AND DISPOSAL
FIGURE 2. CRUDE PROCESSING
-------
CRUDE PROCESSING PROCESS NO. 7
Water Removal
1. Function - The purpose of crude separation is to remove the oily
brine from crude oil. Water is always pumped with oil, and most of
it must be removed before the oil is shipped to the refinery. The
two major separation processes used are free water knock-out and
emulsion breaking.
Free water knock-out is the settling out of the free water in a large
tank equipped with baffles to minimize the amount of turbulence and
mixing.
Emulsions are formed when water and oil systems are violently mixed
in the presence of impurities which impede the settling out of the
water. This water can be removed by one of several means (1) heat,
(2) chemical destabilization, (3) electrical coalescence, and (4)
gravitational settling.
Heat alone is not used as much today as it once was, but it is used
in conjunction with other methods. Chemical destabilization causes
the emulsion to break up by removing the effects of the impurities
that stabilize it. In electrical coalescence, an electrical field
is passed through the emulsion. When the polar molecules holding the
emulsion stable turn to follow the lines of the electric field, the
droplets combine and fall out by the force of gravity. If an emulsion
is not too strong, it may settle out if allowed to sit for some time;
this process is gravitational settling.
The required water disposal may be difficult, especially offshore.
If water cleaning facilities are available, offshore production water
is cleaned before it is pumped into the sea. Otherwise the oily
waste is pumped into tankers or pipelines for treatment onshore.
2. Input Material - Production from an oil well
3. Operating Parameters - Electric dehydrators are 2-4 meters (6-12 ft.)
in diameter and 4-24 meters (12-80 ft.) long. Capacities are 160 to
16,000 cu m per day (1000-100,000 bpd). Operating voltages are 440v
at the switchboard and 16,500v at the electrode. Residence time is
about 20 minutes.
Heater treaters are normally operated at 99°C (210°F).
4. Utilities - Utilities required include fuel for heaters, power to run
equipment to inject chemicals for chemical treatment, and power for
25
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electrical treaters. For electric treaters, electric power consumption
varies with the conductivity of the crude oil. The least conductive
crudes, ordinarily of the high API gravity, require about 0.5 kW for
each 160 cu m (1000 barrels) per day capacity, while heavy crudes may
require 1.5 kW per 160 cu m (1000 barrels) per day capacity.
Heater treaters are powered by fuel gas. They require 5 to 70 normal
cu m of gas per cubic meter of crude processed (3 to 40 x 101* SCF
per 1000 barrels) depending on the amount of water present in the
production.
5. Waste Streams -
. Brine - On the average, two to three cubic meters of water are
produced per cubic meter of oil. This amounts to up to 4.0
million cubic meters (25 million barrels) of oily salt water
produced daily in the U.S. This waste contains an average con-
centration of solids seven times that of sea water. The disposi-
tion of waste brine is shown in Table 2.
Table 2. DISPOSITION OF WASTE BRINE
Amount Disposal Site
72% Underground formations or injection
for secondary recovery.
12% Non-potable water sites, approved
disposal sites, or used in irriga-
tion or for livestock.
12% Unlined pits
4% Rivers
Hydrocarbons - Oil carried along with the brine is a source of
emissions to the air and to water supplies. Current disposal
practices allow the possibility of evaporative emissions as
well as the possibility of water and land contamination.
In isolated locations dregs from the heater treaters may be
dumped into open pits and burned. This practice causes air
emissions from combustion.
Waste water separators are in themselves sources of hydrocarbon
emissions. An estimated 33 metric tons (36 short tons) of hydro-
carbons are emitted daily from these operations.
26
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6. EPA Source Classification Code - None exists
7. References -
(1) Bansback, P. L., "The How and Why of Emulsions", Oil and Gas
Journalt 68 (36) 87-93 (1970).
(2) Waterman, L. C. and R. L. Pettefer, "Oil Field Emulsions and
Their Electrical Resolution", Surface Operations in Petroleum
Production, George V. Chilingar and Carrol M. Beeson, eds.,
New York, American Elsevier Publishing Company, Inc., 1969,
pp. 29-45.
(3) Radian Corp., Study on Control of Hydrocarbon Emissions from
Petroleum Liquids. EPA Contract No. 68-02-1319, Task 12, Austin,
Tx., 1975.
(4) Environmental Conservation. The Oil and Gas Industries, Vol. II,
Washington, D. C., The National Petroleum Council, 1972.
(5) MSA Research Corp., Hydrocarbon Pollutant Systems Study. Vol. I,
APTD-1499, PB 218073, Evans City, Pa., 1972.
(6) Processes Research, Inc., Screening Report. Crude Oil and
Natural Gas Production Processes. EPA Contract No. 68-02-0242,
Cincinnati, Ohio, 1972.
(7) Booz-Allen Applied Research, Inc., A Study of Hazardous Waste
Materials. Hazardous Effects and Disposal Methods. Vol. Ill,
PB-221467, Bethesda, Md., 1973.
(8) Cavanaugh, E. C., et al., Atmospheric Environmental Problem
Definition of Facilities for Extraction, On-Site Processing.
and Transportation of Fuel Resources. EPA Contract No. 68-02-1319,
Task 19, Austin, Tx., 1975.
(9) Reid, George W. and Leale E. Streebin, Evaluation of Waste
Waters from Petroleum and Coal Processing, EPA-R2-72-001,
Washington, D. C., 1972.
27
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CRUDE PROCESSING PROCESS N(h 8
Gas-Oil Separation
1. Function - The purpose of this process is to separate entrained
gases from crude oil.
There are two types of separators: two-phase for separating gas
and oil and three-phase for separating gas, oil, and water. Non-
solution gases can be separated by settling, agitation, baffling,
heat, or chemicals. Most separators of vertical, spherical, or
horizontal configuration employ a series of baffles to separate the
gases from the crude. The horizontal separator is usually used when
the gas oil ratio is large, the vertical separator is used when the
gas oil ratio is low, and the spherical separator is used when the
gas oil ratio is in an intermediate range.
A stage separation procedure may be used in which a series of separators
are operated to perform two or more flash vaporizations at sequentially
reduced pressures. This is particularly useful when well-head pressure
is high.
The gas produced is sent to a gas processing plant and the separated
crude is ready for storage.
2- Input Materials - Oil containing light hydrocarbon gases
3- Operating Parameters - The operating temperatures and pressures will
generally begin with the well-head temperature and pressure and drop
step-wise to ambient conditions. Separator retention times of 1 to
3 minutes are generally adequate, but 5 to 20 minutes may be required
for difficult separations.
4. Uti 1 i ti es - The well-head pressure does most of the work.
5. Waste Streams -
. Hydrocarbons - At remote locations where there is no need for
recovered gases to maintain formation pressure or when there is
no economical way to transport them to a processing plant, the
hydrocarbon gases may be vented or flared. An estimated 1.34
billion cu m/yr (50 billion cu ft/yr) of natural gas is lost to
the atmosphere from venting, flaring, and fugitive losses.
mhi" *! Sour ugas from the sePa™tor must be disposed
must be flared to change the highly toxic H2S to SOV which
A
28
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IwJ! !he ?tmosPhere W1'th combustion wastes. Assuming an
average concentration of 0.5 mole percent sulfur in domestic
naturaVgas, 7.08 million cu m/yr (250 million cu ?t/yr) of gas-
s an °11y bHne waste
6- EPA Source Classification Code - None exists
7. References -
(1) Chilingar, George V. and Carrol M. Beeson, "Separation of
Gas and Oil Surface Operations in Petroleum Production.
George V. Chilingar and Carrol M. Beeson, eds., New York
American Elsevier Publishing Company, Inc., 1969, pp. 15-28.
l^riCv' yho»a^ C" ed" Petroleum Production Handbook. Vol I,
New York, McGraw-Hill, 1962. -- ' -
(3) Processes Research, Inc., Screening Report Crude Oil and
29
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CRUDE PROCESSING PROCESS NO. 9
Crude Storage
1. Function - Crude is stored in tanks to await shipment to the refinery.
The tanks are fixed or floating-roof types with capacities up to
40,000 cubic meters (250,000 barrels). Newer technology provides for
vapor recovery systems to capture the lighter hydrocarbons evaporating
from the crude in the tanks.
Storage tanks also serve the purpose of a settling tank, as they allow
additional production water to separate.
2. Input Materials - Crude oil
3. Operating Parameters - Atmospheric conditions
4- Utilities - Those required in pumping the crude
5. Waste Streams -
. Brine - 12 liters per cubic meter stored crude
. Hydrocarbons - Emissions from storage tanks are of two types:
working losses from loading operations and breathing losses
resulting from expansion and contraction of the vapor space
due to temperature cycles. Emission factors are given below.
Table 3. HYDROCARBON EMISSION FACTORS FOR CRUDE STORAGE
Type of Tank Emission Factor
Fixed Roof
Breathing Loss 40 g/day-103fc capacity
(0.3 lb/day-103 gal capacity)
Working loss 1000 g/day-103& throughput
(8.0 lb/day-103 gal throughput)
Floating Roof
Breathing loss 14,000-73,000 g/day-tank
(30-160 Ib/day-tank)
Working loss Negligible
30
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6. EPA Source Classification Code - None exists
7. References -
(1) Nack, H., et al., Development of an Approach to Identification
of Emerging Technology and Demonstration Opportunities, EPA
650/2-74-048, Columbus, Ohio, Battelle-Columbus Labs., 1974.
(2) Radian Corporation, A Program to Investigate Various Factors
in Refinery Siting, Final Report, Contract No. EQC 31y, Austin,
Tx., 1974.
(3) Environmental Protection Agency, Compilation of Air Pollutant
Emission Factors. 2nd ed., AP-42, Research Triangle Park, N C
31
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NATURAL GAS PROCESSING
Natural gas is composed of methane with decreasing amounts of ethane, propane,
butane, and heavier hydrocarbons. It is normally saturated with water vapor
and may contain nitrogen, helium, carbon dioxide, hydrogen sulfide, and mer-
captans. The purpose of natural gas processing is to produce a natural gas
for pipeline sales and to recover heavier hydrocarbons for refinery, petro-
chemical, or fuel use. Common sales specifications for natural gas include a
gross heating value of not less than 8,900 kcal per cu m (1,000 Btu per cu
ft.), a maximum of 0.6 g H2S per 100 normal cu m (0.25 grains of H2S per
100 SCF), with a maximum of 1.3 grams (20 grains) total sulfur, and a water
content low enough so that line freeze-ups will not occur.
The processes used to meet these sales requirements are presented in this
segment. Although the process steps are presented sequentially in Figure
3, they are by no means intended to be in a prescribed order. Variations
in sequences, operating conditions, and physical locations occur throughout
the industry with local production conditions and geographical locations
dictating the particular processing methods.
Hydrocarbon liquids are separated from raw gas from wells and oil-gas
separators. The gas is then sweetened in an acid gas removal process,
dehydrated, and separated into its hydrocarbon components in the product
separation process. Recovered hydrocarbon liquids are also processed
in the product separation module. The acid gas stream when processed
by the sulfur recovery unit provides by-product sulfur. These processing
steps may be accomplished in the field, at a gas processing plant, or in
a refinery depending on the location of the production with respect to
processing facilities.
Hydrocarbon losses encountered in natural gas processing are mainly in the
form of fugitive emissions. At any point that the system is open to the
atmosphere, hydrocarbon emissions occur. These losses were estimated at
3 kg per 103 normal cu m (190 Ibs per 10r' SCF) of natural gas processed or
about 6,280 metric tons (6,920 short tons) per day in 1973. Emissions of
H2S, S02, elemental sulfur, and glycols are also encountered.
32
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SALES
S]
SALES
SALES |
OR REFINERYJ
Y]
FIGURE 3. NATURAL GAS PROCESSING
-------
NATURAL GAS PROCESSING PROCESS NO. 10
Liquid Hydrocarbon Recovery
Function - The purpose of liquid hydrocarbon recovery is the separation
of condensable hydrocarbons from the natural gas stream. This first
liquid separation step often takes place in the field to facilitate
pipeline transport to a processing center. The process usually involves
a water knockout step to remove any liquid water formed in transporting
the gas from the well, and there may be a further dehydration dictated
by the requirements of the particular recovery process. The recovery
is generally accomplished by changing conditions of the gas so that the
equilibrium between the various components is upset causing the heavier
hydrocarbons to condense. The equilibrium change may be caused by change
in temperature, change in pressure, introducing a new material, or a
combination of these. Fairly wet or very dry gas may be produced,
depending on the efficiency of the recovery process. This process
description deals with the case of the fairly wet gas which must be
further separated in the product separation process before it is sold
to pipeline companies. There are three major types of liquid recovery-
processes used singly or in combination to effect the necessary
separation.
Adsorption is accomplished in towers filled with activated alumina or
charcoal which adsorbs the heavier hydrocarbons. After the adsorbing
material has been saturated, heated gas or steam is passed through
the bed to desorb the hydrocarbons which are condensed and ultimately
fractionated.
In the absorption process the gas is passed through an absorber unit
where absorber oil removes propane and heavier components. The methane
and ethane are allowed to pass up through the absorber tower in the
gaseous phase, while the enriched absorber oil is sent to a stripper.
Refrigeration processes involve decreasing the temperature of the gas
to promote condensation of the heavier hydrocarbons. Of the combina-
tions of processes the most often used is a combination refrigeration/
absorption process.
One of the newer technologies involves the use of a turboexpander in
which the natural gas is expanded through a turbine compressor from
which it exhausts at extremely low temperatures; most of the gas
except methane is condensed.
The wet sour gas produced is sent to the acid gas removal process
and the recovered liquids are sent to the product separation step.
34
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2. Input Streams - Production gas and gas from oil separators.
3. Operating Parameters - Liquid recovery processes vary significantly
in their operating requirements. Temperatures as low as minus 40°C
(-40°F) and pressures as high as 3 x 10s kg/square meter (400 psi)
are encountered.
In the oil absorption process stripping is generally done at low
pressure. The stripped crude is then pumped up to high pressure to
act as an absorbent, and the enriched crude is then reduced to atmo-
spheric pressure. The absorption factor increases as the temperature
decreases; low pressures are conducive to good stripping, but high
pressure aids condensation of the light ends. The molecular weight
of the lean oil used in the absorber depends on the average tower
temperature. Near minus 18°C (0°F), oil with a molecular weight of
120-140 is commonly used; near 38°C (100°F), molecular weights of
180-200 are used.
Turboexpanders operate with feed gas pressures from 8 x 101* to 2 x 106
kg/square meter (100 to 3000 psig) with capacities of 8 x 105 to
42 x 106 cu m per day (30 to 1500 MMscfd). Outlet temperatures may
be as low as minus 250°C (-420°F).
4. Utilities - In general about 3.2% of the gas produced is used in
compression procedures.
Turboexpanders require 0.1 to 2.0% of the feed gas depending upon
compression requirements.
Refrigerated absorption units consume about 0.75% of the produced
gas energy.
5. Waste Streams - Fugitive emissions only
. Hydrocarbons - Emissions result from leaks in pumps, valves,
compressors, and other equipment.
. Hydrogen Sulfide - If the gas is a sour gas, the above mentioned
sources will provide hydrogen sulfide emissions.
6. EPA Source Classification Code - None exists
7. References -
(1) Campbell, John M., "Absorption and Fractionation Fundamentals",
Gas Conditioning and Processing. John M. Campbell, Norman,
Oklahoma, 1970.
(2) Cotterlaz-Rennaz, "New French Gas Cooler Recovers 120 BPD
Gasoline", World Oil 177 (2), 57-59 (1973).
35
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(3) Eckerson, B. A., A, L. Johnson, "Natural Gas and Natural Gas
Liquids". Surface Operations in Petroleum Production. George
V. Chilingar and Carrol M. Beeson, eds., New York, American
Elsevier Publishing Company, Inc., 1969.
(4) "NG/LNG/SNG Handbook", Hydrocarbon Processing, April 1973.
(5) Processes Research, Inc., Screening Report, Crude Oil and
Natural Gas Production Processes, PB-222718, Cincinnati, Ohio,
I J I £ •
(6) Petroleum Extension Service, Field Handling of Natural Gas,
3rd. ed., Austin, Texas, The University of Texas at Austin, 1972
(7) Houghton, J. and J. D. McLay, "Turboexpanders Aid Condensate
Recovery", Oil and Gas Journal. 76-79 (March 5, 1973).
36
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NATURAL GAS PROCESSING PROCESS NO 11
Acid Gas Removal
V- Function - The acid gas removal unit is designed to remove hydrogen
sulfide from hydrocarbon gases by absorption in some aqueous
regenerative sorbent. A number of gas treatment processes are
available, and they are distinguished primarily by the regenerative
sorbent employed. Amine-based sorbents, however, are most commonly
used. J
The feed to the unit is contacted with the sorbent, such as diethanol-
amine, in an absorption column to selectively absorb H2S from the
hydrocarbon gases. Hydrogen sulfide is then removed from the sorbent
in a regeneration step. The products are a sweet hydrocarbon gas and
a concentrated hydrogen sulfide stream. The sweet gas may either be
further processed in light end recovery processes or may be charged
as a raw material to petrochemical processes. The hydrogen sulfide
stream is normally routed to a sulfur plant for recovery of its sulfur
content If there is no sulfur recovery plant available, the sulfide
gas must be flared to produce the less toxic sulfur oxides.
2> Input Materials - The sour wet gas from the liquids recovery process.
The sorbent used to remove hydrogen sulfide is also a feed to this
unit. It is usually regenerable, and make-up rates are generally
quite low. Also required,
1.2 kg of 5 x 10* ^_ steam per kg of aci(J gas removed-
3- Operating Parameters - The following conditions are typical of
absorber operations:
Pressure : 10.5 kg/sq cm
Temperature: 38°C
4. Utilities -
Electricity: .022 kWh/kg removed gas
Cooling Water: 45-82 liters/kg removed gas
5. . Waste Streams -
. Sulfur Compounds - No atmospheric emissions, other than fugitive
losses, are produced from this unit if it is used in conjunct on
with a sulfur recovery unit. If the acid gas is flared"0there are
37
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atmospheric emissions of sulfur oxides. Current information neces-
sary for estimating the amount of sulfur oxides and other sulfur
compounds emitted to the atmosphere from acid gas removal processes
proved unavailable.
. Amine Solutions - Liquid effluents are produced as spent amine
solutions which must be replaced; about 4 liters per 159 m3 (1 gal/
1000 bbl) for diethanolamine. The impact on the water treating
system may be severe, however, since 40,000 to 80,000 liters may
be drained at once. The amount of waste is proportional to the
amount of hydrogen sulfide removed from the gas.
6. EPA Source Classification Code - None exists
7. References -
(1) Nack, H., et al., Development of an Approach to Identification
of Emerging Technology and Demonstration Opportunities. EPA
650/2-74-048, Columbus, Ohio, Battelle-Columbus Labs., 1974.
(2) Radian Corporation, A Program to Investigate Various Factors
in Refinery Siting. Final Report, Contract No. EQC 319, Austin,
Tx., 1974.
(3) "Hydrocarbon Processing Refining Processes Handbook", Hydro-
carbon Proc. 53 (9), (1974). .
(4) Processes Research, Inc., Screening Report, Crude Oil and
Natural Gas Production Processes. PB-222718. Cincinnati.
Ohio, 1972.
(5) Ecology Audits, Inc., Sulfur Compound Emissions of the Petro-
leum Production Industry. EPA Publication No. fabtyy-JH-nxn, rialias
Texas, 1974.
38
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NATURAL GAS PROCESSING PROCESS NO. 12
Sulfur Recovery
1. Function - A sulfur recovery plant converts hydrogen sulfide to
elemental sulfur by controlled combustion and reactions occurring
in a series of catalytic beds. The feed is first combusted with
substoichiometric amounts of air to form sulfur and water. The
off gas is cooled, and sulfur is condensed as a liquid. About 60
to 70 percent conversion occurs in the furnace.
The remaining gases are reheated and passed through catalytic
reactors. Each reactor has an effluent condenser where the elemental
sulfur is recovered. Reheat of reactor effluent is necessary for
sulfur recovery in subsequent reactors. The number of reactors varies
with the conversion desired and with the acid gas concentration.
Normally, two to four reactors are used as only fifty to sixty percent
of the remaining sulfur is converted in each reactor stage.
The unconverted acid gas leaves the process in a tail gas stream and
is either further processed or incinerated to remove the last traces
of reduced sulfur compounds. The sulfur recovered by this process
is sold as a by-product.
2. Input Streams - Acid gases from the acid gas removal plant are the
feed to the sulfur plant.
3. Operating Parameters - The following conditions are typical of those
found in the reactors:
Temperature: 245°C
Pressure: 1-2 Atm
A bauxite catalyst is most commonly employed for this process.
4. Utilities:
Heater: 2220 kcal/kg sulfur
Steam: 4 kg/kg sulfur - generated in a waste heat boiler
5. Waste Streams - The tail gas from this unit represents the major
sulfur emissions in a gas processing plant. Possible sulfur emissions
are S02, H2S, COS, CS2, and mercaptans. After reaction, most of the
sulfur emissions are in the form of S02; sulfur dioxide concentration
in the effluent tail gas is approximately 15,000 ppm. Tail gas clean-
up processes are commercially available to reduce sulfur emissions.
Disposal of the spent bauxite catalyst creates a solid waste problem.
The magnitude of this problem depends upon the design conversion and
operating capacity of the sulfur plant.
39
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6. EPA Source Classification Code - None exists
7. References -
(1) Radian Corporation, A Program to Investigate Various Factors
in Refinery Siting, Final Report, Contract No. EQC 31^, Austin,
Tx., 1974.
(2) Nack, H., et al., Development of an Approach to Identification
of Emerging Technology and Demonstration Opportunities. EPA
650/2-74-048, Columbus, Ohio, Battelle-Columbus Labs., 1974.
40
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NATURAL GAS PROCESSING PROCESS NO. 13
Dehydration
1. Function - Dehydration removes water from the gas after the acid
gas removal process. The required water content is specified as
the dew point, the temperature at which the water begins to condense.
The excess water is removed by refrigeration, absorption, or adsorp-
tion. Refrigeration processes decrease the temperature below the
required dew point; the condensed moisture is collected for disposal.
Absorption processes allow the moist gas to flow over hygroscopic
materials, usually di- or tri-ethylene glycol. The use of a solid
dessicant to remove the water is called adsorption. Sometimes higher
molecular weight hydrocarbons are removed in adsorption as well.
2. Input Materials - Moist wet gas from the acid gas removal process.
Two to five kilograms of glycol are circulated per kilogram of
water to be removed in absorption processes.
3. Operating Parameters - For condensation processes, temperature and
pressure are interdependent. For example, if the required dew
point is 10°C (50°F) at 105,500 kg/sq m (135 psig), and the best
available cooling is 27°C (80°F), pressures of 33,400 kg/sq m (460
psig) will give the desired water content.
For absorption processes using di- or triethylene glycol absorption
temperatures must be kept below the temperature at which the glycol
decomposes (164°C for DEG, 207°C for TEG). Dew point depressions
of 22-28°C (40-50°F) can be obtained using DEG at atmospheric pres-
sure and reboiltfr temperatures of 143-160°C (290-320°F); depressions
of 33-42°C (60-75°F) can be obtained with TEG at reboiler temperatures
of 177-191°C (350-375°F). Temperatures in the regenerator, which
separates the absorbed water from the glycol, usually range from
190-204°C (375-400°F). The pH is controlled at 6.0 to 7.5, as low
pH accelerates decomposition of the glycol.
