EPA 908/4-77-006
EMISSIONS OF PRODUCING
OIL AND GAS WELLS
NOVEMBER 1977
FINAL REPORT
ENVIRONMENTAL PROTECTION AGENCY
ROCKY MOUNTAIN PRAIRIE REGION
DENVER, COLORADO 80239
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a~t
-006
EMISSIONS OF
PRODUCING OIL AND GAS WELLS
November, 1977
Submitted to:
Terry Thoem
Environmental Protection Agency
Region VIII
Denver, Colorado
Contract No. 68-01-3700
Prepared by:
Radian Staff
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ABSTRACT
This report describes the methods and results of a
program to assess the emissions of oil and gas wells. The impact
of the emissions was determined through a combination of source
testing for fugitive emissions, ambient air quality monitoring,
and meteorological monitoring. Fugitive emissions were detected
that ranged from minute leaks to jet-type leaks. Ambient monitor-
ing measured periodically high levels of hydrogen sulfide and
hydrocarbons at the oil field. Emission rates and emission
factors were determined for each of the wells sampled.
This report has been reviewed by EPA, Region
VIII, and approved for publication. Approval does
not signify that the contents necessarily reflect
the views and policies of the Environmental Protection
Agency, nor does mention of trade names or commercial
products constitute endorsement or recommendation
for use.
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PREFACE
This document describes a study of the emissions from
an oil and gas field and was prepared under EPA Contract No.
68-01-3700.
The study was conducted under the direction of Mr.
Terry L. Thoem, Project Officer, Environmental Protection Agency,
Region VIII, Denver, Colorado.
Acknowledgement is given to Chevron Oil Company whose
full cooperation greatly facilitated the field work. Mr. William
Jackson and Mr. Roy Chambers of Chevron contributed significantly
to the program in providing advice and assistance.
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TABLE OF CONTENTS
PAGE
I. INTRODUCTION 1
II. SITE DESCRIPTION 3
III . EXPERIMENTAL 17
A. Ambient Air Monitoring 17
B. Fugitive Emission Sampling 22
IV. RESULTS 32
A. Fugitive Emission Sampling 32
B. Air Quality Results 39
V. DISCUSSION 63
VI. SUMMARY 75
Appendix A - Meteorological Summaries
Appendix B - Tract C-b Air Quality Data
Appendix C - Tract U-a, U-b Air Quality Data
Appendix D - Tract C-a Air Quality Data
111
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LIST OF TABLES
TABLE PAGE
II-l Production of Crude Oil, 1973 Through 1975 8
II-2 Basic Data Rangely Weber Sand Unit
Rangely Field, Colorado 9
III-l Sample Documentation Form
Unit Information 24
IV-1 Leak Survey 34
IV-2 Variations in Leak Rates 35
IV-3 Emission Data 37
IV-4 Hydrocarbon Analyses Results 38
IV-5 Sulfur Analyses 40
IV-6 Diurnal Variation of Ozone (ppb)
Trailer 034, Well 9-X, 11/33/76-
12/01/76 42
IV-7 Diurnal Variation of Hydrogen Sulfide
(ppb) Trailer 033, Well 9-X,
11/22/76 - 12/01/76 43
IV-8 Diurnal Variation of Hydrogen Sulfide
(ppb) Trailer 034, Well 9-X,
11/22/76 - 12/1/76 44
IV-9 Diurnal Variation of Total Hydrocarbons
(ppm) Trailer 033, Well 9-X,
11/22/76 - 12/02/76 45
IV-10 Diurnal Variation of Methane (ppm)
Trailer 033, Well 9-X, 11/22/76 -
12/02/76 46
IV-11 Diurnal Variation of Wind Speed (mph)
Trailer 033 Well 9-X, 11/22/76 -
12/01/76 47
IV-12 Diurnal Variation of Wind Speed (mph)
Trailer 034, Well 9-X, 11/22/76 -
12/01/76 48
IV
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LIST OF TABLES
(Continued)
TABLE PAGE
IV-13 Diurnal Variation of Wind Direction,
Trailer 034, Well 9-X, 11/22/76 -
12/01/76 49
IV-14 Diurnal Variation of Ozone (ppb)
Trailer 034, Collection Station,
12/2/76 - 12/11/76 51
IV-15 Diurnal Variation of Hydrogen
Sulfide (ppb) Trailer 033, Collection
Station, 12/2/76-12/11/76 52
IV-16 Diurnal Variation of Hydrogen Sulfide
(ppb) Trailer 034, Collection Station
12/2/76 - 12/11/76 53
IV-17 Diurnal Variation of Total Hydrocarbons
(ppm) Trailer 033, Collection Station
12/2/76 - 12/11/76 54
IV-18 Diurnal Variation of Methane (ppm)
Trailer 033, Collection Station
12/2/76 - 12/11/76 55
IV-19 Diurnal Variation of Total Hydrocarbons
(ppm) Trailer 034, Collection Station
12/2/76 - 12/11/76 56
IV-20 Diurnal Variation of Methane (ppm)
Trailer 034, Collection Station
12/2/76 - 12/11/76 57
IV-21 Diurnal Variation of Wind Speed (mph)
Trailer 033, Collection Station
12/2/76 - 12/11/76 58
IV-22 Diurnal Variation of Wind Speed (mph)
Trailer 034, Collection Station
12/2/76 - 12/11/76 59
IV-23 Diurnal Variation of Wind Direction
Trailer 033, Collection Station
12/2/76 - 12/11/76 60
IV-24 Diurnal Variation of Wind Direction
Trailer 034, Collection Station
12/2/76 - 12/11/76 61
v
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LIST OF TABLES
(Continued)
TABLE FAGE
V-l Diurnal Variation of Difference in H2S
Levels Between Station 033 and 034
12/2/76 - 12/11/76 67
V-2 Diurnal Variation of Differences in THC
Measurements at 033 and 034
12/2/76 - 12/11/76 69
V-3 Monthly Summary of Air Quality Parameters
Rio Blanco Oil Shale Project 70
V-4 Monthly Summary of Air Quality Parameters
Rio Blanco Oil Shale Project 71
V-5 Monthly Summary of Air Quality Parameters
White River Shale Project 72
V-6 Monthly Summaries of Air Quality Parameters
Tract C-b Oil Shale Project November and
December, 1976 73
VI
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LIST OF FIGURES
FIGURE PAGE
II-l Location of Rangely Weber Sand Field 4
II-2 Rangely Field 5
II-3 Rod Pump 6
II-4 Submersible Pump 7
II-5 Location of Stations at Well 9-X 11
II-6 View of Well 9-X and Monitoring Station 12
II-7 Well 9-X 12
II-8 Collection Station 14
II-9 View of Submersible Pump Well 6 15
11-10 Location of Monitors at Collection Station 16
III-l Cutaway View of Monitoring Trailer 18
III-2 Examples of Units Sampled During Study 25
III-3 Leak Rate Determination 26
III-4 Leaking Value Bagged for Sampling 27
III-5 Sample Calibration Curve for Gas
Chromatograph 30
IV-1 Ambient THC and CEk Concentrations at
Station 034 Near Well 9-X 50
IV-2 Ambient THC and CH4 Concentration at
Station 033 East of Collection Station 62
IV-3 Ambient THC and CH^ Concentrations at
Station 034 West of Collection Station 62
V-l Difference in H2S Levels at Stations 033
and 034 Near Collection Station 68
VI1
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I. INTRODUCTION
This report describes the methods and results of a
program to assess the air quality impacts of producing oil and
gas wells through a combination of source testing, ambient air
quality monitoring, and meteorological monitoring.
Pollutants emitted into the ambient air are either
controlled emissions or fugitive leaks. The number of controlled
emissions in an oil or gas field is not extensive and the primary
sources of emissions are leaks from which fugitive emissions
are released without control of flow or direction. Many poten-
tial sites for fugitive emissions exist in the vicinity of an
oil or gas well. Types of installations, quality of materials,
production methods, and quality of maintenance are important
factors in determining the rate of fugitive emissions, and varia-
tions in these factors can cause emissions to be vastly different
from one well to another.
Since undetected leaks exist in an oil and gas field
and their impact is unknown, this program was undertaken to
determine the magnitude of the problems and the difficulties
associated with conducting such a study. Fugitive emissions
cannot be measured by standard sampling and analytical techniques;
yet, the development of reliable measurement procedures is an
essential prerequisite to the development of strategies for the
control of fugitive emissions. Therefore, two of the primary
objectives of this study were to develop the techniques for
making valid impact assessments of producing oil and gas wells
and identify potential problems in making such measurements and
assessments.
Two techniques were used in conjunction in this study.
One method was to sample the emission of a unit by bagging
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techniques at the point at which the fugitive emission is leaking.
After detecting and observing both gaseous and liquid leaks, the
leak rates were measured or approximated, and the emitted species
analyzed both qualitatively and quantitatively. The other method
was the monitoring of the air quality in the vicinity of the work
unit after the emissions had leaked into the atmosphere.
Section II of this report describes the oil and gas
field studied in this program and the sites chosen for evaluation.
Section III describes the air quality monitoring equipment and
the fugitive-emission sampling techniques. Section IV presents
the sampling and monitoring results. Section V discusses these
results, and a summary is provided in Section VI. The appendices
include meteorological summaries and ambient air quality data
from other nearby monitoring networks.
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II. SITE DESCRIPTION
The sampling and monitoring program was conducted at
Rangely Weber Sand Unit in Rangely, Colorado. Criteria for se-
lecting this field as the test site were location and accessibility,
availability, general operating procedures, type of field, size,
and stage of development.
The Rangely oil field is located in an environment
in northwestern Colorado where there are no significant man-made
sources of emissions. The location of the site with respect to
the federal oil shale tracts is shown in Figure II-l. The re-
lative locations of these sites are shown because each federal
tract has active ambient air monitoring stations. These monitor-
ing stations are a source of background data on the existing air
quality surrounding the oil field.
The Rangely field is an oil and gas field employing
water injection techniques to enhance oil recovery. A map of
the field is shown in Figure II-2. The present production rate
is :
Oil - 59,000 B/D
Water - 227,000 B/D
Gas - 6,000 MCF/D
The Rangely field produces approximately 50 percent of the oil
in Colorado and was ranked nineteenth in production in 1975 and
nineteenth in reserves in 1974 in the United States. Table II-l
compares the production of the Rangely field to the productions
of Colorado, EPA Region VIII, and the United States. The field
uses both submersible electric pumps and the more familiar rod
pumps, shown in Figures II-3 and II-4. Gas engine driven rod
pumps are being phased out as the field becomes fully electrified.
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Basin
.v.>v-.-.':v?x:-J
*.".'o
Area of oil shale deposits
Area of 25 gal./ton or richer
oil shale 10ft. or more thick
Location of federal
lease tracts
FIGURE II-l. LOCATION OF RANGELY WEBER SAND FIELD
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Sampling Locations
g^!i~"
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~J"I -I"
',r-^-j
FIGURE II-2
RANGELY FIELD
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PUMPING UNIT
EL
-PUMP
FIGURE II-3. ROD PUMP
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o
PUMP
-SEAL SECTION
MOTOR
FIGURE II-4. SUBMERSIBLE PUMP
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TABLE II-l
Production
Area
Rangely Field
Colorado
EPA Region VIII
United States
PRODUCTION
(millions
1973
19.378
36.590
266.5
3360.9
OF CRUDE OIL
of barrels )
Production
197^
20.29^
37-508
271.6
3202.6
1975
38.089
3056.8
The Rangely field has been under waterflood since
October, 1958. Waterflooding is a recovery technique designed
to increase oil recovery and/or profitability of producing oil.
The production of oil arid gas from a reservoir is accompanied by
reductions in reservoir pressure which create decreases in pro-
duction rate capability. In waterflooding, water is injected
into the reservoir at a pressure higher than the pressure in the
vicinity of injection. The injected water increases reservoir
pressure and displaces reservoir fluids toward areas of lower
pressure, normally the areas surrounding producing wells.
The Rangely injection water consists of White River water
and produced water which is re-injected. The total daily injec-
tion rate is approximately 304,000 barrels per day. White River
water accounts for 77,000 barrels per day and is considered to be
consumed water. Other pertinent data for the Rangeley field are
presented in Table II-2.
Two locations were chosen for tandem siting of the
ambient air monitoring stations. These sites were chosen so that
two stations at each location could be used to obtain simultaneous
upwind and downwind concentrations. In this way the contribution
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TABLE II-2
BASIC DATA
RANGELY WEBER SAND UNIT
RANGELY FIELD, COLORADO
Producing Formation
Average Producing Depth
Average Reservoir Thickness
Productive Area
Original Oil in Place
Estimated Ultimate Oil Recovery
Cumulative Oil Production*
Cumulative Water Injection*
Original Average Reservoir Pressure
Present Average Reservoir Pressure*
Date Unitized
Injection Patterns
Injection fluids
Date Injection Commenced
Weber
6500 ft.
700 ft.
19,153 acres
1.6 Billion Bbls.
723 Million Bbls.
510,255,473 Bbls.
1,090,295,217 Bbls.
2750 psig
1995 psig
October 1, 1957
Peripheral, 5 Spot,
Diagonal & Crestal
line drive
Water Gas
Water: Pilot phase
12/57, Full scale 10/58
Gas: Commenced 11/50,
Terminated 5/69
WAG: Pilot Phase 1/72
Terminated 8/73
Number of Wells
Oil Producers*
Water Injectors*
Gas Injectors*
Total*
*Data as of July 1, 1975
Active
324
193
0
Inactive
36
38
0
P & A
6
49
0
Total
366
280
0
517
74
55
646
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of a particular source could hopefully be obtained. The factors
that were used in selecting the actual sites were:
1) Types of wells or units in monitoring area,
2) Location with respect to the rest of the
field,
3) Potential sources of emissions in the area,
4) Access and terrain, and
5) Availability of power.
Two sites were chosen on the perimeter of the field in ex-
pectation that the proper wind direction would give minimum
background levels at the station nearest the perimeter. The
northwest site was the most successful in this respect and pro-
vided the most accurate assessment of the contribution of the
oil and gas field.
The initial portion of the testing was conducted at
Pan American Well 9-X on the southeastern edge of the oil and
gas field. Station 034 was sited north of the well and Station
033 was sited south of the well. The locations of the monitoring
trailers with respect to the well are shown in Figure II-5.
Fugitive emission sampling at Well 9-X was conducted simultaneous-
ly with the ambient monitoring. Figure II-6 shows the location
of Well 9-X with respect to one of the monitoring stations.
Well 9-X was a gas engine rod pump well; another view of the
well is shown in Figure II-7.
The latter half of the testing was conducted at
Collection Station Number 1 in the northwestern portion of the
10
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1 INCH = 1000 FEET
WELL M SHUT-IN INJECTION WELL
WATER INJECTION O INJECTOR
WELL
PAN AMERICAN ET AL
FIGURE II-5
LOCATION OF STATIONS AT WELL 9-X
11
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FIGURE II-6
VIEW OF WELL 9-X AND MONITORING STATION
FIGURE 11-7
WELL 9-X
12
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field. Fluids produced from the Rangely wells are mixtures of
oil, gas, and water which must be separated. Collection sta-
tions are surface separation units that serve a number of wells.'
A diagram of a collection station is given in Figure II-8.
Trailer 034 was located west of the collection station
near the perimeter of the field where there would be little
influence from the field due to prevailing wind conditions.
Trailer 033 was sited east of the collection station near Pan
American Well 6, a submersible pump. A view of Well 6 is shown
in Figure II-9. The latter site was subject to the influence
of the collection station and several producing wells. The com-
bination of monitoring sites during this phase helps to assess
the contribution of the oil and gas field on air quality. The
locations of the monitoring trailers with respect to the col-
lection station is shown in Figure 11-10.
13
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HEADER
OIL/GAS/WATER MIXTURE
FROM WELLS
TO INJECTION
TO PIPE LINE
GAS TO GAS PLANT
GAS TO GAS PLANT
METER
FIGURE II-8
COLLECTION STATION
14
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FIGURE II-9
VIEW OF SUBMERSIBLE PUMP WELL 6
15
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FIGURE II-9
VIEW OF SUBMERSIBLE PUMP WELL 6
15
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FIGURE II-9
VIEW OF SUBMERSIBLE PUMP WELL 6
15
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WELL
WATER INJECTION WELL
SHUT-IN INJECTION WELL
r
#- *
COLLECTION
STATION
1 INCH = 1000 FEET
-N-
FIGURE 11-10
LOCATION OF MONITORS AT COLLECTION STATION
16
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III. EXPERIMENTAL
This section describes the procedures and equipment
used for both the ambient air monitoring and the fugitive emis-
sion sampling.
A. Ambient Air Monitoring
Ambient air monitoring techniques were employed to
determine the air quality in the immediate vicinity of the field
sources. The ambient air monitoring stations were operated
adjacent to Well 9-X from November 22 to December 1, 1976. The
stations were then moved to the vicinity of Collection Station
Number 1 and operated from December 1 to December 11, 1976.
For the ambient air quality monitoring portion of the
study, Radian used two of its continuous monitoring systems
housed in a twenty-six foot steel van. This van, pictured in
Figure III-l, provides a stable environment for the computer-
controlled data acquisition system and air quality instrumenta-
tion. Two monitoring systems were provided for each site and
monitored sulfur dioxide, hydrogen sulfide, total hydrocarbons,
methane, carbon monoxide, oxides of nitrogen, ozone, wind speed,
wind direction, and temperature. Particulates were not measured
during this study.
Air Quality Instrumentation
The air quality analyzers were multi-point calibrated
at the beginning of the program and zeroed and spanned daily.
Nitrogen oxides were measured with a Meloy Model NA520
analyzer. This dual-channel analyzer is based on the chemilumine-
sent principle, and continuously monitors both NOX and NO. A
17
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\
AHornnLp Ixinition
A/C Base
(Shop Designed)
TRAILER INTERIOR CUTAWAY VIEWS
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subtraction circuit in the instrument provides a continuous N02
output, but is not used in Radian's system. N02 is calculated
by the computer by subtracting the NO value from the N0x value,
thus avoiding any drift which might occur in the N02 output of
the instrument. This instrument was multi-point calibrated
with NBS span gas using a dilution system. Span checks were
made with a NO in nitrogen cylinder referenced to NBS. The
NA520 has a minimum detectable sensitivity of 5 ppb (parts per
billion) and a linearity of +1 percent.
Both sulfur dioxide and hydrogen sulfide were measured
with Meloy Model SA185 sulfur analyzers. The hydrogen sulfide
analyzer uses a Meloy Model SOX-1 sulfur dioxide scrubber and
the sulfur dioxide analyzer uses a Meloy hydrogen sulfide scrub-
ber. The Model SA185 is a continuous analyzer, and utilizes the
flame photometric principle of operation. The minimum detectable
sensitivity is 5 ppb, and the linearity is +1%. S02 permeation
tubes calibrated by the NBS were used to calibrate the analyzers.
The Meloy Model OA350-2R Ozone Analyzer was used to
monitor ozone. This continuous analyzer is based on the chemi-
luminescent principle and is EPA approved as an equivalent method
for ozone. The analyzer was calibrated by the NBKI method as
specified by the Federal Register, and its internal span source
was verified for span checks. The minimum detectable sensitivity
of this analyzer is 0.5 ppb, and the linearity is +170.
Total hydrocarbons, methane, and carbon monoxide were
monitored with a Bendix Model 8200 gas chromatograph analyzer.
This instrument uses a flame ionization detector and has a
minimum detectable sensitivity of 5 ppb for all three components.
The Model 8200 works on a five-minute cycle, i.e., one air
sample is analyzed every five minutes, and the result is dis-
played for five minutes via a sample and hold circuit. The
19
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Model 8200 was calibrated with undiluted span gas obtained from
Scott Environmental Technology. This span gas contained methane
and carbon monoxide in air; methane was used to calibrate both
the THC and the CH^ channels. A cylinder of CO in nitrogen ob-
tained from NBS was used as a further check on the CO channel.
The air sample was drawn in through a glass cane and
manifold supplied by the Ace Glass Company. The system had a
25 mm diameter, and a constant air flow through the system was
provided by an air pump rated at 60 cfm at 0" head pressure.
The manifold has sampling ports to which 1/4" Teflon lines to
the instrument were connected. All joints in the sampling system
were secured by 0-ring compression fittings. The manifold was
contained in a heated (100 F) chamber to prevent condensation
of moisture from the atmosphere.
Meteorological Instrumentation
The meteorological instrumentation consisted of a low
threshold cup anemometer and light weight wind vane, a humidity
sensor, and a temperature sensor. The temperature sensor was
mounted inside a radiation shield, the Model TT-102 Radiation
Shield for Temperature Sensing Devices by Texas Electronics.
All meteorological instrumentation was mounted atop a 10-meter
retractable tower.
The anemometer was the Model W103 Cup Anemometer
by Weather Measure. This is a high response, low threshold
wind system. Sealed and shielded stainless steel permanently
lubricated bearings and stainless steel precision ground shafts
are used exclusively. The anemometer has an accuracy of +170
or .15 miles per hour, whichever is greater. The threshold is
0.6 miles per hour, the distance constant is 5 feet, and the
range is from 0 to 100 miles per hour.
20
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The wind vane was the Model W104-2 Light Weight Vane
by Weather Measure. This vane features a special low den-
sity, high structural strength foam plastic tail coated with a
high density epoxy and bonded to a stainless steel rod. A 1000
ohm, low-torque wire-wound potentiometer, supplied with two
wipers for a 0° to 540° system, is standard. The response
characteristics of the W104-2 are:
Dead Band: 0 degrees
Damping Ratio: 0.4
Distance Constant: 3.5 feet
Threshold: 0.75 miles per hour
Potentiometer Linearity: +0 . 570
Range: 0 to 540°
The humidity sensor was the Model 2013 Remote Reading
Relative Humidity System by Texas Electronics.
Data Acquisition System
The basis of the data acquisition system was a Data
General NOVA 1200 minicomputer. The NOVA, which has a basic
cycle time of 1.2 ysec was equipped with automatic program load
and power fail/automatic restart features. The computer utilized
8K 16-bit words of core memory. Analog-to-digital conversion
was accomplished via an ADC built by Radian Corporation. The
input/output unit for the system was Texas Instrument's KSR
733 keyboard/printer. This teletype provided keyboard entry
and a hard copy printed output. The data were also recorded
on a cassette magnetic tape unit with three drives. The cas-
sette unit is utilized for program storage and loading as well
as recording. Several important functions in the instruments
as well as in the computer and the trailer were monitored by
lights on a System Status Panel. These data lights were written
21
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onto cassette tape to monitor the complete status of the system
every five minutes. Each channel was sampled once every second,
and the values were compiled into five-minute averages.
B. Fugitive Emission Sampling
Producing wells and collection stations were leak
tested for fugitive emissions. If a piece of equipment was
found to have a leak, the leak rate was measured, and the
emission was analyzed for hydrocarbon and sulfur species.
Leak Detection
All units to be sampled were first inspected to
determine if cleaning was necessary. Residue build-up on
valves, flanges, and other types of coupling could have pro-
duced significant background errors in the results which would
have lead to a distorted analysis of the fugitive emission rates.
The two producing wells and various parts of the collection
station were steam cleaned because of the heavy build-up of
residue. The steam cleaning was followed by brushing, applica-
tion of a solvent, and repeated rinsing with water.
Leaks at the various sampling locations were detected
by spraying the units with a pressure sprayer filled with a
soap solution. Leaks produced a bubbling effect at the source
of the leak. This technique is suitable for detecting even
very small leaks. Squeeze bottles of Snoop were also used to
detect leaks.
Leaking units were photographed and documented ac-
cording to the type and size of unit, i.e., (2-inch valve, 6-inch
flange, etc.), location of the leak on the unit (valve stem,
etc.), type of emission (gaseous, liquid), and arbitrary leak
rate. A sample form for documenting the units tested is given
22
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in Table III-l. Figure III-2 shows a number of different types
of units that were leak tested and sampled. The leak rate des-
ignations included 1) jet-type, 2) large, and 3) slow and minute.
These designations will be discussed further.
Sampling Procedures
After a leak had been detected, the leak was bagged,
the leak rate was determined, and a sample was analyzed for
hydrocarbon and sulfur species.
