United States EPA-600/2-80-205b
Environmental Protection April 1981
Agency
vvEPA Research and
Development
Environmental
Perspective on the
Emerging Oil Shale
Industry
Prepared for
U.S. Environmental Protection Agency
Region VIII
Denver, CO 80295
Prepared by
Industrial Environmental
Research Laboratory
Cincinnati, OH 45268
-------
ENVIRONMENTAL PERSPECTIVE ON THE
EMERGING OIL SHALE INDUSTRY
Volume 2. Appendices
by
EPA OIL SHALE RESEARCH GROUP
Editors
Edward R. Bates
Office of Research and Development
Industrial Environmental Research Laboratory
Cincinnati, Ohio 45268
Terry L. Thoem
Office of Energy Policy Coordination
Region VIII
Denver, Colorado 80295
INDUSTRIAL ENVIRONMENTAL RESEARCH LABORATORY
OFFICE OF RESEARCH AND DEVELOPMENT
U.S. ENVIRONMENTAL PROTECTION AGENCY
CINCINNATI, OHIO 45268
-------
DISCLAIMER
This report has been reviewed by the Industrial Environmental Research
Laboratory, U.S. Environmental Protection Agency, and approved for publication.
Approval does not signify that the contents necessarily reflect the views and
policies of the U.S. Environmental Protection Agency, nor does mention of trade
names or commercial products constitute endorsement or recommendation for use.
ii
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ABSTRACT
Oil shale deposits in the United States are among the richest and most
extensive in the world. Total identified resources of medium and rich shales in the
United States are estimated at 2 trillion equivalent barrels of oil. About 600 billion
barrels is considered recoverable with present technology. This report summarizes
the anticipated EPA regulatory approach toward oil shale development and is
designed to serve as a reference and guide to EPA offices, Federal agencies, and
private developers involved with the emerging oil shale industry.
The report consists of two volumes. Volume 1 conveys EPA's understanding
and perspective of oil shale development by providing (1) a summation of available
information on oil shale resources; (2) a summary of major air, water, solid waste,
health, and other environmental impacts; (3) an analysis of applicable pollution
control technology, including limitations; (4) a guide for the sampling, analysis, and
monitoring of emissions, effluents, and solid wastes from oil shale processes; (5)
suggestions for interim objectives for emissions, effluents, and solid waste disposal,
and (6) a summary of oil shale technology, emissions, and effluents. The report
provides a brief yet thorough discussion of the environmental problems of oil shale
development.
Volume 2 contains six appendices: State-of-the-Art of Oil Shale Development;
Procedures for Ambient Air Monitoring; Past, Present, and Future Monitoring
Activities; Applicable Federal, State, and Local Laws and Regulations; List of
Analytical Procedures Manuals and Quality Assurance Manuals; and Catalog of
Existing Federal, State, and Locally Required Permits.