Regeneration temperatures for solid dessicants are 249 to 260°C
(480-500°F).
4. Utilities - A glycol absorption process requires about 0.1% of the
fuel produced.
5. Waste Streams -
. Glycol - An estimated 0.01 m3 of triethylene glycol per 106
normal m3 of gas processed (0.1 gal per 106 cu ft.) is emitted
by the glycol absorption process in vented water vapor.
41
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. Water - Water contaminated with glycol may be vented as steam
or it may be disposed of as a liquid.
6. EPA Source Classification Code - None exists
7. References -
(1) Campbell, John M., "Absorption and Fractionation Fundamentals",
Gas Conditioning and Processing, John M. Campbell, Norman,
Oklahoma (1970)7
(2) Cotterlaz-Rennaz, "New French Gas Cooler Recovers 120 BPD
Gasoline", World Oil 177 (2), 57-59 (1973).
(3) Eckerson, B. A., A. L. Johnson, "Natural Gas and Natural Gas
Liquids", Surface Operations in Petroleum Production. George
V. Chilingar and Carrol M. Beeson, eds., New York, American
Elsevier Publishing Co., Inc., 1969.
(4) "Gas Dehydration", from "Dehydration and Treating", Engineering
Data Book, Natural Gas Producers Suppliers Association (1972).
(5) Hammerschmidt, E. G., K. R. Knapp, and C. L. Perskin "Gas
Hydrates and Gas Dehydration", Gas Engineers Handbook. New
York, Industrial Press, 1969.
(6) Patterson, E. 0. Jr., "Get Low Dewpoints with Solid Dessicants",
Oil and Gas Journal 67 (9), (108-109) 1969.
(7) "NG/LNG/SNG Handbook", Hydrocarbon Processing, April 1973.
(8) Processes Research, Inc., Screening Report. Crude Oil and
Natural Gas Production Processes. PB-222718, Cincinnati,
Ohio, 1972.
42
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NATURAL GAS PROCESSING PROCESS NO. 14
Product Separation
1. Function - The purpose of this process step is the separation of the
hydrocarbon components of the dehydrated gas and the hydrocarbon
liquids from the liquid recovery process.
Methane is piped to sales; ethane, propane, and butane are stored
under pressure until they are shipped to the refinery as LPG; the
remainder of the hydrocarbons, known as natural gasoline, are stored
at atmospheric pressure to await shipment to the refinery for
processing.
There are several different methods used in accomplishing this
separation. Commonly used processes involve absorption, refrigerated
absorption, refrigeration, compression, and adsorption.
In an absorption process the wet field gas is contacted with an
absorber oil in a packed or bubble tray column. Propane and heavier
hydrocarbons are absorbed by the oil while most of the ethane and
methane pass through the absorber. The enriched absorber oil is
then taken to a stripper where the absorbed propane and heavier
compounds are stripped from the oil.
The natural gas feed to a refrigerated absorption process must be
dehydrated to a minus 40°C dew point prior to entering the unit. All
hydrocarbons except methane are absorbed by absorber oil operating
at this temperature. These absorbed hydrocarbons and the oil are passed
through a series of fractionation columns from which ethane, propane,
and heavier hydrocarbons are removed as product streams.
In refrigeration, a cryogenic process, the natural gas must be dried
to a dew point of minus 101°C or lower using molecular sieve beds.
The dry gas is then passed through a heat exchanger where it is cooled
to minus 37°C. Condensed hydrocarbons are removed in a gas-liquid
separator. The gas from the separator is cooled to minus 93°C and
passed through a second separator where more condensed liquids drop
out. The liquids from two separators are fed to a series of distil-
lation columns where methane, ethane, propane, butanes, natural
gasoline, and other products are recovered.
A compression process uses two stages of compression, each followed
by cooling and gas-liquid separation, to produce a wet natural gas
product and natural gasoline. This is not a widely used process.
43
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The adsorption processes consist of two or more beds of activated
carbon. The beds are used alternatively, with one or more beds on
stream while the others are being regenerated. The activated carbon
adsorbs all hydrocarbons except methane. The bed is regenerated by
means of heat and steam, which remove the adsorbed hydrocarbons as a
vapor. This vapor is then condensed permitting the water to be
separated from the liquid hydrocarbons. The resulting hydrocarbon
product is fed to a fractionation process where the various components
are separated.
2. Input Material - Liquid hydrocarbons from the liquids recovery process
and wet gas from the dehydrator.
3. Operating Parameters - Inlet gas and oil temperatures for absorbers
and refrigerated absorbers:
Water cooled: 32-38°C
Propane cooled: minus 40° - minus 18°C
Pressures in the absorbers may be as high as
2.8 x 10 kg/sq m (400 psi), but are usually lower.
The temperatures, pressures, and molecular weights of absorber
oils are generally controlled to give maximum recovery.
The refrigeration process temperature is minus 37°C to minus 93°C.
4. Utilities - 2-3% of the methane produced.
5. " Waste Streams - Fugitive emissions only from leaking pumps and
valves.
6. EPA Source Classification Code - None exists
7. References -
(1) Houghton, J. and J. D. McLay, "Turboexpanders Aid Condensate
Recovery", Oil and Gas Journal 71 (10), 76-79 (1973).
(2) Eckerson, B. A. and A. L. Johnson, "Natural Gas and Natural
Gas Liquids", Surface Operations in Petroleum Production,
George V. Chilingar and Carroll M. Beeson, eds., New York,
American Elsevier Publishing Company, Inc., 1969.
(3) "NG/LNG/SNG Handbook", Hydrocarbon Processing, April, 1973.
(4) Petroleum Extension Service, Plant Processing of Natural Gas,
Austin, Texas, The University of Texas at Austin, 1974.
44
-------
(5) Cavanaugh, E. C. et al., Atmospheric Environmental Problem
Definition of Facilities for Extraction, On-Site Processing,
and Transportation of Fuel Resources, EPA Contract No.
68-02-1319, Task 19, Austin, Texas, 1975.
45
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NATURAL GAS PROCESSING PROCESS NO. 15
LPG Storage
1. Function - The purpose of LPG storage is to store the liquified
petroleum gas (LPG) before it is shipped to the refinery or to
sales. Because the vapor pressure of LPG is high enough that it
could vaporize at atmospheric pressures, it must be held in pressure
vessels. The ethane, propane, and butane from the separation process
may be stored together or separately. LPG is generally propane, but
it may contain some ethane and butane.
An alternative to storing LPG under pressure is handling it at
reduced temperatures. Refrigerated LPG may be stored in insulated
pits or in underground formations.
2. Input Materials - The ethane, propanes, and butanes from the gas
separation process
3. Operating Parameters -
Pressure vessels:
Temperature: ambient
Pressure: 1.0 x 10s kg/sq m (250 psigv)
4. Utilities - Those required to pump the LPG.
5. Haste Streams - Loading and unloading losses encountered
6. EPA Source Classification Code - None exists
7. References -
(1) Eckerson, B. A. and A. L. Johnson, "Natural Gas and Natural
Gas Liquids", Surface Operations in Petroleum Production,
George V. Chilingar and Carrol M. Beeson, eds., New York,
American Elsevier Publishing Company, Inc., 1969.
(2) Nack H., et al., Development of an Approach to Identification
9f-E?e-^-9_Te_nPo1ogy and Demonstration Opportunities, EPA
650/2-74-048, Columbus, Ohio, Battelle-Columbus Labs., 1974.
(3) Environmental Protection Agency, Compilation of Air Pollutant
Emission Factors, 2nd. ed., AP-42, Research Triangle Park, N. C.,
T973~:
46
-------
(4) Radian Corporation, Study on Control of Hydrocarbon Emissions
from Petroleum Liquids, EPA Contract No. 38-02-1319, Task 12,
Austin, Texas, 19/5.
47
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NATURAL GAS PROCESSING PROCESS NO, 16
Gasoline Storage
1. Function - The purpose of gasoline storage is to store the natural
gasoline from the product separation process before it is shipped to
sales or to the refinery. The capacity of the storage tanks used
varies with the size of lease concerned. The tanks may be fixed
roof, floating roof, or variable vapor space types.
2. Input Materials - Natural gasoline from gas separation
3. Operating Parameters - Temperature and pressure are usually ambient.
4. Utilities - Those required to pump the gasoline.
5. Waste Streams - Gasoline storage emission factors are given in
Table 4.
Table 4. HYDROCARBON EMISSION FACTORS FOR GASOLINE STORAGE
Type of Tank Emission Factor
Floating Roof
Standing losses 10.5 g/day-103&
(0.088 lbs/day-103 gal)
Fixed Roof
Breathing losses 30 g/day-103
(0.25 lbs/day-103 gal)
Filling losses 1.1 g/2,
(9.0 lb/103 gal)
Variable Vapor Space
Filling losses 1.2 g/£
.(10.2 lb/103 gal)
Vapor recovery systems are available for compressing and recycling
gaseous emissions from tanks.
6. EPA Source Classification Code - None exists
48
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7. References -
(1) Eckerson, B. A. and A. L. Johnson, "Natural Gas and Natural
Gas Liquids", Surface Operations in Petroleum Production,
George V. Chi linger and Carrol M. Beeson, eds., New York,
American Elsevier Publishing Co., Inc., 1969.
(2) Nack, H. et al., Development of an Approach to Identification
of Emerging Techno"!pgy and Demonstration Opportunities, EPA
650-2-74-048, Columbus, Ohio, Battelle-Columbus Labs., 1974.
(3) Environmental Protection Agency, Compilation of Air Pollutant
Emission Factors, 2nd. ed., AP-42, Research Triangle Park,
N. C., 1973,
49
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SECONDARY AND TERTIARY RECOVERY TECHNIQUES
When a producing well decreases its production it is either plugged and its
production stopped, or stimulated so that production will be increased. The
problems causing loss of production fall into three major areas. One major
problem, loss of formation pressure, is solved by displacement processes.
A second problem, low permeability of the formation, occurs when the forma-
tion is packed so tightly that the oil cannot flow through it. This is
corrected by an acid treatment or by fracturing to increase the permeability.
The third major problem occurs when the oil is too thick, or viscous, to
flow easily. The viscosity of oil depends strongly on temperature, however,
and when the oil is heated, the viscosity drops so that the oil can flow
easily. These four methods of treatment, displacement, fracturing, acid
treatment, and thermal treatment, are discussed in this section.
50
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SECONDARY AND TERTIARY RECOVERY TECHNIQUES PROCESS NO. 17
Displacement
1. Function - After reservoir pressures have dropped, the displacement
method is used to.increase production by injecting water or gas into
the formation under pressure. In 1968, an estimated 33% of the oil
production in the United States was by water flooding, and it has
been further projected that by 1980 this figure will rise to 50%.
In water flooding, water is injected into the formation under pressure
via an injection well. Production water may be used, but it must
first be treated to prevent corrosion and chemical deposits from
occurring in pipes or machinery.
In gas injection, gas is injected under high pressure via the injection
wells to displace the crude out into the production well. The gas
supply is often production gas.
2. Input Materials - Not applicable
3. Operating Parameters -
. Pressure - often about 1.8 x 10" kg/m2 (25 psi) + formation
pressure, but variable.
Phillips Petroleum Co., at their North Sea Ekofisk field complex,
injects up to 1.4 x 107 m3 (5 x 108 cu ft.) per day of gas at
6.5 x 106 kg/m2 (9200 psi), but this is an unusually high pressure.
Shell Co., at their Ventura field waterflood program, uses a four
plant system with a 3.5 x 10" cu m/day (220,000 b/d) capacity at
injection pressures of 1.4 - 3.5 x 106 kg/m2 (2000-5000 psi).
4. Utilities - At Ekofisk, Phillips Petroleum uses for compression
equipment six units, totalling 82,000 kW (110,000 hp), driven by
gas turbines. At the separation plant are two multi-stage com-
pressors, each connected to 7600 kW (10,200 hp) General Electric
frame 3, two shaft gas turbines. At the injection platform are
four compressors, each driven by a geared GE frame 5 gas turbine
rated at 16,000 kW (22,000 hp) each. Main and spare seal oil pumps
each require a 186 kW (250 hp) motor.
At the Shell Co. Ventura field Waterflood Plant 4 (WP-4), two 3400 kW
(4500 hp) electric motor driven double cased diffuser centrifugal
pumps are used to give a designed capacity of 9500 cu m/day (60,000
b/d) at 3.5 x 106 kg/sq m (5000 psi). At WP-2, eight 447 kW (600 hp)
vertical quintuplex plunger pumps give a designed capacity of 9500
cu m/day (60,000 b/d) at 2.8 x 106 kg/sq m (4000 psi).
51
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5. Waste Streams - None
6. EPA Source Classification Code - None exists
7. References -
(1) "Pioneering Ekofisk System to Inject Gas at 9200 psi",
Petroleum Engineer International, Vol. 46, No. 2, February,
1974, pp. 32-34, 36.:
(2) Blanton, M. L. "Shell Extends Ventura Flood to 5000 psi",
Petroleum Engineer International, Vol. 46, No. 9, August,
1974, pp. 24-26. y
(3) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling, Austin, Texas (1975).
52
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SECONDARY AND TERTIARY RECOVERY TECHNIQUES PROCESS NO. 18
Fracturing
1. Function - The fracturing technique is used to increase production of
oil from sandstone by increasing the permeability of the formation.
This is done by forcing a sand and fluid suspension into the formation
under high pressure, literally cracking it open. After the formation
has been opened, the fluid is pumped out, leaving the sand to hold
the cracks open. This process increases the permeability of the for-
mation, enabling oil and gas to flow into the well.
2. Input Material - Usually a sand and fluid suspension. In three wells
in West Texas, for example, the following input materials were used.
Well A, Crocket County, Texas: 9.5 cu m (2500 gal) LPG-C02 as pad
volume, then 130 cu m (34,000 gal) 1:1:1 Gas Frac fluid containing
11,000 kg (24,000 Ib) of 20-40 mesh sand, then flushed with 9.5 cu m
(2500 gal) 1:1:1 Gas Frac fluid with no sand.
Well B, Sutton County, Texas: 7.6 cu m (2000 gal) LPG-C02 pad volume,
85 cu m (22,500 gal) 1:1:1 Gas Frac fluid containing 900 kg (2000
Ibs) 40-60 mesh sand and 10,000 kg (22,800 Ibs) 20-40 mesh sand, then
flushed with LPG-C02 mixture.
Well C, McCullough County, Texas: 17 cu m (4500 gal) LPG-C02 mixture
pad volume, 53 cu m (14,000 gal) 1:1:1 Gas Frac fluid containing
7000 kg (15,000 Ibs) 20-40 mesh sand, flushed with 17 cu m (4500 gal)
LPG-C02 mixture.
3. Operating Parameters -
. Pressure - variable
For example, in three West Texas wells mentioned above the fol-
lowing pressures were used:
Well A - Average injection rate 3 cu m/min (19 bbl/min) at
3.5 x 10s kg/sq m
Well B - Average injection rate 2 cu m/min (12.5 bbl/min) at
2.1 x 106 kg/sq m
Well C - Average injection rate 1.9 cu m/min (12 bbl/min) at
8.4 x 105 kg/sq m
4. Utilities - Power for compressors
53
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5. Waste Streams - The danger of groundwater contamination exists if the
casing fractures, or if the formation forms a communication with a
water bearing formation.
6. EPA Source Classification Code - None exists
7. References -
(1) Hurst, Robert E., "Designing Successful Gas Frac Treatments",
Petroleum Engineer International, Vol. 45, No. 7, July, 1972,
pp. 67 ff.
(2) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling, Austin, Texas (1975).
54
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SECONDARY AND TERTIARY RECOVERY TECHNIQUES PROCESS NO. 19
Acid Treatment
1. Function - Acid treatment is used to increase production by increasing
.the porosity of carbonate rock formations. In the process, quantities
of acid ranging from fifty to thousands of gallons are pumped into
the well under pressure. The acid then travels out into the forma-
tion, dissolving the rock to allow the oil to travel into the well
more easily.
2. Input Materials - HC1 and sometimes other acids. An example of a
mixture might be 12% HC1 with 3% HF. Proposed acid volume: if 28%
HC1 is used, 1.5 times the volume contained within the fracture be-
tween the well bore and maximum acid penetration distance; if 15%
HC1 is used, three times the fracture volume. Increasing acid
concentration from 15-28% HCT increases penetration distance. At
93°C (200°F), dolomite formation distance can be increased from 38
to 54 m (127 to 178 ft.) by using 28% HC1 instead of 15%.
3. Operating Parameters - Pressure is approximately 1.8 x 10* kg/sq m
(25 psi) + formation pressure. The temperature at which the acid
reaction occurs affects the depth of acid penetration. For example,
an increase in temperature 38 to 140°C (100 to 220°F) could decrease
penetration for 15% HC1 from 37 to 25 m (120 to 82 ft.) in limestone.
and from 87 to 37 m (285 to 120 ft.) in dolomite. Similarly, a pad
that would reduce the reaction temperature of 28% HC1 in a dolomite
treatment from 140 to 66°C (220 to 150°F) would increase the penetra-
tion distance from 54 to 67 m (177 to 220 ft.).
Increased injection rate increases acid penetration, but at rates
greater than approximately 0.5 cu m/min/m (1.0 bbl/min/ft.), penetra-
tion distance approaches a maximum.
4. Utilities - Power for compressors
5. Waste Streams - The corrosive nature of the fluid used causes an
increased possibility that casings may fracture and allow ground-
waters to become contaminated.
6. EPA Source Classification Code - None exists
7. References
(1) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling, Austin, Texas (1975).
55
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(2) Williams, B. B., and D. E. Nierode, "Design of Acid Fracturing
Treatments", Journal of Petroleum Technology, Vol. 24, July,
1972, pp. 849-859.
56
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SECONDARY AND TERTIARY RECOVERY TECHNIQUES PROCESS NO. 20
Thermal Treatment
1. Function - Thermal treatment increases production by heating the oil
through processes such as steam injection, hot water injection, and
in situ combustion.. The heat reduces the viscosity of the oil so
that it can flow more easily.
Hot water and steam injection heat the oil by direct contact
and also displace the oil, causing higher flow rates.
In situ combustion is accomplished by pumping air down the hole and
then setting fire to the oil. This process burns 5-10% of the oil,
causing temperatures as high as 1,500°C and increasing production
from 10% to more than four times primary production levels.
2. Input Materials -
For hot water injection - heated water
For steam injection - steam from on site boiler, about 0.8-0.95 quality
For in situ combustion - air
3- Operating Parameters - For steam or hot water injection, the temperature
used depends on the properties of the oil in the formation. The pres-
sure used also varies, but will generally be 1.8 - 2.1 kg/m2 (25-30
psi) greater than the formation pressure for all the thermal processes.
For example, CIA Shell de Venezuela uses average well-head steam injection
pressures of 6.7 - 70 x 10s kg/m2 (950-1000 psi) from their high-pressure
plant and 5 - 6 x 10s kg/m2 (700-800 psi) from their low pressure plant
at a temperature of 260°C (500°F), while Amoco Production in Winkleman
Dome, Fremont County, Wyoming, uses a normal injection pressure of 8 1 x
10s kg/sq m (1150 psi).
4. Utilities - For in situ combustion, compressors for injecting air are
needed.For steam and hot water injection, power for compressors and
boilers is required; for example,, for their steam project at Lombardi,
Mobil uses approximately 79 cu m of fuel oil, or crude, for each 1000
cu m of steam generated (80 bbl/1000 bbl steam). For a rate of 3000
cu m (20,000 bbl) steam/day, fuel consumption is around 254 cu m/day
(1600 b/d).
57
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Amoco Production at Winkleman Dome uses one steam generator rated
at 9000 kg/hr {20,000 Ib/hr) and two at 10,000 kg/hr (22,000 Ib/hr),
for a total capacity equivalent to 664 cu m water/day (4180 bw/d).
5. Waste Streams - Fugitive emissions from boilers and compressors.
6. EPA Source Classification Code - None exists
7. References -
(1) Bleakly, W. B., "Mobile Eyes Steaming Success at San Ardo",
Oil and Gas Journal, Vol. T[, No. 52, December 24, 1973,
pp. 40-43.
(2) Giusti, Luis E., "CSV Makes Steam Soak Work in Venezuela
Field", Oil and Gas Journal, Vol. 7^, No. 44, November 4,
1974, pp. 88-93.
(3) "Winkleman Dome Steam-Drive Project Expands", Oil and Gas
Journal, Vol. 72, No. 42, October 21, 1974, pp. 114-120.
(4) Smith, C. R., Secondary Oil Recovery, Reinhold Publishing
Co., New York (1966).
(5) Petroleum Extension Service Industrial and Business Training
Bureau, A Primer of Oil Well Drilling, Austin, Texas (1975).
53
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APPENDIX A
CHARACTERISTICS OF U. S. CRUDE OILS
59
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Table A-l. PROPERTIES OF UNITED STATES CRUDE OILS
State
Field
' Alabama
Citronelle (Rodessa, L. Cre.)
Alaska
Swanson River (Hemlock, Eoc.)
Arkantat
Magnolia (Reynolds-Sraackover, Jur.)
Midway (Sraackover, Jur.)
Scliuler (Jones & Cotton Valley Jur.)
Sroackover (U. Cre.)
California
Belgian Anticline (Oceanic, Olig.)
belriilice. South (Tulare, Plio.-Pleist.)
Br™ Olinda (Mio.) . .
Bueno Vista (27-B Banal Etchegoin. Plio.)
Castaio Junction (Zone 10, Mohnian, Mio.)
Coalinga, East (Main Gatchell, Eoc.)
Coalinga Nose (Gatchell, Eoc.)
Coalinga, West (Temblor, Mio.)
Coles Levee, North (Mio.)
Coyote, West (Emery, Repetto, Plio.) ....
Cuyama, South (Dibblee, Mio.)
Cymric (McKtttrick Croup, Tulare, Plio.-
Pleiat.)
Elk Hilla (Shallow U. Plio )
Fruitvale (Chanac, Plio. -Mio.)
Gosford, East (Middle & Lower-Stevens,
Mio.)
Greeley (Rio Bravo- Vedder Mio)
Guijarral Hills (Leda Olig.)
Huntington Beach (S. Main area, Mio.) . . .
Kern Front (Chanac Plio.-Mio.)
Kern River 1 Kern River, Plio.-Pleist.)
Kettlernan North Dome (Temblor, Mio.) . .
Long Beacli (Alamitos, Repetto, Plio.) ....
Midway-Sunset (Plio.-Pleist.)
Montalvo, West (Colonia, Sespe, Olig.) . . .
Newhall-Potrero (Modelo, Mio.)
Oxnanl (Mclnnes, Sespe, Olig.)
Rincon (Plio.)
Russell Ranch (Dibblee, Vaqueros, Mio.)..
Santa Fe Springs (Buckbee, Plio.)
Seal Beach (McGrath Mio.)
Torrance (Del Amo Mio )
Ventura (Pico-Repetto, Plio.)
Wheeler Ridge (Eoc )
Wilmington (Harbor area, Terminal, Mio.)
Colorado
AJena (Dakota "J", Cre.)