A baggable source was any unit or component which
could be completely enclosed by shaping a flexible sheet of
mylar plastic around it, thus sealing the unit completely from
the atmosphere. This procedure insured the integrity of the
bagged sample by preventing atmospheric contamination. Examples
of baggable units included valves, flanges, and similar equip-
ment that could be enclosed by the sheet. Non-baggable sources
were those units which were of such a size as to make bagging
impractical or units which had minute leaks. The details of
the sample collection are given below.
Once a leak had been found and was determined to be
baggable, the leaking unit was covered with a best fit sheet of
mylar plastic with a thickness of 10 thousandths of an inch and
equipped with a 1/4-inch nylon bulkhead fitting. This bulkhead
fitting served as an injection and/or withdrawal port. Mylar
was chosen as the bagging material because it is relatively inert
and strong. The mylar sheets were wrapped around each unit and
taped to form an air tight shroud.
The leak rate was determined by connecting a 1/4-inch
tee to the bulkhead fitting on the bag. One side of the tee
was connected to a water manometer and the other to a dry gas
23
-------
TABLE III-l
SAMPLE DOCUMENTATION FORM
UNIT INFORMATION
Unit
Inspection Number
Unit Number
Sample Method
Leak Type
Product
Time
Date
Line Temp.
Line Pressure
Location
Remarks
24
-------
Rod Pump Wellhead
Units on Collection
Station Treater
Well Manifold At
Collection Station
FIGURE III-2 EXAMPLES OF UNITS SAMPLED DURING STUDY
25
-------
meter or bubblementer. The manometer measured the pressure drop
across the orifice, and the dry gas meter or bubblementer measured
the volume of gas flowing through it. The volume of gas, as
determined by the dry gas meter, was observed for an elapsed time
of generally one or two minutes. By dividing the volume of gas
in liters by the elapsed time in mintes, an uncorrected leak
rate was determined. This value was then corrected for the
pressure drop using the barometric station pressure. The
manometer reading was converted from inches of water to inches
of mercury and then used in the following equation for the
corrected leak rate:
Leak Rate = (Leak Rate) |B.P. + manometer reading]
corr. 'uncorr 29.92 Hg
The dry gas meter was used to measure large leak rates, but slow
leaks were insufficient to produce a positive gas flow capable
of being measured on the dry gas meter. When the dry gas meter
could not be used, a bubblemeter was substituted for it in the
measuring loop. Figure III-3 shows the arrangement for determin-
ing the leak rate on a unit that has been bagged.
FIGURE III-3
LEAK RATE DETERMINATION
26
-------
Samples of the gaseous emissions were taken from the
bag by introducing a 5.0 cc precision gas sampling syringe
through the bulkhead fitting, flushing the syringe four to
five times with the gaseous contents of the bag, and then fill-
ing the syringe and locking in the contents. The syringe was
equipped with mininert valves so that the syringe could be air-
tight when necessary and so that connection could be made to
the bulkhead and repeatedly sample the gases in the bag without
the puncturing associated with normal syringe samples. After
the valves had been closed and the syringe disconnected, the
closed syringe was immediately taken to the instrument trailer
where the sample gas could be analyzed by the portable AID
chromatograph or the sulfur analyzers. Figure III-A is a close-
up view of a valve that has been bagged and is ready to be
sampled.
FIGURE 111-4
LEAKING VALUE BAGGED FOR SAMPLING
27
-------
Analytical Procedures
Samples of the fugitive emissions were analyzed for
total hydrocarbons, specific hydrocarbon species, sulfur dioxide,
and hydrogen sulfide. The emphasis was upon the quantitative
total hydrocarbon analyses. All analyses required sample dilu-
tion.
All hydrocarbon analyses were performed using an AID
Model 511 Portable Gas Chromatograph. Once a sample had been
collected and carried to the analysis area, it was necessary to
dilute the sample to bring the hydrocarbon concentration down
into a measurable range. A 100:1 dilution was the most suitable
since this dilution would bring a 100% hydrocarbon mixture into
the 1.0% or 10,000 ppm range which was the approximate upper
limit of the standard hydrocarbon gas used to calibrate the
chromatograph. Care had to be taken to use ultra-pure air (<1
ppm THC) for the dilution process because the ambient concentra-
tion of hydrocarbons was sufficient to introduce error. To make
the dilution with the gas syringes, all but 0.5 ml of the sample
gas was forced out of the syringe, then refilled with ultra-pure
air. After locking this mixture in the syringe with the mininert
valve, the plunger was cycled four to five times to thoroughly
mix the contents. Again all but 0.5 ml of this gas was forced
out and the syringe refilled with ultra-pure air and mixed
thoroughly as before. The sample was then ready for analysis.
To analyze the gaseous emissions both quantitatively
and qualitatively, an AID Model 511 gas chromatograph equipped
with a flame ionization detector was used with nitrogen as the
carrier gas and ultra-pure hydrogen and compressed air for the
flame detector. The calibration of the gas chromatograph was
performed daily with standard hydrogen gases. Dilutions of
a span gas were made to approximately 1000, 2000, 4000, 6000, and
28
-------
10,000 ppm concentrations using the same method as the sample
dilution process. The various concentrations of standard gases
were injected into the gas chromatograph using the total hydro-
carbon mode (column bypass) and the peak heights observed.
After measurements, all peak heights were converted to the cor-
responding peak height of a standard attenuation setting. These
peak heights were then used to construct a calibration curve of
peak heights versus hydrocarbon concentration. A sample curve
is shown in Figure III-5. A calibration curve was prepared each
time that analyses were performed. When the diluted gaseous
sample was injected into the GC, its peak response was recorded
and the concentration obtained from the calibration curve.
This value was then corrected for the dilution factor to obtain
the hydrocarbon concentration present in the original gaseous
emission. The GC conditions were kept constant throughout all
testing to obtain consistent results.
The various hydrocarbon species present in the gaseous
emissions were qualitatively analyzed using a column packed
with 80-100 mesh chromosorb 102. Standard samples of methane,
ethane, and propane were injected into the GC, and their reten-
tion times were noted. These species eluted as expected with
the lightest being eluted first. Next samples of the gaseous
emissions were injected and analyzed for the various species.
Hydrogen sulfide and sulfur dioxide were analyzed
for in the fugitive gaseous emissions by using the sulfur analyzers
in the monitoring trailers. Five ml samples were taken from
the bagged sources as previously described and then injected
into six-liter Tedlar bags equipped with screw-type valves.
The Tedlar bags which had been partially filled with ultra-
pure air were then filled to capacity with ultra-pure air and
kneaded to insure proper mixing. The Tedlar bags could then
29
-------
uo
o
140 -
120 -
1000 2000 3000 4000 5000
CONCENTRATION (PPM)
6000
7000
8000
FIGURE III-5. SAMPLE CALIBRATION CURVE FOR GAS CHROMATOGRAPH
-------
be connected to the inlet ports of a sulfur analyzer and
treated as ambient samples. The process was to first attach
the Tedlar bag in series with an H2S scrubber and the sulfur
analyzer which would give the S02 concentration of the gaseous
emission. The scrubber would then be removed and the sample
drawn directly into the analyzer. This step would give the
total sulfur concentration and the H2S concentration could be
derived by difference.
31
-------
IV. RESULTS
A. Fugitive Emission Sampling
Gaseous, gas/liquid, and liquid leaks were detected
in the oil and gas field. The emphasis in this program was
on gaseous leaks which fall into the two categories 'of baggable
and non-baggable leaks.
Not all units leaked at the same rate, so leaks were
divided into sub-groups according to their emissions rates.
Leaks were classified as (1) minute and slow leaks, (2) fast or
large leaks, and (3) jet-type leaks. Slow and minute leaks
were those that were not apparent upon visual inspection but
which caused a "nesting" of bubbles when sprayed with soap solu-
tion. A slow leak would have an emission rate of 0.5 ml or less
per minute. This is an arbitrary unit and serves as an indica-
tor of the range. Slow and minute leaks were arbitrarily
assigned leak rates of 20 ml/hour because such leak rates could
not be precisely determined. Large leaks are defined as leaks
that can be felt with the finger but not of the jet-type. Jet-
type leaks are high-pressure leaks that can be heard or seen.
These leaks are easily characterized.
Most leaks were in the minute-slow category and could
only be detected by the nesting of the soap solution around
the leak. Several jet-type leaks were found, and some could
be heard up to 100 feet away. Most large leaks were around
the cap and stem of various sizes of valves, while most of the
smaller leaks were found in lines around smaller fittings.
A few liquid leaks were observed, and one particular
valve had an intermittent gas/liquid leak. While the gaseous
part of the leak was continuous, the liquid portion was not
32
-------
continuous and would flow at seemingly random intervals. This
liquid leak would flow virogously for periods of eight minutes
or longer and then cease. The liquid leak rate was measured at
18.2 ml/minute. No operating procedure or parameter could be
definitely identified as causing the intermittent liquid leak.
Most liquid leaks noted during the study were so small that they
were only detected by the build-up of residue over a long period
of time.
There were potential sources of emissions in the field
that could not be sampled because of physical dimensions or
structures. These sources included oil storage tanks, water
tanks, oil spills, old mud pits and sumps, etc.
The results of the leak detection findings are given
in Table IV-1. The leak survey identifies the types and numbers
of components that were checked and the range of leak rates that
were observed. The leaking units were found after testing three
electric submersible wells, four rod pump wells, and a collec-
tion station. The percentage of leaking units was 9.7% of the
total checked.
During the leak survey, some leak rates were found to
vary with time. This condition was initially found when testing
the same locations on separate days; also, the leak rates could
vary within short periods of time as indicated by the example in
Table IV-2 for two valves at Well 9-X. However, most leak rates
were constant, and those leak rates that varied did not give
noticeable changes in the concentrations of components.
Fugitive emissions from leaking units were analyzed
for total hydrocarbons, specific hydrocarbons, and sulfur com-
pounds. Emission data, including hydrocarbon content and rates,
are given in Table IV-3. The emission data are the results at
seven producing wells and one collection station.
33
-------
TABLE IV-1
00
Type of No.
Unit
Valves
Flanges
Connectors
(tees , elbows ,
unions , etc . )
Swagelock-
Type
Fittings
TOTAL
, of Units
Checked
156
36
148
31
371
LEAK
No. of Leaks
Detected
25
0
2
9
36
i
SURVEY
Percentage
Leaking
16.0
0
1.4
29.0
9.7
Minimum
Leak Rate
0.020 1/hr.
NA
0.020 ml/hr.
0.020 ml/hr.
--
Maximum
Leak Rate
15.6 1/min.
(936 1/hr.)
NA
0.020 ml/hr.2
0.020 ml/hr.2
--
lThe survey was conducted on three submersible pump wells, four rod pump wells, and
one collection station.
2 All leaks for connectors and Swagelock fittings were slow leaks and were arbitrarily
assigned rates of 20 ml/hr.
-------
TABLE IV-2
VARIATIONS IN LEAK RATES
Number
Site
Well 9-X
Type
Unit
valve
Date
11/22/76
Leak Rate
Time (liters/min.)
1100 2.37
1200 6.18
OJ
Well 9-X
valve
11/22/76
1215
1400
2.18
1.41
-------
The emission results are presented on the basis that
the hydrocarbon content is measured as methane. The emission
rates were calculated on a daily basis from the hydrocarbon com-
position and the leak rate. The production rates for each
well allowed the calculation of an emission factor as well as
an emission rate per well.
Table IV-3 presents data for only a portion of the
collection station. Not all of the possible fugitive emission
sources could be sampled at the collection station, and a com-
plete emission value for the entire station could not be ob-
tained. Several structures such as a large tank open to the air
could not be sampled with the available equipment. There were
also enclosed portions of treaters that had definite fugitive
leaks, but hydrogen sulfide had collected inside these structures,
and it was deemed unsafe to work inside these structures for the
extended periods required to sample and make accurate leak
rate determinations. Ambient samples were taken of the air
inside one of the heaters at the collection station and analyzed
for SC>2 and H2S. The results indicated levels of 4 ppm S02 and
19 ppm H2S.
In addition to total hydrocarbon analyses, the emis-
sions were also analyzed to determine specific hydrocarbon
components. Methane, ethane, propane, and varying amounts of
what were probably isomeric butanes were found in the fugitive
emissions. The butanes and higher molecular weight hydrocarbons
were almost negligible. The exact amount of each species
varied with sampling location. Table IV-4 presents the results
of the specific hydrocarbon analyses; the individual species
are presented as percentages of the total hydrocarbon content
and not of the total stream.
36
-------
u>
Production
Unit
9-x
6
35
36
2
3
7
Sta. 1*
Type- of
Unit
RP
ES
ES
ES
HP
RP
RP
Coll. Sta.
Production
BOPD
23
122
HA
55
32
60
HA
Rate
BWPD
1+5
15^2
HA
1050
25
187
NA
Number of
Leaks
8
1
1
1
1
0
0
2)4
TABLE IV- 3
EMISSION DATA
Percent
Hydrocarbon
87
90
82
78
91*
Emission Rate Emission Factor
(Lbs. Hydrocarbon/Day) (Lb. Hydrocarbon/Barrel Oil)
16.5 0.717
0.007 5-7 x 10~6
23.1*
0.009 1.6 x 10" 5
< 0.0010 3,1 x 10" 5
Hone 0
Hone 0
22.6*
RP - Rod pump well
ES - Electric submersible veil
STA - Collection Station Ho. 1
HA - Hot available
* The emission values for Collection Station Ho. 1 do not include all possible fugitive emissions.
-------
TABLE IV-4
oo
00
HYDROCARBON ANALYSES RESULTS
Leak
Number
1
2
3
9
10
Producing
Unit
Well 9-X
Well 9-X
Well 9-X
Collection
Station
Collection
Station
Type of Percent Total Percent Percent
Unit Hydrocarbon (THC) CH^ C2H6
valve
valve
valve
valve
valve
87
87
87
94
94
54.6 22.6
54.4 21.4
54.9 22.8
46.7 30,8
45.4 30.4
Percent
CsHs
22,8
24.2
22.3
22.5
24.2
NOTE: The individual hydrocarbon components are presented as percentage of the
total hydrocarbon rather than as percentages of the total emission flow.
-------
The fugitive emissions contained both S02 and H2S.
The S02 concentrations varied generally between 3 ppm and 10
ppm. However, H2S concentrations were much higher, ranging
as high as 1200 ppm in the undiluted gaseous emissions. Analy-
ses of the sulfur species in fugitive emissions are presented
in Table IV-5.
B. Air Quality Results
The diurnal variations of the important air quality
and meteorological parameters are summarized in Tables IV-6
through IV-24. Tables are not given for S02 and N0x because
the concentrations were negligible throughout the study. The
S02 was below detectable limits at all times. The ozone con-
centrations were also not significant, which is reasonable
for the time of year when the monitoring occured. If there
was little difference in the parameter measured at each trailer
at one of the sites, only the results of Trailer 034 are given.
This situation was common at Well 9-X where the trailers were
close together and emissions were not sufficient to cause a
significant difference between upwind and downwind stations.
Tables IV-6 through IV-13 give the results of the
monitoring at Well 9-X. Tables IV-14 through IV-24 present
the results of the monitoring near the collection station.
The important air quality results are those for H2S, THC, and
CH^. These parameters were the ones most affected by the oil
and gas operations.
When the stations were located near Well 9-X, there
were no significant differences between the measurements at
the two stations. Traces of hydrogen sulfide were detected,
but there were no values above 19 ppb. Total hydrocarbon
concentrations exceeded 50 ppm for extended periods as noted
39
-------
TABLE IV-5
-P-
o
SULFUR ANALYSES
Leak
Number
1
9
10
11
35
36
Producing
Unit
Well 9-X
Collection
Station
Collection
Station
Collection
Station
Well 37
Well 26
Type of
Unit
valve
valve
valve
valve
valve
valve
S02
(ppm)
7.2
9.6
3.0
8.4
3.6
10.8
H2S
(ppm)
326
529
600
1200
345
1200
-------
in Table IV-9. These high concentrations were mainly due to
nonmethane hydrocarbons. The total hydrocarbon and methane
concentrations are compared in Figure IV-1.
When the two monitoring stations were located near
Collection Station No. 1, there were significant differences in
the H2S and the measurements. Station 034 located upwind and
on the perimeter of the field recorded lower values for both
parameters. Station 034 recorded H2S levels above the minimum
detection sensitivity only 6.670 of the time, while Station 033
recorded levels above this value 53.770 of the time. Station
033 recorded total hydrocarbon concentrations over 50 ppm for
approximately 877, of the monitoring, but the THC levels at
Station 034 were generally in the 3-6 ppm range except for
one brief excursion at the end of the monitoring period. However,
the methane concentrations were comparable at both stations for
the same periods. Figures IV-2 and IV-3 are graphic comparisons
of the differences in the hydrocarbon measurements at the two
stations. Station 033 as seen in Figure IV-2 shows the effects
of the surrounding sources of emissions.
41
-------
Table IV-6
Diurnal Variation of Ozone (ppb)
Trailer 034, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
24
31
35
40
45
44
32
15
7
6
3
2
2
2
23
2
2
2
0
0
0
0
1
5
15
23
27
33
37
41
37
23
6
3
2
0
0
0
0
24
0
0
0
0
0
0
0
0
5
13
20
24
33
35
31
30
32
7
1
1
0
0
0
0
25
0
0
0
0
0
0
0
0
3
9
13
20
29
31
34
31
34
35
34
30
25
27
24
19
26
29
28
29
29
27
38
28
29
31
31
31
31
30
29
31
32
31
31
31
31
31
31
31
31
27
31
35
35
35
36
35
35
35
36
37
37
39
42
40
39
39
37
29
16
17
18
17
9
2
28
2
2
5
4
9
9
15
18
26
26
28
32
36
36
36
37
32
19
15
18
8
7
7
6
29
3
6
4
2
2
3
15
6
10
19
25
31
30
32
34
31
30
14
8
4
4
5
2
1
30
2
2
1
2
2
1
1
2
5
11
16
21
26
30
29
30
26
21
20
17
14
9
4
5
1
19
20
21
16
16
14
14
12
10
10
42
-------
Table IV-7
Diurnal Variation of Hydrogen Sulfide (ppb)
Trailer 033, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
14
11
9
13
13
12
11
9
11
6
3
2
2
2
2
2
2
5
5
8
10
9
8
4
23
6
8
7
9
9
13
9
12
11
2
0
0
0
0
0
0
0
0
4
4
5
2
7
11
24
7
8
7
11
8
9
7
7
6
1
0
0
0
0
0
0
0
0
4
10
6
6
3
6
25
9
8
12
8
9
8
5
6
10
7
1
0
0
0
0
0
0
0
0
0
0
0
0
0
26
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
27
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
28
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
--
--
--
--
--
--
29
--
--
--
--
--
--
--
--
0
0
0
0
0
0
0
0
0
0
0
2
1
0
2
1
30
0
0
1
1
2
3
0
3
2
0
0
0
3
4
1
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
43
-------
Table IV-8
Diurnal Variation of Hydrogen Sulfide (ppb)
Trailer 034, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
0
0
0
0
0
3
19
3
5
10
8
12
5
8
23
10
8
14
6
11
11
8
10
9
0
0
0
0
0
0
0
0
7
6
8
3
5
11
11
24
12
10
9
11
11
9
5
8
4
0
0
0
0
0
0
0
0
2
6
5
2
7
4
14
25
7
9
11
10
13
7
11
9
10
5
0
0
0
0
0
0
0
0
0
0
0
0
0
0
26
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
27
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2
0
0
0
._2.8_j
2
3
1
2
1
3
2
0
0
0
0
0
0
0
0
0
0
0
1
1
3
3
5
9
29
7
2
3
7
8
5
0
2
5
1
0
0
0
0
0
0
0
0
3
6
4
2
6
5
30
2
2
6
6
7
8
3
7
6
1
0
0
0
3
0
0
0
0
0
0
13
19
6
6
1 _
0
0
5
5
2
4
3
6
3
3
44
-------
Table IV-9
Diurnal Variation of Total Hydrocarbons
Trailer 033, Well 9-X
Period (11/22/76 to 12/02/76)
DAY
(ppm)
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
14.7
15.1
20.0
20.0
20.8
39.7
49.1
>50
>50
23
>50
>50
>50
>50
>50
>50
>50
>50
43.2
13.1
11.8
10.5
9.5
14.8
12.3
4.2
13.6
36.1
49.2
>50
>50
45.2
>50
>50
24
>50
>50
>50
>50
>50
>50
49.8
49.9
45.1
40.7
37.1
36.4
36.2
36.0
35.8
35.9
35.9
41.4
48.6
>50
>50
>50
49.7
>50
25
>50
49.9
>50
>50
>50
49.9
>50
49.2
>50
48.4
41.3
37.5
36.6
36.0
34.8
34.1
33.9
32.9
32.2
32.3
33.5
33.9
34.3
35.5
26
35.6
35.1
35.2
34.5
34.1
32.0
30.3
30.6
29.3
26.1
23.7
27.3
28.8
30.0
30.5
30.2
28.9
28.5
25.7
27.6
31.0
31.6
31.6
31.3
27
32.6
32.4
32.6
33.2
33.6
33.5
33.3
33.2
33.4
33.3
30.7
24.0
cal
22.8
15.8
--
--
--
--
--
--
--
--
--
28
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
29
--
--
--
--
--
--
--
--
--
--
18.5
31.4
34.3
34.6
34.6
35.3
37.1
38.9
44.0
>50
48.6
47.1
49.9
30
49.9
47.3
45.6
49.9
>50
>50
>50
49.9
49.3
42.7
39.4
37.5
17.8
19.7
27.4
33.1
34.3
35.5
39.1
37.0
32.3
27.4
34.4
45.2
1
34.1
29.2
32,1
32.5
33.3
34.4
36.6
39.4
38.0
15.9
1
45
-------
Table IV-10
Diurnal Variation of Methane (ppm)
Trailer 033, Well 9-X
Period (11/22/76 to 12/02/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
0.7
1.0
2.4
2.7
5.7
6.0
6.7
6.7
5.8
23
5.7
5.7
5.7
7.5
7.2
7.8
6.4
7.3
5.2
1.8
1.1
0.9
0.8
0.8
0.7
0.7
0.9
1.8
4.9
4.8
5.4
5.2
6.4
7.8
24
7.1
6.4
4.9
6.3
5.9
5.5
5.2
5.7
5.0
3 0
1.5
1.1
1.0
0.9
0.8
0.8
0.8
1.8
4.5
7.8
6.1
5.7
4.6
6.0
25
6.2
5.4
6.3
6.1
6.4
5.6
5.3
4.9
5.6
4.8
2.6
1.5
1.1
0.8
0.7
0.6
0.6
0.6
0.6
0.6
0.6
1.2
0.7
1.0
26
1.1
0.9
1.2
1.4
1.0
0.7
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.7
0.7
0.7
0.6
0.6
0.6
0.6
0.6
0.6
0.6
27
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
0.6
--
--
__
__
__
--
28
--
--
--
--
--
--
--
--
--
--
--
--
--
--
__
__
--
29
--
--
--
--
--
--
--
--
--
--
2.1
1.8
1.8
1.5
1.5
1.7
2.6
4.3
6.6
12.6
9.9
9.8
16.0
30 j
13.8
11.8
11.1
13.6
13.4
12.9
13.7
12.6
7.9
5.1
3.9
2.2
2.0
1.9
1.9
1.7
1.8
2.7
4.6
3.7
4.2
5.4
8.5
10.5
1
2.2
0.8
0.7
0.6
0.7
1.1
1.7
2.4
2.2
46
-------
Table IV-11
Diurnal Variation of Wind Speed (mph)
Trailer 033, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
0
0
0
1
1
0
1
0
0
0
1
1
1
4
2
1
0
1
0
0
0
0
0
1
23
0
0
0
1
0
0
0
0
0
2
0
0
0
0
0
0
1
1
0
0
0
0
0
1
24
0
0
0
0
1
0
0
0
0
0
0
0
0
1
1
1
1
0
0
0
0
1
0
-
25
1
1
1
1
0
0
1
0
0
0
0
0
1
3
14
11
12
18
18
12
5
5
5
2
26
2
1
5
5
7
10
12
8
15
16
17
14
14
16
17
16
14
12
16
11
7
10
9
8
27
6
9
7
5
5
6
6
6
8
9
12
10
10
9
7
7
8
5
1
3
1
1
2
2
28
1
0
0
0
0
0
0
2
3
0
0
1
2
3
5
4
2
2
1
1
1
0
0
0
29
0
0
0
1
0
0
1
3
1
1
1
2
1
2
2
0
1
2
1
1
1
1
1
1
30
1
2
1
1
1
0
0
0
1
1
0
2
1
1
1
1
2
2
4
2
2
2
2
3
1
17
8
5
5
2
2
1
3
1
4
47
-------
Table IV- 12
Diurnal Variation of Wind Speed (mph)
Trailer 034, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
1
2
3
4
3
1
0
2
1
0
1
1
1
2
23
1
1
1
1
0
0
1
1
0
3
1
1
0
1
1
1
1
1
0
1
2
0
0
1
24
0
0
0
1
1
0
1
0
1
1
0
1
1
1
1
1
1
0
1
1
0
2
1
1
25
1
2
3
1
2
1
2
1
1
1
1
1
2
4
12
10
10
16
16
10
5
6
5
2
26
3
2
6
4
7
10
12
10
16
18
18
15
13
15
15
16
13
10
15
12
8
9
10
8
27
7
9
6
5
6
6
6
7
8
10
13
11
10
8
7
7
8
5
1
3
2
1
2
2
28
1
0
0
0
1
0
2
3
1
1
1
2
2
3
5
4
2
2
2
1
1
0
0
0
29
1
1
0
2
0
1
1
2
3
1
1
1
2
2
1
2
0
1
1
1
1
1
1
1
30
1
2
1
1
1
2
0
1
1
1
1
2
2
1
1
2
2
2
4
2
2
2
2
4
1
16
8
5
2
2
2
1
2
1
4
48
-------
TABLE IV-13
Diurnal Variation of Wind Direction
Trailer 034, Well 9-X
Period (11/22/76 to 12/01/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
22
20
304
299
302
280
302
353
338
355
325
318
0
273
325
23
332
314
350
267
359
335
313
348
4
69
356
0
47
19
334
329
358
16
353
0
318
337
25
318
24
341
336
339
311
342
326
271
5
355
22
272
12
0
322
13
161
253
350
16
11
358
345
296
349
25
347
306
309
299
357
311
310
322
306
336
89
339
256
172
261
278
269
261
261
258
246
242
308
259
26
31
309
253
282
360
49
50
63
55
56
52
53
39
26
25
33
44
46
46
64
56
60
51
65
27
69
70
84
87
94
80
70
60
78
60
69
70
70
63
45
42
43
61
66
56
57
324
353
339
28
335
355
329
359
345
337
41
40
51
50
8
342
350
186
253
269
333
0
266
297
359
326
353
352
29
5
296
318
308
359
31
131
44
298
354
347
292
340
52
266
350
2
322
280
309
7
302
6
354
30
300
332
308
2
345
329
290
0
349
278
301
1
322
22
235
217
263
123
20
281
320
351
24
12
1
320
298
44
14
353
13
349
2
332
332
49
-------
U1
o
0.