iii
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CONTENTS
Abstract iii
Figures vii
Tables x
Abbreviations xiv
Appendix A - Status and Development Plan of the Oil Shale Industry ... A-l
Rio Blanco Oil Shale Co A-2
Cathedral Bluffs Shale Oil Co A-7
White River Shale Project A-ll
Colony Development Operation A-l**
Union Oil Co A-20
The Superior Oil Co A-22
TOSCO Sand Wash Project A-27
Occidental Oil Shale, Inc A-27
Geokinetics, Inc A-31
Equity Oil Co A-33
Multi Mineral Project A-34
Dow Chemical Co A-38
Laramie Energy Technology Center A-39
References A-41
Appendix B - Procedures for Ambient Air Monitoring B-l
Introduction B-l
Meteorological Measurements B-l
Visibility B-5
SO2 Methods B-7
CO by Nondispersive Infrared Method B-9
Suspended Particles by High-volume Sampler B-9
Ozone Methods B-10
NO2 Methods B-l 1
Carbon Monoxide, Methane, and Nonmethane Hydrocarbons
by Flame Ionization Detection B-l2
Hydrogen Sulfide, Mercaptans, and Organic Sulfides
by Flame Photometric Detection B-l3
Lead Using Atomic Absorption Spectroscopy B-l4
Mercury Methods B-l'/-
Arsenic Using a High-volume Sampler B-l5
Methods for Particulates B-l5
Sulfates Using the Methylthymol Blue Method B-16
Nitrates Using Copperized Cadmium Reduction B-l7
Fluoride on Hi-vol Filters B-l7
Ammonia Methods B-l8
v
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Benzo(a)pyrene Using Fluorometric Analysis B-19
Cj Through Cs Hydrocarbons Using Gas Chromatography B-20
Organics by Absorption, Purge, and Trap Gas Chromatography . . B-20
PAH Using UV Spectroscopy B-20
Polycyclic Organic Matter B-21
Asbestos and Asbestos-like Fibers B-21
References B-22
Appendix C - Environmental Monitoring Activities - Past, Present,
and Proposed C-l
Tract C-a C-l
Tract C-b C-62
Tracts U-a, U-b C-l03
U.S. Department of Energy Rock Springs Research Sites C-l29
Paraho C-l 39
Colony Development Operation C-l51
Bx (Equity) Oil Shale Project C-172
Occidental Oil Shale Inc., Logan Wash Project C-l77
Geokinetics Oil Shale Group C-l 86
Dow Chemical Co C-l93
Talley-Frac/Rock Springs Project C-199
References C-206
Appendix D - Applicable Federal, State, and Local Legislation,
Standards, and Regulations D-l
Legislation D-l
Standards D-2
Permit Programs - Existing D-25
Appendix E - Quality Assurance Bibliography E-l
Appendix F - Federal and State Permits Required for Operation
of an Oil Shale Facility F-l
vi
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FIGURES
Number Page
A-l Project schedules for commercial oil shale projects A-3
A-2 Project schedules for field tests of oil shale projects A-4
A-3 Rio Blanco Oil Shale Co. MDP Mine Development A-6
A-4 Occidental modified in situ retorting process A-8
A-5 Flow diagram of proposed commercial operation on Tract C-b .... A-9
A-6 Flow diagram of proposed commercial White River
Oil Shale Project A-13
A-7 Proposed water control plan for White River Shale Project A-16
A-8 Flow diagram of proposed Superior Oil project A-2.5
A-9 Schematic of Occidental's modified in situ test A-29
A-10 Plan and section of a typical Geokinetics horizontal
in situ retort A -32
A-ll Well layout of Equity in situ test A-35
A-l2 Equity well completion cross section A-36
C-l Tract C-a, regional location map C-2
C-2 Location map for Tract C-a air quality and meteorology
monitoring stations C-3
C-3 Stream-gaging stations, rain-gaging stations and
alluvial aquifer monitoring holes at Tract C-a C-l4
C-U Location map for Tract C-a baseline spring and seepage
sampling sites C-l6
(..'--5 Location map for Tract C-a shallow and deep groundwater
t6St\A/t'-*]iii . a a . , . . . # . , . , . . a a * • . • • • • • • C ~ 2 1
<¦¦¦(; Location map for Tract C-a interim surface-water gaging
arid alluvial test wells C-23
7 Locations of monitoring stations for hydrology
studies during the modular development phase C-24
C-8 Location map for major Tract C-a spring and seep sampling
stations C-2 7
C-9 Location map for Tract C-a proposed commercial development
phase groundwater test wells C-29
C-10 Location map for Tract C-a interim range/browse and faunal
monitoring sites C-34
C-ll Study area for mule deer pellet-group counts (RBOSP
modular development phase monitoring program) C-UO