Grav-
ity,
'API
43 6
29 7
38.4
36 6
32 8
22 5
35.0
1.1 0
24 0
30.6
19.0
17 5
28.8
31.5
20 2
34.0
32.3
32.5
12 7
29 9
25.2
22 8
17.5
34.0
37 2
36.8
37.6
22.6
18 1
14.8
12.6
34.0
22.6
21.6
17.3
16.0
32.7
25 . 7
22 6
28.2
38.6
35.2
11.1
29.7
28 6
32.8
14.7
31.7
23 3
40.0
23 8
31.3
37.0
22.3
44.7
34 8
48.1
Sulfur,
wt.
per cent
0 38
0 16
0.90
1 36
1 55
2 10
0.59
0 23
0 75
0 . 59
3.40
5 07
0.31
0.25
0 55
0 39
0.82
0.42
1 16
0 40
0 2O
0 68
0.93
0.57
0.31
0.63
0.40
1.57
2.50
0.85
1.19
0.40
1.29
0.89
4.10
0.68
0 . 56
1.72
1 86
1.40
0.35
0.35
2.25
0.83
0.87
0.33
4.99
0.55
2.79
0.16
1.84
0.94
0.29
1.33
<0.10
0 5G
0.12
Viscos-
ity,
SU5 at
100'F
40
61
38
42
52
220
40
2 440
135
46
1,230
3 000
67
48
195
43
50
49
6 000
60
US
135
1,750
51
41
40
37
210
680
5,100
6,000
44
208
210
7,648
1,900
46
95
230
80
38
43
6,000
59
63
47
6,000
52
220
35
160
56
38
210
36
48
33
Source:
From Petroleum Processing Handbook edited by W. F. Bland
and R. L. Davidson, Copyright (Q 1967 by McGraw-Hill, Inc.
Used by permission of McGraw-Hill Book Company.
60
-------
Table A-l (Continued). PROPERTIES OF UNITED STATES CRUDE OILS
State C
Field
Illinois
Clay City (Miss )
Salem (Aux Vases Miss )
Indiana
Kan sat
Seely-Wick (BartlcsviUe Pean.)
Louisiana
Rftv Mnivhand 13900' Mio )
Black Bay West (730CK Mio.)
Black Bay West (8050' Mio.)
Black Bay West (8300' Mio )
Eugene Island (Block 32. 7500', Mio.) . . .
Eugene Island (Block 188, 9080', Mio.) . .
Grand Isle (Block 16. B-l, Seg. E, Plio.) .
Little Lake (Textularia Panamengis 1, Mio
Little Lake (Textularia Panamensis 2, Mio
Little Lake (Textularia Panamensia 6, Mio
3rav-
ity.
'API I
38.6
36.4
35.6
36.2
36.0
37.4
37.2
35.2
34.6
38.8
36.8
39.4
43.0
41.1
23.5
39.2
34.4
38.2
33.6
20.2
33.6
36.2
30.0
23.0
30.6
34.4
35.2
34.4
36.8
35.4
39.2
33.6
40.6
31.9
41.7
35.6
36.4
31.0
39.2
36.2
27.1
34.8
37.6
35.0
. 36.4
. 34.6
. 33.6
. 31.3
. 54.9
. 36.2
. 40.4
. 34.6
. 35.4
. 28.2
. 35.4
. 32.1
. 32. J
.) 31.7
.) 36.2
.) 46.:
1
Sulfur,
wt. £
jer cent
0.19
0.15
0.21
0.22
0.23
0.20
0.17
0.20
0.57
0.44
0.18
0.34
0.27
0.23
0.93
0.41
0.12
0.15
0.27
0.46
0.39
0.16
0.27
0.36
0.26
0.18
0.17
0.19
0.37
0.23
<0.10
0.16
<0.10
0.38
<0.10
0.26
0.14
0.20
<0.10
0.19
0.35
0.22
0.18
0.31
0.18
0.22
0.23
0.29
<0.10
0.30
0.14
0.21
0.14
0.37
0.2C
0.27
0.28
0.27
O.lf
\
-------
Table A-l (Continued). PROPERTIES OF UNITED STATES CRUDE OILS
Sinli
Field
Little Lake, South (Textularia PanamensiB
1 "D", Mio.)
Main Pass (Block 69, Mio.)
Ship Shoal (Block 154 Mio.)
South Pane (Block 24. Mio.)
Timbulier Bay (Mio.)
Weeks laland (Mio.) . . . . . . .
West Bay (Mio.)
West Delta (Block 30, Mio.)
West Delta (Block 53, KE, U. Mio.)
West Delta (Block 83 KE, U. Mio.)
Michigan
Albion (Trenton- Black River Ord.)
Afiifftaaippt
Baxter vi lie (L. Tuscalooaa, U. Cre.)
Bryan (Rodessa L. Cre ) ...
Heidelberg (U Tuacalooaa U. Cre.)
Little Creek (L. Tuacaloosa, U. Cre.)
Raleigh (Hoaston, L. Cre.)
8oao U 1.701 Bailey, Rodeaaa, U Cre.)
Tinstey (Selma U. Cre )
Montana
Cut Bank (Cut Bank L Cre ) ....
Pine (Dev.)
New Mexico
Biati (Gallup Cre.)
Caprock. East (Wolfcacop, Perm.)
Eunice-Monument (Grayburg, Perm.). . .
Hobbs (San Andres Perm.)
Jalraat (Yates Perm.)
North Dakota
Beaver Lodge-Tioga (MiBaion-Canyon,
Ord ) .
Blue Butte (Madison Miss.)
Oklahoma
Bradley (Springer. Peon. & Cunningham
Mi*ui ) • - • •
Ctmenl (If. Melton. Ftnn.).
Kulu-Krjbberaon (Hmml'le, M. Ord.)
K/>la-l{itbl»»wjn (Oil Creek. L. Ord.)
Gulden Trend
Antioch. Southwest (Gibovn, Miw.) . . .
Grav-
ity,
"API
34.8
30.6
36 0
31.9
37 4
2V. 1
32.3
34.4
37.6
33.2
32.1
27.0
32.3
35.0
41.9
17.1
35.0
37.2
23.3
38.0
45.8
41.1
30.4
33.4
39.0
33.8
39.6
29 . 6
37.6
43.2
46.0
28.8
42.1
37.4
36.2
36.4
28.9
39.4
38.6
41.7
35.0
39.6
42.8
46.0
41.1
41.3
35.0
30.6
3.1.2
42.1
:t!l.8
3H.O
37.4
42.1
Sulfur,
wt.
per cent
0.26
0.25
0 23
0.27
0 ^0
0.36
0.26
0.33
0.24
0.19
0.27
0.33
0.43
0.37
0.10
2.71
0.43
1.47
3.75
0.16
0.43
0.89
1.02
0.60
0.85
0.36
0.32
0.6S
0.18
0.17
0.17
0.97
0.10
1.41
1.22
0.12
1.65
0.36
0.70
0.11
0.95
0.12
<0.10
0.23
0.52
0.31
0 22
0.24
0.47
0.22
O..T.ri
O.U7
O.31
0.11
Viscos-
ity,
SUSat
100°F
49
61
41
52
44
78
Gl
43
41
51
64
02
66
48
44
1,480
50
47
370
43
58
41
79
47
38
55
38
72
40
35
35
54
35
41
47
35
64
36
37
34
42
39
32
34
34
35
56
43
56
38
41
VI
VI
39
62
-------
Table A-1 (Continued). PROPERTIES OF UNITED STATES CRUDE OILS
Stall
Field
NRW Hope. Southeast (fiibnon. Miau.) ...
Joiner City (Bois D'Arc. Sil.-Dcv.)
Knox (Dornick HHIa Penn )
Sho-Vel-Tum District
Milroy (Deese Penn.)
Sholem. A lee hem (Springer. Perm.)
Velma (L. Dornlck Hills, Springer. Penn.)
Pennsylvania
Bradford (U Dev )
Texo*
Anahuac (Marg No I Olig.)
Andrews North (Dev.)
Bakke (l>*v )
Dakke (Penn )
Bakke (Wolfcamj> Perm )
Block 3L (Dev )
Borregoa (N-1*! Frio Olig.)
Borregos (R-13 Vicksburg Olig.) ....
Cowden, South (Grayburg, Perm.)
Diamond "M" (Canyon Reef, Perm.)...
Dollar hide (Clear Fork Perm )
Dollar-hide (Dov.)
Dollarliide (Sil ) •
Dollarhkle, Kast (Ellen.. Cambro-Ord.) ,
Kant 'IVxas (Woodbine U Ore.) .....
Km inn ((*rnybur(fr-Sun Andrw*. l'«rm.) . . .
Kmiieror, !>M:II (S*t»:n Uivcru, Quettn.
jVrtn )
art , m mrne ( em,
Fuhnnan-Mascho (Grayburg. Perm.) . . . .
Fullcrtoii, South (Wolfcamp. Perm.).. • •
— T
rav-
ity,
API
42.1
41.1
40 . 5
28. «
37.0
40.4
43.0
39.8
37.6
28.0
36.0
30.0
26.8
21.0
29.1
41.1
33.2
43.2
39.0
36.8
44.3
4S.2
44.7
30.8
44.7
45 C
39.4
37.4
41.5
44.5
42.1
40.6
42.3
38.2
39.0
41.7
37.0
30.4
36.6
34.6
36.6
36.8
45.4
37.4
38.2
41.5
41.3
42.3
29.7
37,4
45. U
4U.2
4!l.O
35 . 0
. 45.0
44.1
. 34.2
. 31.3
. 39 . 6
. 41.5
. 43.4
|-
Sulfur,
wt.
;>er cent
0.14
O.l'.i
0.14
0.112
0.00
0.47
<0.10
0.25
0.16
1.41
0.57
1.73
1.44
1.68
1.36
0.11
0.23
0.22
0.11
0.78
0.30
0.11
<0.10
0.10
0.1A
0 2t
<0.10
0.41
0.23
0.18
<0.10
<0.10
<0.10
<0.10
<0.10
0.38
<0.10
1.89
0.96
1.77
0.76
0.78
0.20
0.42
0.57
0.23
0.36
0.10
3.11
0.25
<0.10
<0.10
:<
37
44
47
40
38
36
-------
Table A-1 (Continued). PROPERTIES OF UNITED STATES CRUDE OILS
State
Field
Gillock (HudKinga Frio, Olig.) . ...
Gillock, South (Frio, Olig.)
Goldsmith (5600', 0. Clear Fork. Perm.)..
Goldsmith (Clear Fork-Tubb. Perm.)
Goldsmith (Dev.)
Goldsmith, East (Holt, Perm.)
Goldsmith, North (Kllea, Cam.-Ord.)
Goldsmith, West (U. Clear Fork, Perm.) . .
Goldsmith, West (Ellen. Cam.-Ord.)
Goldsmith, West (Fusselrnan, Sil.)
Goldsmith, West (San Andres. Perm.)
Goose Creek (Frio, Oils.)
Hastings, East (Frio, Olig.)
Hastings, West (Frio Olig )
Hawkins (Eagle Ford, V. Cre.)
Headlee (Dev.)
Headlee (Ellen. Cam -Ord )
High Island (Mio.)
Howard-Glasscock (Yates Perm.)
Hull (Caprock, Mio.)
Jameson (Strawn, Penn.)
Jameson (Strawn Reef, Penn.} .
Jo-Mill (Spraberry, Perm.)
Jordan (Ellen., Cam.-Ord.)
Jordan (San Andrea, Perm.)
Kelly-Snyder (Canyon Reef, Penn.)
Kelny (Frio, Olig.)
Kelsey South (18-A. Frio Olig )
Kermit (Ellen.. Cam.-Ord.)
Kermit (Yates and Seven Rivers, Perm.)..
Kermit, South (Dev.)
Keystone-Colby (Queen, Perm.)
Keystone- Ellenburger (Ellen., Cam.-Ord.).
Keystone-Silurian (Sil.)
KMA (Strftwn Penn.)
Lake Pasture (FT-569, Frio-Sinton, Olig.).
Lake Pasture (H-440, Greta, Olig.)
Liberty. South (EY, Olig.)
Magutex (Dev.)
Magutex (Ellen. Cam.-Ord.)
Means East (Strawn, Penn.)
Midland Farms (Ellen., Cam.-Ord.)
Midland Farms, North (Grayburg, Perm.).
Midland Farms, Northeast (Ellen., Cam.-
Ord.)
Old Oc*an (Armstrong Frio Olig.)
Old Ocean (Chenuult, Frio Olig.)
1'eKORus (Penn.)
Pen well (Ellen., Com.-Ord.) . . :
Penwell (Ban Andres, Perm.)
Plymouth (610CK Frio, Olig,)
Grav-
ity,
"API
45 2
38 0
38.0
38 0
40 9
38 4
36 4
37 0
37.4
42 6
37 4
34.4
35.0
31 5
31.0
30 2
26.8
47 4
81 1
27.3
30 6
31 1
40 9
44 3
37 4
43 1
33 2
30.8
40 0
43 4
41.8
36.8
32.3
34.2
32.7
42.1
37.8
35 4
40 0
37.2
23.7
31.1
36.4
28.6
40.2
46.9
31.5
30.0
35.6
43.0
50.6
31 7
39.6
30.0
49.2
36.8
25.4
40.4
53.0
4S.4
35.6
41.7
33.2
37.2
42.3
40.6
Sullur,
wt.
per cent
<0 10
0 11
0.52
0 57
0 16
1 16
0 15
0 58
0.53
0 32
0 96
1.38
0.13
0 15
0.15
0 17
2.19
<0 10
<0 10
0.26
1 18
0 35
<0 10
<0 10
0 11
0 28
1 4g
0 22
0 13
<0 10
0.19
0.94
0.79
0.95
0.69
0.13
0.63
0 49
0.31
0.13
0.20
2.12
0.14
0.86
0.30
0.12
2 37
2.40
1.11
O.JO
<0.10
2 04
0. 13
2.37
<0.10
0.14
0.21
0.55
<0.10
<0.10
0.17
0.24
1.69
0 12
0 12
0.13
Viscos-
ity,
SVS at
100°F
34
38
46
44
40
40
5y
44
44
39
43
43
42
48
55
58
135
37
35
79
61
41
34
36
43
38
46
37
33
34
39
42
81
48
68
40
43
51
39
35
60
48
40
90
38
39
53
54
46
35
34
46
40
53
38
43
71
47
33
36
48
40
45
39
3-1
37
€4
-------
Table A-l (Continued). PROPERTIES OF UNITED STATES CRUDE OILS
State
Field
Plymouth (Greta, Frio, Olig.)
Plymouth (Main Greta, Frio, Olig.)
Portilla (7100', Frio. Olig.)
I'ortilla (7300', Frio. Olift.) ... .
Portilla (7400', Frio, Olig.)
Portilla (8100', Frio, Olii?.)
1'rentice (B70O', Clear Fork, Perm.)
Prentice (Glorieta, Perm.)
Quitrnan (Sub-Clarkaville, U. Cre.)
Quitmau (Trinity, L. Cre.)
Robertson (L. Clear Fork, Perm.)
Robertson (San Angelo-Clear Fork, Perm.)
Robertson, North (7100', Clear Fork,
Perm.) . . .
Russell (6100' Glorieta, Perm.)
Rysaell (7000* Clear Fork, Perm.)
Russell, North (Dev.)
Salt Creek (Canyon, Penn.)
Sand Hills (Ellen., Cam.-Ord.) .
Sand Hills (McKnight, San Andres, Perm.)
Sand Hills (Tubb, Perm.)
Scarborough (Yates, Perm.)
Seeligson (Zone 14-B, Frio, Olig.) ....
Seeligsoo (Zone 19-B, Frio, Olig.)
Seeligson (Zone 19-C, Frio Olig.)
Seeligson (Zone 20, Frio, Olig.)
Seeligson (Zone 21-D, Frio, Olig.)
Seminole (San Andres, Perm.)
Seminole, West (San Andres, Perm.)
Shatter Lake (Dev.)
Shafter Lake (San Andres Perm.)
Sharon Ridjje (1700' Kan Andres. Perm.). .
Sharon Ridge (2400' San Anfcelo, Perm.) . .
Hhiiron Urine (Clear Fork Perm )
Spraberry Trend nrea (Spraberry, Perm.) . .
Taft (Frio. Olix.)
Tulco (Trinity L. Cre )
Tliompnon CIBOO', Miu.)
Thompson, North (Vick«hur(?. Oli«.)
Thompson, tjouth (Mio.)
TXL (Dev.) . .
TXL (Ellen., Cam.-Ord.)
TXL (San Andres Perm.)
TXL (Tubb, Perm.)
University-Block 9 ( Dev.)
University-Block 9 (Penn.) . ...
University-Block 9 (Wolfcamp, Perm.)
Van (Woodbine- Dexter, U. Cre.)
Waddell (Grayburg Perm )
Walnut Rend (Hudspeth, Strawn, Penn.)..
Walnut Bend (U. Strawn, Penn.)
Walnut Bend (Winger, L. Strawn, Penn.). .
Wnrd-Kstes, North (Yates Perm.)
Ward South (Yatea Perm )
Wiisnon flfi (Cloar Fork Perm )
WusMon 72 (Clear Fork, Perm.) . . ....
W»jbHti:r (M unfit) ulina, l''rit>, Olig.)
W«l«li (San Aii'lres Perm.)
Went Columbia ("7. " Frio. O!ii<.)
W«»t Columbia New (Krio, Otij{.)
Wt^it Uam:li (41 -A. Krio, OliK-)
Grav-
ity.
"API
23.5
28 8
40 4
39 8
39 0
30 0
25.9
28 6
20 3
1(1 2
43 8
34 0
29.9
34 8
32 7
34 6
40 2
36 8
37 0
31.7
36 8
34 0
41 5
41.3
41 9
40 2
41 5
33 6
31 7
38 6
37 4
27.1
28 2
2'J 1
36 0
31 1
35.0
21 K
20 5
23 8
36 4
25 7
40 5
34 8
38 6
42 3
30 8
36 4
44 7
36 4
37.0
35 4
33 6
46.0
44.1
31.0
34 0
35 8
32 8
31 9
33.2
29. 3
'.Vi. 3
28 0
2H.fl
31 5
Sulfur,
wt.
per cent
0.19
0 15
<0 10
<0 10
0 14
0 12
2.60
2 68
2 06
3 64
0 92
1 31
1.95
0 79
1 20
1 23
0 31
0 63
0 73
3.33
0 92
1 00
<0 10
20
140
46
64
35
39
41
39
49
47
30
45
39
51
46
38
38
77
45
42
43
44
42
fit
45
(>.r>
c>:t
41
65
-------
Table A-1 (Continued). PROPERTIES OF UNITED STATES CRUDE OIL
Slot*
Field
Wert Ranch <9S-A , Frio. Olio)
Wont Ranch (Gt&Mcock* Frio Olig }
Wait Ranch (Greta. Olig.)
Weet Ranch (Ward Frio, Ollg.)
Whita Point. Eut (5800' Oreta. Olig.)
White Point. Eaat (5600' Brigh»m. Frio.
dig.)
Yalea (8aa AndrM Perm.) .
Via*
Aneth (Kermoaa, Peon*)
Ratherford (Par&doi, Penn.)
White Mas (Paradox. Penn.)
Wyoming
Beaver Creek (Steele. U. Cre.)
Big Muddy (Frontier. U. Cre.)
Big Saad Draw (Tenaleep, Peon.)
Byron (Tenaleep, Peno.)
Coyote Creek (Minneliua, Peon.)
Elk Buio (Frontier U Cre)
Four Beer (Madiran. Mia*.)
Oertand (Axnadea. Peao.)
Glearoek (Dakota* L* Cre.) . .
Grieve (L. Cre.)
Hamilton Dome (Tenelet p. Peao.) .'
Little Buffalo Baaio (Phoephoria, Perm.) . .
Oregon Bum (Enbar-Teadeep-Madiaoa,
Salt Creek (Wall Creek, U. Cre.)
Winklemoa Dome (Phosphoria, Perm.)...
Grav-
ity,
'API
39.8
31.0
24. 9
30.8
27.3
38.4
30 2
40.4
40.0
41.3
41.1
33.8
35.8
34.2
3S.S
24.3
28. S
40.9
39.4
43 3
13. 8
Z7.S
22.0
34.4
44.8
38.2
22. 8
SO. 7
15.2
38.8
34.0
20. i
36.9
28.2
39.0
33.8
25.7
Sulfur,
wt.
Mr cent
0.11
0.13
0.16
0.15
0.13
0.13
1.54
0.20
<0.10
<0.10
0.10
0.20
0.12
1.35
1.87
2.50
2.52
<0.10
0.12
<0 10
3.58
3.43
2.88
0.16
<0.10
<0.10
2.98
3.31
1.23
0.12
1.70
3.25
0.12
2.18
0.37
1.32
2.59
Viscos-
ity,
SUSaX
100°F
39
41
57
40
44
35
59
38
37
37
36
48
47
43
37
140
63
38
37
35
6.000
as.
ISO.
55
35
42
230
340
41
39
43
360
43
86
33
43
93
Geologic age names are abbreviated as follows: Cambrian, Cam.;
Cambro-Ordovician, Cam.-Ord.; Cretaceous, Cre.; Lower Cretaceous,
L. Cre.; Upper Cretaceous, U. Cre.; Devonian, Dev.; Upper
Devonian, U. Dev.; Eocene, Eoc.; Jurassic, Jr.; Miocene, Mio.;
Lower Miocene, L. Mio.; Upper Miocene, U. Mio; Mississippian,
Miss.; Oligocene, Olig.; Ordovician, Ord.; Lower Ordovician,
L. Ord.; Middle Ordovician, M. Ord.; Pennsylvania, Penn.;
Permian, Perm.; Pliocene, Plio.; Pliocene-Miocene, Plio.-Mio.;
Pliocene-Pleistocene, Plio.-Pleist.; Upper Pliocene, U. Plio.;
Silurian, Sil.; Pre-Cambrian, Pre-Cam.