i 40
z
o
30 '
o
z
o
o
20
10
THC
23
NOV 23
24
NOV
2S
NOV 25
NOV 26
DATE
27
NOV 27
28
29
NOV 29
30
3° DEC
FIGURE IV-1. AMBIENT THC AND CHt, CONCENTRATIONS AT STATION 034 NEAR WELL 9-X
-------
Table IV- 14
Diurnal Variation of Ozone (ppb)
Trailer 034, Collection Station
Period 12/02/76 to 12/11/76
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
27
33
34
35
33
28
17
28
24
21
15
14
3
13
14
10
5
4
5
6
8
12
10
13
20
21
28
29
27
19
22
24
24
25
26
14
8
4
12
12
13
10
7
3
3
4
10
12
17
23
24
23
24
23
22
21
16
17
19
20
19
22
5
23
22
17
12
6
12
15
14
18
21
25
24
24
31
34
34
33
30
30
30
27
27
29
27
6
19
17
11
20
25
23
24
16
19
24
25
28
35
39
43
42
32
27
23
25
27
26
26
26
7
25
25
25
24
22
22
21
21
23
27
33
35
39
42
43
42
39
35
32
31
31
24
27
25
8
21
20
16
16
14
13
8
9
14
21
26
31
37
39
38
33
29
24
25
26
31
28
25
10
9
19
22
7
10
12
10
11
6
14
11
16
22
25
34
35
33
31
29
26
27
29
33
23
30
10
34
37
38
35
31
32
29
25
26
30
35
37
37
38
39
40
38
26
30
34
29
27
24
21
11 _
19
20
21
16
16
14
14
12
10
51
-------
Table IV-15
Diurnal Variation of Hydrogen Sulfide (ppb)
Trailer 033, Collection Station
Period (12-02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
0
4
25
21
9
12
15
19
3
16
5
6
8
4
15
5
10
8
0
0
0
0
0
0
0
3
17
14
16
11
11
13
40
4
27
36
32
51
37
31
9
3
0
0
9
11
11
0
0
0
2
7
4
2
1
1
0
2
5
3
0
0
0
0
0
0
0
0
2
0
6
11
8
7
5
7
6
6
6
6
7
7
7
6
7
6
6
8
7
6
7
7
6
3
0
0
0
0
0
0
25
21
14
31
39
30
30
6
7
1
21
24
48
42
20
33
30
10
0
0
0
0
0
0
0
0
4
3
14
6
0
7
12
8
14
11
6
2
0
0
0
1
8
1
0
0
4
0
2
0
22
29
14
11
13
12
5
12
9
8
6
7
12
16
10
6
12
12
4
8
1
0
0
10
5
0
0
0
0
10
0
0
0
0
0
0
0
8
7
1
0
0
0
0
0
12
1
10
19
11
25
19
9
5
11
15
9
6
7
16
15
14
52
-------
Table IV-16
Diurnal Variation of Hydrogen Sulfide (ppb)
Trailer 034, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
0
0
0
0
0
0
0
0
0
0
0
0
3
0
0
0
0
1
3
4
1
1
2
6
1
1
0
0
0
0
0
0
0
0
0
1
1
4
0
0
0
0
0
2
4
1
4
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
5
0
0
3
7
3
0
0
0
0
0
1
1
1
0
0
2
4
10
2
0
2
5
1
6
6
6
4
2
1
1
0
3
4
3
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
7
3
0
1
0
12
1
1
4
1
4
0
0
0
0
0
0
0
0
0
0
0
10
1
0
8
0
0
0
0
1
4
0
3
14
9
3
1
0
0
0
0
0
0
0
0
0
0
2
4
9
0
10
11
4
0
2
0
3
3
11
11
2
1
0
0
0
0
0
0
0
0
2
4
0
10
0
0
0
3
2
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
11
0
0
5
5
2
4
3
6
3
53
-------
Table IV- 17
Diurnal Variation of Total Hydrocarbons (ppm)
Trailer 033, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
cal
17.8
27.1
49.8
>50
>50
>50
>50
>50
3
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
34.9
25.6
43.8
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
4
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
23.8
24.8
27.0
45.5
29.5
19.8
39.5
43.4
>50
>50
>50
>50
>50
>50
5
>50
>50
>50
>50
>50
>50
>50
>50
46.0
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
6
--
--
--
--
--
--
--
--
--
--
--
--
--
--
cal
29.3
28.3
41.5
>50
>50
>50
>50
>50
7
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
8
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
30.9
38.2
>50
>50
>50
>50
>50
>50
>50
9
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
10
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
39.8
25.5
42.6
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
>50
11
>50
>50
>50
>50
>50
>50
>50
54
-------
Table IV-IB
Diurnal Variation of Methane (ppm)
Trailer 033, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
0.8
1.7
1.5
1.4
2.3
3.0
3.2
3
3.2
1.8
1.7
2.1
1.6
2.6
1.6
2.0
1.9
1.0
0.9
0.7
0.6
0.5
0.5
0.5
1.4
2.3
1.4
1.5
1.4
1.4
2.1
,.5
4
3.6
4.3
3.8
6.1
4.9
4.3
2.2
1.6
2.0
1.0
0.7
0.5
0.5
0.6
0.5
0.5
1.1
1.8
1.9
1.5
1.1
0.8
0.9
1.4
5
1.3
0.9
0.8
1.1
1.3
1.0
0.7
1.2
1.7
1.3
--
--
--
--
--
--
--
--
--
--
--
--
--
--
6
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
--
3.1
2.3
1.9
2.7
3.1
2.6
2.5
1.5
7
0.9
1.8
1.8
3.2
3.5
2.9
2.1
2.2
2.3
1.3
0.8
0.5
0.4
0.4
0.4
0.4
0.7
0.7
0.8
1.2
1.1
1.0
1.3
1.4
8
1.7
1.7
1.6
1.5
1.4
1.4
1.5
1.5
1.8
1.6
1.1
0.6
0.4
0.4
0.4
1.5
1.8
0.8
0.9
1. 1
1.2
1.3
1.2
1.5
9
1.7
1.7
1.7
1.9
2.3
2.1
2.0
2.0
2.1
1.8
1.2
0.9
0.8
0.7
0.6
0.6
0.6
1.1
0.9
1.0
0.9
0.8
0.8
0.9
10
0.8
0.7
0.7
0.6
0.7
1.1
1.2
1.6
1.8
1.6
1.1
0.6
0.5
0.5
0.8
0.6
0.6
1.0
1.2
1.2
1.9
2.1
1.9
1.9
11
2.3
2.2
2.1
2.1
2.4
2.4
2.4
.
55
-------
Table IV- 19
Diurnal Variation of Total Hydrocarbons (ppm)
Trailer 034, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
1.8
4.2
3.0
4.1
4 9
1.5
1.6
1.8
2.1
2.1
3
2.3
1.8
1.8
2.2
7.8
4.9
4.4
4.8
4.6
4.4
3.9
3.9
4.0
4.0
4.3
5.4
6.2
4
5.3
5.0
4.2
4.8
4.7
7.0
8.7
6.5
8.4
5.5
5.7
4.1
4.6
4.5
3.8
3.6
3.6
3.5
4.1
3.7
3.7
3.7
3.8
3.8
5
3.7
4.1
7.2
11
11
6.4
5.3
4.8
4.2
4.1
5.4
6.4
6.2
4.3
3.7
4.5
4.9
5.7
4.8
3.9
8.3
7.3
4.6
9.2
6
11
6.0
6.3
6.3
4.8
5.2
5.8
8.0
6.2
5.4
4.7
4.6
3.9
3.6
3.2
3.5
3.3
3.4
3.5
3.6
3.7
3.8
3.6
3.6
7
6.7
4.0
4.2
4.1
8.6
4.8
4.3
5.1
4.9
6.0
4.3
4.4
4.0
3.4
3.3
3.4
3.3
3.4
3.6
3.4
3.6
7.6
4.5
3.8
8
4.5
4.3
4.0
4.1
4.3
4.6
4.7
5.4
6.7
6.0
5.3
4.8
3.7
3.3
3.4
3.5
3.6
3.7
3.7
3.6
3.4
3.5
4.3
6.7
9
4.2
6.8
6.2
5.1
4.4
4.9
4.2
5.0
4.5
8.9
7.4
5.1
5.0
3.6
3.5
3.8
3.6
3.6
3.8
3.8
3.8
3.9
6.6
4.7
10
3.9
3.8
4.3
5.6
5.6
3.9
3.8
4.3
5.3
4.4
4.2
3.8
3.6
3.6
3.5
3.4
3.5
3.4
3.4
3.5
3.7
3.9
4.4
4.3
11
4.2
3.9
6.2
6.8
4.9
18
48
45
43
56
-------
Table IV-20
Diurnal Variation of Methane (ppm)
Trailer 034, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
3.5
0.8
0.8
1.2
1.3
3
1.3
1.4
1.2
1. 1
1.1
1.1
1.1
1.1
1.1
1.1
1.1
1.2
1.3
1.4
4
1.3
1.3
1.2
1.2
1.2
1.4
1.6
1.4
1.8
1.3
1.2
1.1
1.2
1.2
1.1
1.0
1.0
1.0
1.1
1.0
1.0
1.1
1.1
1.1
5
1.1
1.1
1.4
1.7
1.9
1.4
1.3
1.2
1.1
1.1
1.3
1.3
1.4
1.1
1.0
1.0
1.1
1.2
1.2
1.1
1.2
1.6
1.2
1.4
6
1.7
1.3
1.4
1.4
1.2
1.2
1.2
1.5
1.3
1.2
1.1
1.1
1.1
1.0
0.9
1.0
0.9
1.0
1.0
1.0
1. 1
1.0
1.0
1.0
7
1.3
1.0
1.0
1.0
1.5
1.1
1.0
1.1
1.0
1.2
1.0
1.0
1.0
0.9
0.9
0.9
0.9
0.9
1.0
1.0
1.0
1.3
1.1
1.0
8
1.1
1.1
1.0
1.1
1.1
1.1
1.1
1.2
1.3
1.2
1.2
1.0
1.0
0.9
0.9
0.9
1.0
1.0
1.0
1.0
1.0
1.0
1.1
1.3
9
1.0
1.2
1.2
1.1
1.1
1.1
1.1
1.2
1.1
1.4
1.3
1.1
1.2
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.3
1.1
10
1.0
1.0
1.0
1.2
1.2
1.0
1.0
1.0
1.2
1.1
1.0
1.0
1.0
1.0
0.9
1.0
0.9
0.9
0.9
1.0
1.0
1.0
1.0
1.0
11
1.0
1.0
1.3
1.4
1.1
1.2
0.4
0.4
0.4
57
-------
Table IV-21
Diurnal Variation of Wind Speed (mph)
Trailer 033, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
4
6
7
4
1
1
0
0
3
1
1
1
0
0
0
0
0
0
1
1
1
2
1
1
1
1
6
10
8
6
2
0
0
4
1
2
1
0
0
1
2
0
1
2
1
0
3
1
4
4
5
5
3
4
8
7
3
5
5
5
1
1
2
2
1
2
1
1
3
1
1
2
5
6
8
7
4
4
6
3
1
1
1
6
0
1
0
1
3
0
1
1
0
1
1
0
2
2
2
1
1
1
0
1
0
1
1
2
7
1
2
1
1
0
0
0
0
1
1
1
0
2
3
5
-
3
4
2
3
0
0
1
0 J
8
1
1
3
1
0
0
0
0
1
2
1
0
0
2
4
7
7
4
1
2
5
4
0
0
9
1
1
1
0
1
0
0
1
0
0
0
5
3
5
7 .
5
5
7
7
3
4
6
3
1
10
2
2
4
2
2
2
2
0
1
2
3
3
4
3
5
6
5
5
5
2
1
1
1
0
11
0
0
0
0
0
0
0
58
-------
Table IV-22
Diurnal Variation of Wind Speed (mph)
Trailer 034, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
4
4
6
7
7
8
10
5
1
1
0
0
3
1
1
1
0
0
1
0
0
0
1
1
2
2
1
2
2
1
6
9
8
6
4
0
0
4
1
2
1
0
0
1
2
0
1
3
2
1
4
2
6
6
5
5
3
5
8
8
5
6
5
6
2
1
2
3
3
2
1
3
4
2
3
4
7
8
10
8
5
6
8
5
3
3
3
6
2
3
3
3
4
2
3
2
2
3
3
2
4
3
3
2
1
1
1
1
0
1
1
2
7
1
2
1
1
1
1
1
1
1
1
2
2
4
4
5
3
3
5
3
4
1
2
3
1
8
1
1
3
2
0
0
0
0
1
2
2
2
1
3
5
8
8
6
2
3
6
5
1
1
9
2
1
1
1
1
1
1
1
1
0
1
7
4
6
8
5
7
7
6
4
5
7
4
1
10
3
3
5
3
2
2
2
1
1
3
3
4
5
4
6
7
7
6
5
3
1
1
1
0
11. _
0
0
1
1
0
1
0
1
0
I
59
-------
TABLE IV-23
Diurnal Variation of Wind Direction
Trailer 033, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
229
245
246
247
244
297
232
230
3
242
251
293
244
207
196
167
217
181
105
108
91
96
102
100
113
220
248
255
256
261
241
277
225
4
240
213
192
232
230
150
47
276
148
98
103
163
89
165
221
230
249
260
198
239
239
251
249
259
5
260
275
24
9
29
19
100
232
245
276
47
84
117
115
52
61
65
45
46
22
73
44
99
74
6
70
87
38
69
58
118
106
78
127
90
24
112
112
122
206
172
190
199
214
206
193
233
233
312
7
138
247
228
225
185
215
208
239
216
145
104
123
158
221
244
--
266
231
263
246
200
323
249
223
8
225
254
253
241
224
248
234
195
119
103
91
82
109
223
232
229
236
254
250
249
247
244
220
312
9
253
137
220
265
250
212
203
239
188
188
123
216
166
215
233
250
221
261
252
293
266
317
137
177
10
149
160
151
110
218
237
229
201
250
163
134
142
167
175
213
204
232
252
253
269
242
236
237
201
11
182
220
91
187
226
110
246
60
-------
TABLE IV-24
Diurnal Variation of Wind Direction
Trailer 034, Collection Station
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
88
320
221
223
236
254
256
265
282
313
328
328
3
309
295
339
331
317
343
331
317
342
60
68
79
66
95
92
125
260
252
272
261
272
275
339
339
4
317
314
335
353
319
13
41
341
11
93
88
353
69
318
231
243
264
276
192
248
252
267
271
271
5
278
321
347
348
43
35
64
307
267
287
35
59
120
121
60
69
73
50
51
34
74
54
92
92
6
52
70
40
80
73
96
88
30
45
89
68
38
128
82
246
176
256
290
301
330
358
301
286
286
7
92
286
316
294
344
328
345
314
332
74
74
66
187
229
245
257
278
246
283
255
289
321
285
285
8
288
306
275
310
325
319
325
345
49
62
88
56
55
241
247
237
241
262
279
283
258
235
323
323
9
286
350
316
317
302
334
301
310
355
347
30
222
322
238
243
260
228
275
271
307
288
320
140
140
10
164
156
153
99
327
272
274
347
304
177
134
138
167
174
218
212
237
260
265
296
321
321
287
287
11
320
298
44
4
353
13
349
2
332
61
-------
CL
a
z
o
r
UJ
o
z
o
o
STATION 033
THC
DEC 3 DEC 4 DEC 5 DEC 6 DEC 7 DEC 6 DEC 9 DEC 10
3 4 5 6 7 8 8 1011
DATE
FIGURE IV-2
AMBIENT THC AND CH^ CONCENTRATION AT STATION 033 EAST OF
COLLECTION STATION
STATION 034
z
UJ
o
z
O 20
O
THC
CH4'
DEC 3
DEC 4 DEC 5
5
DEC 6 DEC 7 DEC 8 DEC 9 DEC 10
7 8 9 10 11
DATE
FIGURE IV-3
AMBIENT THC AND CH4 CONCENTRATIONS AT STATION 034 WEST OF
COLLECTION STATION
-------
V. DISCUSSION
A number of fugitive emissions were identified ranging
from minute to jet-type leaks. Less than ten percent of the
potential sources of emissions were leaking, and although there
were several large leaks, most leaks were minute. The most
prevalent leaks were associated with valves; flanges and other
types of connectors did not make significant contributions to
the overall leak rate. The total number of sites and types
of units that were inspected were necessarily limited in this
survey program. Other possible sources of fugitive emissions
such as treaters, sumps, oil spills, large open vessels, open pits,
etc. were identified but were outside the scope of the program.
There are many potential leaks in an oil and gas field.
These leaks may be caused by temperature, pressure, vibration,
friction, variable operating conditions, and corrosion. The
extent of these emissions and the degree of hazard or impact
are generally determined by the maintenance level in the area
of interest. Maintenance is the key to reducing losses due to
most fugitive emissions. The quality of maintenance in any in-
dustrial area is a variable but significant factor. Fugitive
emissions are inevitable in a production facility subject to
pressure and stress, but effective maintenance can minimize the
effect of such emissions. Relatively few leaks were identified
at the Rangely field, and these were generally small. However,
as seen in Table IV-3, a large leak can contribute significant
emissions. The hydrocarbon emission rate per well ranged from
zero to 23.4 pounds per day. The emission factors for these
sites varied from zero to 0.717 pounds per barrel of oil produced.
The variation in the emission rates and factors indicate that
the quantity of fugitive emissions is not related to production
rate but is instead a function of maintenance and the speed with
which leaks can be identified and repaired.
63
-------
Only a few sites were sampled because this program
was a general study to survey the types of fugitive emissions
in a producing oil and gas field, to develop sampling and moni-
toring procedures, and to obtain an indication of the effects
of fugitive emissions on air quality. Therefore, emission rates
and emission factors for the entire field were not extrapolated
because of the limited statistical base. However, the detec-
tion of several large sources of fugitive emissions combined
with the monitoring results show that fugitive emissions in-
fluence the air quality in the vicinity of the field.
The emissions from the oil and gas field did have an
impact on the air quality of the immediate area, particularly
with respect to hydrogen sulfide and hydrocarbons. The con-
tributions of the emissions are most evident in the high con-
centrations of these two species. No significant sources of
emissions other than fugitive emissions were evident at the
time of the study.
The concentrations of hydrogen sulfide were highest
near the collection station where the monitor was subject to
the station as well as nearby producing wells. The hydrogen
sulfide levels were episodic; that is, the levels would be below
the detection limits of the monitor, rise to a peak value, and
then fall below detection limits. During the monitoring near
the collection station the increase in H2S levels coincided with
increased wind speeds.
The total hydrocarbon levels were as high as 50 ppm
at both the northwestern and southeastern monitoring sites.
High hydrocarbon levels would, of course, be expected on the
site of a facility such as an oil and gas field. The major
contribution to the high hydrocarbon levels came from nonmethane
hydrocarbons. Longer-term monitoring would be required to
64
-------
determine if the recorded levels are persistent or are a short-
term phenomenon. There are several relevant aspects of these
readings.
First, the large concentrations of nonmethane hydro-
carbons are influenced by the higher density of the heavier
hydrocarbons causing a possible concentration gradient with the
nonmethane hydrocarbons being more concentrated than methane
near ground level. This effect would be more pronounced during
the cold periods when the monitoring occurred.
Secondly, the total hydrocarbon readings are expressed
on the basis of methane response. A gas such as propane will
give a reading approximately three times as high as methane for
the same volume concentration. Flame ionization detectors such
as the one used in this study are coming under intense scrutiny
due to substantially discrepant nonmethane hydrocarbon measure-
ments from various types of hydrocarbon analyzers measuring iden-
tical samples of ambient air. Substantial discrepancies can
arise using different models of such analyzers. Therefore, am-
bient nonmethane hydrocarbon measurements can only be used as
possible guidelines and should not be taken as exact values.
An uncertainity in the ambient hydrocarbon measurements cannot
be assigned, but the uncertainity in other measurements in this
study is within it 20 percent.
The upwind/downwind results of monitoring at the two
sites produced different results. The only significant upwind/
downwind differences were for H2S and total hydrocarbon at the
northwest site. The monitoring at Well 9-X did not produce a
significant difference in upwind and downwind values. The single
source of emissions between the two stations was not large
enough to produce a detectable difference, and the measurements
were due to the total emissions upwind of the two stations.
-------
These two stations were downwind of the major portion of the oil
field leading to large hydrocarbon measurements at both stations.
Measurements taken near the collection station on the
northwest perimeter of the field showed more upwind/downwind varia-
tions. Trailer 034, which was the western monitoring site, recorded
minimum background levels because of the prevailing wind direc-
tions, terrain, absence of producing sites upwind from it, and
its location closer to the edge of the field. This site monitored
lower levels of both H2S and THC than Trailer 033 which was east
of the collection station and subject to the influences of other
facilities as well as the collection station. Table V-l gives
the diurnal variation in the difference between the H2S readings
at stations 033 and 034. The average difference on an hourly
basis is shown in Figure V-l. The difference in the total hydro-
carbon readings is given in Table V-2. When the wind was from
the west or northwest the outer station, 033, measured minimum
levels and provided a background measurement with which to reference
the higher levels seen at the other monitoring station.
Although the oil and gas emissions do influence the
immediate air quality in the vicinity of the oil field, the air
quality monitored by other nearby networks recorded the types of
low level pollutant concentrations associated with remote areas.