66
-------
Table A-2. TRACE ELEMENT CONTENT OF UNITED STATES CRUDE OILS
Stata aad Field
ALABAMA
Toxey
Toxey
ALASKA
Kuparuk, Prudhoe Bay
Kuparuk, Prudhoe Bay
McArthur River, Cook Inlet
Prudhoe Bay
Put River, Prudhoe Bay
Redoubt Shoal, Cook Inlet
Trading Bay, Cook Inlet
ARKANSAS
Brlster, Columbia
El Dorado, East
Schuler
Smackover
Stephens-Smart
Tubal, Union
West Atlanta
CALIFORNIA
Ant Hill
Arwln
Bradley Sands
Cat Canyon
Cat Canyon
Coal Inge r
Coal Oil Canyon
Coles Levee
Coles Levee
Cuyaaa
Cymric
Cymric
Cymric
Cymric
Cymric
Cymric
Edison
Elk Hills
Elwood South
Gibson
Cots Ridge
Helm
Helm
Huntlngton Beach
Inglewood
Kettleman
Kettleman Hills
Las Florea
Loropoc
Lompoc
Lost Hills
Midway
Nlcolal
North Bel ridge
North Bel ridge
North Bel ridge
Nortn Belridge
Orcuct \
Oxnard
Purlsma
Raisin City
V
9
10
32
28 •
ud
31
In
nd
nd
nd
12
15.2
' nd
18.5
nd
41
14.3
9.0
134.5
128
209
5.1
6.0
11.0
2.2
10.0
30.0
0.8
0.6
1.0
6.0
8. 3
nd
37
188
14.0
2.5
29
125.7
34.0
11.0
106.5
37. A
199
39.0
82.6
246.5
—
--
—
23
162.5
403.5
218.5
8.0
Trace \ElesicaL. p
Nl Fe Ba Cr Hn
14
16
13
12
nd
11
6
4
nd
nd
11
10.3 1.2 <1 <1 <1
4
22.7 6.3 <1 <1 <1
nd
<1 <1 <1 <1 <1
66.5 28.5 <1 <1 nd
28 ,0
—
75
102
21.9 5.1 <1 <1 Emission spectroscopy
2.9J
Emission spectroscopy
Emission spect
-------
Table A-2 (Continued). TRACE ELEMENT CONTENT OF UNITED STATES CRUDE OILS
State and Field
Rio Bravo
Rio Sravo
Rio Bravo
Russell Ranch
San Joaqula
Santa Marl*
Santa Maria
Santa Maria
Santa Maria
Santa Maria Valley
Santa Maria Valley
Santa Maria Valley
Santa Haxla Valley
Signal Hill
Signal Hill
Tejon Hills
Ventura
Ventura
Ventura Avenua
Wheeler Rtdge
Wilmington
Vllalaglon
Wilmington
Ullntngtan
Wilmington
U liming ton
UUnlngton
COLORADO
Badger Creek
Badger Creek
Cramps
Cramp
Hlavatha
Hoffat Dome
Rangely
Rangely
Rangely
Seep
White River Area
FLORIDA
Jay
IU.1N01S
tendon
Laud on
KANSAS
Brewster
arswster
Brock
Coffeyvllie
Cunningham
Cunningham
lola
lela
"Kanaas-1"
"Kansas-2*
Me Lout h
Otis Albert
Otts Albert .
rawnee Rock
Rhodes
Rliodes
Rhodes
fttiodea
Rhodes
Rhodes
Solomon
irac. Ela— cr »
V Ml Fe fta Cr «n
2.2
— — 2.6
— — 2.5
12.0 26.0
44.8 —
223 97 17
202 —
ISO 106
280 130
207 97
240 —
280 —
174 174 1.7 <1 1.7 <1
28 —
25 57
64 44
42 SI
49 33 31
15.2 —
7 1.9
43 «1
41 46 28
53 51
— 53
— 60
46 60
36.0 84 36 3.6 <1 nd
<1 5
— >21
<1 6.3 <1 <1 <1 <1
21.3 6.0 <1 <1
-------
Table A-2 (Continued). TRACE ELEMENT CONTENT OF UNITED STATES. CRUDE OILS
State and Field
LOUISIANA
Bay Marchard
Colqultt, Clalrborne
Colqultt, Clalrborne
Colqultt, Callrborne
(Saackover B)
Delta (West) Offshore,
Block 117
Delta (West) Block 27
Delta (West) Bluck 41
lugene Island, Offshore.
Block 276
Eugene Island, Offshore.
Block 238
Lake Washington
Mala Pass, Block 6
Main Past, (lock 41
Olla
Ship Shoal. Offshore.
Block 176
Ship Shoal, Offshore,
Block 176
Ship Shoal, Block 208
Shoagaloo, H. Red Rock
South Pass, Offshore,
Block 62
Tlnballer. S., Offshore,
Block 94
MICHIGAN
Trent
V
nd
nd .
nd
od
nd
nd
ad
4
Bd
ad
Bd
• nd
• <1
ad
ad
nd
ad
nd
ad
—
Trace Uamaac. oa» •
Nl Pe Be Cr Hn . Mo Sn As
2
nd
nd
nd
2
2
2
nd
nd
4
1
J.56 0.07
nd
nd
2
ad
4
nd
0.23
Analytical Method
Emission spectroscopy
Emission spectroscopy
Emission sptfctfodcopy
Emission spec t rtiscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Imlsslon spectroscopy
talsslon spectroscopy
emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
.Emission :pectroseopy
Emission spectroscopy
Year
1971
1971
1971
1971
1971
1971
1971
1971
1971
1971
1971
1971
1952
1971
1971
1971
1971
1971
1971
1956
MISSISSIPPI
Baxtervllla, Lamer and
Merlon
Beldelberg
Mississippi
TallhalU Creek. Smith
Tellhella Creek, Smith
TallhalU Creek. Smith
(Saackover)
Tlngley. Yasoo
40 15
15.3J 6.02 1.78
' — .7
nd nd
nd ad
nd
nd
Eaisslon spectroscopy
Emission speccroscopy
S.OQ3 Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
1971
1952
1966
1971
1971
1971
1971
MONTANA
Bell Creak
Big Wall
Soap Creek
nd 2 Emission spectroscopy
24 13.2 <1 <1 <1 <1 ad Emission spectroscopy
132 13.2 <1 <1 <1 <1 nd Eaisslon spectroscopy
1971
1961
1961
MEW MEXICO
Rattlesnake
Rattlesnake
Table Mesa
<1
<1
9.9 <1 <1 <1
<1 nd Emission spectroscopy
-------
Table A-2 (Continued). TRACE ELEMENT CONTENT OF UNITED STATES CRUDE OILS
State and Field
Crist Creek
Havklns
Hawkins
Horns Corner
Katie
Katie
Katie
Katie
Kendrfck
Konawa
Laf foon
Little River
Middle Cllllland
Naval Reserve
Hex England
H. Dill
N. Z. Castle Ext.
N. E. Elmore
N. E. Elmore
N. Okenab
N. V. Horns Corner
Olympia
Osage City
S. W. Maysvllle
S. W. Mayavllle
Tatuas
Ta turns
Tatuus
Weleetka
W. Holdenvllle
W. Wewoka
Wewoka
Weuoka Lake
Wowoka Lake
Uewoka Lake
Ulldhorse
Wynona
Hynona
TEXAS
Anahiiac
•rant ley-Jackson , Hopkins
Brant ley-Jackson, Snachover
Conroe
Bast Texas
East Teicas
East Texas
East Texas
Bdgewood, Van Zandt
Floley
Jackson
Lak,e Trammel/Nolan
Hlrando
Panhandle, Carson
Panhandle, Hutchlnson
Panhandle, West Texas
Kefuglo
KafuRlo, Light
Sale Flat
Scurry County
Sweden
Talro
Talro
Waffiton
Went Toxiift
U • f. «-„
* ttl rt'XJlti
Wertroncopy
Emission spectroscopy
Emission spectroscopy
nd nd Emission spectroscopy
Emission spectroscopy
nd nd Emission spectroscopy
Emission spectroscopy
nd nd Emission spectroscopy
nd nd Emission spectroscopy
nd nd Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
•Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
nd nd Emission spectroscopy
Emission spectroscopy
Emission spectroscopy
X-ray fluorescence
Emission spertroscopy
X-ray fluorescence («xt. etd.)
Emission spectroscopy
Enlsslon spectroscopy
Emission spectroscopy
Emission spertroscopy
Emission spectroscopy
Emission spr-.ttroscopy
Emission spcutroscopy
nd nd Kralfiflion spectroscopy
nd :i!nn spcrl ro-'*rnpy
Kt&lsslou fipct. troscilpy
(1)
CoH)rlmeTric
Clu-mlr.il
Cheralt-ol
Year
1956
1956
1956
1956
1956
1956
1956
1956
1961
1956
1961
1956
1961
1961
1961
1956
1956
1956
1956
1956
1956
1956
IQCl
1 ?D1
1956
1956
1959
1959
1960
1956
1956
1956
1956
1956
1956
1956
1941
1961
1961
1958
1971
1971
1952
1971
1952
1952
1952
1971
1961
1952
1971
1952
1971
1971
1952
1952
1958
1952
1952
1956
1952
1958
1971
J960
1152
1958
115R
1952
1952
70
-------
Table A-2 (Continued). TRACE ELEMENT CONTENT OF UNITED STATES CRUDE OILS
Trace PI rnnnf ppm
State and Field
UTAH
Duchesne
Duchesae
Duchesne County
Red Wash
Red Wash
Roosevelt
Roosevelt
Virgin
Virgin
Wflflt FieSflAeUlC VetHtty
Wildcat
WYOMIKC
Beaver Creek
Big Horn Mix
Blaon Basin
Circle Ridge
Corral Creek
Crooks Cap
Dallas
Dallas
Derby
Elk Begin
Elk Basin
Garland
Crass Creak
Half Moon
Half Moon
Hamilton Done
Hamilton Dome
Hamilton Domo
Little Mo
Lost Soldier
Lost Soldier
Lost Soldier
Mitchell Creek
North Oregon Basin
North Oregon Basin
. Oil Mountain
Pilot Butte
Pilot Butte
Pltie Bldge
Prescott So. 3
Recluse
Roe 11s
Salt Creek
Salt Creek
Salt Creek
Salt Creek
Skull Creek
South Casper Creek
South Fork
South -Spring Creek
South Spring Creek
Steamboat Butte
Uashakle
Ulnkleiun Done
V
..1
<1
<1
ad
nd
<1
<1
14.4
8.1
Uj
.4
0.14
nd
15.97
1.1
59
2.1
66
66
39
38
8.4
36
106.4
98.6
50.6
106.4
55.2
106.4
83
<1
<1
<1
72.0
77.0
72.0
"jLrt n
Ov.U
144.0
45.0
24.0
nd
21.0
nd
88
84.0
1.4
<1
__
12.9
21.9
HI
<1
<1
12.3
ad
nd
3.2
5.4
14.4
8.1
•i 7 I
J 1 Li
7.5
ad
3.6
2.7
11.2
11
2.2
.15.4
66
39
9.2
2
24
28.9
27.8
<1
26.6
8.6
24.3
16
<1
<1
-------
Table A-3. SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
Stat«/Region and Field
Sulfur,
Weight
Percent
Nitrogen,
Weight
Percent
ALABAMA
Citronelle 0-38 0.02
ALASKA
Granite Point 0.02 0.039
McArthur River 0.16 0.160
Middle Ground Shoal 0.05 0.119
Prudhoe Bay (North Slope) 1.07 0.23
Swanson River 0.16 0.203
APPALACHIAN
Allegany 0.12 0.028
Bradford 0.11 0.010
ARKANSAS
Magnolia 0.90 0.02
Schuler and East 1.55 0.112
Smackover 2.10 0-08
CALIFORNIA
SAN JOAQUIN VALLEY
Belridge South
Buena Vista
Coalinga
Coalinga Nose
Coles Levee North
Cuyaraa South.
Cymric
Edison
Elk Hills
Frultvale
Greeley
Kern Front
Kern River
Kettleman North Dome
Lost Hills
McKittrick - Main Area
Midway Sunset
Mount Poso
Rio Bravo
COASTAL AREA
Carpenteria Offshore —
Cat Canyon West 5.07 0.54
Dos Cuadras •— ~~
Elwood —
0-23
0.59
0.43
0.25
0,39
0.42
1.16
0-20
0.68
0.93
0.31
0.85
1.19
0.40
0.33
0.96
0.94
0.68
0.35
0.773
' —
0.303
0.194
0.309
0.337
0.63
0.446
0.472
0.527
0.266
0.676
0.604
0.212
0.094
0.67
0.42
0.475
0-158
72
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
jitate/Reglori and Field
Orcutt
Rincon
Sah Ardo
Santa Ynez***
Santa Maria Valley
South Mountain
Ventura
LOS ANGELES BASIN
Beverly Kills
Urea Olinda
Coyote East
Coyote West
Dominguez
Huntington Beach
Inglewood
Long Beach
Montebello
Richfield
Santa Fe Springs
Seal Beach
Torrance
Wilmington
COLORADO
Range ly
FLORIDA
Jay
ILLINOIS
Clay City
Dale
Loudon
New Harmony
Salem
KANSAS
Bemis-Shutts
Chase-Silica
Eldorado
Hall-Curney
Kraf t-Prusa
Trapp
LOUISIANA
NORTH
Black Lake
Caddo-Plnc Island
Delhi
Haynesville (Ark. -La.)
Homer
Lake St. John
Rodcssa (La. -Tex.)
Sulfur.
Weight
Percent
2.48
0.40
2.25
—
4.99
2.79
0.94
2.45
0.75
0.95
0.82
0.40
1.57
2.50
1.29
0.68
1.86
0.33
0.55
1.84
1.44
0.56
0.32
0.19
0.15
0.27
0.23
0.17
0.57
0.44
0.18
0.34
0.27
0.41
—
0.37
0.82
0.66
0.83
0.17
0.46
Nitrogen,
Weight
Percent-
0.525
0.48
0.913
—
0.56
—
0.413
0.612
0.525
0.336
0.347
0.360
0.648
0.640
0.55
0.316
0.575
0.271
0.394
0.555
0.65
0.073
0.002
0.082
0.080
0-097
0.158
0 .102
0.162
0.13
0.085
0.108
0.-171
0.076
—
0.026
0.053
0.022
0.081
—
0.032
73
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
State/Region and Field
OFFSHORE
Bay Marchand Block 2
(Incl. onshore)
Eugene Island Block 126
Grand Isle Block 16
Grand Isle Block 43
Grand Isle Block 47
Main Pass Block 35
Main Pass Block 41
Main Pass Block 69
Ship Shoal Block 208
South Pass Block 24
(Incl. onshore)
South Pass Block 27
Timbalier S. Block 135
Timbalier Bay
(Incl. onshore)
West Delta Block 30
West Delta Block 73
SOUTH, ONSHORE
Avery Island
Bay De Chene
Bay .St. Elaine
Bayou Sale
Black Bay West
Caillou Island
(Incl. offshore)
Cote Blanche Bay West
Cote Blanche Island
Delta Farms
Garden Island Bay
Golden Meadow
Grand Bay
Hackberry East
Hackberry West
Iowa
Jennings
Lafitte
Lake Barre
Lake Pelto
Lake Salvador
Lake Washington
(Incl. offshore)
Leeville
Paradls
Quarantine Bay
Rome re Pass
Venice
Vinton
Weeks Island
~W«»st Bay
Sulfur,
Weight
Percent
0.46
0.15
0.18
—
0.23
0.19
0.16
0.25
0.38
0.26
0.18
0.66
0.33
0.33
.—
0.12
0.27
0.39
0.16
0.19
0,23
0.16
0.10
0.26
0.22
0.18
0.31
0.30
0.29
0.20
0.26
0.30
0.14
0.21
0.14
0.37
0.20
0.23
0.27 <
0.30
0.24
0.34
0.19
0.27
Nitrogen,
Weight
Percent
0.11
0.030
0.04
—
0.04
0.071
0.025
0.098
0.02
0.068
0.049
0.088
-•-.
0.081
0.09
— .—
— — .
0.060
0.04
_.—
0.04
0.04
0.033
0.01
0.055
0.06
— — .
__
0.054
__
0.039
«
— .
0.02
0.035
0.02
0.146
0.019
—
0.061
__
__
0 .044
— —
0 .071
74
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
State/Region and Field
MISSISSIPPI
Baxterville
Heidelberg
Tins ley
MONTANA
Bell Creek
Cut Bank
NEW MEXICO
Caprock and East
Denton
Empire Abo
Eunice
Hobbs
Maljamar
Monument
Vacuum
NORTH DAKOTA
Beaver Lodge
Tloga
OKLAHOMA
Allen
Avant
Bowlegs-
Burbank
Cement
Gushing
Earlsboro
Edmond West
Eola-Robberson
Fitts
Glenn Pool
Golden Trend
Healdton
Hewitt
Little River
Oklahoma City
Seminolo, Greater
Sho-Vel-Tum
Sooner Trend
St. Louis
Tonkawa
Sulfur,
Weight
Percent
2.71
3.75
1.02
0.24
0.80
0.17
0.17
0.27
1.14
1.41
0.55
1.14
0.95
0.24
0.31
0.70
0.18
0.24
0.24
0.47
0.22
0.47
0.21
0-35
0.27
0.31
0.15
0.92
0.65
0.28
0 .16
0.30
1.18
—
0.11
0.16
Nitrogen,
Weight
Percent
0.111
0.112
0.08
0.13
0.055
0.034
0.014
0.014
0.071
0.08
0.062
0.071
0.075
0.019
0,016
0.21
—
0.140
0.051
0.152
0.08
—
0.045
0.115
-.-
0.096
0.15
0.15
0.148
0.065
0.079
0.016
0.27
—
0 . 04
0.033
75
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
.State /Region and Field
tEXAS
•DISTRICT 1
Big Wells
Darst Creek
Luling-Branyon
DISTRICT 2
Greta
Refuglo
Tom O'Connor
West Ranch
DISTRICT 3
Anahuac
Barbers Hill
Conroe
Dickison-Gillock
Goose Creek and East
Hastings E&W
High Island
Hull-Merchant
Humble
Liberty South
Magnet Withers
Old Ocean
Raccoon Bend
Sour Lake
Spindletop
Thompson
Webster
West Columbia
DISTRICT 4
Agua Duke-Stratton
Alazan North
Borregas
Government Wells N.
Kelsey
La Gloria and South
Plymouth
Seeligson
Ti j er ina-Canales-Blucher
White Point East
DISTRICT 5
Mexia
Powell
Van and Van Shallow
Sulfur,
Weight
Percent
—
0.78
0.86
0.17
0.11
0.17
0.14
0.23
0.27
0.15
0.82
0.13
0.20
0.26
0.35
0.46
0.14
0.19
0.14
0.19
0 .14
0.15
0.25
0.21
0.21
<.l
0.04
<.l
0.22
0,13
<.l
0.15
<.l
<.l
0.13
0.20
0.31
0.8
Nitrogen,
Weight
Percen^
—
0.075
0.110
0.038
0.027
0.038
0.029
0.041
0.06
0.022
0.014
0.028
0.03
0.048
0-081
0.097
0.044
0.033
0.029
0.048
0.016
0.03
0.029
0.046
0.055
0.015
0.014
0,029
0.043
0.008
0.008
0.049
0.015
0.010
0.02
0.048
0.054
0.039
76
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
^State/Region and Field
DISTRICT 6
East Texas
Fairway
Hawkins
Neches
New Hope
Quitman
Talco
DISTRICT 7-C
Big Lake .
Jameson
McCamey
Pegasus
DISTRICT 8
Andector
•JSlock.31
Cowden North
Cowden South, Foster,
Johnson
Dollarhide
Dora Roberts
Dune
Emma and Triple N
Fuhrman-Mascho
Fullerton
Goldsmith
Headlee and North
Hendrick
Howard Glasscock
latan East
Jordan
Kermit
Keystone
McElroy
Means
Midland Farms
Penwell
Sand Hills
Shafter Lake
TXL
Waddell
Ward South
Ward Estes North
Yates
Sulfur,
Weight
Percent
0.32
0.24 :
2.19
0.13
0.46
0.92
2.98
0.26
<.l
2.26
0.73
0.22
0.11
1.89
1.77
0.39
<.l
3.11
<.l
2.06
0.37
1.12
<.l
1.73
1.92
1.47
1.48
0.94
0.57
2.37
1.75
0.13
1.75.
2.06
0.25
0.36
1.69
1.12
1.17
1.54
Nitrogen,
Weight
0.066
—
0.076
0.083
0-007
0.036
—
0-071
0.034
0.139
0.200
0.033
0.032
0.095
0.127
0.074
0.023
0.111
0.025
0.085
0.041
0.079
0.083
0.094
0.096
0.120
0.10
0.092
0.042
0.080
0.205
0 .080
0 .205
0.085
0 . 04 1
0.067
0 .098
0 .08
0 .107
0 .150
77
-------
Table A-3 (Continued). SULFUR AND NITROGEN CONTENT OF THE GIANT U.S. OIL FIELDS
State/Region and Field
Sulfur,
Weight
Percent
Nitrogen,
Weight
Percent,
DISTRICT 8-A
Cogdell Area
Diamond M
Kelly-Snyder
Levelland
Prentice
Robertson
Russell
Salt Creek
Seminole
Slaughter
Spraberry Trend'
Wasson
DISTRICT 9
KMA
Walnut Bend
DISTRICT 10
Panhandle
UTAH
Greater Aneth
Greater Redwash
WYOMING
Elk Basin (Mont.-Wyo.)
Garland
Grass. Creek
Hamilton Dome
Hilight
Lance Creek
Lost Soldier
Oregon Basin
Salt Creek
0.38
0.20
0.29
2.12
2.64
1.37
0.77
0.57
1.98
2.09
0.18
1.14
0.31
0.17
0.55
0.20
0.11
1.78
2.99
2.63
3.04
0.10
1.21
3.44
0.23
0 .063
0 .131
0 .066
0 .136
0 .117
0 .100
0 .078
0 .094
0 .106
0 .173
0 .065
0.068
0.05
0.067
0.059
0.255
0.185
0.290
0.311
0.343
0.055
0.076
0.356
0.109
Source: Magee, E.M., H. J. Hall, and G. M. Varga, Or,
Potential Pollutants in Fossil Fuels, PB 225
039, EPA-R2-249, Contract No. 68-02-0629,
Linden, N.J., Esso Research and Engineering
Co., 1973.
78
-------
APPENDIX B
GEOGRAPHICAL LOCATION OF OIL AND GAS
PRODUCTION ACTIVITIES
79
-------
Table B-l. PRODUCTION OF CRUDE OIL AND LEASE CONDENSATE BY STATES, 1973
States and Districts
Florida
New York
Pennsylvania
West Virginia
DISTRICT I
Illinois
Indiana
Kansas
Kentucky
Michigan
Nebraska
North Dakota
Ohio
Oklahoma
South Dakota
Tennessee
DISTRICT II
Alabama
Arkansas
Louisiana
Mississippi
New Mexico
Texas
DISTRICT III
Colorado
Montana
Utah
Wyomi ng
DISTRICT IV
Volume Produced, 1000 bbl1
90
2
9
7
108
84
15
181
24
40
20
55
24
524
1
1
969
32
49
2278
154
277
3547
6337
100
95
90
389
674
80
-------
Table B-l (Continued). PRODUCTION OF CRUDE OIL AND LEASE CONDENSATE BY STATES, 1973
States and Districts
Alaska
Arizona
California
Nevada
DISTRICT V
Total U.S.
Volume Produced, 1000 bbl l
198
2
921
_
1121
9209
Volumes in thousands of 42 gallon barrels.
1 gallon - 3.785 liters.
Source: Annual Statistical Review, Petroleum Industry
Statistics. 1965-1974. Washington, D.C.,
American Petroleum Institute, 1975.
81
-------
Table B-2. PRODUCTION OF NATURAL GAS BY STATES, 1973.
State
Alabama
Alaska
Arizona
Arkansas
California
Colorado
Florida
Illinois
Indiana
Kansas
Kentucky
Louisiana
Maryland
Michigan
Mississippi
Missouri
Montana
Nebraska
New Mexico
New York
North Dakota
Ohio
Oklahoma
Pennsylvania
South Dakota
Total Production, Million SCF*
36
612
1
437
1,407
387
93
4
1
2,458
171
23,264
1
125
323
--
167
13
3,352
12
138
256
5,177
215
--
82
-------
Table B-2 (Continued). PRODUCTION OF NATURAL GAS BY STATES, 1973.
State Total Production, Million SCF1
Tennessee
Texas
Utah
Virginia
West Virginia
Wyomi ng
TOTAL U. S.
1
25,452
215
14
572
1,033
65,937
Volumes in millions of standard cubic feet.
Iscf = 0.0267 normal cubic meters
Source: Annual Statistical Review, Petroleum Industry Statistics,
1965-1974* Washington, D. C., American Petroleum Institute,
1975.
83
-------
Table B-3. LOCATION OF LARGE DOMESTIC OILFIELDS
Est. Est.
1974 Prod. 'CUM. Prod. Reserves1 No
State & Field 10000 bbl }000 bbl 1000 bb.1 "ells
ALABAMA
Citronelle
ALASKA
Granite Point
McArthur River
Middle Ground Shoal
Prudhoe Bay
Swanson River
APPALACHIAN
Allegany
Bradford
ARKANSAS
Magnolia
Schuler and East
Smackover
CALIFORNIA
SAN JOAQUIN VALLEY
Belridge South
Buena Vista
Coalinga
Coalinga Nose
Coles Levee North
Cuyama South
Cymric
Edison :
Elk Hills
Fruitvale
Greeley
Kern Front .
Kern River . . .
Kettleman North Dome
Lost Hills
McKittrick
Midway Sunset
Mount Poso
Rio Bravo
COASTAL AREA
Cat Canyon East and West
Dos Cuadras
Elwood
Orcutt
Rincon
San Ardo
Santa Ynez*
Santa Maria Valley
South Mountain
Ventura
LOS ANGELES BASIN
Beverly Hills
Brea Olinda
Coyote East
Coyote West
Oominguez
Huntinglon Beach
Inglewood
long Beach
Montebello
Richfield
4,866
4,233
39,191
9,033
2,181
9,741
400
2,600
446
613
2,860
8,544
4,003
6,483
3,504
1,218
1,471
2919
1,206
789
1016
677
3,235
26,765
643
2,165
6,538
4,920
2,527
170
6,064
14,990
40
1,776
3,319
12,877
3,558
1,640
11,393
4,656
3388
674
2,143
1,110
19,035
3,588
2,598
558
1,476
112,122
56,131
253,387
87,695
6,674
154.297
166,400
658,695
152,870
105,736
508,507
194,803
617,240
632,959
432,473
140,848
208,617
131 500
113.339
283,788
101817
107*973
134,691
635,757
452,104
119,092
206,314
1,197,423
168,357
113,139
174,126
102,488
103,266
148,789
123,549
37,877
34,321
136.748
97.000
416
25
52
33
10-20 million 3
51,197
1,415
19,774
7,130
4,264
21,493
77,900
32,427
65,887
30,959
12,766
11,002
24405
12*500
1,031,000
11,400
3 100
30i300
850,000
3,756
21,700
43,022
420,191
20,620
1,731
48,100
73,247
479
13,035
20.209
274.160 1031800
- 1-3 million -
159.363
130,617
793,393
78,834
343585
98*135
232,141
258,272
923,820
296,656
878,213
184,500
164,852
26,612
16,142
. 88,500
31,384
24 919
«.*TjC Li.
5,300
. 18,361
10,162
118,800
25,100
20,605
5,120
16,372
42
2,100
17,300
56
108
2,611
2,667
1,137
2219
' 74
116
135
746
/f U
527
93
349
• J*t3
47
^/
952
4,531
129
1,149
952
6,027
498
48
590
123
12
176
312
913
214
441
809
128
771
/£!
67
161
131
1,118
432
733
178
304
84
-------
Table B-3 (Continued). LOCATION OF LARGE DOMESTIC OILFIELDS
State & Field
. Est. Est.
1974 Prod.1 CUM. Prod.Reserves1 No
10000 bbl 1000 bbl 1000 bt>l He^s
Santa Fe Springs
Seal Beach
Tprrance
Wilmington
COLORADO
Rangely
FLORIDA
753 600,697 11,218 242
1,236 187,989 11,900 176
2,747 182,332 17,591 364
65,382 1,681,810 697,935 2,335
20,284 513,615 158,379
369
33,166 75,383 237,617 85
ILLINOIS
Clay City .
Dale V
Lawrence
Loudon
Main
New Harmony
Salem
KANSAS
Bemis-Shutts
Chase-Silica
Eldorado
Hall-Gurney
Kraft-Prusa
Trapp
LOUISIANA
Avery Island
Bay DeChene
Bay St. Elaine
Bayou Sale
Black Bay West
Calliou Island
Cote Blanche Islai
Delta Farms
Garden Island Bay
Golden Meadow
Grand Bay
Hackberry East .
Hackberry West
Iowa
Jennings
Lafitte
Lake Barre
Lake Pelto
Lake Salvador
Lake Washington
Leeville
Paradis '.
Quarantine Bay
Romere Pass . . .
Timbalier Bay .
Venice
Vinton
Weeks Island
West Bay
W. Cote Blanche
2,713
389
812
2,693
870
1,380
2,783
1,933
1,185
1,085
1,821
866
1,332
, ONSHORE
1,252
5,464
4,804
2,793
7,068
18,023
id 6,982
916
. ... 8,403
2,256
3,934
1,753
. 2,944
1,250
280
5,727
4,613
3,110
1,662
6,488
2,419
4,057
3,523
2,218
7,985
4,400
2,994
6,446
6,679
Bay 7,880
307,937
100,403
362,201
363,553
223,974
155,355
355,773
218,408
250,429
279,932
127,244
117,824
207,023
78,808
74,815
143,406
145,141
91,538
516,898
78,996
110,053
174,829
115,299
152,533
93,492
117,896
92,363
111,689
212,532
170,632
100,747
75,472
198,674
125,226
103,213
149,648
80,347
234,619
158.185
122,886
200,175
176,543
147.316
17,063'
4,597
4,600
21,447
2,100
14,645
14,227
16,592
9,571
10,058
12,756
7,176
12,977
31,192
52,165
56,494
29,859
58,462
183,102
51,004
9,947
81,508
19,701
52,467
16,508
22,104
7,637
3,311
45,463
49,368
34,253
34,528
76,326
24,774
26,131
35,352
24,653
192,126
46,815
17,114
89,825
63,457
102,684
2,138
495
2,631
1,234
3,101
980
1,228
925
1,033
760
1,175
590
919
38
80
95
91
145
361
58
41
249
207
161
85
158
37
84
244
119
66
50
144
92
75
122
37
355
115
177
82
198
322
85
-------
Table B-3 (Continued). LOCATION OF LARGE DOMESTIC OILFIELDS
State ft Field
1974 Prod.'CUB. Prod!Reserves1 No
10000 bbl looo bbl 1000 bb.1
LOUISIANA, NORTH
Caddo-Pine Island 3 .34ft
Delhi
Haynesville (Ark.. La.)
Homer
Rodessa, (La., TexJ . .
6,583
. 1,644
. 318
. 351
313,014
165 956
171,874
92,227
175,474
26,986
44044
13,126
8,005
4,526
7,370
105
190
153
145
LOUISIANA, OFFSHORE
Bay Marchand Blk. 2
(Incl. onshore)
Eugene Island Blk. 126
Eugene Island Blk. 175
Eugene Island Bik. 276
Eugene Island Blk. 330
Grand Isle Blk. 16 ....
Grand Isle Blk. 43
Grand Isle Blk. 47
Main Pass Blk. 35 .
Main Pass Blk. 41
Main Pass Blk. 69
Main Pass Blk. 306 .
Ship Shoal Blk. 204 ...
Ship Shoal Blk. 207 ...
Ship Shoal Blk. 208 .
South Marsh Island
Blk. 73
South Pass Blk. 24
(Incl. onshore)
South Pass Blk. 27 .
South Pass Blk. 62
South Pass Blk. 65 ...
Timbalier Bay Blk. 21 . .
West Delta Blk. 30 ...
West Delta Blk. 58
West Delta Blk. 73
MISSISSIPPI
Baxterville
Heidelberg
Tinsley
MONTANA
Bell Creek .
Cut Bank
Pine :
NEW MEXICO
Caprock and East
Denton
Empire Abo
Eunice
Hobbs .
Maljamar
Monument
Vacuum
32,632
4,429
8,059
4,687
19,747
13,156
20,999
3,972
. 2,155
10,396
7,973
5,573
5,732
6,223
10,559
5020
15,223
. 11,568
. 6,446
10,105
. 9,449
22,586
10,035
. 7,654
6,853
5,039
2,543
9.345
3,189
2,904
484
1,561
12,267
,4,079
4,722
5,854
387
13,152
429,534
89,207
37,300
46,769
40,488
211,052
163,669
65,069
79,768
144,519
191,010
31,942
27,140
44,419
92,506
40,848
371,476
258,926
48,402
46,193
159,698
312,462
38,091
128,219
167,013
115,229
196,017
68,819
138,439
78,601
92,810
124,675
111,171
126,215
221 451
104,105
210,412
274,986
220,466
35,803
82,700
118.231
190,754
138,948
206,403
34,931
20,232
135,481
68,990
118,058
77,860
130,581
132,494
64,152
118,524
126,074
141,598
143,807
100,111
137,538
111,909
146,781
67,987
34,771
23.983
47,126
58,718
21.416
7,190
15,325
88,829
31,776
33232
60,895
29,588
125,014
293
53
76
60
120
92
230
71
77
100
132
134
58
53
86
37
V*
436
342
64
62
221
216
81
98
198
263
184
228
839
112
614
188
251
806
412
"t*t
819
114
972
NORTH DAKOTA
Beaver Lodge
Tioga
OKLAHOMA
Allen
Avant
3,117
953
2,540
360
78,510
56,253
126,921
106,602
21,506
29,480
13,079
2,398
138
215
1,500
645
86
-------
Table B-3 (Continued). LOCATION OF LARGE DOMESTIC OILFIELDS
1974 Prod.1
State & Field 10000 bbl
Bowlegs
Burbank
Cement
Cushing
Earlsboro
Edmond West
Eola-Robberson
Fitts
Glenn Poo!
Golden Trend
Healdton
Hewitt
Little River
Oklahoma City
Postle
Seminole Greater
Sho-Vel-Tum
Sooner Trend
St. Louis .
Tonkawa
TEXAS
District 1
Darst Creek
Luling-Branyon
District 2
Greta All
Lake Pasture
Refugio All
Tom O'Connor
West Ranch
District 3
Anahuac
Barbers Hill
Conroe
Dickinson-Gillock
Goose Creek & East
Hastings E&W
High Island all
Hull-Merchant
Humble all
Magnet Withers all
Old Ocean
Oyster Bayou
Raccoon Bend
Sour Lake
Spindletop
Thompson all
Tombal!
Webster
West Columbia
District 4
Aqua Dulce-Stratton . .
Borregas all
Kelsey all
Plymouth
Seeligson all
Tijerina-Canales-Blucher
White Point East
District 5
Mexia .,
Powell
Van and Van Shallow
1,665
3,685
1,280
2,965
620
625
3,720
2,565
1,980
8,135
7,575
6,595
330
2,000
6,780
1,010
34,250
9,810
1,100
275
1,731
. 1,345
4,476
. 4,439
314
25,667
14,560
. 8,949
497
21,737
1,839
760
27,912
1,204
1,521
1,473
. 3,025
577
5,520
2,002
925
171
. 16,319
2,932
24,762
1,018
2,122
2,072
2,125
802
2,453
3,867
. 909
129
92
16,264
Cum. Prod.
1000 bbl
158,492
504,039
140,236
463,182
216,424
155,147
107,977
150,873
309,421
402,011
294,240
218,986
159,901
733,896
70,560
199,456
1,002,456
199,414
216,145
135,212
141,384
147,162
116,951
65,537
95,160
496,410
76,469
248,759
124,529
540,659
107,953
130,749
502,991
130,859
193,909
161,839
80,931
121,307
94,837
91,721
117,386
153,741
370,071
103,647
412,958
157,514
138,000
108,293
107,518
116,718
263,203
100,528
99,681
107,353
130,063
419,384
Est. Est.
Reserves1 No
1000 bb.1 «ells
6,508
36,961
14,764
21,818
3,576
'4,853
32,023
12,127
10,579
97,989
25,760
31,014
5,099
16,104
60 102
10,544
247,544
50586
8'855
l',788
18,616
12,838
43,049
44,112
4,840
203,590
298,531
106,241
10,471
134,341
42,047
9,251
172,009
19,141
11,091
28,161
44,069
8,693
51,667
33,279
7614
3,259
129,929
32,217
162,042
12,486
32,000
26,707
42,482
8,282
61,797
64,472
10,319
2,64/
937
130,616
175
1,070
1,465
1,700
200
450
485
635
1,035
1,200
1,460
1,180
165
265
285
255
8,040
2,975
610
205
864
1,403
191
212
67
830
624
234
100
588
70
221
439
98
385
413
286
37
35
135
334
72
305
216
148
193
393
502
344
103
433
182
154
97
37
427
87
-------
Table B-3 (Continued). LOCATION OF LARGE DOMESTIC OILFIELDS
State & Field
District 6
East Texas
Fairway
Hawkins
Neches
Quitman all
Talco
District 7-B
Eastland County . .
Stephens County
District 7-C
Big Lake
MeCamey
Pegasus
District 8
Andector
Block 31
Cowden North
Cowden South,
Foster Johnson
Dollarhide
Dune
Emma & Triple N
Fullerton all
Goldsmith all
Hendrick
Howard Glasscock
Tatan East
Jordan
Kermit
Keystone
McElroy
Means all
Midland Farms all
Penwell
Sand Hills ...
Shatter Lake
TLX all
Waddell ....
Ward South
Ward Estes North
Yates
District 8-A
Anton
Anton Irish
Cogdell Area
Diamond M
Kelly-Snyder
Levelland
Prentice
Russell all
Salt Creek
Seminole all
Slaughter
Spraberry Trend .
Wasson all
Welch
District 9
Archer County
Cooke County . .
, KMA
Walnut Bend
Wichita County . .
Wilbarger County
Young County
District 10
Panhandle
1974 Prod.1
10000 bbl
72,312
13,741
39,630
4,819
... 3,360
3,773
241
1,877
. . 500
794
2,568
. . . . 6,538
6,267
14,954
16,714
5,843
7,448
1,993
6,756
17,431
654
6,902
4.197
3.426
934
5,101
11,820
6,644
6,396
1,485
5,092
2,325
3.656
2,788
546
. 6,170
. 18,192
7,443
4,800
10,237
6,864
76,433
12,391
5.932
2,697
13.093
20.102
47,033
18,190
. 86,784
6,160
2,640
2,106
2,051
4,711
4,787
1,976
1,563
12,347
Est.
Cum. Prod. Reserves L
1000 bbl 1000 bb.1
4,241,715
123,703
535,697
60,132
80,205
237,534
120,482
169,155
124,664
124,089
113,008
128.037
143,861
276,320
299,613
150,205
126,476
96,694
238,417
578,658
252,215
310,153
86,412
102,424
112,374
272,902
309,518
146,249
176,039
84,967
189,105
72,033
236.342
81,605
96,643
310,174
605,446
78,354
73,727
187,918
197,028
616,472
232,508
93,846
112,041
126,663
219,347
595,465
379,633
703,095
88,531
238,970
94.713
167.376
101,145
504,852
159,717
142,237
1,283,585
1,758,285
76,234
289,303
39,868
29,469
32,466
12,410
18,002
10,336
5.911
26,992
56,963
46,139
48,180
100,387
59,795
73,524
18,306
61,583
96,342
2,785
64,847
38,588
27,576
17,626
47,098
50.482
63,751
48,961
15,033
55,895
27,967
28,658
28,395
3,357
64,826
994,556
31,646
41,112
132,082
77,972
491,640
92,492
46,154
22,959
103,337
95,653
194.535
130,367
629,453
61,469
20,411
18,642
17,624
38,855
41.675
21,112
19,666
131,415
Est.
No
Wells
13,360
97
464
166
246
608
294
558
101
884
181
93
120
1,042
1,310
147
899
259
579
2,761
196
1,892
873
336
469
792
1,970
376
337
472
1,069
436
730
425
472
1,966
584
t
177
146
386
461
680
1,617
308
224
119
375
2,526
3,669
2,117
391
4,119
1,981
899
278
6,875
1.782
2,483
10,268
-------
Table B-3 (Continued). LOCATION OF LARGE DOMESTIC OILFIELDS
State & Field
, , Est. Est.
1974 Prod.1Cun. Prod.Reserves1 No
10000 bbl loop bbl 1000 bb.1 Wei 1 s
UTAH
Greater Altamont 21,898 46,197
Greater Aneth . 7,927 259 554
Greater Red Wash 3,364 90.433
228,435
55,558
45.511
223
403
215
WYOMING
Elk Basin
(Wyo.-Mont.) .
Garland . . . .
Grass Creek
Hamilton Dome
Hilight
Lance Creek
Lost Soldier
Oregon Basin
Salt Creek
8,887
3,441
2,764
. 4,454
. 7,358
348
. 3,425
11,354
. 13,284
448,442
112,260
140,295
218,253
48,299
104 632
141,618
240,315
542.518
69,759
25,863
24,605
35,527
85,552
2 359
23,659
79,651
82,113
255
207
248
246
165
44
62
321
1,329
A
Volumes in thousands of 42 gallon barrels.
1 gallon = 3.785 liters.
Source: "Here are the Big U. S. Reserves",
Oil and Gas Journ. 73, 116-118
(1975).
89
-------
Table B-4. NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Alabama
Mobile
Alaska
Kenai Burducjh
Arizona
Apache
Arkansas
Columbia
LaFayette
California
Fresno
Kern
Kings and Fresno
Los Angeles
Orange
Santa Barbara
Ventura
Colorado
Arapahoe
l.aPlatta
Logan
Mesa
Morgan
Rio Blanca
Florida
Bradford
Illinois
Dougl as
Kansas
Barber
Ellsworth
Fi nney
Ford
Grant
Harper
Harvey
Kearney
Kingman
Morton
Pratt
Reno
Rush
Scott
Sedgewick
Seward
Stanton
Total Number
of Plants
1
2
1
1
2
1
16
1
17
5
7
6
1
1
1
1
3
4
1
V
1
2
1
1.
5
1
1
1
2
4
1
1
1
1
1
4
f\f>
Total Gas
Capacity1 ,
MMSCFD
2.0
45.0
2.5
75.0
71.0
46.0
833.5
100.0
404.0
140.0
250.0
180.0
8.0
300.0
10.0
20.0
39.0
60.5
900.0
560.0
30.0
1426.0
200.0
25.0
1325.0
85.0
3.0
215.0
125.0
217.5
12.0
--
24.0
' 200.0
130.0
1350.0
7.0
Total Gas
Throughput1 ,
MMSCFD
1.3
34.2
--
40.0
--
53.0
368.7
44.0
225.9
73.9
115.0
60.6
7.6
206.4
6.0
14.3
16.1
34.7
680.0
545.0
..
1360.0
195.0
—
1246.4
44.0
0.9
96.0
126.5
--
--
--
24.0
173.0
116.0
1237.0
5.1
-------
Table B-4 (Continued). NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Kentucky
Floyd
Green
Greenup
Louisiana
Acadia
Allen
Ascension
Assumption
.Avoyelles
Beau regard
Bossier
Caddo
Calcasieu
Cameron
Clai borne
Concordia
East Baton Rouge
Evangel ine
Iberia
IberviHe
Jefferson
Jefferson Davis
Lafayette
Lafourche
Lincoln
Mo rehouse
Natchitoch.es
Quachita
Plaquemines
Pointe Coupee
Richland
St. Bernard
St. Charles
St. James
St. Landry
St. Martin
St. Mary
Tensas
Terrebonne
Vermilion
Webster
North Big Island Field
Total Number
of Plants
1
1
1
7
1
2
3
1
3
5
1
6
13
3
1
1
2
3
1
1
4
1
4
3
1
1
2
7
3
1
4
'2
4
5
6
8
1
14
6
5
1
Total Gas
Capacity1,
MMSCFD
50.0
925.0
—
626.0
24.0
--
--
7.0
21.0
450.0
25.0
--
2269.5
--
7.0
8.0
140.0
165.0
71.0
100.0
425.0
32.0
211.0
330.0
500.0
150.0
140.0
2620.0
130.0
. 15.0
3165.0
75.5
312.0
--
3436.0
120.0
2615.5
2200.0
333.5
1.5
Total Gas
Throughput1 ,
MMSCFD
50.2
--
--
438.5
12.6
--
--
--
17.9
90.1
--
--
76.7
3.3
5.0
118.0
92.0
69.0
76.0
--
33.3
135.0
90.0
500.0
154.0
41.0
—
"—
17.4
2904.0
--
. 32.8
297.0
--
--
60.0
--
--
189.4
0.8
91
-------
Table B-4 (Continued). NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Michigan
Crawford
Hillsdale
Osceola
St. Clair
Washtenau
Mississippi
Adams
Clarke
Forrest
Jasper
Marion
Pike
Smith
Montana
Fall on
Glacier
Mussel shell
Powder River
Richland
Roosevel t
Nebraska
Cheyenne
Kimball
New Mexico
Eddy
Lea
McKinley
Rio Arriba
Roosevel t
San Juan
North Dakota
Burke
Williams
Oklahoma
Alfalfa
Beaver
Beckham
Blaine
Caddo
Canadian
Carter
Cimarron
Cleveland
Total Number
of Plants
1
1
1
1
1
1
2
1
1
2
1
1
1
1
1
1
1
1
1
1
5
23
1
1
1
5
'2
1
1
7
1
2
1
1
2
1
2
Total Gas
Capacity1 ,
MMSCFD
1.5
38.0
54.0
35.0
600.0
4.0
40.0
60.0
10.0
29.0
20.0
15.0
5.8
30.0
4.0
25.0
6.0
2.5
12.5
12.0
330.0
—
—
95.0
56.5
1368.0
32.0
105.0
45.0
310.0
225.0
70.0
7.0
125.0
80.0
50.0
__
Total Gas
Throughput1 ,
MMSCFD
1.0
30.5
52.0
29.0
600.0
0.7
26.0
11.8
--
10.5
7.2
8.0
5.0
20.0
1.0
9.5
4.0
0.8
7.0
6.1
__
•--
--
68.4
36.7
1271.2
....
76.2
33.1
264.7
95.0
47.5
--
105.8
72.4
42.0
_.
92
-------
Table B-4 (Continued): NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Creek
Custer
Dewey
Ellis
Garfield
Garvin
Grady
Grant
Harper
Hughes
Kay
Kingfisher
Lincoln
Logan
Love
Major
Marshall
McLean
Noble
Okfuskee
Oklahoma
Pontotoc
Semi no le
Stephens
Texas
Woodward
Pennsylvania
Elk
Venango
South Dakota
Butte
Texas
Anderson
Andrews
Aransas
Atacosa
Bee
Bexar
Brazoria
Brooks
Calhoun
Callahan
Carson
Cass
Chambers
Total Number
of Plants
2
2
6
1
5
4
2
3
1
1
4
4
3
1
• 2
3
1
4
1
1
4
2
3
5
6
3
1
1
1
1
8
1
4
3
1
10
7
4
1
1
2
4
Total Gas
Capacity1,
MMSCFD
26.0
58.0
195.0
50.0
203.0
--
--
50.0
225.0
25.0
388.7
248.0
37.0
35.0
73.0
162.0
27.0
65.0
3.0
1.0
186.0
6.5
60.0
--
369.0
321.0
4.0
4.0
38.0
15.0
422.0
75.0
--
207.0
150.0
2509.7
714.0
273.0
5.0
10.0
85.0
__
Total Gas
Throughput1 ,
MMSCFD
•: "? - •
50.0
152.0
10.0
152.9
72.0
39.2
206.5
. -_
338.7
201 .4
--
14.4
--
--
19.7
M.4
2.0
0.6
5.6
15.5
'
315.4
-- .