Summaries of the air quality parameters for the three federal
oil shale leasing tracts are given in Tables V-3, V-4, V-5, and
V-6. The concentrations of all pollutants at the three oil shale
monitoring areas are background levels with no episodes of high
levels. Measurement of H2S, S02, and oxides of nitrogen were at
the minimum detectable limits of the analyzers. Measurements at
the tracts indicated no undue amounts of hydrocarbons. There
were no variations at the oil shale tracts corresponding to
the high levels recorded at Rangely and subsequently no indica-
tion of long-range transport of these pollutants.
66
-------
TABLE V-l
Diurnal Variation of Difference in H2S Levels
Between Station 033 and 034
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
4
25
21
9
12
15
19
3
16
5
6
8
3
12
1
9
7
-2
-6
-1
-1
0
0
0
3
17
14
16
11
11
12
39
4
27
36
32
51
37
29
5
2
-4
-1
9
11
11
0
0
0
2
7
4
2
1
1
0
2
5
3
0
-3
-7
-3
0
0
0
0
2
-1
5
10
8
7
3
3
-4
4
6
4
2
6
1
6
1
2
4
7
6
6
4
3
3
2
0
0
0
0
0
0
25
21
14
31
39
30
30
6
7
-2
21
23
48
30
19
32
26
9
-4
0
0
0
0
0
0
0
4
3
14
6
-10
6
12
8
14
11
6
2
-1
-4
0
-2
-6
-8
-3
-1
4
0
2
0
22
29
14
11
13
12
3
8
9
8
-4
-4
8
16
8
6
9
9
-7
-3
-1
-1
0
10
5
0
-2
-4
0
10
0
0
0
-3
-2
0
0
8
6
1
0
0
0
0
0
12
1
10
19
11
25
19
8
4
11
15
9
1
2
14
11
11
NOTE: Values calculated as 033-034.
67
-------
00
DATE
FIGURE V-l. DIFFERENCE IN H2S LEVELS AT STATIONS 033 AND 034 NEAR COLLECTION STATION
-------
TABLE V-2
Diurnal Variation of Differences in THC
Measurements at 033 and 034
Period (12/02/76 to 12/11/76)
DAY
HOUR
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
2
23
45
>49
>48
>48
>48
>48
3
>48
>48
>48
4
>45
>45
>46
>45
>45
>43
>41
>44
>42
>45
18
21
22
41
26
16
36
40
>46
>46
>46
>46
>46
>46
5
>46
>46
>43
>39
>39
>44
>45
>45
>42
6
26
25
38
>46
>46
>46
>46
>46
7
>43
>46
>46
>46
>41
>45
>46
>45
>45
>44
>46
>46
>46
>47
>47
>47
>47
>47
>46
>47
>46
>42
>46
>46
8
>46
>46
>46
>46
>46
>45
>45
>44
>43
>44
>45
>45
>46
>46
>46
27
34
>46
>46
>46
>47
>47
>46
>43
9
>46
>43
>44
>45
>46
>45
>46
>45
>35
>41
>43
>45
>45
>46
>47
>46
>46
>46
>46
>46
>46
>46
>43
>45
10
>46
>46
>46
>44
>44
>46
>46
>46
>45
>46
36
22
39
>46
>47
>47
>47
>47
>47
>47
>46
>46
>46
>46
11
>45
>46
>44
>43
>45
>32
> ?
> 5
>27
i
NOTE: Calculated as 033 level - 034 level
69
-------
TABLE V-3
MONTHLY SUMMARY OF AIR
Parameter
03
CO
NO
NOX
CH^
THC
H2S
S02
OU
THC
H2S
S02
03
CO
NO
NOX
CH4
THC
H2S
S02
OU
THC
H2S
S02
RIO BLANCO OIL
November
Minimum
ppm
SITE
0.024
0.000
0.004
0.002
1.305
1.429
0.000
0.000
SITE
1.375
1.380
0.001
0.001
SITE
0.010
0.000
0.001
0.000
1.314
1.398
0.002
0.001
SITE
1.319
1.339
0.001
0.000
QUALITY PARAMETERS
SHALE PROJECT
, 1976
Maximum
ppm
1
0.039
0.971
0.013
0.012
1.970
1.936
0.014
0.000
2
1.565
1.819
0.013
0.008
3
0.042
1.281
0.022
0.019
1.599
1.635
0.010
0.009
4
1.459
1.700
0.021
0.024
Arithmetic
Mean
0.033
0.062
0.010
0.009
1.602
1.788
0.001
0.000
1.461
1.488
0.003
0.001
0.026
0.541
0.005
0.003
1.484
1.505
0.003
0.002
1.644
1.504
0.002
0.001
All values are expressed in ppm and are based upon hourly averages.
70
-------
TABLE V-4
MONTHLY SUMMARY OF AIR QUALITY PARAMETERS
RIO BLANCO OIL SHALE PROJECT
December, 1976
Parameter
03
CO
NO
N0x
THC
H2S
S02
Minimum
ppm
0.013
0.000
0.000
0.000
1.361
1.385
0.002
0.001
Maximum
ppm
0.043
0.681
0.011
0.010
1.667
1.810
0.004
0.004
Mean
0.026
0.218
0.003
0.004
1.470
1.500
0.003
0.002
All values are based on hourly averages and are expressed in ppm.
71
-------
TABLE V-5
MONTHLY SUMMARY OF AIR QUALITY PARAMETERS
WHITE RIVER SHALE PROJECT
November and December, 1976
Parameter
03
Total Sulfur
N0x
CO
CH4
THC
Minimum
ppm
0.010
0.000
0.001
0.000
1.4
1.4
Maximum
ppm
0.041
0.001
0.012
1.0
7.3
8.7
Mean
0.024
0.000
0.005
0.1
1.6
1.7
December. 1976
Parameter
Minimum
ppm
Maximum
ppm
Mean
03
Total Sulfur
NO
X
CO
CH4
THC
0.015
0.000
0.001
0.100
1.6
1.5
0.062
0.002
0.021
1.0
2.7
2 7
0.033
0.000
0.007
0.200
1.7
1.8
All values are based on hourly averages and are expressed in ppm
72
-------
TABLE V-6
MONTHLY SUMMARIES OF AIR QUALITY PARAMETERS
TRACT C-b OIL SHALE PROJECT
NOVEMBER AND DECEMBER, 1976
Parameter
03
NOV
X
H2S
S02
CO
CIU
THC
03
NO
X
Hz S
S02
CO
CH4
THC
Minimum
ppm
November
0.021
*
*
*
0.12
1.4
1.5
December
0.022
*
*
*
0.10
1.2
1.3
Maximum
ppm
0
0
0
0
1
1
3
0
0
0
0
0
2
4
.058
.050
.007
.006
.3
.7
.3
.047
.030
.008
.001
.96
.0
.2
Mean
0.
0.
0.
0.
0.
1.
1.
0.
0.
0.
1.
1.
040
004
001
001
31
5
7
034
002
0
*
38
5
6
*Below minimum detection limit.
All values are based on hourly averages and are expressed in
ppm.
73
-------
Meteorological summaries and monitoring results for
the oil shale tracts are given in the appendices.
74
-------
VI. SUMMARY
The following list summarizes the findings of this
program:
1) Techniques for fugitive emission sampling were
tested and proven.
2) Leaks were detected in 9.7 percent of the units
checked.
3) Both rates and composition were determined for
the fugitive emissions.
4) Emission rates varied from zero to 23.4 pounds
per day per site, and emission factors varied
from zero to 0.717 pounds per barrel of oil.
5) Unlike processing facilities which are usually
tested for fugitive emissions, leak rates for
some sites in the oil field were variable.
6) Maintenance is the key to reducing losses from
fugitive emissions.
7) Ambient air quality detected high concentrations
of H2S and total hydrocarbons, indicating the
influence of fugitive emissions on the air quality
in the vicinity of the oil and gas field.
8) Upwind/downwind monitoring at the northwest site
provided background versus oil field measurements
that show the effects of oil field emissions on
ambient air quality.
75
-------
9) The total hydrocarbon concentration in the ambient
air was high, and the major constituents were non-
methane hydrocarbons. The indicated high levels
of NMHC were due to the FID measurement techni-
que and the suspected settling of the denser
hydrocarbons causing a concentration gradient.
10) No high levels of pollutants were detected at any
of the surrounding monitoring networks which would
correspond to the levels at the oil field. There
were no indications of long-range transport.
76
-------
APPENDIX A
METEOROLOGICAL SUMMARIES
A-l
-------
Monthly Meteorological Summary
A. Summary of the Meteorological Conditions in
Northwestern and West Central Colorado During
November 1976
Grand Junction, Colorado, sixty miles to the south-
southwest of the Tract C-b, received a total of 0.04 inch of
precipitation during November, which is 0,57 inch below the
monthly normal of 0.61 inch. Grand Junction also received a
trace of snow during November. Measurable precipitation (>.01
inch) was recorded only on November 14th. The region received
79 percent of the possible monthly sunshine. Sky cover by
cloudiness averaged 4.3 out of a possible 10 during the daylight
hours and 3.6 out of a possible 10 during the entire month. The
region had thirteen clear days, eleven partly cloudy days, and
six cloudy days during the month.
Air mass changes occurred in the region with a
frequency of about once every five or six days during November.
Temperatures were cool but near seasonal normals. Transport
winds were not as strong as those which prevailed in the area
during October. Five cold fronts, all of continental polar
origins, passed through the region during October. These
continental polar cold frontal passages occurred on November
2nd, 6th, 16th, 21st, and 26th.
A-2
-------
B. Summary of the Meteorological Conditions in the
Oil Shale Tract C-b Region During November 1976
An upper-level ridge which had a mean position over
western Colorado was responsible for the below normal precipita-
tion totals which occurred during November. The Tract C-b region
was located on the downstream side of an upper-level ridge in the
western United States. As a result, very little troughing
occurred in the Tract C-b region during November. The only
precipitation which occurred fell on the 13th and 14th. Since the
long wave trough was located in the eastern section of the country,
most of the continental polar air masses were directed toward the
eastern half of the United States. Therefore, temperatures in
the Tract C-b region were near normal during November.
Five continental polar cold frontal passages occurred
during- the month. These fronts were fairly mild since the major
thrust of the cold air was to the east of the region.
The monthly average temperatures recorded at the meteoro-
logical tower during November were: 34.4°F at 8 feet; 34.2 F at
30 feet; 34.6°F at 100 feet; and 32.9°F at 200 feet. These aver-
ages are approximately 9F° lower than those recorded in October.
The warmest days of the month were the 1st through the 10th. The
coolest days were the 26th through the 29th. The highest tempera-
ture recorded at the meteorological tower during November was 61 F
at the 8-foot level on the 5th. The coldest temperature recorded
at the meteorological tower was -7°F at the 200-foot level on the
morning of the 27th.
Monthly average relative humidities during November
were slightly higher than they had been in October in the Tract
C-b region. This increase can be attributed solely to the
A-3
-------
decrease in monthly average temperatures which occurred during
November. The average moisture content of the air in the
district actually decreased during the month. At the meteoro-
logical tower, the monthly average relative humidities were: 52.5
percent at 8 feet, 55.7 percent at 30 feet, 57.0 percent at 100
feet, and 54.8 percent at 200 feet. These relative humidities
correspond to dew points of 19°F, 20°F, 21°F, and 18°F,
respectively. The most humid days of the month were the 14th,
15th, and 26th. The driest days were the 6th, 9th, and 10th.
Winds at the meteorological tower during November were
not as strong on the average as the winds that prevailed during
October because of the lack of short waves moving through the
Tract C-b region. Resultant wind vectors at the meteorological
tower during November were: 236.5 degrees at 0.9 miles per hour
at 8 feet; 237.4 degrees at 1.2 miles per hour at 30 feet; 249.3
degrees at 1.4 miles per hour at 100 feet; and 255.2 degrees at
2.1 miles per hour at 200 feet. The scalar average wind speeds
associated with these resultant wind vectors were 3, 4, 5, and
6 miles per hour, respectively. The Ekman spiral and Ekman
effect, i.e., a veering in direction and increase in speed as a
function of increasing height above the surface, were in evidence
during most of November. A reference to the November wind roses
for the meteorological tower indicates that the winds at that
location were primarily south-southwesterly at all four levels,
with a relatively high frequency of occurrence of southwesterly
winds in addition.
The windiest days of the month at the meteorological
tower were the 14th, 25th, and 26th. The days having the lightest
winds were the 1st, 2nd, 5th, 7th, 9th, 17th, 18th, 19th, 21st, and
23rd. The highest five-minute average wind speed recorded at the
tower during November was 28 miles per hour at the 200-foot level
on the 25th and 26th.
A-4
-------
Precipitation totals in the Tract C-b Monitoring Network
during November were generally very much below normal. Only 0.04
inch of precipitation was recorded at the meteorological tower
during November. The largest daily precipitation total recorded
in the network during November was 0.03 inch on November 13th.
The greatest five-minute precipitation total recorded during the
month was 0.01 inch (a precipitation rate of 0.12 inch/hour), re-
corded on the 13th and 14th. Measurable precipitation (>.01 inch)
was recorded at the meteorological tower on only two days of the
month. The precipitation on these days was in the form of snow.
The monthly average station pressure during November
was 791.9 millibars at the meteorological tower. This reading is
0.3 millibar higher than the October average station pressure of
791.6 millibars. The highest daily average station pressures
occurred on the 1st, 2nd, 3rd, 4th, 7th, 8th, and 17th. The
lowest daily average station pressures occurred on the 25th and
26th.
Cloudiness increased slightly in the Tract C-b region
during November, compared to the October cloud cover and insolation
statistics. The region received an insolation total of 6711.9
langleys, which is equivalent to a daily average insolation total
of 224 langleys/day. This average is only slightly below the
normal for November of 250 langleys/day in the Tract C-b region.
On a diurnal basis, the greatest solar radiation rates occurred
between 1100 and 1200 hours. The greatest daily radiation totals
were received on the 1st, 4th, and 15th. The lowest daily solar
radiation totals were received on the 13th, 14th, and 26th. The
greatest five-minute radiation total received during November
was 5.20 langleys (a rate of 1.04 langleys/minute), which occurred
on the 3rd. The largest hourly insolation total received during
November was 54 langleys, which occurred on the 15th between 1100
A-5
-------
and 1200 hours. Because of the progressively decreasing solar
elevations and the increasingly shorter periods of daylight that
prevailed during November, the total possible solar radiation
which could be received during a day decreased monotonically
throughout the month.
The slight increase in cloudiness and decrease in
insolation which affected the Tract C-b during November caused
the unstable stability classes to become less common than they had
been in October. Using the Pasquill method of stability deter-
mination, "C" stability (slightly unstable) was the most common
stability, occurring during 185 dr*time hours, or 62.5 percent
of the time. In decreasing order of frequency, "D" (neutral)
stability occurred during 59 hours, or 19.9 percent of the time,
and "B" (very unstable) stability occurred during 52 hours, or
17.6 percent of the time. "A" (extremely unstable) stability did
not occur.
A-6
-------
Monthly Meteorological Summary
A. Summary of the Meteorological Conditions in
Northwestern and West Central Colorado
During December 1976
Grand Junction, Colorado, sixty miles to the south-
southwest of the Tract C-b, received a total of only 0.01 inch
of precipitation during December, which is 0.54 inch below the
monthly normal of 0.55 inch. According to the National Weather
Service Office in Grand Junction: "This is the 2nd driest
December of record. The driest was 1900 with a trace." Grand
Junction received 0.1 inch of snow during December. Measurable
precipitation (>.01 inch) occurred on December 5th. The region
received 84 percent of the possible monthly sunshine. Sky cover
by cloudiness averaged 3.8 out of a possible 10 during the day-
light hours and 3.3 out of a possible 10 during the entire month.
The region had seventeen clear days, six partly cloudy days, and
eight cloudy days during the month.
Air mass changes were infrequent during December. Only
two frontal passages occurred during December, which is far below
average. This decrease in cold frontal passages was due to the
presence of an upper-level ridge over the western United States
for most of December. Temperatures in the Tract C-b were cool
due to seasonal influences. Transport winds were slightly
stronger than those which prevailed during November. A maritime
polar cold frontal passage occurred on the 9th and a continental
polar cold frontal passage occurred on the 12th.
A-7
-------
B . Summary of the__Meteorological Conditions
in the Oil Shale Tract C-b Region During
December 1976
An upper-level ridge over the western United States
was responsible for the below-normal precipitation totals and
slightly below normal average temperatures which occurred during
Df-.cember. Since a long wave trough was located in the eastern
United States, most of the continental polar outbreaks during
the month were directed to the east of the Tract C-b into the
eastern sections of the country. In addition, the long wave
ridge in the western United States prevented most Pacific
(maritime polar) fronts from penetrating the western United
States. No precipitation occurred in the Tract C-b area during
December. Slightly belox^ normal temperatures affected the Tract
C-b area, a reflection of the cold air which often stagnates in
the Great Basin during the winter months.
A maritime polar cold frontal passage occurred on
December 9th and a continental polar cold frontal passage occurred
on December 12th. These fronts were fairly mild since the major
thrust of the cold air was to the eastern half of the United
States.
The monthly average temperatures recorded at the
meteorological tower during December were 27.4°F at 8 feet;
26.0°F at 30 feet; 27.2°F at 100 feet; and 25.6°F at 200 feet.
These averages are approximately 7F° lower than those recorded
in November. The warmest days of the month at the meteorologi-
cal tower were the 2nd, 3rd, 4th, 8th, 9th, 13th, 17th, and 18th.
The coolest days were the 6th and 25th. The highest temperature
recorded at the meteorological tower during December was 49°F
at the 8-foot level on the 17th. The coldest temperature record-
ed at the meteorological tower was 8°F at the 8- and 30-foot
levels on the morning of the 25th. This reading also occurred
at the 30-foot level on the morning of the 6th.
A-8
-------
Monthly average relative humidities during December
were nearly the same as those that prevailed during November.
Therefore, since average temperatures were lower in December than
in November, the average moisture content of the air was slightly
lower during December (in order to maintain the same average
relative humidity) At the meteorological tower, the monthly
average relative humidities were 52.7 percent at 8 feet; 57.4
percent at 100 feet; and 53.3 percent at 200 feet. These relative
humidites correspond to dew points of 12.5°F, 13°F, and 12°F,
respectively. The relative humidity sensor at the 30-foot level
was inoperative for most of the month. The most humid days of
the month were the 1st, 5th, 6th, 10th, and 31st. The driest
days were the 16th, 17th, and 18th.
Winds at the meteorological tower during December were
only slighly stronger than the winds during November. Resultant
wind vectors at the meteorological tower during December were
200.7 degree;; at 1.6 miles per hour at 8 feet; 200.4 degrees at
2.3 miles per hour at 30 feet; 206.0 degrees at 2.8 miles per
hour at 100 feet; and 214.5 degrees at 3.6 miles per hour at
200 feet. The scalar average wind speeds associated with these
resultant wind vectors were 3, 5, 6, and 6 miles per hour, re-
spectively. The Ekman spiral and Ekman effect, i.e., a veering
in direction and increase in speed as a function of increasing
height above the surface, were evident during December. A
reference to the December wind roses for the meteorological tower
indicates that the winds at that location were primarily south-
southwesterly, with a relatively high frequency of occurrence of
southerly and southwesterly winds in addition.
The windiest days of the month at the meteorological
tower were the 7th, 8th, 9th, 23rd, 27th, and 31st. The days
A-9
-------
having the lightest winds were the llth, 12th, 14th, 16th, 17th,
20th, and 22nd. The highest five-minute average wind speed
recorded at the tower during December was 40 miles per hour at
the 200-foot level on the 16th. On a diurnal basis, the strongest
winds at the tower occurred between 1300 and 1600 hours, when
vertical mixing and the downward transfer of momentum were
maximized. The winds were lightest during the early morning
hours, between 0500 and 0900 hours, when the friction layer was
stable.
Precipitation totals in the Tract C-b Monitoring Network
during December were generally very much below normal. No pre-
cipitation was received at the meteorological tower during
December. Only 0.01 inch was received at Grand Junction.
The monthly average station pressure at the meteoro-
logical tower during December was 790.5 millibars. This reading
is 1.4 millibars lower than the November average station pressure
of 791.9 millibars. The highest daily average station pressures
occurred on the 1st and 2nd. The lowest daily average, station
pressures occurred on the 9th, 30th and 31st.
Cloudiness decreased slightly in the Tract C-b region
during December, compared to the November cloud cover and insola-
tion statistics. The region received an isolated total of 5680.4
langleys, which is equivalent to a daily average insolation total
of 183 langleys/day. This average is slightly below the National
Weather Service standard for December of 200 langleys/day in the
Tract C-b region. On a diurnal basis, the greatest solar radia-
tion rates occurred between 1200 and 1300 hours. The greatest
daily radiation totals were received on the 1st and 20th. The
lowest daily solar radiation totals were received on the 5th and
6th. The greatest five-minute radiation total received during
A-10
-------
December was 4.75 langleys (a rate of 0.95 langleys/minute),
which occurred on the 9th and 10th. The largest hourly insola-
tion total received during December was 50 langleys, which occurred
on the 9th between 1100 and 1200 hours. Because of the pro-
gressively decreasing solar elevations and the increasingly shorter
periods of daylight that prevailed during the first two-thirds of
December, the total possible solar radiation which could be re-
ceived during a day decreased monotonically throughout that period.
During the last one-third of December, progressively increasing
solar elevations provided for increasingly longer periods of
daylight. Thus, the total possible solar radiation which could
be received during a day increased monotonically throughout the
last one-third of December.
The slight decrease in cloudiness and decrease in insola-
tion which affected the Tract C-b during December caused the un-
stable stability classes to become 1 ess common than they had
been ii November. Using the Pasquill method of stability de-
termination, "C" stability (slightly unstable) was the most
common stability, occurring during 166 daytime hours, or 57.2
percent of the time. In decreasing order of frequency, "D"
(neutral) stability occurred during 88 hours or 30.3 percent of
the time, and "B" (very unstable) stability occurred during 36
hours, or 12.4 percent of the time. "A" (extremely unstable)
stability did not occur.
A-ll
-------
APPENDIX B
TRACT C-b AIR QUALITY DATA
B-l
-------
RI-JKNAL VARIATION OF NITROGEM -OXIDES (UG/M**35
TRAILER NO, - 23 PERinOfll/ 1/76 TO 11/30/76)
DAY
i
Q
3
4
5
o
7
8
y
IP!
1 1
12
1 3
14
15
16
17
18
! 9
20
?1
22
23
24
25
2 f"i
27
28
29
30
MEAN
12343
9 11 * *
*****
* 12 IS 12 *
4; 51 34 39 5?
* * * 1 5 1 8
* * * 1 i) 1 vi
* * 11 * *
* * * +11
:? * 11 13 12
*****
* * 1 1 13 2 tf
* 1 ? 13 14 17
* * * 12 y
* * * 1 0 *
39 32 94 93 -93
80 0 1 H 1 i/i
t » r a f it', 1 Ki »
H 0 'J R
f) / 3 9 1 r/i M 12 13
* * * 50 3
* * * * * i a * ; * :
5 ? m 52 5 3 5 .4 27: * *
1 h 9 14 12 1 4 : t 2 \ VI *
1 i':l 9 * * * * * 1 V>
* * * * 5 1 W 9 I'd 1 1
* * * * 1 4 H : * :
* * * * 12 is 9 *
14 H 13 17 13: 15 16
* * * : * 12
87 9 # 9 » fi 9 * * : : * :
9. 8. B, 12, 8, 6, 5. 5,
1 4 15 16
10 27 12
13 12
13 * *
15 14 lt>
: *:
* 11 10
* * 9
17 17
* 10 10
* * *
5, 6, 6.
17 18 19 20 21 22 23
9 * * *
* * 15 * 28 38 40
12 11 14 12 10 9 9
* * * * 10 10 12
* * 11 IB * 10 *
9 13 13 15 17 13 9
* 10 13 9 * * *
5. 5, 5, 5, 6, 5. 5,
24 MEAN
* 7,
* 7,
* 4,
47 13,
9 24,
9 9f
* R,
1H 8.
* 3.
7,
* 3,
* 3,
6,
* 6,
* 6,
* 5,
9 9.
* 2.
* 6*
* 0,
3,
* 5,
21 1.