2.5
0.8
30.0
6.0
176.2
64.0
, 160.1
134.0
105.0
1661.9
558.9
173.2
3.0
7.0
55.0
__
93
-------
Table B-4 (Continued). NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Cherokee
Cochran
Colorado
Comanche
Concho
Cooke
Crane
Crockett
Dawson
Dewi tt
Dimmitt
Duval
Eastland
EC tor
Erath
Fisher
Fort Bend
Franklin
Frio
Gaines
Galveston
Gray
Grayson
Gregg
Hale
Hans ford
Hardeman
Hard in
Harris
Harrison
Henderson
Hidalgo
Hockley
Hopkins
Houston
Howard
Hutchinson
Irion
Jack
Jackson
Jefferson
Jim Hogg
Jim Wells
Karnes
Kenedy
Total Number
of Plants
1
1
4
1
1
2
6
6
2
1
1
2
4
8
1
2
3
1
1
3
4
6
3
5
1
2
1
3
5
4
3
11
. 3
1
1
1
9
2
3
5
7
2
5
1
1
Total Gas
Capacity1 ,
MMSCFD
30.0
25.0
595.0
5.0
14.0
33.0
--
183.0
8.0
150.0
15.0
105.0
23.3
811.0
25.0
30.0
132.0
50.0
20.0
113.0
93.0
245.0
75.0
--
16.0
510.0
15.0
139.0
--
360.0
235.0
639.0
122.0
--
40.0
55.0
1093.0
30.6
19.0
--
--
108.0
826.0
60.0
210.0
Total Gas
Throughput1
MMSCi'.i
15.1
20.0
391.7
0.7
10.7
21.6
--
155.?,
--
130.0
18.0
62.6
18.6
--
6.0
29.6
108.6
41.0
9.0
52.5
53.7
--
--
61.1
16.0
--
6.0
81.2
--
116.6
170.4
311.3
99.7
13.0
30.0
--
—
26.5
14.6
--
233.8
74.7
--
49.0
203.6
94
-------
Table B-4 (Continued). NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY,- 1972
State
County
Kent
Kleberg
Lavaca
Leon
Liberty
Live Oak
McClennan
McMul 1 en
Madison
Marion
Martin
Matagorda
Maverick
Midland
Montague
Montgomery
Moore
Navarro
Nolan
Nueces
Ochiltree
Palo Pinto
Panel a
Parker
Pecos
Potter
Reagan
Reeves
Refugio
Runnels
Rusk
San Patricio
Schleicher
Scurry
Shackleford
Smith
Starr
Stephens
Stonewall
Taylor
Terry
Tom Green
Upton
Van Zandt
Victoria
Total Number
of Plants
1
2
3
1
4
5
1
2
1
1
2
9
1
7
1
5
7
1
3
10
2
3
6
2
9
2
3
2
5
1
4
8
•1
4
2
2
7
6
1
1
1
2
6
3
3
Total Gas
Capacity1,
MMSCFD
16.0
1759.0
275.0
10.0
152.0
267.0
60.0
47.0
20.0
3.2
23.0
1001.0
5.0
—
25.0
160.0
1590.0
12.0
36.0
938.0
250.0
120.0
--
135.0
--
230.0
198.0
38.0
386.5
1.1
58.5
—
56.0
303.0
25.0
13.0
252.0
—
16.0
8.0
5.0
7.0
--
105.0
149.0
Total Gas
Throughput' ,
MMSCFD
12.0
1760.5
132.5
1.7
76.2
137.2
46.4
?6.0
19.7
2.5
19.0
--
2.2
--
6.8
105.6
666.0
11.0
24.9
776.6
—
85.0
--
106.7
--
129.1
106.6
—
179.1
0.2
—
247.7
; .50.4
--
17.0
4.6
246.0
--
9.8
2.5
4.7
3.9
--
57.1
89.5
95
-------
Table B-4 (Continued). NATURAL GAS PROCESSING PLANTS IN
THE UNITED STATES, JANUARY, 1972
State
County
Waller
Ward
Webb
Wharton
Wheeler
Wilbarger
Willacy
Kinkier
Wise
Wood
Yoakum
Young
West Panhandle Field
San Juan
Uintah
West Virginia
Kanawha
Wayne
Wetzel
Wyomi ng
Campbel 1
Carbon
Converse
Crook
Fremont
Johnson
Lincoln
Natrona
Park
Sublette
Sweetwater
Uinta
Washakie
Volumes in million standard
1 SCF = 0.0267 normal cubic
Source: Process Research, Ii
Total Number
of Plants
1
4
1
2
2
1
2
7
2
5
2
3
1
2
1
1
1
1
9
2
2
2
2
1
1
1
2
1
2
1
1
cubic feet per day.
meters .
rtc.. Screening Report, Crude Oil
Total Gas
Capacity1 ,
MMSCFD
1260.0
--
190.0
130.0
--
1.4
119.0
--
--
--
237.0
23.0
90.0
180.0
38.0
35.0
170.0
80.0
151.6
222.5
108.0
J7.0
94.6
15.0
250.0
80.0
22.7
20.0
40.0
100.0
50.0
and Natural
Total Gas
Throughput1 ,
MI4SCFD
1076.0
--
130.0
67.5
21 .0
0.7
49.9
--
239.4
"0
226.5
15.6
45.0
103.8
17.6
29.0
104.0
82.5
129.8
195.1
"
9.0
77.4
4.7
190.6
60.0
18.7
12.4
36.5
28.5
31.5
Gas Production Processes, PB-222718, Cincinnati. Ohio, 197T7
96
-------
Table B-5. WELLS DRILLED IN THE U. S.
State
Alabama
Alaska
Arizona
Arkansas
California
Colorado
Florida
Georgia
Idaho
Illinois
Indiana
Iowa
Kansas
Kentucky
Louisiana
Mary! and
Michigan
Mississippi
Missouri
Montana
Nebraska
Nevada
New Mexico
New York
North Carolina
North Dakota
Ohio
Oklahoma
Total
1974
95
32
11
300
1,993
823
48
5
2
740
403
2
3,066
734
3,001
2
390
463
55
648
228
2
1,138
311
10
134
1,785
3,063
Wells Drilled
1975 Forecast
124
119
8
306
2,199
901
96
0
0
773
407
0
3,117
766
3,387
0
526
534
24
691
262
4
1,237
327
0
198
1,765
3,147
97
-------
Table B-5 (continued). WELLS DRILLED IN THE U. S.
TOTAL WELLS DRILLED
State 1974 1975 Forecast
Pennsylvania
South Dakota
Tennessee
Texas
Utah
Virginia
West Virginia
Wyoming
1,327
10
no
10,309
187
52
822
1,072
1,281
17
112
10,952
212
48
816
1,147
TOTAL U. S. 33,373 35,503
Source: "Drillers Sank More Wells than Considered in Early-
Year Planning". Oil and Gas Journal 73(4), 110-111
(1975).
98
-------
APPENDIX C
PARTIAL LISTING OF DOMESTIC PRODUCERS
99
-------
Table C-l. PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Integrated Oil Companies
Amerada Hess Corp.
American Petrofina, Inc.
Ashland Oil, Inc.
Atlantic Kichfield Co.
Champ!in Petroleum Co.
Cities Service Co.
Colorado Interstate Corp.
Continental Oil Co.
Crown Central Petroleum Corp.
Diamond Shamrock Oil and Gas Co.
El Paso Natural Gas Co.
Exxon Corp.
Getty Oil Co.
Gulf Oil Corp.
Hunt Oil Co.
Husky Oil, LTD.
Kerr-McGee Corp.
Marathon Oil Co.
Mobil Oil Corp.
Murphy Oil Corp.
National Cooperative Refinery
Association
Pennzoil Co.
Phillips Petroleum Co.
Quaker State Oil Refining Corp.
Shell Oil Co.
The Signal Companies, Inc.
Skelly Oil Co.
Standard Oil Co. of California
Standard Oil Co. (Indiana)
The Standard Oil Co. (Ohio)
Sun Oil Co.
229,000 bpd crude
19,000 bpd crude and condensate and
55 HMscfd natural gas in USA and
Venezuela
23,000 bpd crude and 32 MHscfd
natural gas - mid 1973
Worldwide figures for 1972 - 651,900
bpd crude and 2 billion scfd natural
gas
1972 - 4,400 bpd crude and 16,600 bpd
natural gas liquids
1972 - 1.85 trillion cubic feet
delivered to sales
1972 U. S. Production - 1,073,000 bpd
crude and natural gas liquids
1973 Worldwide Production - 420,000 bpd
crude and natural gas liquids
1971 Worldwide Production - 3,282,200
bpd crude and natural gas liquids
1972 - 39,272 bpd crude and natural
gas liquids and 81,462 Mcfd natural gas
1971 Net Production - 15.2 million
barrels of crude and natural gas liquids
1972 domestic production - 189,600 bpd
crude and natural gas liquids and 442.9
million cfd natural gas
1972 - 2 million bpd crude and natural
gas
1971 - 49,000 bpd crude and natural gas
liquids and 66,000 Mcfd natural gas
1973 - 8,500 bpd crude
1972 - 363,100 bpd crude and natural
gas liquids
1971 - 2,710 bpd crude
1972 - 629,000 bpd crude and natural
gas liquids
1972 Worldwide Production - 3,3.24,000
hpd crude and natural gas liquids
1972 - 50,055 bpd crude and natural
gas liquids
72 - 369,007 bpd crude and 49,598 bpd
tural. gas liquids
100
New York, New York
Dallas, Texas
Ashland, Kentucky
Los Angeles, California
Fort Worth, Texas
New York, New York
Colorado Springs, Colorado
Houston, Texas
Baltimore, Maryland
Amarillo, Texas
El Paso, Texas
New York, New York
Los Angeles, California
Pittsburgh, Pennsylvania
Dallas, Texas
Calgary, Alta, Canada
Oklahoma City, Oklahoma
Findlay, Ohio
New York, New York
El Dorado, Ark.
McPherson, Kansas
Houston, Texas
Bartlesville, Oklahoma
Oil City, Pennsylvania
Houston, Texas
Beverly Hills, California
Tulsa, Oklahoma
San Francisco, California
Chicago, Illinois
Cleveland, Ohio
St. Davids, Pennsylvania
-------
Table C-l (Continued).-. PARTIAL LFSTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Integrated Oil Companies (Cont.)
Tenneco Inc.
Texaco, Inc.
Texas Eastern Transmission Corp.
Union Oil Company of California
1972 - 81,778 bpd crude and natural gas
liquids and 938 MMcfd natural gas
1972 - 4,021,000 bpd crude and natural
gas liquids
1971 - 326,800 bpd crude and 1.6 billion
scfd natural gas
Large Independents
A. L. Abercrombi
J. S. Abercrombi Mineral Co., Inc.
Ada Oil Co.
Adobe Corp.
J. W. Akin
Aladdin Petroleum Corp.
Alpar Resources, Inc.
Allen and Shumate, Inc.
Altex Oil Corp.
Aluminum Company of America
Amarex, Inc.
Amax Petroleum Corp.
American Independent Oil Co.
American Natural Gas Production
Co.
American Pacific International,
Inc.
American Trading and Production
Corp.
Ames 011 and Gas
Anchor Production, Co.
Ancora-Verde Corp.
James K. Anderson
Richard S. Anderson, Inc.
A&N Producing Services, Inc.
Anschutz, Corp.
An-Son Corp.
Antelope Gas Products Co.
Morris R. Antweil
Apache Corp.
Apco 011 Corp.
Apexco, Inc.
Appleton Oil Co.
Aquitainc Oil Corp.
Aracca Petroleum Corp.
Ard Drilling Co.
Argo Petroleum Corp.
Armer Oil Co.
Monthly Production - 37,000 bbl crude,
500 MHcf natural gas
Proven Reserves Dec., 1972 - 99,790,450
Mcf natural gas; 7,826,000 barrels crude
Houston, Texas
New York, New York
Houston, Texas
Los Angeles, California
Wichita, Kansas
Houston, Texas
Houston, Texas
Midland, Texas
Wichita Falls, Texas
Wichita, Kansas
Perryton, Texas
Alice, Texas
Vernal, Utah
Pittsburgh, Pennsylvania
Oklahoma City, Oklahoma
Houston, Texas
New York, New York
Detroit, Michigan
Los Angeles, California
Baltimore, Maryland
Houston, Texas
Tulsa, Oklahoma
San Francisco, California
Midland, Texas
Midland, Texas
Jackson, Mississippi
Denver, Colorado
Oklahoma City, Oklahoma
Midland, Texas
Hobbs, New Mexi co
Minneapolis, Minnesota
Houston, Texas
Minneapolis, Minnesota
Oklahoma City, Oklahoma
Houston, Texas
New York, New York
Midland, Texas
Los Angeles, California
Fort Worth, Texas
101
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office. Location
Large Independents (Cont.)
Armour Properties
Atlantic International Oil Corp,
Atlantic Oil Co.
Austral Oil Co., Inc.
Aztec Oil and Gas Co.
Bailey Gas Systems, Inc.
Barber Oil Exploration, Inc.
Barber Oil Inc.
J. C. Barnes Oil Co.
Barnwell Drilling Co., Inc.
Basin Oil Co.
Basin Petroleum Corp.
H. W. Bass and Sons, Inc.
Perry R. Bass
Murphy H. Baxter
Bay Rock, Corp.
Beard Oil Co.
Beaver Mesa Exploration Co.
Belco Petroleum Corp.
Belden and Blake Oil Production
Bell Brothers
J. Ainslic Bell
Kelly Bell
Bell Petroleum Co.
Bel ridge Oil Co.
Benedum-Trees Oil Co.
Bengal Producing Co.
Bennett, Mills, Estate
Bennett Production Corp.
Beren Corp.
Berry and Ewing
Thomas N. Berry and Co.
Bertman Gas and Oil Corp.
Big 6 Drilling Co.
Big Four Petroleum Co.
Blackrock Oil Co.
Blackwood and Nichols Co.
Blaik Oil Co.
B. B. Blair
BKG, Inc.
Bock and Bacon
Bolin Oil Co., A Partnership
Bond Operating Co.
Bonray Oil Co.
Daily Production - 3,000 bbl crude;
103 MMcf natural gas
1970 - 90.1 MMcfd natural gas;
33,762 bpd crude and condensate
Wichita Falls, Texas
Columbus, Ohio
Los Angeles, California
Houston, Texas
Dallas, Texas
Tulsa, Oklahoma
Houston, Texas
Carlesbad, New Mexico
Midland, Texas
Shreveport, Louisiana
Big Springs, Texas
Oklahoma City, Oklahoma
Dallas, Texas
Fort Worth, Texas
Houston, Texas
San Antonio, Texas
Oklahoma City, Oklahoma
Denver, Colorado
New York, New York
Canton, Ohio
.Robinson, Illinois
Los Angeles, California
Midland, Texas
Encino, California
Los Angeles, California
Pittsburgh, Pennsylvania
Dallas, Texas
Houston, Texas
Bowie, Texas
Denver, Colorado
Taft, California
Stillwater, Oklahoma
Houston, Texas
Houston, Texas
Cashing, Oklahoma
Midland, Texas
Oklahoma City, Oklahoma
Oklahoma City, Ofcla.
Tulsa, Oklahoma
Independence, Kansas
Houston, Texas
Wichita Falls, Texas
Dallas, Texas
Oklahoma City, Oklahoma
102
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Bounty Production Co.
BP Alaska Inc.
BP North America, Inc.
Bracken Oil Co.
Bradco Oil and Gas Co.
The Bradley Producing Corp.
Brea Canon Oil Co.
T. S. Bridges Oil Operating Co.
Brldwell Oil Co.
Bright and Schiff Oil and Gas
Producers
Brooks Hall Oil Corp.
H. L. Brown, Jr.
Maurice L. Brown Trust
BTA Oil Producers
George L. Buckles Company
Burk Royalty Company
Burlington Northern Inc.
Burmah Oil Development, Inc.
R. L. Burns Corp.
Buttes Gas and Oil Co.
W. K. Byrom
Cabeen Exploration Corp.
Cabot Corp.
Cactus Operating Co.
Caddo Oil Co., Inc.
Gallery Properties, Inc.
Cal-Mon Oil Co.
Calvert Funds, Inc.
Capataz Corp.
Cardinal Petroleum Co.
Carlsberg Petroleum Corp.
F. William Carr
Carter and Mandel Co.
Caul kins Oil Co.
Cayman Corp.
Cenard Oil and Gas Co.
Cenex (Farmers Union Central
Exchange, Inc.)
Century Petroleum, LTD.
Chambers Mauren
Champlin Exploration, Inc.
Chandler and Associates, Inc.
Chanslor-Western Oil and
Development Co.
Charter Oil Co.
4,000 bpd crude; 24 MMscfd natural
gas
103
San Antonio, Texas
New York, New York
New York, New York
Tyler, Texas
Houston, Texas
Wellsvilie, New York
Brea, California
Fort Worth, Texas
Wichita Falls, Texas
Dallas, Texas
Oklahoma City, Oklahoma
Midland, Texas
Kansas City, Missouri
Midland, Texas
Monahans, Texas
Wichita Falls, Texas
Billings, Montana
New Orleans, Louisiana
San Bernardino, California
Oakland, California
Hobbs, Mew Mexico
North Hollywood, California
Boston, Massachusetts
Wichita Falls, Texas
Shreveport, Louisiana
Houston, Texas
Tulsa, Oklahoma
Midland, Texas
Billings, Montana
Los Angeles, California
Corpus Christi, Texas
Lubbock, Texas
Denver, Colorado
Palos Verdes Peninsula,
California
Dallas, Texas
St. Paul, Minnesota
Fort Worth, Texas
Coalinga, California
Enid, Oklahoma
Denver, Colorado
Chicago, Illinois
Jacksonville, Florida
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Chartiers LTD.
Chase Production Co.
D. C. Cheesman and Son
Cheyenne Petroleum Co.
Chorney Oil Co.
Citronelle Unite
.City of Long Beach
C&K Petroleum, Inc.
Clarcan Petroleum Corp.
Cleverock Energy Corp.
Clinton Oil Co.
Coal Oil and Gas Co.
Estate of George H. Coates
Collier Diamond C Oils, Inc.
C. G. Collins Petroleum Corp.
Columbia Drilling Co.
Columbia Oil Corp.
Condor Operating Co.
Connally Oil Co., Inc.
Consolidated Oil and Gas, Inc.
Cooper and Brain, Inc.
Cordele Operating Co.
Cornell, Drew, Inc.
Cornell Oil Co.
Coronado Oil Co.
Edwin L. Cox
Creslenn Oil Co.
Crestmont Oil Co.
Houston Petroleum Co.
Crystal Oil Co.
Cummins and Walker Oil Co., Inc.
Da Mac Drilling Co., Inc.
Damson 011 Corp.
Danoil, Inc.
The Daube Co.
Davis Investment Co.
Davis Oil Co.
Dearing Inc.
Deck Oil Co.
Depco Inc.
Delhi International Oil Corp.
Delta Drilling Co.
Diamond M. Drilling Co.
Ray J. Diekemper, Jr.
Dorchester Exploration, Inc.
0. L. Dorland
Midland, Texas
Oxnard, California
Houston, Texas
Oklahoma City, Oklahoma
Denver, Colorado
Citronelle, Alabama
Long Beach, California
Houston, Texas
Denver, Colorado
Denver, Colorado
Wichita, Kansas
Ardmorc!, Oklahoma
San Antonio, Texas
Fort Worth, Texas
Campbellsvilie, Kentucky
Houston, Texas
San Angelo, Texas
Odessa, Texas
Abilene, Texas
Denver, Colorado
Wilmington, California
Corsicana, Texas
Lafayette, Louisiana
Dallas, Texas
Denver, Colorado
Dallas, Texas
Dallas, Texas
San Marino, California
Houston, Texas
Shreveport, Louisiana
Corpus Christi, Texas
Great Bend, Kansas
New York, New York
Fort Worth, Texas
Ardmore, Oklahoma
Long Beach, California
Denver, Colorado
Dallas, Texas
Tulsa, Oklahoma
Denver, Colorado
Dallas, Texas
Tyler, Texas
Houston, Texas
Lubbock, Texas
Midland, Texas
Midland, Texas
104
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
The Dow Chemical Co.
Drilling and Production Co.
Dugan Production Corp.
Halter Duncan Oil Properties
Eason Oil. Co.
Edinger Inc.
Eldorado Oil and Gas, Inc.
Elf Petroleum Corp. - U.S.A.
Elk Oil Co.
Engineered Operating Company
Equity Oil Co.
Exchange Oil and Gas Corp.
Expando Production Co.
Fair Oil Co.
Falcon Petroleum Co.
Falcon Seaboard, Inc.
Olen F. Featherstone
Felmont Oil Corp.
Bob Ferguson
Ferguson and Bosworth
Bert G. Fields
Fikes, Leland, Estate
Five Resources, Inc.
Flag-Redfern
Florida Gas Exploration Co.
Fora Co.
Forest Oil Corp.
Formax Oil Co.
Fortune Drilling Corp.
Fortune Production Co.
Francis Oil and Gas, Inc.
Freeport Oil Co.
Frost Oil Co.
Galaxy Oil Co.
Samuel Gary, Oil Producer
General American Oil Co.
of Texas
General Crude Oil Co.
General Exploration Co.
The GHK Co.
GilUland 011 and Land Co.
Warren Ginther and Co.
Goldking Production Co.
Goldston Oil Corp.
Grace Petroleum Corp.
Graham - Michaelis Corp.
1971 - 30,000 bpd crude and condensate;
183,000 Mcfpd natural gas
Houston, Texas
Torrance, California
Farmington, New Mexico
La Salle, Illinois
Oklahoma City, Oklahoma
Oklahoma City, Oklahoma
Dallas, Texas
New York, New York
Roswell, New Mexico
Wichita Falls, Texas
Salt Lake City, Utah
New Orleans, Louisiana
Wichita Falls, Texas
Tyler, Texas
Coalinga, California
Houston, Texas
Roswell, New Mexico
New York, New York
Los Angeles, California
Bakersfield, California
Dallas, Texas
Dallas, Texas
Houston, Texas
Midland, Texas
Jackson, Mississippi
Borger, Texas
Bradford, Pennsylvania
Irvine, California
San Angelo, Texas
Fort Worth, Texas
Tulsa, Oklahoma
New Orleans, Louisiana
San Antonio, Texas
Wichita Falls, Texas
Denver, Colorado
Dallas, Texas
Houston, Texas
Los Angeles, California
Oklahoma City, Oklahoma
Santa Maria, California
Houston, Texas
Houston, Texas
Houston, Texas
New York, New York
Wichita, Kansas
105
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Graner Oil Co.
Gray Operating Co., Inc.
Great Basins Petroleum Co.
Great Expectations Oil Corp.
Great Plains Land Co.
Great Western Drilling Co.
Great Yellowstone Corp.
Green & Michael son Producing Co.
H. J. Gruy and Associates, Inc.
Gulf Interstate Overseas Ltd.
Henry H. Gungoll & Associates
Hadson Ohio Oil Co.
Michel T. Halbouty
Halliburton Oil Producing Co.
Claude B. Hanill, Independent Producer
Hamilton Bros. Oil Co.
Jake L. Hamon
Hanagan Petroleum Corp.
Roger C. Hanks
Hanover Planning Co. Inc.
Hanson Oil Corp.