58,
* 0,
1,
6,
TOTAL NJMBE* OF OBSERVATIONS a 7015
MEAN
N3
* DENOTES A VAC 10 SAMPLE BELCH THE MINIMUM DETECTABLE. CTMIT OF THE INSTRUMENT
: INDICATES CALIBRATION DURING THE HOUR
-------
DIJRNAL VARIATION OF NITRIC DXIDE (UG/M**3)
TRAILED MO, - ?3 PERIOOCn/ 1/76 TO 11/30/76)
AY
2
3
4
5
6
7
8
9
0
1
2
3
4
5
6
7
8
9
3
1
2
3
4
5
6
7
e
9
0
9
*
*
*
*
*
*
*
*
*
2.
*
*
*
*
*
*
*
*
*
1,
11
*
*
*
*
*
*
2,
11 12 13 14 15 16 17 ttf 19 2B 21 22 23 24 MEAN
*
*
*
B
*
*
*
*
*
10
*
*
*
*
*
*
*
*
*
*
*
*
10
*
*
*
*
*
*
*
9
*
*
*
*
*
*
*
*
*
56
*
*
*
*:
16
*
*
*
*
* :
14
la
*
*:
12
*
9
*
*;
* j
*
9
*:
* 10 27 12 14 IS
*
10
*
*:
*
*
10
9
*
*:
11
*
13
*
*
*
*
13
*
*
*
12
*
*
*
*
15
*
*
*
*;
*
*
*
*
10
t
*
*
*
*
*
*
*
*
*»
*
*
*
*
*
*:
*
*
*
9
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
9
*
*
*
*
*
t
t
*
*
*
*
*
9
*
*
*
*
t
*
*
i 1 * 4 K « K 17 17 1/1 * *
* DENOTES A VAIID SAMPLE BELOW THE MINIMUM DETECTABLE LIMIT OF THE INSTRUMENT
: INDICATES CALIBRATION DURING THE HOUR
7.
7,
6,
6,
2.
2,
a»
0,
BI
1.
2.
6.
2,
H,
6,
2.
3,
If
0.
0,
2,
1,
-------
VARIATION OF NITROGEN 31 OX IDECUG/M**33
? MO, - 23 PERIOQUl/ 1/76 TO M/30/76J
H D J!'?
1 >> 3 4 'i 6 / 3 9 10 11 12 13 14 115 If) 17 16 19 23 21 22 23 24 MEAN
HAY
1
?.
3
4
15
6
7
8
y
l (vi
1 1
12
13
14
15
16
17
1 0
19
?t)
2 1
82
23
24
25
26
27
28
29
3 PI
MEAM
* *
* * *
* 12 16
47 51 34
* + *
* * *
* * *
* * *
* * *
* * 11
* * +
* * 11
* !2 1 3
* * *
* * *
fi3 ^2 94
5. 7, 7,
IP * * * * * c> *
3^ 52 52 5.1 52 53 £>'<] ?6:
15 Id 1 ti 9 1. 4 12 12! *
****** * :
******
1 3 2 vS 1 vi * * * * * J
14 1 / 14 14 13 17 S * I
***** :
93 93 87 93 JJ 9 69 * * !
*:
8, 9t ^» 7, Bf 8t 5, 3,
y 34 .13 * * * * 15 * 23 38 40 47 13,
************* 5,
* ************ 2.
*;**** 9 13 13 15 17 13 9 9 9f
; *: * * * 58,
1. 2, 2. 2, 2, 2, 3. 4. 3, 4, 4. 3, 4,
TOTAL MJM0E* OF OBSERVATIONS = 7315 HEAM = 5f
+ DENOTES A VALID SAMPLE BEt.O« THE MINIMUM DETECTABLE LIMIT OF THE INSTRUMENT
J INDICATES CAL.I33ATION DURING THE HOUR
-------
VARIATION OF SULFUR DIQXIOE (UG/M**3)
R NO, - 23 PERinDCU/ 1/76 TD l
1234b678yiM 11 12 53 14 15 16 17 18 19 20 21 22 23 24 MEAN
DAY
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
ID
17
1 W
19
20
21
22
23
24
25
26
27
28
29
30
MEAN
dd
1
t_n
1, 1. 1. 1, 2, 1. 1. 1, 1, 1. 2, 2. 2. 2, 2, 1, 1, 1, 1. 1. 1, 1, 1.
TOTAL NJMRER OF OBSERVATIONS = 83&7 M£AN a 1,
* DENOTES A VALID SAMPLE BELOW THE MINIMUM DETECTABLE: LIMIT OF THE INSTRUMENT
* 0t
* tf.
* 3,
* 5,
* 0.
* 3,
* a.
* 0,
* 0,
* 0,
* 0,
* 0.
IS 9,
* 0*
* 1.
* 0,
* 0i
i.
: INDICATES CALIBRATION DURING THE HOUR
-------
!)AY
0
4
5
6
;
8
9
10
1 i
12
13
M
Ib
16
17
18
19
2r^
21
22
?3
24
2o
26
27
?H
29
30
ME AM
Md v^» ji^i * ^.t.^-iv '-^ - T-i .t.-^Mpn_> ifj \^*
*t? ^J* ^ E^^r J£ Jti. Y * 'S kM
DIJ^NAL VARIATION OF HYDROGEN S'JLFJOE C JG/M**3)
TRAILER Nu, - 23 PERJODtll/ 1/76 TO 11/30/76)
HOUR
i 2 3 4 b 6 7 3 9101112131415161718192
*
^ !
1. t. I. 1. 1. 1. 1. 1. 1, U l( 1. 9f It It 1. 0, 0i 0.
>i 21 22 23 24 MEAN
* * a
* * & «
* U »
" *
* t
* * * * *
* * * * »
* * "*
* 2,
* * * is ,
* * lc)t
^ i
*
. 0* t, 1. 1,
TOTAL NJ^BI-R OF OBSERVATIONS = 83^7 HEAS = 1,
f * DENOTES A VALI3 SAMPLE BELO"< THE MINIMUM DETECTABLE- LIMIT OF THE INSTRUMENT
CTv
: INDICATES CALIBRATION DURING THE HOUR
-------
DIURNAL VARIATION OF TOTAL HYDROCARBONSCUG/M**3 X 10**-1)
TRAILER NO, - 23 PERIOOC11/ 1/76 TO 11/30/76)
HOUR
l 2 3 4 5 6 7 3 a IB 11 12 13 14 15 16 17 18 19 ?.M 21 22 23 24 MEAN
DAY
1
2
3
4
5
6
7
B
9
10
11
12
13
1 4
15
16
17
16
19
20
21
22
S3
24
25
26
27
28
29
30
MEAN
113
127
lib
1 0 3
1MX
1M9
i ''49
107
1 0H
1 17
103
las
1 .3 3
104
J 09
112
1 £5 1
113
1 3 ft
98
11 J
ira
192
IPS
10S
114.
115
127
129
112
104
1UJ
105
1 0B
107
113
1 ^9
1 05
i y v
1 P) o
1 fl 9
1 1 1
1ft 3
1 17
136
07
1 r"iH
It 1
1 91
164
134
115,
116
H9
107
120
118
103
103
111
106
109
107
126
112
1Mb
105
105
l la
3 11
98
110
1 f-1 H
97
IMS
114
192
161
104
114,
11?.
Ill
115
104
104
110
107
1 08
106
115
116
107
104
IBS
110
ill
\w
103
1 0M
97
105
1 1 6
192
158
105
114,
lid
114
12^
IBd
1^8
109
108
109
106
114
124
1H5
1H3
1 F! 9
11?
11 H
99
if;i2
1 "12
97
1 H6
11 a
1.93
155
1W9
lib.
1 12
! 14
118
116
117
111
11 1
113
11 M
108
10b
113
123
106
104
11-1 9
114
111
1 00
102
99
.IP 7
121
196
154
104
116,
111
116
124
118
3,534
1 tf tj
139
108
1 15
136
113
113
1 ?5
135
138
113
11S3
J. 05
136
99
109
1 ?5
196
151
104
116,
116
113
118
126
105
111
ill
11^
103
105
123
119
105
106
107
111
111
105
101
99
103
1 29
198
148
1 04
ns.
114
119
121
110:
104
105
108
109
110
105
114
114
105
104
1M9
110
110
1«4
103
1 00
101
108
1 32
204
146
105
114,
117
110
111
125
101
107
109
111
1 0W
10H
117
105
104
108
110
110
101
102
102
99
108
140
209
142
105
116
114
112
133
104
105
102:
ill:
111
1 W5
Mil
112
103
134:
} 05
J 10S
t
99
103
10 il
103
:
214!
136:
105
,113,
ff
107
103
128
126
102
10a:
102
117
f
*
:
IP 4
107
107
103
106
106
99:
104
102
98
10 PI
107
123
*
133
109.
102
110
1P2
122
122
100
1.07
109
UH
121
109:
1PI4
106
108
104
106
107
1M7
101
96
99
100
98
1W5
139
165:
130
104
in.
105
116
109
123
129
98
105
104
105
t
109
103
106
108
103
102
108
1 ?8
104
96
99
101
99
137
147
179
125
106
112,
105
116
114
123
117
106
112
105
104
:
108
103
107
lia:
104
102
108
109
102
97
100
99
93:
J07
155
190
120
103
113,
107
114
107
120
118
101
107
132
104
118:
107
103
108
106:
104
102
107
108
104
98
102
98
104:
107
156
195
117
f
113,
107
111
107
119
119
108
106
103
105
113
107
104
105
105
103
102
107
108
104
107
102
102
104
107
167
198
114
105
113,
107
105
113
122
103
103
113
105
110
112
104
105
104
106
102
107
108
103
99
102
99
105
107
170
IBS
108
104
112.
120
107
112
120
116
111
106
108
IDS
109
108
105
105
104
102
102
105
108
102
102
101
102
105
109
178
181
106
104
113.
114
111
125
117
108
111
108
105
118
110
105
108
104
103
103
105
114
103
1P3
100
99
105
107
176
177
108
116
113,
105
113
108
118
115
103
111
108
105
108
110
105
105
105
106
104
106
108
103
101
100
98
105
107
178
174
106
110
112,
113
122
133
116
112
131
105
106
104
107
111
105
105
105
102
105
106
138
103
1 0^
100
98
105
107
181
172
105
116
112,
119
113
107
119
117
105
106
106
104
108
113
110
107
105
102
104
109
109
103
102
100
99
105
107
183
170
104
106
113,
109
104
122
115
105
103
110
1214
107
108
105
109
105
103
104
109
103
102
101
101
98
105
108
185
167
104
103
112,
110,
114,
110,
118,
121,
110.
103.
137.
138.
110,
110,
136,
110,
HI,
105,
134,
137,
110,
107,
131,
133,
101,
101,
133,
147,
138,
132,
137,
TOTAL NJ1BER DF OBSERVATIONS - 7453 MEAN * 113,
: INDICATES CALIBRATION DURING THE HOUR
-------
D I U .? h A L.
OF MFfHAN* (UG/n**3 X 1 0 * * - 1)
PE.WinrX]17 1776 TJ ii/33/Xb)
DAY
2 13 !4 15 3 b 17
2w 21
23 24 MEAN
p
3
4
5
6
7
8
9
Ul
1 1
12
13
15
16
17
If}
2?
23
25
27
25
?9
3tf
M E A N
w
1
oo
93 fM 95 P..} f<3 !">:$ y3 03
fJ! ? ' rt 9 Tin ?.'..''> ijri BW f*M
9f> 9«- '.'§ I.'D -<9 9b o 3 eg
^ "13 94 -4 93 94 93 94
94 a 2 02 « i 91 91 v i 93
92 OX 92 91 VJp" 9! 93, 91
9 3 ^ 3 9 fi 94 94 9 4 9 3 ') 3
(1 p .) p rj j i; p O "', O 4 C) ,'J ty .^|
0 ,1 -) $ 9 /i w 4 c; ^ o 4 ;? ,j y ^
9S '55 95 94 f>* 9. 1 9/5 Qfi
O ,J 1 f,i , ; [ fl 3 j ;!) ^ J ',; j ^ r.i , ; ^ 3 ^ J ra 1_ ;
t)(.i *& 9') j. :'? j, '-y if-- y i^t'i lets :
9 3 '"> 4 -v J> ^3 93 9 3 ;) 1 Q 5
->3 ',-3 93 'V3 yo Mb Db 9i 3B 97
97 'V 97 97 97 ^f, 97 95
94 (->u; 96 '")') 9!j 9o 93
9 p 9 3 92 9 2 9 y ' < y 9 4 9 2
91 91 92 1 i-i :) '
iv,;.i 1'-'13 95 97 97 97 9o 97
97 07 97 OX 97 97 97 9H
9» 9h 96 L»i) 9:3 95 :H? 9 fi
05, ?h. 95, 9S, 96, 9',, 9b, 95,
TorAI. MJ^cE-V OF
: 1 N 0 T C ft T £ .'i C A U 1 * * A T I 0 N [
89
9 P
9b
9 4 I
rn
on
Sb
I P 1,
!, (-1 2
94
93
92
92
9H
II?'?
r>7
.97
9b
PS.
OI.JSE
)'J*TN
,', ri
OS
91
95
07
99
94
95
9 6
32
'Jy
97
97
9b
95
RV
5
: "5 So 94
94 91 R 9 69 39
9?l 9i5 «y f.9 83
: -95 K5 3 «7 94 93
92 ?4 ?- 92 9 J 91
9 / 9 1 I 93 93 93
9 1 J 9 2 & 4 92 92.
9 7 ? H1! 4 « t> 93 tj ?
9 5 J 9 7 : 0 b 95
93 Q3 03 9?. 92
: 96 97 05 9b 94
9 6 9 b "57 96 95.
Ob 94 04 94 94
93? : 9 7 9 4 9 3
94 5)S Ob 9S 9&
; 95 96 96 SS 96
: 03: 94 95 94
97 92 91 92
91 Qi 03 93 93
93 92 93 93 92
92 91 0 ] 9 A 9 1 :
97 97 98 97 9 a
: 1 « 3 99 9 b 98
97; : 97: 96 102
9 b' ! H f) 95 95 96
95 9b 9b 95
, 95, 96, 95, 94, 94,
ATI 0 M 5 = 7453 M£A
THE7 HfliJR
94 93
8b» R.9
96 94
9rt 91
93 93
'Ji 92
97: 90
9 !) 95
94 94
95: 9 P
93 9g
93 93
9t> 95
95 96
94 95
92 90
04 y 4
92 92
96: gib
98 99
96 97
97 99
95 .96
: 97
94, 94,
» =
P4 1
97
94:
91
93
96
92
96
94
D4
95
9f?
03
95
96
94
91
94
02
95
9*) ,
101
96
96
95,
95,
89
90
94
94
93
93
94
91
95
04
94
95
93
94
96
93
89
93
91
93
103
.97
96
96
95,
03
89
09
94
94
93
93
95
96
95
94
94
93
92
94
95
93
93
92
96
90
99
97
96
105
95,
94
.94
94
93
93
93
91
97
94
94
.95
93
92
94
93
92
93
93
99
97
96
99 !
94,
94
99
09
95
93
92
93
92
91
94
93
94
95
92
92
94
95
93
sh)
93
92
95
96
99
97
95
IflM
94,
94
99
89
96
93
92
93
92
91
94
96
94
95
95
93
92
94
.96
92
90
92
92
95
98
99
10?)
96
96
94,
93
89
69
96
93
92
92
92
92
94
96
94
95
92
92
95
96
P2
91
93
91
95
98
99
97
97
97
94,
3fi,
92,
90,
93,
95,
53,
93,
93.
95*
94*.
97,
99,
94,
951
95 ',
92,
94,
93,
93,
98.
U0.
99,
97.
97,
-------
DIURNAL VaSlATIQN OF NON-METHANE HYDROCARSONS (U5/M**3 X 18**-l)
TRAILED NQ, - 23 PERIOQU1/ 1/76 TO 11/30/76)
HOUR
1 8 3 4 5 ft 7 8 9 10 Jl 12 13 14 15 16 17 IB 19 28 21 22 23 24 MEAM
ivY
14.
23,
21.
25,
26,
17,
15,
isl
16,
15,
12.
13.
13,
U'.
13,
13.
12,
10.
9.
8.
8,
47!
90,
36,
10,
1
2
3
4
5
6
7
3
9
0
1
2
3
4
5
6
7
5
9
!d
!1
!2
i i
. o
M
>5
35
?7
33
?9
}tf
MEAN
IP
22
22
31
23
14
1 5
1 0
1 5
13
12
12
1 2
1 ?
1 ?
1 1
1 4
IS
9
1r\
9
3
7
1 i!i
U
69
68
9
23.
21
26
24
31
3o
?fi
1 1
17
13
1 3
11
13
12
Iw
11
13
14
14
11
14
1
13
6
Itf
1?
8*
67
8
Slrj,
21
19
IS
24
23
11
1 6
15
15
1 6
12
23
13
IB
10
12
14
U
6
4 V
1 0
7
6
1 '3
15
93
64
8
19.
19
21
23
25
21
12
12
16
14
14
12
12
1 4
12
10
12
1 4
14
8
7
6
10
16
95
61
9
19.
24
?.S
19
?s
2t5
15
16
15
14
14
1 1
13
1 H
11
1 I?'1
1 4
1 4
1 4
7
7
f
6
1 ti
19
96
53
14
23.
19
25
23
2B
23
2^
19
19
16
1 «
11
13
14
12
10
13
14
14
8
9
7
Itf
22
98
57
8
21.
TOTAL M
27
22
27
29
25
12
34
16
15
2W
11
12
13
11
1 1
13
14
13
i i
l I
12
7
10
27
99 1
54
8
?1 t
JMBER
27
27
25
22
32
12
19
17
16
14
U
19
13
1 3
11
13
1 4
14
1 2
9
7
1. 0
29
Pi 8
49
8
21,
OF
2J
16
29
25
16:
1?.
14
15
16
16
11
13
12
11
10
15
13
16
11
1 [^
B
9
10
32
107
49
9
20,
24
21
21
30
8
15
17
15
14
11
17
Itt
11
14
14
14
8
10
7
10
40
113
45
10
21
DBSERV
23
22
t 27
35
12
15
1 7\ *
14:
15
12
: 14
15
7
lis
3 2
: 13
»
7
(
7
3
11
:
117:
40:
10
. 18,
ATIQMS
: 7 12
15 23 27
13 13 21
25 25 29
31 26 33
1 « B 7
15: 11 12
10 15 11
13 14 12
: 24 ?
: 12: 13
ia 10 10
10 IP 11
11 11 11
8 911
: e 8
11 11 12
30 11 12
6:78
646
568
977
10 8 10
19 4$ 49
: fie; 83
37 35 30
a 10
14. 16, IB,
= 7453
U
27
26
3i3
22
14
19
13
12
:
13
1 0
13
22:
10
9
11
12
0
5
7
7:
9
57
88
25
7
19.
MEAN
13
24
18
27
23
10
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11
12
20:
12
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14
10:
10
9
10
12
9
6
6
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69
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22
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19,
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21
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24
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70
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72
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19.
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16
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23
26
22
17
13
12
14
14
13
11
11
9
8
10
11
12
9
13
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9
10
75
84
10
7
18,
16
22
21
38
23
15
18
14
15
15
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10
11
10
9
10
11
18
9
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7
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75
79
12
11
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10
24
19
23
21
11
17
14
15
13
13
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1 0
13
11
12
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9
1?
7
9
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79
76
10
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18,
19
34
14
20
18
9
13
14
13
12
15
12
11
11
10
12
12
13
10
9
7
10
9
81
75
10
16
18.
25
24
19
22
24
13
14
13
13
14
16
16
12
10
9
11
14
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Id
12
7
10
9
84
70
9
10
19,
16
22
15
26
21
14
15
17
12
13
13
12
13
10
9
12
14
12
10
10
6
10
10
86
70
7
6
18,
INDICATES CALIBRATION DURING THE HOUR
-------
g
DIURNAL VARIATION OF OZOME (UG/1**3)
TRAILER MO. 23 PcKIOPCll/ 1/76 TO 11/3(3/76)
Hfl jf?
1 2 3 4 b d 7 6 9 1W 11 12 13 14 15 lb 17 18 19 2'/i 21 22 23 24 MEAN
DAY
1
2
3
4
5
6
7
3
9
1 0
11
12
13
H
15
16
17
18
19
25)
21
22
23
24
25
26
27
28
29
30
MEAN
75
73
72
66
77
71
65
71
72
72
61
55
55
1 'fl 4
92
94
93
69
71
7-5
92
85
136
102
86
93
95
64
75
79
77
77
73
63
79
74
64
71
72
72
60
53
38
1 71 3
89
93
99
59
67
75
93
85
1*2
102
8H
9 11
97
64
74
79
76
78
7 j)
69
79
74
63
71
71
88
55
53
57
li?2
8S
,91
97
69
73
73
96
91
99
104
86
93
97
So
74
79
78
77
71
S5
78
74
63
69
71
69
5 vi
55
62
1 0 4
79
3b
95
7M
57
74
9o
91
95
1 ?2
85
9$
9 a
65
75
78
78
7y
72
7 id
77
73
65
S9
72
71
50
55
64
1014
82
8b
94
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69
73
9fj
9 1
98
I fl4
94
96
99
65
76
tiPl
7 a
7fr>
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G7
75
72
64
66
71
71
47
54
62
IP! 2
77
8H
95
66
68
75
96
92
94
IP 4
77
97
97
86
76
77
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77
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67
76
70
53
56
57
73
41)
54
65
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9^
$2
53
73
1 71 ii
0 I
94
1 27
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M
76
76
73
75
69
64
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63
66
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73
47
53
65
99
S7
71
83
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7(3
131
98
96
103
73
a 7
93
63
76
76
70
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& $
& t'l
68
65
60
69:
62
65
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103
82
73
60
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62
69
93
38
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65
63
74
73
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59
56
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75
6d
70
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83
83:
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75
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70:
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1 0 3
83
1 ^9
87
87:
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83
81
76
76
65:
73
73
75
71
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59
*
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9
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1 0 1
1^1
60
79:
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114
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76
7H
67
7B
76
81
76
74
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69
63
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IPII
1914
102
85
77
67
108
86
1 1 «
106
1PI8
91
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65
80
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76
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72
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105
106
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! 62
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89
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63
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72
71
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109:
80
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62
113
88
99
102
f
92:
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64
80
;
83
77
69
71
76
78
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73
67
69
74
62
65
97
1513
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78
7a
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3.08
86
1^2
102
84
91
99
63
8«)
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74
71
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69
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74:
66
64
71
62
64
88
96
IP! 3
74
70
69
99
81
102
95
85
93
97
62
81
: 84:
1 79
69
67
68
72
66
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73*.
6*3
69
65
59
63
91
97
97
66
70
66
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79
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61
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83
77
73
72
69
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68
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57
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99
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84
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96
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91
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62
74
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7
76
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73
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61
72
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86
92
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7 a
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74
107
86
105
99
83
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96
62
73
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8 78
76
73
72
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7$
6^
73
73
74
65
57
60
91
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72
69
78
102
98
1^1
93
82
89
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63
76
77
79
75
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68
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62
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72
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65
56
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94
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70
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78
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91
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96
85
89
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65
75
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7
76
69
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73
64
71
72
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54
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89
91
101
68
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80
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80
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88
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74
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57
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6£
9i
P:<
9f.
96
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7£
7J
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TOTAL NJ^BE'^ OF OBSERVATIONS = 7«7s MEAN s 79,
^ ; INDICATES CAtiaRATlOM DURING THF. HHUR
o
-------
VARIATION OF MTROr,£»l OX I OES (UG/ K* *ol
R NO, « 23 »EPIOD(12/ 1/76 TQ 12/31/76)
DAY
1
2
vi
4
5
6
7
3
9
10
n
12
13
14
15
16
17
13
19
20
21
82
?3
24
35
25
27
28
29
31
MEAN
1 2
15 12
* t
fr *
* *
* *
* *
ifc ^V
A *
* *
* *
4 *
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* *
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* ; * *
* * ft * * * !
* * * 9 2 6 2 S
* * * * * *
******
******
******
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******
******
******
1, 2, 2. 2, 13. 3.
9
23!
?2
*
*
*
*
*
*
IP3
9,
HO'JP
1!* U 12 13 14 15 16 17 18 19 20 ?1 22 23 f>4
35 * : * * * !«.;::* 9
1819 ************
**;*************
** ::t9;*** ******
* * * 0 910 *:* * * it * * * *
: * * * 72 ;
3, 4, 2', I, 4( 1, 1, 2, i, 1, 1. 1. 1, 2. 2.
TOTAL
DF OBSERVATIONS s 7662
MEAN
3,
7t
'-1 9
2.
1,
' 9
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8,
5,
1,
0!
~ 9
0.
5,
5,
* DENOTES A VALIJ SAMPLE
THE MINIMUM DETECTABLE- L-TMTT OF THE INSTRUMENT
5 INDICATES CAL.I3RATIOM DURING THE HOUR
-------
VARIATION OF M T S I C 'JX I D£
NO, - 23 PERIODC!?/ 1/76 TO
DAY
1
o
4
5
5
7
3
9
Ji3
n
12
13
14
15
1 6
17
18
IS
50
?t
32
2o
24
25
2S
27
28
31
ME
1 ?
if £
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£ &
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t K
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* DENOTES A VAU9 S^^LF BELQW THF «TNIMLIK DETECTABLE LIMIT OF THE INSTRUMENT
t INDICATES CALI33ATIPN DURIVG THE HOUR
-------
!'j R vl A L VARIATION OF 1J I T R 0 r, i- N (j I 0 X T 0 1 ( U G / M * * 3 )
T *4 ! L E 3 N U , .. 23 « £ R I ft 0 (1 ? / i / / <=> TO I ?. / 3 1. / 7 6 )
)AY
1
2
3
4
(o
5
7
8
9
13
11
12
13
14
15
16
17
18
59
2»
21
22
?3
24
25
25
27
28
MEAN
9 10 H
13 14 15 16 17 1-8 1.9 20 21 2? ?3 ?4
td
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15
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1, 2, 2, 2,
35 :*:** * ::j?:*s
* *:17J* * r ? : ; *** * * * * * +
2625?21Bl-9 :* * * * * * * * * * * *
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4 ^ 4 ^ 4 4 ^ A- A A ^
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&$f£3t'b1z1r1(i('kit1fitibt£'li'ft'$t
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WWWWffWww^WTrirWwwWff
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* * *: ;* + *6
-------
VARIATION OP SI.HFljr? OIDX I 3F CUS/?4**3)
ER NO, -a 23 PERlODd?/ 1/70 TO 12/M/76)
1 2 3 A 5 S 7 8 9 IM 11 12 13 14 15 16 17 18 19 ?0 21 ?2 23 ?4
DAY
i
2
3
0
6
7
B
Q
1 i
12
13
i 4
15
1 0
17
13
2:d
21
?2
23
24
26
27
23
*
*
*
*
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I
it
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9
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TUTAL ^J^BE,-? OF OBSEWVATIOMS = 8^39 MEAN = f
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^ * DENOTES A VAl T^ SAMPLE REUOW THE MIMIMU^ [)ET£C f A3l.t LIMIT OF THE INSTRUMENT
-P-
J INDICATES CALJ3=!ATIOM DURING THE HOUR
-------
VARIATION OF HYOROGEW 3ULFIOECJG/M**3)
. E 3 NO, * 23 P £ f? I n 0 (1 2 / J/76 TO 1 ? / 3
DAY
i
2
3
7
8
9
10
11
12
13
H
15
16
17
18
19
22
21
22
23
24
25
25
27
23
29
33
31
M c A N
Cd
(-*
On
9 10 11 12 13 14 15 16 17 18 19 20 31 22 33
* 4
* *
* *
* *
* it
* *
* *
* *
* *
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J 0
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tf 11 1 ^
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U 1.
TOTAL, MJMBER OF OBSERVATIONS *
M F A M
U
P.
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ft
* DENOTES A VALID SMPLE KEIOW THE MINIMUM DETECTABLE LIMIT OF THE INSTRUMENT
? INDICATES cALi3'A.TinN DURIMG THE HOUR
-------
DIURNAL. VARIATION OF TOrn HYDROCARBONS CU37^**"5 X ie**-H
TRAILER HO, -c 23 P£'JTODC12/ 1/76 TO 12/31/76)
\ 2 3 4 5 6 7 8 9 Ifci 11 12 13 H 15 16 J7 18 19 20 21 22 23 24 M?*.[>
DAY
111510 8 134. 106 111 121 117 :114:1331!?7113111 ', I ', MM 6 36 ° 9
2
3
4
5
$
7
3
9
10
1 1
12
13
14
15
16
17
18
19
20
21
22
23
24
25
25
27
28
29
32
31
H E A N
1 ?> 1 101
133 140
39 9P
99 99
134 1 8 §
83 87
91 91
92 93
93 93
123 103
133 103
1^4 104
1:35 137
112 i?3
1 83
J3S 132
m m
1^4 1^5
1 B & 1 ?' 5
1 22,132,
1'.52
t 4 2 143
9/j 90
91
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89 88
92 91
93 93
10? 17,3
103 132
5 0 7 104
1 '1 3 1 0 3
1116 1?3
134 1 0 3
96
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101 l«l
104 104
110 1 J5 0
193.182,
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1 3 3
92
94
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91
93
117
101
100
1 ?3
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133
1 02
if 1
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142 142
114 11<1
89 8 ?
91 91
If 2
37 3£
93 92
93 93
H5 95
1 5? 1 1-31
103 } ?! 3
112 1'46
(?8 r-u
l£-;2 133
1B2 132
1*0 i 131
104 1. 3 4
1 ? 9 1 7( S
145
11 4
89
95
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92
9?
139
181 1
133
111
1 '? 1
132
J&2
131
1K4
105
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90
103
9.9
57
96
92:
151
104
t ?3
1^5
110
1R3
1 fi 1
IP 2
104
1 V9
1«2
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t
:
139!
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103
100
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115
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228
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1 T 4
1^2
1 '* 0
3.34
132
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112.
105
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11-5
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104
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95
97
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122
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1 £' 5
r/.9'.
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135
91
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113
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107
305
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95
91
95
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132
163
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ff
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94
92
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103
106
105
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107
1 1 v'< ,
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147
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1 24
93
90
92
93
i '2
103
103
102
104
i PU1
( 5^ V
1 f^ *)
:
1 ?6
134,
274
104
144 144
89 R9
1?(3 101
1'.'5 102
93 93
9 4 & 4
92 94
116 96
\ tf 1 1 0 2
1^4 1 cl 4
1 Pi d 1 1? 1
1 r/l 2 102
1^4 1 Pi 4
1 f-J fei 9 9
1^1 102
103 101
1 ? 5 1 K 3
1 P 6 1^5
1 i3 i) 1 1 M
i«4.11 J
266
144
89
1 Ptf
97
91
1 ? 1
93
102
1P5
102
i W 1
1 04
9S
1^3
1^2
1^3
1 J1 0
1 V'1 5
,112,
145
89
1 04
92
91
93
91
1 02
1H7
103
101
1 04
99
104
1E2
1K3
H/5
IRS
1 1 W3
144
B9
1 ^5
95
91
93
90
1 R2
1*5
1 Pi 4
1 PI
KM
99
1'pia
1P2
1 M
lfl&
106
,1^3
144
88
108
17)3
97
91
93
99
102
104
106
1 tf 2
104
1 R n
102
101
1?3
1K6
1 06
,104
145
86
1 ^0
92
91
92
90
102
104
m
1 03
1 ^3
1 "i 43
1513
1 02
104
137
106
,132
144
F9
99
i 03
95
91
92
9^
102
112
1K4
1 r/i5
1 r1 4
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IP 3
1512
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138
136
.103.
1 5 < ,
l <;?,
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115,
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95 ,
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112,
112.
IB 4,
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H'1?.
1 :<5 'i ,
182.
1?3,
l : ' ,
1 y 5 1
1 ?7 ,
TOTAL MJ'-liiE^ OF nriSE'^VATTOMS = 52^5 MEAN = 105,
C AH 3^'ATI DM DU'HMr; THE
-------
DAY
1
2
3
o
7
8
9
$0
t t
12
13
14
15
16
17
15
21
22
23
24
25
26
27
26
29
3B
31
A E
1
94
38
34
94
129
113
113
114
1H
113
79
93
9r?
87
91
92
93
9 1
91
91
03
1U2
91
91
92
92
98
2
94
95
94
129 1
112 1
116 1
114 1
1131
113 1
98
89
91
37
91
93
91
91
91
91
93
92
sy
9v:>
90
92
91
. 97,
3
94
94
95
29 1
12 i
14 1
10 1
16 1
13 1
8?
91
39
91
93
92
91
91
91
94
92
9?
91
33
91
98,
4
e
*
97
30 1
13 1
14 1
14 1
16 1
13 1
8?
89
90
86
91
93
91
91
91
91
91
02
39
9v4
90
9l;1
91
97,
5
96
94
93
13
U
14
1 5
1 0
By
89
«/
fib
91
93
91
9^
91
9^
91
92
90
90
Q;-I
91
97,
6
97
94
94
1 0 4
114
114
114
114
114
80
89
9 0
"7
91
93
91
9f!
91
90
9 (?>
92
93
81!
9t:i
92
7
97
9 Li
132
114
114
114
1H
114
Bfc)
69
98
yz
03
y l
9»
91
98
9 1
91
9 ('!
96
3y
9 1
9fi
'J ? V A
A 1 L E
8
97
P4
93
133
114
115
114
114
114
79
83
5?
52
92
Si
93
91
95
91
91
91
98
9 TI
91
r 23
L VAR
9
97
: :
94
95
101
J2S
115
116
114
114
114
80
89
89
a 8
92
921
9!
90
91
94
91
91
90
9ft
90
91
, &8t
1ATIQN OF MPTHAME(UI5/M**3 X
* ? 3 FEWJOQfl?/ 1/76 TO 1?
H n -..I P
Ik5 11 12 13 14 15 16
98 98 08 J 10*< 9,y 98
96 93 ; : j :
94 93 9b 95 95 9b
i fl f 1 9 y 97 9 5 95 95 95
IHi: 1«2 S7 97 38 96
1 136 11 8 131
1255119 119 120 120
120 123 118 116 127 123 J14
113
117
114
113
113
:
s
90
90
88:
95
Pi:
91
90
91
94
91
91
By
91
90
:
92
9S,
115
118
115
113
113
*
91
t
Qd
9 1 S
9 9
91
91
91
91
92
91
01?
89
91
93
*
1
92
103.
115
117
]
1 1 4
113
82
94
91
£>tj
91
97
91
75
91
90
92
91
92 :
90
91
94
:
91
99'.
114
117
*
1H
113
83
92
91
93
91
95
93
95
93
9*3
91
92
91
9fl
91
P5
J
92
96,
113
116
J
11.6
;
31
93
95
91
95
9d
91
92
9tf
92
92
91
90
92
92
:
92
93,
114
117
;
118
:
80
92
IPS:
93
90
94
92
92
92
Sid1
93
92
gt
91
91
J
91
98,
113
116
lie
117
t
7.9
91
93
52
93
92
92
92
93
89
9rf
92
PI
91
92
i
91
99,
/31/
57
99
118
95
98
131
113
114
119
11$
116
79
90
92
92
94
92
91
91
93
09
91
52
9?)
90
95
92
92
91
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1 S
t
114
95
94
130
113
its
US
117
116
80
90
90
91
94
94
91
91
92
89
91
93
93
9?.
93
y l
91
91
98,
19
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94
94
129
113
117
115
ue
116
79
9H
89
91
101
91
91
93
90
90
92
Q\A
92
92
91
91
91
98,
t
108
14
94
129
112
113
115
1 1 6
116
79
91
89
91
93
91
91
94
91
90
92
89
93
91
90
91
92
98,
94
93
129
112
114
121
113
116
80
92
H9
91
93
90
91
93
91
9:3
92
89
96
91
912
91
92
98,
22
94
98
94
93
129
113
11?
117
117
115
79
90
92
89
91
93
90
91
91
91
90
92
89
91
91
9B
91
91
97,
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94
97
94
93
129
113
113
115
lie
114
79
91
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91
92
90
91
91
91
91
92
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91
90
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92
91
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96 1/1?,
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94 95,
130 13',%
127,
113 116,
113
-114
115
113
79
90
91
88
91
92
90
51
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92
03
92
89
91
91
90
93
92
97,
114,
117,
116.
J 15,
114,
80,
66 ,
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94 ,
92,
91.
92,
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92 ,
91,
21 t
91.
91,
92.
Cd
i
TOTAL NUMBER OF OBSERVATIONS s
INDICATES CHI33ATIQN DURING THE HOUR
7323
ME AS
98,
-------
DAY
1
2
3
DIURNAL VARIATION OF ->nN*Ml- THiNE ri Y C3 OH a^S ONS O.'G/M* * 3 X 1 '/>**-!)
T^.MLEW MO, ? 23 PE.'UQIMI?/ 1/76 T3 12/31/7CO
13 11
i 0 J q
9 10 11 12 13 14
23 19
fr 12
16 I/ IS 19 2 a
7 15 1?
22 23 24
: 12 5 4
IRQ 157
5
5
7
8
9
10
11
12
13
14
15
16
L7
18
10
20
21
?2
?3
?4
?5
2$
?7
?0
29
30
ii
MFAM
1 ,3
1 2
9
1 4
2
3
a
2
11
13
13
12
IJJ
1 t
11
14
U
3,
\V
9
9
15
n
0
H
2
n
12
12
13
1 1
13
n
n
15
15
10.
12
13
13
43
1
0
10
H
16
12
12
12
3 1
1 1
14
19
J0.
13
9
1
13
0
0
0
17
11
12
12
12
11
7
11
! 1
13
14
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13
M
11
5
13
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0
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1 1
12
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12
11
11
1 1
14
15
ii.
5 2
0
8
3
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0
0
V,
24
1 1
12
22
8
11
11
11
14
IX
1H.
13
0
8
2
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11
12
13
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3
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14
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14
18
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5
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101
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12
12
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11
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14
15
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15
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54
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15,
IS,
TOTAL
OF OBSERVATIONS
ME
INDICATES CALIBRATION 0"RING THE HOUR
00
-------
'.) T J !< N A L, V /i 3 I A T ! n ,\' 0 F P / n \i F (!) f> 7 ^* * 3)
r^1 l"0, - 23 p~:anOU?7 j 7 7 £ T'j 1 2/3 1/7f;
1b
1 b 17
2 vi ? 1 22 ? 3 ? 4
f. u «). » vj r. ..; HI- «i :*',i ". .1 t 1 :> l .6 /i ^'-1 .'j(< -! 7 4h /!/ 14 4:-:' <1 i
OB (i i "59 v; CT- ,v 57 ft/i ft 3 6?; 'i ;*:
r>? ft',:1 f'.i PI <"'' 4S 4b 43 ,-i>v V?; 7b:
6 i.' VJ ft' l'' '-> ,S,1 S? S^ «, /, 4 ft tv,i /l (5 j
7 ,; 7i 71 74 79 73 7'. 73 ^ ')c> r>3
,-;; =.-,..1 :,;> AS >.<-, >.s -;.; ,-:., ft,; v, So
!*>b '-J3 6/1 n .'l f- } f).:j '"*) I-'--! 6b f)7 7r'
7v 7H 7H 7<) =. 1 f-'f T-i 77 73 7 4 : :
> 4 'vi h 9 * '-. '.- 1 f.; ? S3 61 '< 2 r, :>\ .<; 3
: 4 7fc 7 ti 74 7 ; 73 7 ; ft 3 6 7 ti7 KP :
<;-, 57 68 67 6K fio p.[< fly F-"b n? 6 2
7 | 72 7 >: 7 L> 7 1 7 ^ 7 -1 7 fi 7 ^ K o : r- 1 :
!'i -. ^ h 53 5 ^ ^7 f' 3 ^ 3 - ? f> M ri h 57
?! i M ^-: fvV ""'.i ^-J '-51 M c>fi: XV t P4
77 77 77 73 V ? 7 1 7 ? 7 ^ ^ P 7 1. 7 5 J
7 ? 7 '.i ft Q So ?-' 7 f^.i * ;; H =j r, 7 6 ;< 7 ;. :
/D 7:p 7b 73 70 71 ?i 72 7:^ 73 75
V? fj^ yu '; i *:? f;2 ^ i. f>;> A2 v hti
'-, , GH 57 66 ^.t. f;M So !-:7 fi.'? Ei f) 4 64 fN 4 fi f<
., t u 1 u { 1 J ^ i ' " S t.) F n [< .<; F R v A T I ;^! !
:- ; r-JD.f CATcS CAl.mAT]Ox; D'-'KI.'-Jfj THE Hi
7 2 7 1
^ f; 7 -'i
H 4 6 ,j
'i ^ J f;- 3
: f. 7 ?
M 3 '> .1
7 1 6 r>
P ;^ 71
7? 71
ft 7 7 ?
n 7 « 3
ft »; f. :<
5 ft 5 B
ft ft p9
7 y : 7 o
7 J 7 b
7 V 7 !3
f; y t ^, /
r\ /3 / ^
7 9 7 7
fW 6«
5 CJ ? 3
7 l'i 71
ft W r- 0
3 = 83R
D ! i W
74
71
s s
ft"! :
r\ -"I
ft' 3
7 c!
7?
7'.i
'/ ,1
59
ft'l
7 ,S
77
R ,1
77
R 7
P /
77J
ft 7
73
77
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71
7
77
64
ft^
fil
73
fi P
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64
ft ;)
7M
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7,1
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73
77
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63
7tj
ftfi
6?
7H
71
l-'EA*
Q d ri 7 I
7 /< : 5 w : ft «
5 b 4 .'( 4 2
77 7 -^ 7 \
ft !? 5 4 fj 3
7 /j 57 ft 1
5 ':.' ft b X 3
fi 2 ft 2 ^ (>
15 3 6 P S f)
7 ,ft : 7 ;3 7 7
fi 7 6 > -i fi 3
7 tf 7o 71
g H 9 ri fi 3
7 ^ 5 5 ft" g
K 1 5 a ft f,
*> 6 £> J? 6" 4
72 S y 63
77 73 6&
7 b 74 71
7 b 7 J 74
^' t; £j f * AX
.? " " n rv o
69 6 b 63
fi b ^ 4 o 3
7 Xj 6 9 n i)
ft y R **
07 fi 7 p H
fi «3 B9 h (t
79 P '>) 7 y
7 M M B s 5
s1 = 67,
77
ft<
PI
f-/)
^5
57
77
^ 1
7?.
f3b
fi9
f>2
*?«?
fid
77)
67
73
^ /i
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63
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ftb
(-5
65
5b
7B
54
73
59
r>3
5o
Ii9
7:^
ft"6
71
67
r> /
M 4
61
R3
72
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7?
(C .i
0 ^i
63
63
69
6b
6(3
57
79
t>5
77
4(3
71
Po
6.-1
6 4
fil
6 j
3 5
fib
74
90
ft"7
65
59
65
6"{3
71
7:-
63
82
6b
fib
67
53
73
65
77
47
56
615
61
63
57
q 1
83
6 5
72
ft.'?
69
67
57
7C5
67
73
5'i
v3
5 2
67
68
67
57
77
66
79
47
71
M
ft. 6
62
66
61
*5 1
P, 4
57
73
ft 6
7!
66
sy
73
69
75
67
C /
0 Q
63
66
7 i-5
66
53
75
67
81
6H
61
SB
P ;'.
63
RS
P3
H3
74
P6
71
64
6vj
76
69
74
67
fib
63
65
71
68
57
7:")
67
h *
6"
f,'.;
6 ,-i
n n
f > <.
7?
72
fi '.'
7c
6 ii
6 j
^ 1
63
73
72
73
C ,i
O 4
64
(-b
67
7 j
6 a
62
7H
-------
APPENDIX C
TRACT U-a, U-b AIR QUALITY DATA
C-l
-------
2
3
5
S
9
10
TOTAL SULFUR
CPPB)
WHITE RIVER SHALE
SITE A
6
PROJECT, UTAH
*****
*****
************
PRELIMINARY DATA
AS OF 24/JAN/77
NOVEMBER, 1976
AEROVIRONMENT INC.
*
********************
SUBJECT TO
REVISION
r5 CLOCK HOUR
0
" A
'« T
11 E
n
" 1
" 3
!5 n
H 5
n 6
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0
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[CA]
0
0
0
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0
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0
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[LOCAL STANDARD TIME]
11
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**********************
21
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6
23 AVE
0
[CA]
0
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1
1
OUTPT [VERSION N 38 JUL 76]
-------
TOTAL SdLFUW
(i- ^
WHITE RIVER SHALE
PROJECT, UTAH
SITE A 6
DECEMBER. 1976
AEROVIRONMENT INC.
*********************
*
* PRELIMINARY DATA
* AS OF 21/JAN/77
*
*********************
*
* SUBJECT TO
* REVISION
*
D
A
T
F
. 1
3
7
8
9
10
i
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n
1 ti
IS
17
1 -i
1 «
21
C **
cH
JO
31
AV
SO
CLOCK HOUR
00
C
0
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0
0
r,
0
0
0
CCA)
n
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0
0
0
u
n
0
0
n
0
0
0
0
0
01
. 0 .
0
0
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0
0
0
0
0
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f
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IJ
U
0
n
0
0
n
0
0
n
0
0
0
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0
u
0
02
0
0
0
0
0
0
0
C
0
0
11
0
CCA]
0
0
0
0
0
0
0
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0
0
0
0
0
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0
0
0
0
0
0?
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0
0
0
0
0
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0
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0
0
0
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0
0
0
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0
1)
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0
0
0
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0
0
0
0
0
0
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0
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0
0
0
0
0
0
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0
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0
CCA]
0
0
n
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
05
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
06
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0
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0
0
0
0
0
0
0
0
0
0
07
0
0
0
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0
0
0
0
0
0
0
0
CCA]
0
0
0
0
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0
0
0
0
0
0
0
0
0
0
0
0
08
1
1
0
0
0
0
0
0
0
0
0
0
0
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0
0
0
1
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0
0
0
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0
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0
0
0
0
0
0
0
09
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1
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0
0
0
0
0
0
0
0
0
0
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0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
10
1
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
CLOCAL STANDARD
11
1
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
2
0
0
0
0
0
0
0
0
0
0
12
1
1
0
Q
0
0
0
0
0
0
0
0
0
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0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
13
1
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0
0
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0
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14
1
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0
0
0
0
0
0
0
0
15
1
0
0
0
0
1
1
0
0
0
0
0
CCA]
0
0
0
2
0
0
0
0
0
2
0
0
0
0
0
1
0
0
0
1
16
1
0
1
0
0
1
1
0
0
0
0
0
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0
1
0
2
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
1
17
0
0
0
0
0
0
0
0
0
0
0
0
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0
0
0
1
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
18
0
0
0
0
0
0
0
0
0
0
0
0
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0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
19
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
20
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0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
21
0
0
0
0
0
0
0
0
0
0
0
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0
0
0
0
0
0
0
0
0
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0
0
0
0
0
0
0
0
0
0
22
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
25
0
0
0
0
0
0
0
0
0
0
0
0
CCA]
0
ff
0
0
0
0
0
0
0
0
0
0
0
0
0
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0
0
0
0
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0
0
0
0
0
0
0
0
0
0
0
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0
0
0
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0
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0
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1
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J
3
OUTPT [VERSION N 2H JUL 76]
-------
TOTf-L
"(Ppr-'j
HYDPOC4W60NS
WHITE RIVER SHALE PROJECT,UTAH
********
SITE A 6
.NOVEMBER, 1976
AEROVIRONMENT INC.
PRELIMINARY DATA *
AS OF 21/JAN/77 *
*********************
*
SUBJECT TO *
kEVISIO'-J " *
*
**********************
t
t
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t i
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1
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1 .6
1.7
1 . 7
1 .6
1.7
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1.7
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1.6
,1
CLOCK HOUR [LOCAL STANDARD TIME]
02
03
04
05
06
07
0«
09
10
11
12
13
14 15
16
17
18
19
20
21
22
23 AVE
1.5 1.5 1.6 1.6 1.6 1.5
1.6 1.6 1.6 1.7 1.6 2.0
1.5 1.5 1.6 1.5 1.5 1.5
1 .b 1.5 1.5 1.5 1.5 1.6
1.7 1.6 1.6 1.7 l.t> 1.6
1.5 1 .b 1.5 1.5 1.5 1.5
1.6 1.5 1.5 1.6 1.5 1.6
l.a i.u i.o 1.4 i.a 1.4
1.6 1.6 1.6 2.1 1.6 1.7
1.6 1.6 1.7 1.7 1 .fl 1.7
1.6 1.5 1.8 1.6 1.6 1.6
1.6 1.6 1.7 1.4 1.9 1.8
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.8 1.8 1.8 1.8 .6 1.7
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.7 1.7 .7 1.7 .7 .7
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1.7 1.7 .7 1.7 .8 .7
1.7 1.7 .7 1.8 .2 .6
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.7 1.6 1.7
.51.8 2.5
.51.5 1 .«
.51.5 I."