Harding Oil Co.
Har-Ken Oil Co.
Harkins & Co.
Wayne Harper
Dan J. Harrison, Jr.
Sam G. Harrison
Hathaway Co.
Estate of William G. He!is
Helmerich & Payne, Inc.
Herley Kelly Co.
Herman Geo. Kaiser, Oil Producer
Herndon Drilling Co.
A. E. Hermann Corp.
Hewit & Dougherty
Estill S. Heyser, Jr.
Highland Resources, Inc.
A. G. Hill
Hilliard Oil & Gas, Inc.
W. B. Hinton Drilling Co., Inc.
Hissom Drilling Co.
HNG Oil Co.
Holder Petroleum Corp.
Holloway Dynamics, Inc.
W. W. Holmes, Operator
Long Beach, California
Ardmore, Oklahoma
Los Angeles, California
Fort Worth, Texas
Dallas, Texas
Midland, Texas
Tulsa, Oklahoma
Midland, Texas
Dallas, Texas
Houston, Texa',
Enid, Oklahoma
Oklahoma City, Oklahoma
Houston, Texas
Oklahoma City, Oklahoma
Houston, Texas
Denver, Colorado
Dallas, Texas
Roswell, New Mexico
Midland, Texas
New York, New York
Roswell, New Mexico
Dallas, Texas
Owensboro, Kentucky
Alice, Texas
Dallas, Texas
Houston, Texas
Houston, Texas
Santa Fe Springs, California
New Orleans, Louisiana
Tulsa, Oklahoma
Long Beach, California
Tulsa, Oklahoma
Tulsa, Oklahoma
Amarillo, Texas
Beeville, Texas
Dallas, Texas
Houston, Texas
Dallas, Texas
Menlo Park, California
Mt. Pleasant, Texas
Midland, Texas
Midland, Texas
Lovington, New Mexico
Austin, Texas
Merced, California
106
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Home Stake Production Co.
Houston Oil and Minerals Corp.
Houston Production Co.
Howell Drilling, Inc.
H & S Oil Co.
J. M. Huber Corp.
William A. & Edward R. Hudson
Roy M. Huffington, Inc.
Hughes & Hughes Oil & Gas
Hughes & New Oil Co., Inc.
Thomas D. Humphrey, Oil Properties Ltd.
Indiana Farm Bureau Cooperative
Associates Inc.
Industrial Development Associates
Inexco Oil Co.
Tom L. Ingram
Inlet Oil Corp.
Intercontinental Energy Corporation
International Energy Co.
Invent, Inc.
The Iron Mountain Oil Co.
L. B. Jackson Co.
T. L. James & Co., Inc.
Jefferson Lake Sulphur Co.
Jenkins Drilling & Supply Co.
Jenney Oil Co., Inc.
Jernigan Oil Company
F. T. Johnson, Jr.
A. V. Jones & Sons
Jones - B'Brien, Inc.
Josey Oil Co.
J - W Operating Co.
G. E. Kodane & Sons
Kaiser - Francis Oil Company
Kathol Petroleum, Inc.
Katz Oil Co.
Kentucky Drilling and Operating Corp.
Kewance Oil Co.
S. H. Killingswdrth
Kllmarnock Oil Co.
Kilroy Co. of Texas, Inc.
Klmball Production Co.
Kimbell Oil Company
Kingery Drilling Co., Inc.
King Oil Co.
500 bpd oil & gas production
Tulsa, Oklahoma
Houston, Texas
Houston, Texas
San Antonio, Texas
Artesia, New Mexico
Houston, Texas
Fort Worth, Texas
Houston, Texas
Beeville, Texas
Natchez, Mississippi
Dallas, Texas
Indianapolis, Indiana
Sante Fe Springs, California
New York, New York
Roswell, New Mexico
Dallas, Texas
New York, New York
Dallas, Texas
Houston, Texas
Forth Worth, Texas
Tulsa, Oklahoma
Ruston, Louisiana
Houston, Texas
Oklahoma City, Oklahoma
Chestnut Hill, Massachusetts
Oklahoma City, Oklahoma
Wichita Falls, Texas
Albany, Texas
Shreveport, Louisiana
Houston, Texas
Dallas, Texas
Wichita Falls, Texas
Tulsa, Oklahoma
Wichita, Kansas
San Antonio., Texas
Lexington, Kentucky
Bryn Mawr, Pennsylvania
Longview, Texas
New Orleans, Louisiana
Houston, Texas
Houston, Texas
Fort Worth, Texas
Ardmore, Oklahoma
Tulsa, Oklahoma
107
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
King Resources Co.
Kirby Petroleum Co.
Kissinger Petroleum Corp.
KKA Corp.
K & K Oil Co.
Knight & Miller Oil Corp.
Knox Industries, Inc.
Koch Industries, Inc.
KRM Petroleum Corp.
Krumme Oil Co.
Laco Oil Co.
Ladd Petroleum Corp.
Lake Konel Oil Co.
Lamb Oil & Gas
Lano Oil & Gas Co.
Forrest C. Lattner
Laymac Corp.
Lear Petroleum Corp.
Lloyd Corp. LTD.
Lofton Oil Co.
Logue & Patterson, Inc.
Lohman - Johnson Drilling Co. Inc.
Lone Star Gas Co.
Nipak, Inc.
Long Beach Oil Development Co.
Longhorrt Production Co.
Longstreet 011 Corp.
Louisiana Land & Exploration Co.
Louisiana - Pacific Resources, Inc.
Ralph Lowe Estate
Lubell Oil Co.
Luling Oil & Gas Co., Inc.
LVO Corp.
Lyons Petroleum Corp.
Mabee Petroleum Corp.
MacDonald 011 Corp.
MacKellar, Inc.
Mack Oil Co.
MACPET
Madison Oil Co.
Magellan Petroleum Corp.
Magness Petroleum Co.
Hagulre 011 Co.
Mallard Exploration, Inc.
1971 total production - 119 MMcf
natural gas; 3,882,589 bbl crude;
205.4 million gallons natural gas
liquids
Denver, Colorado
Houston, Texas
Denver, Colorado
Houston, Texas
Los Angeles, California
Denver, Colorado
Midland, Texas
Wichita, Kansas
Denver, Colorado
Bristow, Oklahoma
Abilene, Texas
Denver, Colorado
Tyler, Texas
Portland, Texas
Wichita, Kansas
San Antonio, Texas
Bakersfield, California
Dallas, Texas
Beverly Hills, California
Wichita Falls, Texas
Dallas, Texas
Evansville, Indiana
Dallas, Texas
Dallas, Texas
Long Beach, California
Dallas, Texas
McAllen, Texas
Now Orleans, Louisiana
Palo Alto, California
Midland, Texas
Tulsa, Oklahoma
San Antonio, Texas
Tulsa, Oklahoma
Shreveport, Louisiana
Tulsa, Oklahoma
Dallas, Texas
Oklahoma City, Oklahoma
Duncan, Oklahoma
St. Paul, Minnesota
Wichita Falls, Texas
Hartford, Connecticut
Oklahoma City, Oklahoma
Dallas, Texas
Midland, Texas
108
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Table C-l (Continued). .PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Manziel Interests
Marrion Corp.
Mark Production Co.
The Mayflower Co.
Maynard Oil Co.
The Mayronne Co.
McAlester Fuel Co.
W. C. McBride, Inc.
McClellan Oil Corp.
McCormick Oil & Gas Corp.
McCulloch Oil Corp.
McMahon - Bullington Drilling Co.
McMoran Exploration Co.
McRae Oil Corp.
Meadco Properties
John W. Mecom
Medders Petroleum Corp.
Mesa Petroleum Corp.
Miami Oil Producers, Inc.
Michigan Oil Co.
Midwest Oil Corp.
Minerals Management, Inc.
George Mitchell & Associates, Inc.
M. J. Mitchell
Mohoma Petroleum Corp.
Moncrief Oil Interests
Monsanto Co.
Moranco
E. F. Moran, Inc.
Morgan Brothers
Mormac Oil & Gas Co.
Robert Mossbacher
Moss Petroleum Co.
MWJ Producing Co.
National Oil Co.
Natol Petroleum Corp.
Natomas Co.
Natural Resources Corp.
Newmont Oil Co.
North American Resources Corp.
North American Royalties, Inc.
Northern Pump Co.
Northwest 011 Co.
Northwest Production Corp.
Nueve Operating Co. of Texas
1968 total production - 1,412,028 bbl
crude; 1,371,117 Mcf natural gas
200 Mcfd gas; 15,000 bpd oil,
distillates, plant products
109
Tyler, Texas
Mobile, Alabama
Tyler, Texas
Oklahoma City, Oklahoma
Dallas, Texas
Harvey, Louisiana
McAlester, Oklahoma
St Louis, Missouri
Roswell, New Mexico
Houston, Texas
Los Angeles, California
Wichita Falls, Texas
Dallas, Texas
Houston, Texas
Midland, Texas
Houston, Texas
Wichita Falls, Texas-
Amarillo, Texas
Abilene, Texas
Alma, Michigan
Denver, Colorado
Casper, Wyoming
Houston, Texas
Dallas, Texas
Fort Lauderdalc, Florida
Fort Worth, Texas
St Louis, Missouri
Hobbs, Mew Mexico
Evansville, Indiana
Wichita Falls, Texas
Corpus Christi, Texas
Houston, Texas
Dallas, Texas
Midland, Texas
Los Angeles, California
Oklahoma City, Oklahoma
San Francisco, California
Denver, Colorado
Houston, Texas
Houston, Texas
Chattanooga, Tennessee
Minneapolis, Minnesota
Dallas, Texas
El Paso, Texas
Abilene, Texas
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Oakland Corp.
Occidental Petroleum Corp.
Ocean Drilling & Exploration Co.
Oceanic Exploration Co.
Estate of Gladys 0'Donne 11
Offshore Exploration Oil Co.
Oilfield Consultants, Inc.
Oil, Gas and Minerals Corp.
Oil & Gas Futures, Inc.
Oil Management Corp.
Oil Ventures International Inc.
Oleum, Inc.
Charles W. Oliphant
Joseph I O'Neill Properties
Onyx Oil Co.
W. B. Osborn, Operator
Pacific Lighting Exploration Co.
Pacific Oil & Gas Co.
Pan Ocean Oil Corp.
Pantepec International, Inc.
Pardue Oil
Patoil Corp.
Pauley Petroleum Inc.
Payne - Johnston
Pearson - Sibert Oil Co. of Texas
Peet Oil Co.
Pel-Tex. Inc.
Perkins & Cull urn
Perkins Production Co.
Perkins Production Co.
Perkins - Prothro Co.
Perryman Operating Co., Inc.
Petro Grande, Inc.
Petroleum Corporation of Texas
Petroleum, Inc.
Petroleum International, Inc.
Petroleum Management, Inc.
Petroleum Research Corp.
Petroleum Resources Co.
Petrox Development Corp.
Pexamin, Inc.
B. R. Phillips, Jr.
The Pickens Co., Inc.
D. W. Pickett
Daniel J. Pickrell
Pip Petroleum Corp,
Shreveport, Louisiana
Los Angeles, California
New Orleans, Louisiana
Denver, Colorado
Wilmington, California
Newport Beach, California
Houma, Louisiana
Woodland Hills, California
New Orleans, Louisiana
Dallas, Texas
New York, New York
Longview, Texas
Tulsa, Oklahoma
Midland, Texas
Abilene, Texas
San Antonio, Texas
Los Angeles, California .
Oklahoma City, Oklahoma
New York, New York
Hartford, Connecticut
Breckenridge, Texas
San Antonio, Texas
Los Angeles, California
Tyler, Texas
Beverly Hills, California
San Antonio, Texas
Houston, Texas
Wichita Falls, Texas
Wichita Falls, Texas
Duncan, Oklahoma
Wichita Falls, Texas
Athens, Texas
Dallas, Texas
Breckenridge, Texas
Wichita, Kansas
Tulsa, Oklahoma
Laurel, Mississippi
Littleton, Colorado
Cushing, Oklahoma
Great Nick, New York
Houston, Texas
Dallas, Texas
Dallas, Texas
Corpus Christi, Texas
Burlingame, California
Bloomfield Hills, Michigan
110
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
Pitcock, Inc.
Polaris Production Corp.
Prewitt Oil Corp.
Prochemcho Exploration Co.
Prudhoe Production, Inc.
Publishers Petroleum
Pyramid Oil Co.
Quintana Petroleum Corp.
Rancho Oil Co.
Ray Resources Corp.
Reading & Bates Oil & Gas Co.
Relco Exploration Co., Inc.
Reserve Oil and Gas Co.
Riddle & Gotlieb
Roark & Hooker
Robbins Petroleum Corp.
Rocket Oil Co.
Royal International Petroleum Corp.
Royal Oil & Gas Corp.
James E. Russell Petroleum, Inc.
Rutherford Oil Corp.
Ryder Scott Management Co.
Sabine Royalty Corp.
Sage Oil Co. Inc.
Samedan Oil Corp.
Samson Resources Co.
Corey arid Josey Schneider, Inc.
Scoggins Petroleum Corp.
Scope Industries
Seitz & Comegys Oil Co.
Serio Exploration Co.
Shaheen Natural Resources Co., Inc.
Sheldon Petroleum Co.
Shenandoah Oil Corp.
Fred W. Shield
S. & J. Operating Co.
Sklar & Phillips & Associated Co.
R. E. Smith
Southern Hydrocarbons Production
Co., Inc.
Southern States Oi1 Company
Southland Royalty Co.
South Louisiana Production Co.i Inc.
Ralph Spence
SRG Oil Corp.
Staley Oil Co.
1973 - 10,306 bpd crude &
condensate; 35,302 Mcfd
natural gas
Graham, Texas
Midland, Texas
Abilene, Texas
Houston, Texas
McAllen, Texas
Oklahoma City, Oklahoma
Santa Fe, California
Houston, Texas
Dallas, Texas
Charleston, West Virginia
Tulsa, Oklahoma
Monroe, Louisiana
Los Angeles, California
San Antonio, Texas
Abilene, Texas
Longview, Texas
Duncan, Oklahoma
New Orleans, Louisiana
Indiana, Pennsylvania
Abilene, Texas
Houston, Texas
Wichita Falls, Texas
Dallas, Texas
Los Angeles, California
Ardmore, Oklahoma
Tulsa, Oklahoma
Dallas, Texas
Dallas, Texas
Los Angeles, California
Wichita Falls, Texas
Natchez, Mississippi
New York, New York
Lubbock, Texas
Fort Worth, Texas
San Antonio, Texas
Wichita Falls, Texas
Shreveport, Louisiana
Houston, Texas
New Orleans, Louisiana
Jackson, Mississippi
Fort Worth, Texas
Alexandria, Louisiana
Tyler, Texas
Abilene, Texas
Wichita Falls, Texas
111
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Table C-1 (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
Office Location
C. R. Starnes, Et Al
Albert Stevenson, Estate
J. B. Stoddard, Estate
Stroube Development Co.
Suburban Propane Gas Corp.
Sullivan and Co.
Summitt Energy, Inc.
Sundance Oil Co.
Sunrise Oil, Inc.
The Superior Oil Co.
Sylvan Oil Operating Co.
Tamarack Petroleum Co., Inc.
Tonnehill Oil Co.
Teal Petroleum Co.
Paul C. Teas
The Termo Co.
Tesoro Petroleum Corp.
Texas American Oil Corp.
Texas Crude Oil Inc.
Texas International Co.
Texas Oil & Gas Corp.
Texas Pacific Oil Co., Inc.
Texfel Petroleum Corp.
J. Cleo Thompson
Thums Long Beach Co.
Tipperary Corp.
J. D. Tompkins
Traders Oil Company of Houston
Transocean Oil, Inc.
Trend Exploration Ltd.
Triad Oil and Gas Co., Inc.
Trico Industries, Inc.
Trinidad Petroleum Corp.
Triton Oil & Gas Corp.
Allen K. Trobaugh
True Oil Co.
Trumpter Petroleum Corp.
Tucker Drilling Co., Inc.
Twin Montana, Inc.
Union Texas Petroleum Division
United Oil Corp.
Universal Resources Corp.
Upham Oil & Gas Co.
U. S. Natural Resources, Inc.
U - Tex Oil Co.
UV Industries Inc.
112
Gladewater, Texas
Los Angeles, California
Dallas, Texas
Corsicana, Texas
San Antonio, Texas
Tulsa, Oklahoma
Dallas, Texas
Denver, Colorado
Fort Lauderdale, Florida
Los Angeles, California
Tulsa, Oklahoma
Milwaukee, Wisconsin
Monterey, California
Houston, Texas
Dallas, Texas
Long Beach, California
San Antonio, Texas
Midland, Texas
Fort Worth, Texas
Oklahoma City, Oklahoma
Dallas, Texas
Dallas, Texas
Los Angeles, California
Dallas, Texas
Long Beach, California
Midland, Texas
Abilene, Texas
Houston, Texas
Houston, Texas
Denver, Colorado
Jackson, Mississippi
Gardena, California
Birmingham, Alabama
Dallas, Texas
Midland, Texas
Casper, Wyoming
Fort Worth, Texas
San Angelo, Texas
Graham, Texas
Houston, Texas
Oklahoma City, Oklahoma
Dallas, Texas
Mineral Wells, Texas
Menlo Park, California
Salt Lake City, Utah
Salt Lake City, Utah
-------
Table C*l (Continue)!}'. PARTIAL LISTING OF DOMESTIC PRODUCERS
Company
Production
' Office Location
Vanderbllt Resources Corp.
Van Dyke Oil Co.
Varn Petroleum Co.
Vaughey & Vaughey
Vaughn Petroleum, Inc.
Venus Oil Co.
W. D. Vestal 011 Co.
Victory Oil Co.
Viersen & Cochran
Vincent & Welch, Inc.
Ralph II. Viney & Associates
A. J. Vogel, Inc.
Wadsworth Oil Co.
W. T. Waggoner Estate
Keith F. Walker
Walsh & Watts, Inc.
0. F. Warren & Co., Inc.
Warrior Oil Co.
Watson Oil Co.
Webb Resources
R. P. Webb
Weco Development Corp.
Weeks Natural Resources, Inc.
Wei law Corp.
Westates Petroleum Co.
West Coast Oil Co.
Western Oil Shale Corp.
Western States Producing Co.
Westheimer - Neustadt Corp.
Westland Oil Development Corp.
W. Ridley Wheel Estate
White Shield Oil & Gas Corp.
Whitestone Corp.
M. H. Whittier Corp.
Whittington Operating Co.
Wise Operating, Inc.
The Wiser Oil Co.
Witco Chemical Corp.
Wollfson Oil Co.
Woodbine Production Corp.
Woods Petroleum Corp.
Yates Petroleum Corp.
J. Lee Youngblood
250 MMscf per month gas
Dallas, Texas
Houston, Texas
Wichita, Kansas
Jackson, Mississippi
Dallas, Texas
San Antonio, Texas
Iowa Park, Texas
Long Beach, California
Okmulgee, Oklahoma
Lake Charles, Louisiana
Midland, Texas
Midland, Texas
Houston, Texas
Vernon, Texas
Ardmorei Oklahoma
Fort Worth, Texas
Tulsa, Oklahoma
Denver, Colorado
Shreveport, Louisiana
Denver, Colorado
Vernon, Texas
Denver, Colorado
Westport, Connecticut
Midland, Texas
Los Angeles, California
Oildale, California
Midland, Texas
San Antonio, Texas
Ardmore, Oklahoma
Houston, Texas
Fort Worth, Texas
Tulsa, Oklahoma
Greenwich, Connecticut
Los Angeles, California
Houston, Texas
Tyler, Texas
Sisterville, West Virginia
New York, Mew York
Dallas, Texas
Kilgore, Texas
Oklahoma City, Oklahoma
Artesia, New Mexico
Dallas, Texas
113
-------
Table C-l (Continued). PARTIAL LISTING OF DOMESTIC PRODUCERS
Company Production Office Location
Marshall R. Young Oil Co. . Fort Worth, Texas
Yucca Petroleum Co. Amarillo, Texas
Zephyr Oil Co. Tyler, Texas
Source: U.S.A. Oil Industry Directory. 13th Ed. Tulsa, Oklahoma,
The Petroleum Publishing Company, 1974.
114
-------
APPENDIX D
MATERIALS FOR DRILLING FLUID SYSTEMS
115
-------
Table 0-1. MATERIALS FOR DRILLING FLUID SYSTEMS
Fresh Water Muds
Product Trade Name
Ala-Clay
Al-Gel
Ala-Lig
Ala-Phos
Ala-Tan
Ala-Thin
Alamo CMC
Alamo Quebracho
A. C. Quebracho
Anhydrox
Aid ay
Altan
Altan Pure
Alpine Lignite
Alpine Graphite
AP-25, AP-44
Alkatan
Aquagel
Atlas Gel
Atlas Lig
Barafos
Barium Carbonate
Barium Carbonate
Barium Carbonate
Baroco
Benex
Bicarb, of Soda
Caustic Soda
Carbonox
Control gel
Caso
Control M-D
Control tan
Controlcal
Cellex
Control old
Control sol
C-M-C
Cronox 211
Cypan
Caltrol
Calcium Chloride
Dowcide G
Driscose (Sev. Grades)
Oakol i te
Emulsifier SMB
Emulsite
E P Mudlube
Floxit
Graphite
Green Band
Gypsum
High Yield
Hydrogel
Hexaphos
Hydropel
Hydrocarb
Hydrotan
H.Q.M. Starch
Impermex
Impermex Preservative
Kero-X
Kw1k-Thik
Kemical
Kembreak
Kylo
Description
Blended sodium montmorillinite
and calcium mont.
Sodium montmorillinite
Caustic ligm'n
Sodium tetraphosphate
Caustic tannin
Mined lignite
Sodium carboxymethyl-cellulose
Quebracho extract
Quebracho-lignite compound
Barium carbonate
Sub-bentonite
Quebracho mixture
Pure quebracho
Mined lignite
Graphite
Caustic tannin
Caustic quebracho
Wyoming bentonite
Wyoming bentonite
Lignitic compound
Sodium tetraphosphate
Barium carbonate
Barium carbonate
Barium carbonate
Sub-bentonite
Sodium polyacrylate
Bicarbonate of soda
Sodium hydroxide
Organic thinner
Bentonite
Potassium stearate
Drilling detergent
Lignite
Calcium lignosulfonate
Sodium carboxymethyl-cellulose
Pregelatinized starch
Nonionic surfactant
Sodium carboxymethyl-cellulose
Fresh water corrosion inhibitor
Sodium polyacrylate
Calcium chloride
Calcium chloride
Bactericide
Sodium carboxymethyl-cellulose
Processed lignite
Inorganic emulsifier
Caustic lignite
Extreme pressure lubricant
Polyelectrolyte
Graphite lubricant
Sub-bentonite
Gypsum
Sub-bentonite
Bentonite
Phosphate
Emulsified asphalt
Caustic carbonox
Caustic tannin
Grain-based starch
Pregelatinized starch
Formaldehyde compound
Defoaming agent
Extra high-yield bentonite
Quick lime
Calcium lignosulfonate
Sodium polyacrylate
116
Maker or Distributor
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lurcher Co.
Baroid Div. National
Lead Co.
Alpine Mud Service
Alpine Mud Service
Alpine Mud Service
Alpine Mud Service
Alpine Mud Service
Alpine Mud Service
Magcobar
Baroid Div. National Lead Co.