.51.6 1.7
.51.6 2.0
.4 1.5 2.0
.51.5 1 .«
.6 1.9 6."
.61.6
-------
L TOTAL HYDROCARBONS
' (PPM)
WHITE RIVER SHALE
SITE A
' DECEMBER
6
,1976
» AEROVIRONMENT
PROJECT, UTAH
*****
*
*****
* PRELIMI
* AS OF 2
*
INC.
**********
*
* SUBJ
>Q * REV
n *
12, **********
j-
is 1
E
IS
H
n
2
«
16
19
>0
y__
D
A
T
E
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
AV
SO
CLOCK HOUR
00
1.7
1.8
1.7
1 .9
1 .8
1.8
1 .5
1.5
1.5
1 .6
1 .6
1 .7
1 .8
1.8
1.7
1.6
2.0
1 .9
2.0
1.9
1.8
1 .9
1.8
1 .7
1 .6
1.6
1.7
_L?7
1 .6
1.8
i_. 7
1.7
. 1
01
1.6
1.8
1.8
1.8
1 .8
l.b
1 .7
1.5
1.6
1 .5
1.6
1 .7
1.8
1 .6
1.8
1 .8
2.0
1.9
2.0
1.9
1 .9
1 .9
.8
.7
.7
.7
.7
. 7
1.6
1.6
1 .9
1.8
. 1
02
1.6
1 .8
1.7
1.8
1 .8
1 .6
1 .6
1.5
1.5
1 .5
1 .7
1.7
2.0
1.8
1.8
1.9
2.0
1 .9
2.0
e.O
1 .8
1 .9
1 .8
1.9
1.7
1.6
1.7
1.6
1.8
1.9
1.8
.2
03
1.6
1.8
1 .8
1 .8
1.7
1 .6
1 .5
1.5
1 .5
1.6
1.7
1 .9
1.8
1.8
1.9
2.0
2.0
1.9
1.9
1.8
1.9
2.0
1.8
1.6
1.6
1.7
1 .6
1.6
1.8
1x9
1.8
.1
04
1.6
1 .8
1.7
1.7
1 .8
1.5
1.5
2.2
1 .7
1.7
1 .«
1 .8
1.7
1.9
2.0
1 .9
1.9
2.0
1.8
1 .9
1.9
2.2
1.6
1.6
1.6
1.6
1.8
L.9
1.6
.2
0,5
1.6
1 .8
1.7
1.8
1.5
1.6
1.5
1.7
1.7
1 .8
1 .8
1.7
1 .9
2.0
1.9
2.0
1.9
1.8
2.0
1.9
2.0
1.6
1.6
1.6
1.6
1.9
2,1
1.8
.2
06
1.8
1.5
1.5
1.7
1.7
1.8
1.8
1.7
1 .9
2.0
1.9
2.0
1.9
1.8
2.t
1.9
2.5
1 .6
1.6
1.6
1.6
1.9
1.6
1.6
.2
07
1.7
1.8
1.5
1.8
1.7
1.7
1.7
1 .8
1.8
1.8
2.0
1.9
1 .9
1.6
1.9
1.8
2.0
2.5
1.9
1.7
1.6
1.6
1.6
2.1
1.9
1.6
.2
08
1.7
1.8
1.6
1.5
1.7
1.8
1.9
1.9
2.3
2.1
1.9
2.0
2.0
1.8
2.1
2.3
2.0
1.9
1.6
1.6
1.6
2.7
1.9
1.9
.a
09
1.6
1.8
2.0
1.9
1.5
1.5
1.7
2.1
2.6
1.9
2.7
2.3
2.0
2.1
1.9
2.0
2.2
2.2
2.1
2.0
1.6
1.8
2.0
2.4
1.9
2.0
.3
10
1.7
2.4
.6
1.7
1.7
2.3
2.7
2.2
2.5
2.3
2.5
2.2
2.2
2.0
2.4
1.9
2.1
1.9
1.6
1.9
2.6
2.6
2.0
2.0
.3
(LOCAL STANDARD
11
1.6
1.7
1.9
1.6
1.6
1.5
1.7
1.9
2.2
1.8
2.1
2.0
2.2
1.9
2.1
1.8
2.4
1.8
1.9
1.8
1.7
2.0
1.9
2.6
1.9
1.9
.2
12
1.6
1.7
1.7
.5
.6
1.8
2.2
2.0
2.0
1.9
2.0
1.8
.9
.9
.0
.9
.9
.7
.6
1.8
1.7
2.6
1.8
1.6
.2
13
1.6
1.6
1.7
1 .7
1.6
1.6
1.6
1.8
1.8
2.0
1.9
2.1
2.3
2.0
1.9
1.9
1.6
1.8
1.8
1.8
1.6
CCA]
2.0
1.9
1.6
****
NARY
1/JA
****
ECT
IS 10"
****
****«
***
DATA
N/77
*******
TO
N
********
TIME]
14
1.7
1.7
1.7
1 .6
1.5
1.6
1.8
1.8
1.6
1.7
1.9
1.8
1.9
2.2
1.8
1.8
1.8
1.6
1.6
1.7
1.6
1.6
1.6
1.8
1.7
15
1.6
1.8
1.5
1.5
1.6
1.6
.7
.8
.7
.9
.8
2.0
.1
.7
.8
2.0
2.1
2.0
1.6
1.6
1.7
1.7
1.6
1.8
1.7
16
1.5
1.6
1.8
1 .7
1.6
1 .7
1.5
1.6
1 .7
1.7
1.6
1.6
1.9
1.6
2.2
2.2
1.7
1.6
1.6
1.7
1.8
1.6
1.7
1.7
1.6
2.0
1.7
17
1.6
.8
.6
.8
1.6
1 .7
1.7
1.7
1.7
2.0
1.9
1.9
2.2
1.7
2.1
1.7
1.7
1.5
1.6
1.7
1.7
1.6
1.9
1.7
16
1.6
2.0
1 .6
1.6
1.6
1.6
1.7
1.8
1.9
1.9
2.0
2.2
1.7
2.0
1.7
.8
.6
.7
.6
.7
.6
.6
1.7
19
1.6
1.6
1 .8
1.6
1.6
1.5
1 .8
1.6
1.8
1.7
1.6
1.9
1.9
2.0
2.2
1.7
1.9
1.6
1.7
1.7
.6
.6
.6
.6
.6
1.7
20
1.6
1.6
1.6
1.6
1.6
1.6
1.6
1.7
1.7
1.8
1.9
2.0
2.0
2.2
.8
.9
.8
.7
.6
.6
.6
.6
.6
2.0
1.7
21
1.7
1.6
1.8
1.6
1.5
.5
.6
.8
.7
.6
2.0
1.9
2.0
2.2
1 .8
1.9
1.8
1.7
1.6
1.6
1.6
1.6
1.6
1.9
1.7
22
1.6
.7
.8
.6
.5
.5
.5
.5
.6
.8
.7
.6
2.0
1.9
2.0
2.0
1.8
1.9
1.9
1.7
1.6
1.6
1.7
1.6
1.6
1.6
1.7
23
1.8
1.7
1.6
1.8
1.6
1.6
1.5
1.5
1.7
1.6
1.6
1 .8
2.0
1.7
1.8
2.0
1.9
2.0
2.0
1.6
1.9
1.6
.7
.6
.7
.7
1.8
1.7
1.9
1.7
AVE
1.7
1.8
1.8
1.7
1.6
1.5
1.7
1.6
1.6
1.7
1.6
1.9"
1.8
2.0
2.0
2.0
2.0
1.9
1.9
1.9
1.9
1.8
1.7
1.6
1.7
1.9
1.9
1.6
P
e
A
K
1.9
2.4
1.8
1.8
1.9
1.8
2.2
2.2
1 .8
1.9
2.3
2.7
2.2
2.7
2.3
2.5
2.2
2.2
2.1
2.4
2.5
2.5
2.0
1.8
2.6
2.7
2.1
( 1
C ]
OUTPT (VERSION N 28 JUL'76]
-------
METHANE
1
"' (PPM)
' WHITE RIVER SHALE PROJECT, UTAH »,»****************«** 2
3 * 3
' SITE A 6
« NOVEMBER, 1976
7 J
8 AEROVIRONMENT INC.
9
10
» CLOCK HOUR tLOCAL STANDARD TIME]
i« A
" T 00 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20
" E
2 1.5
a 31.5
» 4 1.5
s 51.5
6 1.4
7 1.6
" o a .s
"19 .5
» O> in S
" 11 .5
a 12 .7
« 14 .6
15 .5
* 16 .5
" 17 .6
58 18 1.6
» 19 1.7
» 20 1.6
21 1.7
" 23 1.6
2U 1.7
" 25 1.7
16 26 1.6
27 1.7
29 1.7
50 30 1.6
31 t 3 C
.5 l.U 1.5 .5 .5 1.5 .5 1.5 1.5 1.5 1.5 1.5 1.5
.5 1.5 1.5 .5 .5 1.5 .6 1.5 1.7 1.6 2.0 1.6 1.5
.5 1.5 1.5 .5 .5 1.5 .5 1.5 1.6 1.5 1.5 1.4 1.4
.5 1.5 1.5 .5 .5 1.5 .5 1.5 1.6 1.5 1.5 1.4 1.4
.U l.U 1,4 .4 .4 1.5 .5 1.6 1.6 1.6 1.6 1.6 1.6
.6 1.8 1.6 .6 .6 1.6 .6 1.6 1.6 1.5 1.5 1.5 1.5
.8 1.5 1.5 .5 .5 1.5 1.5 1.5 1.6 1.7 1.6 1.6 1.5
.5 1.5 1.5 .5 1.5 1.5 1.6 1.6 .7 1.6 .5 .4 .4
.5 1.5 1.4 ,U l.U l.U l.U 1.4 .6 1.6 .5 .5 .5
.5 1.5 1.5 .5 1.5 1.5 l.b l.U .5 1.5 .5 .5 .5
.6 1.6 1.7 .7 1.7 1.6 .8 1.7 .6 1.6 .7 .6 .6
.6 1.6 1.6 .7 1.6 1.7 .7 1.7 .6 1.6 .6 .6 .6
.6 1.6 1.6 1.6 .6 1.5 .6 1.7 .8 1.9 .7 .5 .5
.5 1.5 1.6 1.6 .7 1.6 .6 1.6 1.6 1.5 .5 .4 .4
.5 1.5 1.5 1.5 .6 1.6 .6 1.6 1.5 1.5 CCA] .6 .5
.6 1.6 1.6 1.6 .7 1.7 .7 1.6 1.8 1.8 .7 .6 .6[
.6 1.6 1.6 1.6 .6 1.7 1.6 1.6 1.6 1.6 .6 .7 .6
.8 .7 1.7 1.7 .7 1.8 1.7 .9 .9 1.8 1.7 .6 .6
.7 .7 1.7 1.7 1.7 1.7 1.7 .7 .7 1.7 1.7 1.6 1.6
.7 .7 1.6 1.7 1.7 1.9 2.0 .9 .9 2.0 1.9 1.7 1.5
.7 .7 1.7 1.7 1.7 1.7 1.7 .7 .7 1.7 1.7 1.6 1.6
j7 1^8 1.7 1.7 1.7 1.8 1.8 .6 .9 1.8 1.7 1.6 1.6
.5 .5 1.5 1.4 1.4
.6 .6 1.4 1.5 .4
.4 .4 1.4 1.4 .4
.4 .4 1.4 1.4 .4
.5 .5 1.5 1.6 .7
.5 1.5 1.5 1.5 .4
.5 1.4 ]
.4 1.4
.5 1.?
5.5 2.2
.6 1.6
.6 7.3 I
.5 1.5
.5 1.5
.5 1.6
A] CCA] CC
.6 1.6
.5 1.5
.5 1.5
.6 1.6
.9 1.6
.5 1.5 .5
.4 1.4 .4
.5 1.5 1.5
.6 1.6 1.6
.6 1.6 1.6
.4 1.6 1.7
.5 1.5 1.5
.5 1.5 1.5
.6 1.6 1.6
A) CCA] 1.4
.6 1.6 1.6
.6 1.6 1.6
.5 1.5 1.5
.6 1.7 1.7
.6 1.6 1.6
.4 1.5
.5 .5
.4 .4
.4 .4
.6 .6
.5 .5
.5 .5
.4 .4
.5 1.5
.6 1.6
.6 1.6
.6 1.6
.5 1.5
.5 1.5
.6 1.6
.6 1.6
.6 1.6
.6 1.6
.6 1.6
.5 .5
.7 .7
.7 .7
.7 .7
1 t ) ( 1 [ 1 C 1 C 1 ( I t ) t 1 ( ) ( ) ( ) ( 1 ( 1 ( 1 ( 1 C 1 t 1 t ) ( ) 1
PRELIMINARY DATA *
AS OF 21/JAN/77 * *
* !
AftftftAftritftftA^AAftftftftAfkA '
* »
SUBJECT TO * *
REVISION * 10
* u
13
P 'i
E i.
21 22 23 AVE A
K 16
19
.4 .4 1.5 .4 1.6
.4 .4 1.5 .5 1.5 2;
.4 .5 1.5 .5 2.0
.4 .4 1.5 .5 1.6 2-j
.4 .5 1.5 .5 1.6 2sj
.6 .6 1.6 .5 1.7 ^
.5 .5 1.5 .5 1.8 r
.5 1.5 1
.4 1.5
.5 1.5
.6 1.6
.6 1.6
.6 1.6
.5 1.5
.5 1.5
.6 .6
.6 .7
.6 .6
.6 .6
.5 1.5
.7 1.7
.6 1.7
.5 .5 1.8 A
.4 1.5 1.7 2«
.51.5 1.6 y\
.6 1.6 3.5 3'
.61.6 1.8
.6 2.1 7.3 33J
.51.6 1.9 »
.5 1.5 1.7 36
.6 1.6 1.6 3d
.7 1.6 1.7 a
.6 1.7 1.9
.71.6 1.8 w
.6 1.6 1.7 «
.6 1.7 2.0 «
.7 1.7 ; 1.7
.6 1.7 1.9 «
1 t 1 ' t 1 ( 1 I J s ,
Sj
OUTPT (VERSION N 28 JUL 761
-------
T
^ MFTHANF
1 (PPM)
2
3
5
fl
;
9
10
13
':» 0 .
" A
" T 00 01 03 03
" E
WHITE RIVER SHALE PROJECT, UTAH **********************
*
SITE A 6
DECEMBER. 1976
AEROVIRONMENT INC.
CLOCK HOUR [LOCAL STANDARD TIME]
04 05 06 07 08 09 10 11 12 13 14 15 16 17
u a i.8 1.8 1.7 1.7 1
.7 1.7 1.8 .8 1.7 1.8 1.8 1.6
" a 1 . 8 1.7 1.7 1.7 1.7 1.7 1.7 .7 1.7 1.8 2.0 1.8
H 5 1.7 1.7 1.7 1.8 1
"I 7 l.b l.fe l.b 1.7 1
"o 8 I-6 1«6 I-6 I-6 1
19 I 9 1.6 1.6 1.6 1.6 1
B--J10 l.fe l.b 1.6 l.b 1
1 1) 1.7 1.7 1.7 1.7 1
.7 1.7 l.fe .h 1.7 1.8 1.8 1.6
" 14 1.7 1.7 1.7 1.7 ]
* 15 1.7 1.7 2.0 1.7 1
» 16 1.8 1.8 l.H 1.9 1
17 17 1..9 1.9 1,9 1.9
" 18 1.8 1.8 1.8 1.6
19 19 1.9 1.9 1,8 1,8
K 20 1.8 1.8 1.9 1.8
21 1.8 1.8 1.8 1.6
" 22 1,8 1,9 1,8 1.8
" 23 1.8 1.8 1.8 1.8
24 1.7 1.7 1.7 1.7
15 25 L*7 1,6 1.7 1,7
K 26 1.6 1.9 1.8 1.6
27 1.6 1.7 1.6 1.6
» 28 i,6 1,6 1,6 1.6
' 29 1.7 1.6 1.6 1.6
M 31 L*6 1.8 1,9 1.9
M go m\ 9\ 1 1 , 1
.7 1.7 1.7 1.8 1.8 1.8 1.8 1.7
.8 1.8 1.8 1.9 a.O 2.1 3.1 1.9
.9 1.9 1.9 l.fl 1.9 2.0 ?,0 1.8
.8 1.8 1.8 1.8 1.8 1.8 a.O a.l
.8 1.9 1.9 1.8 1.8 1.9 1.9 1.9
.8 1.8 1.8 1.8 1.9 1.8 1.9 1.8
.8 1.8 1.8 1.8 1.8 1.8 1.8 1.7
.8 l.fl 1.9 1.9 1.9 1.9 a.O 1.8
.6
.7
.6
.6
.8
,8
.8
.7
.8
.8
.8 <
.6 .8 1.6 .6 1.6
.7 .7 1.7 .7 1.7
.6 .6 1.6 .6 1.6
.7 1.7 a. 7 .8 .9
.8 1.8 1.9 1.9 .9
.4 2.4 1.9 1.8 .8
.9 a.O .8 1.9 .8
.9 a.o .9 a.o a.o
.7 1.7 .7 1.7 1.7
.8 1.7 .7 1.7 1.7
?.l 1.7 .7 1.7 1.7
.8 1.6 .8 2.0 2.0 1.9 .8 1.7 a.O 1.7 1.7 .7 3.3 1.7
.6 1,6 .8 1.7 1.8 1.8 .8 1.7 1.7 1.6 1.6 .6 1.6 1.6
.6 1.6 .6 1.6 1.6 1.6 .6 1.7 1.6 1.6 1.6 .6 1.6 1.6
.6 1.6 .6 1.6 1.7 1.7 1.8 1.8 1.7 1.7 1.7 1.7 .7 1.7
.8 1.9 .8 1.9 1.8 1.8 1.8 1.8 1.6 1.8 1.8 1.7 .9, 1.7
PRELIMINARY DATA
* A3 OF ai/JAN/77
*
*********************
*
* SUBJECT TO
* REVISION
*
**********************
p
E
18 19 20 21 22 23 AVE A
K
.6 .6 1.6 1 .7 1.9 1.71.6 1.9
.6 .6 1.6 1.6 1.6 1.6 .7 1.8
.6 .6 1.6 1.6 1.6 1.9 .7 1.9
.6 .6 1.6 1.6 1.6 1,6 .6 1.8
.7 .7 .8 1.8 1.8 1.8 .8 a. 7
.8 .8 .8 1.9 .9 1.9 .9 a.l
.8 .8 .8 1.8 .8 1.8 .9 2. a
.8 .8 .8 1.8 .8 1.8 .8 2.1
2.1 a.o a.o a.o .9 1.9 .9 2.1
1.7 1.7 1.8 1.7 .8 1.8 .8 1.9
1.8 1.8 1.8 1.8 .8 1.81.8 l.A
1.7 1.7 1.7 .7 .7 1.81.8 a.l
a. 8 1.7 1.7 .7 1.7 1.7 1.8 a. 8
1.6 .6 .6 .6 1.6 1.61.7 1.8
1.6 .6 .6 .6 1.6 1.6 1.6 1.9
1.7 .8 .9 1.8 1.8 1.8 1.7 a.O
1.8 1.8 .8 1.6 1.8 1.8 1.6 1.9
OUTPT [VERSION N 38 JUL 763
-------
CARSON MONOXIDE
3
6
a
9
10
15
16
18
21
M
re
[7
"0
» 1
» CO
)1
13
ts
17
"
«
»
*
(PP!*)
WHITE RIVER SHALE
PROJECT, UTAH
SITE A 6
NOVEMBER, 1976
AEROVIRONMENT INC.
******
*
* PRE
* AS
*
****
LlM~i
OF 2
************
*
NARY DATA *
l/JAN/77 *
*
**********************
* *
* SUBJECT TO *
* REVISION *
* *
**********************
D
A
T
E
1
2
3
4
5
6
7
a
5
10
1 1
12
13
15
17
18
19
20
21
23
24
25
26
27
28
29
30
31
AV
SO
CLOCK HOUR
00
.0
.0
.1
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WHITE RIVER SHALE PROJECT, UTAH
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SITE A 6
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.004
.007
.003
.001
.004
.004
.012
( }
.006
.002
20
.006
.003
.010
.009
.009
.009
.005
.007
.007
.005
.007
.000
.005
.009
.006
.004
.008
.007
.007
.004
.004
.004
.004
.003
.007
.003
.001
.003
.003
.011
t I
.006
.002
**********************
* *
* PRELIMINARY DATA *
AS OF 21/JAN/77 *
*
*********************
*
SUBJECT TO *
REVISION *
*
**********************
P
E
21 22 23 AVE A
K
.006 .006 .008.007 .009
.003 .003 .003.005 .008
.010 .009 .009.006 .010
.009 .009 .009.009 .012
.006 .006 .008.008 .010
.008 .009 .008.008 .009
.005 .005 .005.007 .008
.007 .007 .007.007 .010
.007 .007 .006.006 .007
.004 .004 .004.005 .007
.007 .007 .007.005 .00"
.004 .004 .004.004 .007
.005 .005 .004.004 .005
.009 .006 .008.007 .009
.006 .006 .006.007 .009
.003 .003 .003.004 .006
.007 .007 .008.005 .009
.007 .007 .007.007 .008
.005 .007 .005.006 .008
.004 .004 .004.005 .009
.000 .000 .004.003 .005
.004 .004 .004.004 .007
.003 .003 .003.004 .007
.003 .003 .003.003 .006
.007 .007 .006.004 .010
.003 .003 .003.004. .007
.001 .003 .003.003 .004
.003 .001 .003.003 .006
.003 .001 .003.003 .006
.011 .009 .006.005 .012
t 1 t ] t ] t 1 t J
.006 .005 .005.005 C ]
.002 .002 .002.002 t J
2
4
5
E
8
9
10
11
12
13
14
'S
'6
17
H
20
21
23
24
1
15
re
27
2E
2<3
32
25
37
M
39
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41
,..
tt
41
5C
-
OUTPT tVERSION N 28 JUL 76]
-------
T
2
3
t
5
a
B
'1
IS
"L
16
17
P°
t
(PPM)
D_
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6
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12
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17
18
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20
21
gg
27
28
29
30
31
AV
SJ2.
00
.009
.008
.a 0-3.
. 008
.006
.006
.001
~!"006~
.012
.008
.006
.006
.008
_.108_
.008
.006
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(IM)
[OR)
HMI
.002
.004
.004
_*PP4
.006
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01
.007
.006
....003.
.008
.006
^006
.001
.006
.010
_,008
.006
.004
,008
.006
. 008
,008
".008
.006
UM1
[IM]
(OR)
[IM]
.002
,003
.004
.004
_J.P_04
.005
,002
02
.007
.008
... 0 0 3
.006
.000
~!o06
.000
.OOL
.006
.010
.OOP
.006
.004
.004
.008
,006
.008
.006
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(IM)
[OR)
[IM]
.002
.003
.004
.004
..002
.005
_.002
03
.007
.006
_.003.
.008
.006
.004
.001
. Jf V v 5
.006
.012
...MIL
.006
.004
jOU8
.006
.OOfl
.006
.008
.006
[OK)
.002
.003
.004
.004
_.Q04
.005
,002
04
.QQ1
.006
.006
...001
.009
.006
.004.
.004
.001
.006
.010
_,.QQ8
.008
.006
_iOQ8.
.00~4
.006
.006
.008
.006
[IM]
[IM]
[OR]
JIM]
.002
,003
.002
.002
. t.P. 04
.005
.003
05
.007
.006
.001
.009
.006
.-.0.01 _
.004
.001
.004
.010
_,008
.008
.008
,008
.004
.006
j.006
.008
.006
[IM]
[OR]
[IM]
[IMJ
.002
_,003
.004
.004
.005
-*P03_
06
* U U.fi
.006
.006
.001
.009
.006
.005
.004
.000
,001
.006
.010
,00fi
.006
.006
,008
.0041
.006
.006
.008
.006
IIM]
[IMJ
[OR)
[IMJ
tIM]
.002
.003
.002
.004
.002
.005
07
^flQ.3.
.007
.006
.001.
.009
.006
.^0 0 3.
.003
.001
,001
.008
.010
.008
".006
.008
.006
.004
.006
.008
.006
.006
(I Ml
IIM)
[OR]
[IM
[IM]
.002
.003
.004
.004
.005
CLOCK HOUR
06 09 10
_.D0.4_..aojL-*flil6.
.006 .007 .007
.006 .006 .006
.001 .003 .003
.009 .009 .009
.(106 .006 .008
.003 .004 .006
.001 .003 .003
j_003 .001 ,001
.008 .008 .010
.008 .008 .010
,00« .010 ,012
.004 [CAJ [CA]
.008 .008 .010
.008 .010 .008
.004 .004 .006
.006 .006 .006
.008 .006 .008
.008 .006 .010
.003 .000 .000
[IM] IIMJ [IM]
[IM] [IMJ [IMJ
[OR] [OR] [OR]
tIM] (IM) [IM]
[IM] tIM) [IM]
.002 .002 .003
.003 .005 .006
.004 .004 .006
.005 .004 .005
.004 .004 .005
.005 .005 .006
.002 .003 .003
WHITE RIVER SHALE PROJECT. UTAH ********************** J
* * 3
SITE A 6 * PRELIMINARY DATA *
* AS OF 21/JAN/77 * !
DECEMBER. 1976 * * «
********************** 7
AEROVIRONMENT INC. * *
* SUBJECT TO * '
* REVISION * "
* * "
********************** ii
-.3
[LOCAL STANDARD TIME!
P . «
E '*
11 ia 13 14 15 16 17 18 19 20 21 12 23 AVE A
K "
20
.006 .007 .009 .007 .007 .006 .006 .006 .004 .004 .004 .006 .009.005 .009
.009 .014 .011 .009 .011 .012 .011 .009 .009 .011 .009 .008 .008.009 .014 «
.009 .012 .013 .011 .011 .013 .011 .009 .006 .004 .003 .001 .001.007 .013 *
.003 .001 .008 .011 .009 .009 .009 .009 .009 .009 .009 .009 .008.005 .011 «j
.011 .013 .014 .011 .009 .009 .011 .009 .009 .009 .006 .008 .006.009 .014 H
.009 .011 .008 .008 .008 .006 .004 .004 .004 .003 .003 .003 .003.006 .Oil ^
_.M6_JL.005_JOJO_.OOe__,00&__JL006 .004 .006 .004 .004 ,004 ,004 ,006,005 .010 j--'
.008 .010 .013 .010 .010 .Oil .010 .008 .008 .0"o~4 .004 .001 .001.006 .013 ^
.001 .003 .004 .003 .004 .004 .006 .006 .006 .006 .006 .004 .004.003 .006 p
,004 .004 .010 .012 .010 .010 .010 .013 .010 .008 .006 .006 .006.005 .013 p
.012 .015 .017 .021 .021 .015 .014 .014 .012 .010 .008 .008 .008.010 .021 j"
.012 .012 .014 .010 .016 .016 .016 .014 .010 .008 .008 .010 .010.011 .016 te
.01? .014 .016 .016 .018 .016 .016 .012 .010 .008 .006 .006 .008.011 ,01ft !«
tCAJ .016 .016 .008 .010 .014 .012 .010 .006 .006 .006 .006 .004.009 .016 M
.012 .014 .016 .016 .018 .016 .014 .014 .010 .008 .010 .008 .008.010 .018 *
.010 .012 .014 .008 .012 .010 .010 .008 .010 .006 .008 .006 .006.009 .014 U
.008 .014 ,012 .014 .016 .016 .014 .012 .010 .003 .008 .006 .008.008 .016 "
.004 .010 .012 .016 .016 .016 .014 .010 .010 .008 .006 .006 .006.009 .016 *
.008 .008 .012 .016 .018 .016 .014 .010 .004 .006 .001 .006 .006.009 .018 1*
.008 .010 .014 .016 .014 .012 .012 .010 .008 .008 .006 .008 .006.009 .016 U
.000 .000 .000 [IMJ [IMJ [IMJ [IMJ [IMJ [IM] [IM] [IM] [IMJ [IMJ.004 .006
[IM] [IM] IIM) [IM] (IMJ [IM] tlMJ [IM] [IMJ [IMJ [IMJ [IM] (IM][ ] [ ) .j
[I"] [OR] [OR] [ORJ (OR) [OR] [OR] [OR] [OR] [OR] [ORl [OR] [OR] [ ] [ J rt
tOR) [OR] [IM] tIM) [IMJ [IMJ [IM] [IM] [IM] [IM] [IMJ [IM] [IM] [ ] [ ]
CIMJ [IM] tIMJ [IM] tIM) (IM) [IM] [IM] [IMJ [JM] [IM] [IM] [IMJ [ J [ J «
[CAJ [CA] .005 .005 .003 .003 .003 .003 .003 .003 .003 .003 .003.003 .005 «
.005 .006 .006 .006 .006 .006 .005 .006 .006 .006 .005 .006 .005.004 .006 .-
.011 .009 .009 .006 .008 .008 .008 .006 .006 .005 .005 .004 .004.005 .011 »
.005 .006 .006 .011 .009 .008 .006 .007 .005 .004 .004 .004 .004.005 .011 «|
.007 .007 .007 .005 .005 .005 .004 .004 .004 .004 .004 .004 .004.004 .007 wj
.004 .004 .005 .005 .005 .007 .007 .005 .005 .005 .005 .004 .004.004 .007 ^
.007 .009 .010 .010 .011 .010 .010 .009 .007 .006 .006 .006 .006.007 t J L
.003 .004 .004 .004 .005 .004 .004 .003 .003 .002 ,008 .002 .002.002 ( 1 *
55
OUTPT [VERSION N 28 JUL 76]
-------
0 Z U >N h
t
2
3
4
e
B
9
(PPf )
WHITE RIVER SHALE
PROJECT, UTAH
SITE A 6
NOVEMBER, 1976
AEROVIRONMENT INC.
**********************
*
PRELIMINARY DATA
AS OF 21/JAN/77
*
********************
SUBJECT TO
'° REVISION
11 *
12 *******************
17
?Q
21
12
n
z<
n
"n
H 1
»| '
J' ^
12
J3
H
)S
»
)7
la
"
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ia
50
17
!j
D-
A
T
E
1
2
3
a
5
6
7
8
9
10
11
12
13
ia
15
16
17
18
19
20
21
22
25
26
27
29
30
AV
SO
CLOCK HOUR
00
.024
.020
.018
.019
.017
.016
.019
.018
.015
.016
.Oia
.029
.022
.030
.018
.023
.020
.016
.013
.022
.022
.023
.025
.025
.035
.032
.030
.026
.020
.022
.005
01
.024
.019
.019
.017
.016
.010
,018
.018
.015
.015
.ou
.030
,021
.027
.015
.022
.018
.016
.017
.021
.023
.023
.026
.02U
.025
.036
.033
.030
.025
.021
L J
.021
.006
02
.020
.019
.018
.016
.016
.016
.017
.oia
.015
C 1 4
.031
,020
.025
.Oia
.022
.017
.017
.018
.020
.023
.024
.025
.C23
.Oao
.035
.028
.025
.021
[ ]
.021
J0_0_6._
03
.021
.018
.017
.oia
.Oia
.016
.017
.017
.015
.oia
.015
.031
.019
.023
.013
.022
.016
.016
.018
.021
,02a
.023
.026
.022
.025
.039
.035
.025
.023
.019
.021
oa
.018
.017
.015
.012
.015
.015
.016
.015
.Oia
.013
.013
.032
.018
.019
.013
.020
.016
.015
.018
.021
.024
.023
.027
.022
.023
.039
.037
.026
,02a
.019
.020
.007
05
.016
.016
.013
,012
.oia
.014
,015
.015
.oia
.013
.031
.017
.018
.016
.018
.015
.015
.016
.019
.023
.023
.025
.023
.0?3
.033
.037
.022
.023
.019
[ 1
.019
06
.017
.015
.013
.011
.014
.017
.oia
.oia
.014
.012
.013
.031
.014
.015
.015
.018
.015
.015
.015
.019
.023
.023
.025
.023
.021
.029
.038
.024
.023
.019
[ ]
.019
.006
07
.017
.012
.011
.010
.012
.014
.013
.014
.013
.011
.013
.031
.Oia
.Oia
.oia
.017
.015
.oia
.015
.020
."23
.023
.023
.019
.031
.038
.023
.021
.018
.007
08
.015
.015
.012
.012
.016
.016
.014
.013
.013
.014
.013
.033
.015
.013
.014
.020
.015
.015
.016
.018
.021
.022
.023
.024
.021
.033
.038
.025
.023
.020
.019
.007
09
.020
.018
[CA]
.014
.015
.017
.018
.012
.013
.014
.016
.033
.020
.013
.016
.020
.017
.017
.017
.021
.024
.024
.023
.021
.021
.035
.039
.027
.027
.021
[ 1
.020
.007
10
.025
.023
[CA]
.019
.022
.020
.020
.016
.020
.019
.018
.033
.023
.015
.020
.028
tCAJ
.018
.019
.021
.024
.025
.023
.022
.021
.034
.039
.032
.027
.026
.023
.006
(LOCAL STANDARD TIME]
11
.029
.030
[CA]
.025
,02a
,02a
.023
.019
.024
.021
.021
.033
.026
.022
.029
.033
.023
.023
.022
.020
.031
.032
.029
.027
.022
.035
.039
.035
.032
.029
.027
.005
1*
.033
.027
[CA)
.029
.026
.026
.028
.028
.025
.023
.024
.033
.025
.025
.035
.034
.026
(CA)
.028
.024
.031
.036
.033
.033
.028
.033
.039
.037
.033
.030
C 1
.030
.004
13
.034
.030
[CA]
.030
.030
.031
.029
.028
.027
.026
.024
.034
.026
.028
.035
.036
.030
.029
.031
.031
.033
.038
,03a
.033
,03a
.033
.039
.038
.022
.030
.031
.004
1.
.035
.034
(CA)
.032
.032
.032
.031
.029
.029
.027
.022
.034
.026
.028
.037
.035
.031
.030
.032
.037
.036
.040
.037
.034
.035
.032
.037
.038
.027
.033
[ )
.032
.004
15
.036
.033
[CA]
.032
.035
.032
.033
.029
.029
.023
.030
,03a
.032
.029
.038
.035
.032
.032
.034
.039
.037
.041
.038
.037
.036
.033
.038
.033
.033
.034
[ 1
.034
.004
16
.035
.033
.031
.032
.035
.032
.033
.029
.026
.021
.029
.034
.032
.032
.036
.035
.031
.033
.034
.037
.037
.039
.037
.036
.038
.034
.038
.033
.033
.032
.033
.004
17
.032
.027
.029
.029
.033
.031
.030
.028
.023
.020
.027
.031
.029
.029
.030
.030
.028
.032
.029
.034
.036
.036
.034
.033
.038
.035
.037
.031
.031
.031
t ]
.031
.004
18
.024
.023
.024
.022
.024
.029
.022
.020
.019
.017
.027
.029
.028
.028
.026
.026
.023
.025
.026
.026
.028
.031
.028
.026
.036
.034
.036
.027
.027
.029
.026
.004
19
.024
.024
.021
.020
.021
.023
.022
.019
.018
.016
.027
.029
.031
.028
.026
.025
.019
.023
.026
.024
.024
.027
.025
.024
.035
.034
.033
.027
.027
.030
C ]
.025
.005
20
.024
.023
.020
.020
.021
.020
.019
.017
.017
.015
.026
.030
.032
.033
.025
.024
.019
.021
.023
.023
.024
.025
.024
.024
.031
.033
.032
.027
.026
.028
.024
.005
21
.023
.020
.021
.021
.020
.019
.020
.017
.016
.015
.027
.026
.030
.027
.026
.023
.016
.021
.023
.024
.024
.025
.025
.026
.029
.032
.031
.024
.024
.027
[ )
.023
.004
22
.022
.019
.019
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.019
.019
.019
.016
.016
.015
.026
.024
.030
.026
.023
.022
.018
.021
.022
.023
.024
.024
.024
.026
.031
.03" 2
.033
.023
.023
.025
C )
.023
.005
23 AVE
.021.025
.019.022
.018.019
.019.020
.019.021
.019.021
.019.021
.015.019
.016.019
.016.017
.029.021"
.021.031
.031.024
.021.024
.024.023
.021.025
.017.021
.019.021
.022.022
.024.025
.023.027
.024.028
.024.028
.026.027
.033.028
.032.034
.030.036.
.023.029
.023.026
.024.025
t 1 C )
.022.024
.005.004
* *
?
A
K
.036
.034
.031
.032
.035
.032
.033
.029
.029
.027
.030
.034
.032
.033
.038
.036
.032
.033
.03a
.039
.037
.041
.038
.037
.038
.040
.039
.036
.033
.034
C )
J
i'
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* ?
7
1
1\
7.
31
C
o.
37
39
«0
41
^2
£4
45
46
47'
50
51
53
. M
OUTPT [VERSION N 28 JUL 76)
-------
e
6
(PPM)
WHITE RIVER SHALE
PROJECT, UTAH
SITE A 6
DECEMBER. 1976
AEROVIRONMENT INC.
****
*
*****
**********
** *
PRELIMINARY DATA
AS OF 21/JAN/77
******************
SUBJECT TO
REVISION
12 *******************
14
n
JI
M
)7
t?
"
t*i
»
"
.
D
A
T 00 01 02 03 04 05
f
L_»0.25_.»Q37_,03.9__..03a._..036 ..039
2 .024 .024 .024 .023 .023 .023
3 .021 .021 .021 .020 .020 .021
4 .022 .021 .020 .020 .020 .021
5 .020 .021 .021 .022 .023 .022
6 .030 .031 .029 .029 .027 .026
7 ..Q27 .026 .026 .025 .023 ..022
1 8 .021 .020 .019 .017 .018 .019
M 9 .023 .021 .021 ,021 .020 .020
^IQ .028 .03U .037 .035 ,034 ,030
11 .026- .026 .024 .024 .023 .023
12 .02« .023 .023 .024 .021 .020
U LIM) H*'l UHL IIMJ_ (IM IIMJ
14 .026 .023 .026 .026 .029 .029
15 .029 .029 .030 .029 .02.8 .027
Ife .033 ,034 .032 ,026 ^027 ,027
17 .030 ,031 .030 ,029 ,029 .029
18 .028 .028 .026 .027 .028 .027
J9 ,031 ,0"^2_j031_,033 ,033 .032
20 .036 .035 .033 ,034 ,031 .030
21 .039 .036 .035 .034 .035 .035
22 037 .038 ,037 .036 .035 ,035
23 .033 .032 .033 .032 .032 .032
24 .037 .037 .037 .037 .037 .035
25 039 ,039 ,039 .041 .040 .036
26 .036 .038 .038 .039 .035 .036
27 .035 .038 .038 .039 .039 .039
28 052 051 051 ,050 .050 .042
29 .037 .037 .038 .038 .037 .034
30 .033 .034 .033 .033 .0?7 .031
3; 030 j031 ,033 j031 ,028__,030
AV .030 .031 .031 .030 .030 .029
sp .007 007 007 .007 ,007 ,006
CLOCK
06
^.037
.022
.022
.020
.025
.025
.025
.019
.018
,025
.021
.019
[IM]
.028
.028
.029
.028
.028
.031
.031
.036
.035
.033
.038
.03«
.036
.041
.040
.036
.031
.027
.029
.007
07
06
...OJfe.^os.y.
.022 .023
,018 .019
,019.....QI9_
.027 .021
.025 .0?fr
.Or? 4 .022
.017
.016
.,025
.021
.020
[IMJ
.027
.027
.027
.029
.028
.030
.031
.035
.033
.029
.031
.037
.036
.043
.043
.038
.029
.026
.028
.007
.017
.017
,025
.020
(IMJ
[IMJ
.032
.027
.027
.029
.028
.031
.031
.037
.032
.029
.030
.036
.033
.041
.042
.036
.024
.030
.026
.007
09
.034
.023
.019
.0.20.
.023
.028
.022
.019
.015
,025
.024
(IMJ
IIMJ
(CAJ
.026
.030
.027
.028
.033
".034
.038
.032
.031
.032
.038
.034
.042
.045
.037
.029
..028
.029
.007
HOUR
10
(LOCAL STANDARD TIME!
11
_. 03 5-^.03 6.
.026 .029
.020 .023
_.019 .024
.025
.030
.028
.021
.019
.027
.027
(I Ml
(IMJ
[CAJ
.033
.032
.030
.029
.034
.035
.040
.032
.035
.037
.040
.038
.043
.042
.038
.029
,027
.031
.007
.029
.037
^230
.026
.024
,032
.033
(1MJ
(IMJ
.033
.038
,039
.036
.033
.036
.038
.045
.041
.037
.041
.043
.044
.047
.042
.044
.032
.032
.035
.007
12
13
14
.037 .037 .036
.031 .032 .034
.024 .028 .028
.026 .030 .028
.032 .032 .033
.040 .041 .042
_,03.2 .034 .036
.026
.025
_,035
.034
[IM]
[IM]
.038
.044
.042
.040
.035
.043
.045
.048
.041
.042
.047
.044
.046
.055
.050
.042
.031
.034
.036
.006
.029
.026
.036
.034
(IMJ
[IMJ
.040
.045
.041
.040
.035
.043
.046
.050
.045
.030
.051
.046
.046
.060
.050
.038
.035
.035
.039
.006
.033
.027
.038
.038
[IM]
(IMJ
.042
.046
.046
.040
.035
.042
.046
.052
.050
.035
.052
.048
.052
.060
.045
.035
.041
.038
.041
.006
15
_..OJ8_
.035
.031
mJ!Z9
.036
.042
.035
.035
.030
.039
.038
[IMJ
.032
.044
.045
.050
.039
.039
.044
.047
.054
.050
.041
.050
.049
.052
.060
.047
.037
.043
.038
.042
.006
16
_^>27_
.034
.030
^02_8
.036
.040
_i034
.035
.029
.038
.037
IIMJ
.032
.043
.043
.048
.036
.040
.044
.047
.052
.047
.042
.047
.046
.052
.060
.047
.039
.043
.035
.041
.007
17
_a.013_
.034
.028
_..Q26__
.035
.034
^033
.029
.028
.033
.031
(IM)
.028
.037
.036
.045
.032
.034
.042
.044
.051
.046
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.049
.047
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.055
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.039
.044
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.036
.006
16
_.Q29
.027
.024
_.-5a3_
.037
.032
.030
.025
.024
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.027
CM]
.025
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.039
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.041
.036
.043
.042
.044
.059
.040
.034
.043
.038
.035
.006
19
_.0?7_
.025
.022
_.Q22
.036
.032
_jJ28
.024
.024
.030
.027
(IM]
.023
.033
.036
.035
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.062
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.033
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20
_.026...
.025
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^025
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.022
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(IMJ
.023
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.031
.032
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.039
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.034
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.040
.041
.058
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.034
.042
.033
.032
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21
.^86
,024
.022
.,016
.033
.030
,023
.025
.027
.028
.026
IIMJ
.024
.026
.036
.030
.026
.031
.032
.037
.040
.035
".034
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.040
.040
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.031
.007
22
_..,025
.023
.024
_jO}9
.031
.029
_,021
.024
.028
.026
.026
[IM]
.025
.027
.037
.029
.027
.031
.033
.036
.039
.035
.035
.039
.039
.039
.056
.038
.036
.034
.029
.031
.007
23 AVE
,025.034
..022.026
.021.023
,020.022
.029.029
.028.032
,021.027
.024.024
.027.023
.027.031
.024.028
II"] .022
.026.026
.028.032
.035.034
.029.034
.028.031
.031.031
.035.035
.039.038
.036.042
.034.038
.037.034
.041 .040
.038.041
.038.041
.054.049
.039.045
.035.037
.031.035
.029.032
.031.033
.007.007
**
**
P
E
A
K
.039
.035
.031
.030,
.037
.042
.036
.035
.030
.039
.038
.024
.032
.044
.046
.050
.040
.040
.OU4
.047
.054
.050
,OU2
.052
.049
.052
.062
.052
.044
.044
.038
[ 1
t )
OUTPT (VERSION N 28 JUL 76)
-------
APPENDIX D
TRACT C-a AIR QUALITY DATA
D-l
-------
RIO BLANCO OIL SHALE PROJECT
DAILY
AVERAGES
December
Day
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
Monthly
Average
Maximum
Point
Minimum
Point
S02
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.002
.002
.002
.002
.002
.002
.002
.002
.001
.001
.001
.001
.001
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.002
.004
.001
H2S
0.004
0.004
0.004
0.004
0.004
0.004
0.004
0.003
0.002
0.002
0.002
0.002
0.002
0.002
0.002
0.002
0.002
0.003
0.003
0.003
0.002
0.002
0.002
0.002
0.003
0.003
0.002
0.002
0.003
0.003
0.003
0.003
0.004
0.002
THC
1.586
1.577
1.566
1.567
1.625
1.573
1.487
1.420
1.444
1.451
1.455
1.451
1.458
1.465
1.482
1.491
1.487
1.495
1.505
1.480
1.477
1.519
1.472
1.474
1.495
1.506
1.488
1.492
1.500
1.810
1.385
CH
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
1.
k
564
551
542
533
565
521
432
394
398
412
433
439
434
436
455
466
474
416
474
454
444
486
454
446
472
483
460
460
470
667
361
1976
NO
0.002
0.002
0.002
0.002
0.002
0.003
0.006
0.007
.._
0.003
0.003
0.004
0.005
0.004
0.005
0.005
0.004
0.004
0.005
0.003
0.003
0.003
0.002
0.004
0.010
0.000
NO
0.004
0.004
0.004
0.004
0.003
0.005
0.007
0.009
0.004
0.003
0.004
0.005
0.005
0.003
0.008
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.003
0.011
0.000
CO 03
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
.150
.109
.100
.123
.058
.101
.345
.291
.205
.307
.266
.257
.240
.241
.261
.268
.258
.235
.307
.311
.234
.255
.249
.220
.272
.272
.196
.231
.129
.121
.157
.2.8
.681
.000
0.024
0.025
0.022
0.023
0.024
0.025
0.026
0.023
0.026
0.029
0.026
0.025
0.027
0.027
0.028
0.026
0.025
0.026
0.028
0.026
0.029
0.029
0.032
0.030
0.028
0.026
0.027
0.030
0.026
0.024
0.026
0.026
0.043
0.013
D-2
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT NO.
EPA 908/4-77-006
2.
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
Emissions of Producing Oil and Gas Wells
5. REPORT DATE
November. 1977
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
8. PERFORMING ORGANIZATION REPORT NO.
Radian Corporation
100-114
9. PERFORMING ORGANIZATION NAME AND ADDRESS
Radian Corporation
P.O. Box 9948
8500 Shoal Creek Blvd.
Austin, Texas 78766
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-01-3700
12. SPONSORING AGENCY NAME AND ADDRESS
EPA
Region VIII
1860 Lincoln Street
Denver, Colorado 80295
13. TYPE OF REPORT AND PERIOD COVERED
Final
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
Project Officer for this study was Terry L. Thoem (303/837-5914), EPA, Region VIII,
Denver, Colorado.
16. ABSTRACT
This report describes the methods and results of a program to assess the
emissions of oil and gas wells. The impact of the emissions was determined through
a combination of source testing for fugitive emissions, ambient air quality
monitoring, and meteorological monitoring. Fugitive emissions were detected that
ranged from minute leaks to jet-type leaks. Ambient monitoring measured periodically
high levels of hydrogen sulfide and hydrocarbons at the oil field. Emission rates
and emission factors were determined for each of the wells sampled.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.IDENTIFIERS/OPEN ENDED TERMS
COS AT I Field/Group
Fugitive emissions
Ambient air quality
Oil and Gas
13 DISTRIBUTION STATEMENT
Document is available to the public through
NTIS, Springfield, Virginia, 22151
19. SECURITY CLASS (This Report)'
21. NO. OF PAGES
79
20. SECURITY CLASS (This page)
22. PRICE
EPA Form 2220-1 (9-73)
D-3
------- |