Atlas Mud Company
Atlas Mud Company
Baroid Div. National Lead Co.
Magcobar
Milwhite Mud Sales Company
Mud Control Laboratories
Baroid Div. National Lead Co.
1
1
1
Baroid Div. National Lead Co.
Mud Control Laboratories
Mud Control Laboratories
Mud Control Laboratories
Mud Control Laboratories
Mud Control Laboratories
Baroid Div. National Lead Co.
Mud Control Laboratories
Mud Control Laboratories
1
United Engineering Corp.
1
Milwhite Mud Sales Co.
1
1
1
1
Baroid Div. National Lead Co.
Magcobar
Baroid Div. National Lead Co.
Magcobar
1
Milwhite Mud Sales Corp.
1
Magcobar
Brown Mud Co.
1
1
Baroid Div. National Lead Co.
Baroid Div. National Lead Co.
1
Baroid Div. National Lead Co.
Baroid Div. National Lead Co,
Baroid Div. National Lead Co.
Magcobar
1
Marathon Chemical Corp.
1
-------
Table 0-1 (Continued). MATERIALS FOR DRILLING FLUID SYSTEMS
Fresh Hater Muds (Cont.)
Product Trade Name
Llgco
L1me
Lube-Flo
Lubri-Film
Lignox
Llg-No-Sol
Maccogel
Kagcogel
Magcophos
Me Quebracho
May Gel
.May Clay
Haylig
Maystarch
May col
Maco-Hex, Maccoflos
Macco-Lig
Mikol Starch
Mil gel
Mil Graphite
Mil starch
Mil Flo
Mud-Bac
Mud Floe
Mil-Natan 1-2
Mil Quebracho
My-Lo-Jel
Palcotan
Palcotan 905
Pel tex
P-95
Polytone
Pyro, Anhydrous
Paraformaldehyde
Preservative
Phosphate
Q8T
Q-Broxin
Q-X Quebracho
Quebracho
Qualex
Quick-Gel
Ray Flo
RD 111
Ranger Pure Quebracho
Sapp
Spersene
Shale-Ban
Soda Ash
Sodium Bichromate
Sol tex
Super-Col
Superllgco
Shale-Rez
Sodaphos
Super ben
Superyield
Super Quebracho
Super Thin
Super Starch
Smentox
Tannex
Tanco
Tannathin
Tower-Gel
Treat
TSPP
T-8
Uni-Cal
Uni-Gel
Descri pti on
Maker or Distributor
Mineral lignite
Calcium hydroxide
Ground gilsonite
Extreme pressure lubricant
Calcium lignosulfonate
Modified lignosulfates
Wyoming bentonite
Uyonring bentonite
Sodium tetraphosphate
Quebracho
Wyoming bentonite
Sub-bentonite
Mineral lignite
Pregelatinized starch
Calcium chloride
Complex .phosphates
Mineral lignite
Pregelatinized starch
Wyoming bentonite
Graphi te
Pregelatinized starch
Modified polyflavinoid Comp,
TrisNitro (bactericide)
Flocculant.
Caustic quebracho
Quebracho (pure)
Pregelatinized starch
Lignosulfonate
Redwood bark extract
Modified lignosulfonate
California clay
Treated lignite
Pyrophosphate
Paraformaldehyde
Complex phosphates
Quebracho-based thinner
Ferrochrome lignosulfonate
Quebracho compound
Quebracho
Sodium carboxymethyl-cellulose
Extra high yield bentonite
Hemlock extract
Processes lignosulfonate
Pure Quebracho
Sodium acid pyrophosphate
Chrome lignosulfonate
Shale control compound
Soda ash
Sodium bichromate
Mud lubricant
Extra high yield bentonite
Caustic lignite
High pressure lubricant
Phosphate
Wyoming bentonite
Sub-bentonite
Quebracho mixture
Mineral lignite
Pregelatinized starch
Cement contamination treating
agent
Quebracho compound
Quebracho compound
Lignite
Wyoming bentonite
Causticized lignite
Tetra sodium pyrophosphate
Shale control mud
Modified alkyl aryl sulfonate
Wyoming bentonite
117
Milwhite Mud Sales Co.
1
1
Milwhite Mud Sales Co.
Baroid Div. National Lead Co.
Alpine Mud Service
Macco Corp.
Magcobar
Magcobar
Magcobar
May Brothers, Inc.
May Brothers, Inc.
May Brothers, Inc.
May Brothers, Inc.
May Brothers, Inc.
Macco Corp.
Macco Corp.
1
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
1
Mud Control Laboratories
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Magcobar
1
1
Alamo Lumber Co.
Macco Corp.
1
1
1
1
Mud Control Laboratories
Baroid Div. National Lead Co.
Magcobar
1
1
Baroid Div. National Lead Co.
1
1
May Brothers, Inc.
1
Magcobar
Baroid Div. National Lead Co.
1
1
1
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Brown Mud Co.
1
Superbar Sales
Superbar Sales
Superbar Sales
Superbar Sales
Superbar Sales
Baroid Div. National Lead Co.
Baroid Oiv. National Lead Co.
Milwhite Mud Sales Co.
Magcobar
Black Hills Bentonite
Atlas Mud Co.
1
Magcobar
Milwhite Mud Sales Co.
United Engineering Corp.
-------
Table 0-1 (Continued). MATERIALS FOR DRILLING FLUID SYSTEMS
Fresh Water Muds (Cont.)
Product Trade Name
Viz-Thin
Workover Clay
Wyo-Jel 200
X-Cor
XP-20
Description
Lignite pitch
Low yield workover clay
Bentoni te
Corrosion inhibitor
Chrome lignite
Maker or Distributor
1
Milwhite Mud Sales Co.
Archer-Daniels-Midland
Baroid Div. National Lead Co.
Magcobar
Salt Water Muds
Ala-Sol
Alpine Gel
Atlas Salt Gel
Atlosol S
Attapulgus 150
Ceox
Control foam
Cronox 609
Defoamer No. 23
Emulsifler S
F-S Clay
Florigel
Florigel H-Y
Heviwater
Maysal Clay
Salt
Salt Gel
Salt-Drill
Salt Water Gel
Super Sal
Attapulgite clay
Attapulgite clay
Attapulgite clay
Anionic-noniom'c surfactant
Attapulgite clay
Emulsifier
Defoamer
Corrosion inhibitor
Mud defoamer
Nonionic emulsifier
Attapulgite clay
Attapulgite clay
Attapulgite clay
Mud dispersant
Attapulgite clay
Sodium chloride
Attapulgite clay
Hemlock bark extract
Attapulgite clay
Attapulgite clay
Alamo Lumber Co.
Alpine Mud Service
Atlas Mud Co.
Atlas Chemical Ind.
Min. & Chem. Philipp
Mud Control Laboratories
Mud Control Laboratories
United Engineering Corp.
Baroid Div. National Lead Co.
1
United Engineering Corp.
Floridin Co.
Floridin Co.
Dowel1 Div., Dow Chem.
May Brothers, Inc.
1
Magcobar
1
Milwhite Mud Sales Co.
Superbar Sales
Air/Gas Drilling Materials
Afrox
Atlas Corrosion Inhibitor
100
Atlas Hi -Foam
AM-9
G-2
Gafen Fa-1
Foaming agent •
Polar organic
Nonionic surfactant
Chemical grout
Foaming agent
Foaming agent, fresh to mod.
1
Atlas Mud Co.
Atlas Mud Co.
1
Dowel 1 Div., Dow Chemical
Antara Chemical
Gafen Fa-5
Gafen Fa-7
Halliburton-Sorb
Howco-Suds
Hydro-Lok
Oilfos
OK Liquid
Synfoam
Tergltol NP-35
Tergitol NPX
Tergitol TMN
Well-Foam FS
Well-Foam 3
Well-Foam 917
Well-Parch
salt
Foaming agent, saturated
salt
Foaming agent, fresh and saline
Water absorbing agent
Surfactant, foaming agent
Water Shutoff plastic slurry
Deflocculating agent
Foaming agent
Foaming agent
Nonyl phenyl polyethylene
glycol ether
Nonyl phenyl.polyethylene
glycol ether
Trimethyl nonyl ether of
polyethylene glycol
Foaming agent
Foaming agent
Corrosion inhibitor
Dryin and anti-ballin agent
Antara Chemical
Antara Chemical
Halliburton Co.
Halliburton Co.
Halliburton Co.
1
1
Mud Control Laboratories
1
Well Completions, Inc.
Well Completions, Inc.
Well Completions, Inc.
Well Completions, Inc.
Invert Emulsion and Oil Muds
Atlas-Invert 400
Black Magic Supermix
Black Magic Premlx
•Chemical V
Chemical W
Control Invert
Polyoxyethylene product,
Fluid for high temp, wells
Oil fluid, not high weight
Additive to Black Magic, improve
gel
Treating agent for Black Magic
Oil mud concentrate
118
Atlas Mud Co.
Oil Base, Inc.
Oil Base, Inc.
Oil Base, Inc.
Oil Base, Inc.
Mud Control Laboratories
-------
Table 0-1 (Continued). MATERIALS FOR DRILLING FLUID SYSTEMS
Invert Emulsion and Oil Muds (Cont.)
Product Trade Name
Control Emulsion Oil
Driloil
Driltreat
Duratone
Economagic
E-Z Mul
Gel tone
Hot Lime
Invermul
Invertin
Jel-Oil
Ken Oil
Ken-X Concentrate 1
Ken-X Concentrate 2
Ken-X Concentrate 3
OB Mixflx
OB Gel
Petrotone
Peptomagic
Perm-Base
Perm-Wate
Protectomagic
Protecto-Mul
No-Bloc
Special Additive 47
Special Additive 58
Therm-oil
Description
Nonionic surfactant
Oil mud concentrate
Oil mud stabilizer
Oil mud filtration control agent
Crude-oil based completion fluid
Emulsifier for CaCl solutions in
oil
Oil mud gelling agent
Varifat lime
Oil mud emulsifier
Emulsifier
Oil mud
Oil mud
Invert emulsifier
Stabilizer (weight)
Stabilizer (temperature)
Viscosity reducer
To increase viscosity
Oil mud suspending agent
Crude oil-based fluid
Oil mud concentrate
Calcium carbonate
Oil dispersed asphalt
Concentrate for invert emulsion
Invert emulsion fluid
To improve suspension properties
To improve suspension, gel
properties
Invert emulsion concentrate
Maker or Distributor
Mud Control Laboratories
Baroid Div. National Lead Co.
Baroid Div. National Lead Co.
Baroid Div. National Lead Co.
Oil Base, Inc.
Baroid Div. National Lead Co.
Baroid Div. National Lead Co.
1
Baroid Div. National Lead Co.
Dowell Div., Dow Chemical
Magcobar
1
1
1
1
Oil Base, Inc.
Oil Base, Inc.
Baroid Div. National Le.'id Co.
Oil Base, Inc.
Macco Corp.
Maceo Corp.
Oil Base, Inc.
Magcobar
Magcobar
Oil Base, Inc.
Oil Base, Inc.
Milwhite Mud Sales Co.
Low Solids Muds
Alloid
Anti-Foam
Atlas Emulso 500
Atlas Drilling Surfactant
Atlasfloc
Barafloc
Dril Hex
Driscose
Loloss
Lube Flow
Mac-0-Mul
Mudfloc
Separan
Pregelatinized starch
Capryl alcohol
Non-ionic surfactant
Anionic surfactant
Flocculating gum
Clay flocculant
Guar gum
Sodium carboxymethyl-cellulose
Gum Guar
Shale control
Non-ionic surfactant,
emulsifier
Highly active flocculating
agent
Flocculating agent
Alpine Mud Service
Milwhite Mud Sales Co.
Atlas Mud Co.
Atlas Mud Co.
Atlas Mud Co.
Baroid Div. National Lead Co.
1
1
Baroid Div. National Lead Co.
1
Macco Corp.
Mud Control Laboratories
Milwhite Mud Sales Co.
Surface Active Agents
Aluminum Stearate
Atlas Drilling Surfactant
100
Atlas Drilling Surfactant
200
Atlas Drilling Surfactant
300
Atlas Emulso 500
Atlosol
Ceox
Con Det
Control M-D
Control Emulsion Oil
Control Flow
Control sol
Aluminum s tea rate
Anionic surface active
emulsifier
Petroleum sulfonate
Nonionic surfactant
Nonionic surfactant
Mixed esters
Soluble oil-type surfactant
Anionic detergent
Low solids mud additive
Anionic surface active.
emulsifier
Oil-soluble surfactant
Nonionic surfactant and
emulsifier ,
119
i
Atlas Mud Co.
Atlas Mud Co.
Atlas Mud Co.
Atlas Mud Co.
1
Mud Control Laboratories
Baroid Div. National Lead Co.
Mud Control Laboratories
Mud Control Laboratories
Mud Control Laboratories
Mud Control Laboratories
-------
Table D-l (Continued). MATERIALS FOR DRILLING FLUID SYSTEMS
Surface Active Agents (Cont.)
Product Trade Name
D-D
Drilling Milk
Drill Lube
DME
DMS
Emulsifier F
Emulsifier S
Maco-Mul
Maco-Lube
Magconate
Mil white M-D
Mi 1-01 ox
Olox
Santomerse
Seeco-Mul
Trimulso
White Magic
Description
Mud detergent
0/W emulsifier
Surfactant, EP lubricant
For compounding surfactant muds
For compounding surfactant muds
Nonionic surfactant
Nonionic surfactant
Nonionic surfactant, emulsifier
Surfactant, EP lubricant
Petroleum sulfonate
Low-solids mud additive
Vegetable oil soap
Neutralized soap
Sodium alkyl aryl sulfonate
Vegetable oil soap
Emulsifier
Non-fluorescing emulsifier
Maker or Distributor
Magcobar
Magcobar
1
1
1
1
1
Macco Corp.
Macco Corp.
Magcobar
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
1
1
1
Baroid Div. National Lead Co.
Oil Base, Inc.
Weighting Materials
Ala-Bar
Albar
Atlas Bar
Baroid
Control bar
Dri-Job
Drilling Bar
G-7 Super Weight
Galena
Invertiri Wate
Maccowate
Magcobar
Maybar
Mil-Bar
OB Hevywate
OB Wate
Superbar
Uni-Bar
Yuba Barite
Barite (barium sulfate)
Barite
Barite
Bari te
Barite
Low gravity barite
Barite
Iron-arsenic compound
Lead sulfide
Acid-soluble material
Barite
Barite
Barite
Barite
Barite
Calcium carbonate
Bari te
Barite
Barite
Alamo Lumber Co.
Alpine Mud Service
Atlas Mud Co.
Baroid Div. National Lead Co.
Mud Control Laboratories
Macco Corp.
Drilling Mud, Inc.
Magcobar
Baroid Div. National Lead Co.
Dowel 1 Div., Dow Chemical
Macco Corp.
Magcobar
May Brothers
Milwhite Mud Sales Co.
Oil Base, Inc.
Oil Base, Inc.
Superbar Sales
United Engineering Corp.
Yuba Milling Div.
Lost Circulation Additives
Ala-Fiber
Ala-Flake
Ala-Mica
Ala-Plug
Alseal
Atlas Fiber
Atlas Mica
Ala-Shell
Alflake
Alpine Mica
Aspun Fiber
Bark-Seal
Beaver Dam
Bristex
Bristex-Seal
Cel-Flakes
Cell-0-Phane
Cell-0-Seal
Cedar Seal
Cert-N-Ceal
Chek-Loss
Chip-Seal
Control Fiber
Fibrous material
Shredded cellophane flakes
Shredded mica
Graded walnut shells
Cane, wood fiber blend
Sugar cane bagasse
Sized mica
Pecan shells-
Shredded cellophate flakes
Graded mica
Aspen fibers
Shredded tree bark
Ground gilsonite
Hog bristles
Hog bristles and cotton lint
Ground cellophane
Shredded cellophane flakes
Shredded cellophane flakes
Cedar fibers
Delayed action bentonite,
gran. mat.
Sized neoprene rubber
Shredded wood fiber
Fibrous material
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alamo Lumber Co.
Alpine Mud Service
Atlas Mud Co.
Atlas Mud Co.
Alamo Lumber Co.
Alpine Mud Service
Alpind Mud Service
1
Alpine Mud Service
Gibralter Minerals
1
1
United Engineering Corp.
1
Magcobar
1
1
Milwhite Mud Sales Co.
Magcobar
Mud Control Laboratories
120
-------
Table D-l (Continued). MATERIALS FOR DRILLING FLUID SYSTEMS
Lost Circulation Additives (Cont.)
Product Trade Name
Control Wool
Cottonseed Hulls
Chemical W
Chrome Leather
Dick's Mud Seal
Feather Stop
Fiber-Seal
Flbertex
Formaplug
Formaseal
Flaxseal
Hy-Seal
Jel flake
Ko-Seal
King Seal
Krevice Klog
Leather Floe
Leather Seal
Leath-0
Magco-Fiber
Magco-Mica
Masterbridge
Masterplug
Masterseal
Mayfiber
Mayflakes
Maymi ca
Micatex
Mil-Cedar Plug
Mil-Fiber
Mi If lake
Milmica
Mil-Plug
Mil Seal
Mil-Wool
Mud Fiber
Mica
Nut Plug
Oil Patch
Palco Seal
Pheno-Seal
Polyflake
Poly-Plug
Poz-Plug
Plug-Git
Plastic Seal
Rubber Seal
Seal flakes
Silvacel
Stop-It
Strata-Seal
Super Fiber
Super Seal
Super Mica
Superbridge
Tuffernel1
Tuf-Plug
Wall-Nut
Walnut Plug
Wool
Description
Acid-soluble mineral wool
Cottonseed hulls
Agent to form gel pills
Shredded leather
Ground paper
Feathers
Blended fibers
.Cane fibers
Clay-cement
Air blown asphalt
Ground flax shive
Ground paper
Cellophane flakes
Granulated corn cobs
Textile fibers
Drop bags of granular bentonite
Leather fibers
Leather fibers
Leather fibers
Shredded wood fiber
Graded mica
Extra-course almond shells
Shaped rubber
Almond shells
Cane, wood fiber blend
Shredded cellophane flakes
Grade mica
Mica
Cedar wood-fibers
Sugar cane bagasse
Shredded cellophane flakes
Graded mica
Pulverized walnut shells
Wood chips
Fibrous mineral wool
Cane fibers
Sized mica
Ground walnut shells
Ground walnut shells
Processed redwood fibers
Ground plastic
Oil soluble film
Fibers and plastic
Wood chips
Wood fibers
Ground formica
Ground rubber
Fragmented cellulose
Fir and balsum fiber
Cedar wood fibers
Expanded perlite
Cane, wood fibers
Shredded cellophane flakes
Graded mica
Expanded perlite
Walnut shells
Ground walnut shells
Nutshells
Walnut shells
Mineral wool
Maker or Distributor
Mud Control Laboratories
1
Oil Base, Inc.
Alamo Lumber Co.
1
Mil white Mud Sales Co.
Magcbbar
Baroid Div. National Lead Co.
Magcobar
Oil Base, Inc.
Archer-Daniels-Midland
Baroid Div. National Lead Co.
1
Mud Control Laboratories
Alamo Lumber Co.
Baroid Div. National Lead Co.
Magcobar
Baroid Div. National Lead Co.
Milwhite Mud Sales Co.
Magcobar
Magcobar
Masterseal Sales Corp.
Masterseal Sales Corp.
Masterseal Sales Corp.
May Brothers
May Brothers
May Brothers
^Baroid Div. National Lead Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Milwhite Mud Sales Co.
Magcobar
1
Magcobar
Mud Control Laboratories
1
1
Baroid Div. National Lead Co.
Cherokee Laboratories
1
Baroid Div. National Lead Co.
Alamo Lumber Co.
Atlas Mud Co.
Mud Control Laboratories
1
1
1
Superbar Sales
Superbar Sales
Superbar Sales
Mud Control Laboratories
Ma ceo Corp.
1
Baroid Div. National Lead Co.
i
Several distributing companies
Source: Rogers, Walter F., Composition and Properties of Oil Well Drilling Fluids
Houston, Texas, Gulf Publishing Company, 1963.
121
-------
. P.tPOHl NO.
EPA-600/2-77-023b
Tf-CHNICAL RCl'OHT DATA
(I'll a\f rca-l lua.~.ifhoni on tin' AC' ' nt Itcjnrr cuinptctingi ^
— J2'' : 3. w.Cif'
.. TITLE A\D SUU7 ITI.E
Industrial Process Profiles fcr Environmental Use:
Chapter 2. Oil and Gas Production Industry
5. Rf-POHT DATE-
February 1977
6. PEI-iFORMJNG O H GA XlTZATfo N CODE
GlynJa E. WilXins
7Pf RFQhM~INU OHGANI.JA1IGN NAME AND ADOmiSS
Radian Corporation
8500 Shoal Creek Boulevard
P.O. Box 99)»8
Austin, Texas 78766
12. SPONSORING Ant'NCY IJAMf /-NL' AOOFU.SS
Industrial Er;vi rorir/intnL Research Laboratory
Office of Research and Development
U.S EiTVIRONM'^rAL PROTF.CT'I ON AGENCY
Cincrl-.-ir-ritl, Ohio V;xf,8
16. SUPPLKVU N I A»Y NO I I S
IINT'S ACCtOSIOr*NO.
8. PERFORMING ORGANIZATION HM'C'HT NO.
10. 1'HOCjflAM ELLMti'JT NO.
3AB015
II.'CONI HACT/GRA'NT NO.
68-02-13.19, Task 3^1 &r;;i >:
13. I'YHt OF RLf'ORT AMD PLRIOD CCVi H
Initial.: 6/7.5=11/16... ......
14. SF'ONSORING AGtNCY CODE
KPA/600/12
i 0
C. ABS1 RACT
The catalog of Industrial Process Profiles for Environmental Use was developed as
aid ir, defining the environmental Jr::pacts of ipr.v.ptri al activity in the United .f-l.
Entries for ?ach industry are in consistent for.T.aT, and form separate chapters cf
study. Tha oil ^.nd gas production industry is involved in locatinr and ret.j-ievi'n
oil and gas from underground formations and preparing the veil streams for use by
ccnsraers. The industry is discussed in five segments: (l) Exploration and ?:^
Preparation, (2) Drilling, (3) Crude Processing, (10 Natural Gas Processing, and
(5) Secondary &nd Tertiary Recovery. Tv/o process flow .sheets and tv?nty pi-occss
Oescriutions have teen prepared to characterize the industry. Within each proces
description ava.ilab.Le data have been presented on input materials, operating para.
utility requirements and vaste streams. Data related to the subject matter, incl
ing company and prod-act dats.,' are included as appendices.
•~r\
ii.--
-che
.rr.eter
ud-
7.
.1.
fJhECniPVORS
KEY WORDS ANO DOCUr.'.ENT At-.'ALYSIS
IfeRS/OHEN ENDED TERMS
Pollution
Oil Production
Ges Production
i Exploration
}Oil Drilling
Crude 0.11 rroccssing
Natural Gas Pro:-nt
Solid Waste Cun'-rol
T;nviror:riitntal li pact
H; 'V; I '-;•>! ."'' Cl./.SS ;•;/ / H, parti
l>;?n.'if-r.i fied
i
COSATI l-ii'ld 'i<
07C
11H
13B
21D
il, NO OF I-
130
i2.i'nlCE.
V/2
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