C-l2 Sampling site locations for aquatic ecology studies
during the modular development phase C-42
C-l3 Tentative locations of soil sampling sites C-45
vii
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Number Page
C-14 Location map for Tract C-a vegetation monitoring sites
for the proposed commercial development phase biological
resource monitoring program C-48
C-15 Location map for Tract C-a re vegetation test plots for
the baseline solid waste data-gathering program C-51
C-16 Environmental sound-level monitoring sites, RBOSC Tract C-a . . . C-60
C-17 Baseline air quality and meteorological monitoring
network at Tract C-b C-64
C-18 Ambient air quality interim and development monitoring
network at Tract C-b C-66
C-19 USGS stream-gaging stations and springs and seeps utilized
during surface-water monitoring program at Tract C-b C-72
C-20 Precipitation gages on or near Tract C-b C-76
C-21 Alluvial and deep wells established in the Tract C-b
area and used during baseline monitoring C-78
C-22 Alluvial test wells in Tract C-b area during development
phase monitoring C-82
C-23 Deep aquifer monitoring well sites in Tract C-b area
during development phase monitoring C-84
C-24 Vegetation sampling site locations used during baseline
data gathering at Tract C-b C-85
C-25 Interim phase biological resource monitoring program
at Tract O ¦¦ b C™90
C-26 Development phase biological resource monitoring
program sites at Tract C-b C-93
C-27 Environmental noise monitoring network at Tract C-b C-99
C-28 Location map for Tracts U-a and U-b projects C-104
C-29 Location map for Tracts U-a and U-b air quality monitoring
stations for the baseline data gathering programs C-106
C-30 Location map for Tracts U-a and U-b interim air quality
and meteorology monitoring stations C-109
C-31 Water and geologic resources baseline monitoring stations C-114
C-32 Location map for Tracts U-a and U-b biological resource
sampling sites C-119
C-33 Area location map for DOE oil shale in situ research sites C-130
C-34 Monitoring well patterns at Rock Springs research sites
and Upper Green River C-135
C-35 Sampling points of gaseous process emissions at Anvil
Points operations, Colorado C-l^l
C-36 Sampling sites for ambient air quality monitoring around
the mine at Anvil Points C-143
C-37 Sampling sites for ambient air quality monitoring in the
crushing area at Anvil Points C-1W
C-38 Sampling sites for ambient air quality measurements around the
retorting operations and shale disposal areas at Anvil Points .... C-145
C-39 Locations of stream sampling sites at Anvil Points C-1^8
C-40 Cross section showing the design of the lysimeters
at the Paraho Development C-l50
viii
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Number
Page
C-41 Plot plan of lysimeter study site C-152
C-42 Location map for CDO primary weather stations C-154
C-43 Location map for CDO atmospheric dispersion sampling stations . • C-156
C-W Location map for CDO and USGS water quality sampling stations . . C-159
C-H5 Location map for CDO aquatic ecosystem sampling sites
for the baseline biological resource monitoring program C-163
C-46 Colony revegetation plots, Dow Property, Garfield
County, Colorado C-167
C-47 Location map for BX (Equity) oil shale project and
mechanical weather station C-17^
C-48 Location map for BX (Equity) air resources and water
resources monitoring sites • • • • C-175
C-49 Location of meteorological and hydrological
installations at Logan Wash C-178
C-50 Location map for biological monitoring program at
Logan Wash C-183
C-51 Sites of noise measurement at Grand Valley and vicinity C-185
C-52 Locations of meteorological monitoring equipment
around Geokinetics project site C-188
C-53 Vegetation plot design for Geokinetics plant
monitoring program 1 C-19<*
C-54 Surface and groundwater monitoring sites at the Dow
development C-195
C-55 Tentative subsidence monument pattern at the Dow
development C-198
C-56 Pattern of observation wells at the Talley-Frac development • • • • C-202
D-l Designated Class I areas in oil shale region D-7
D-2 Current stream classification for oil shale country D-9
D-3 Proposed stream classifications D-l8
D-4 Fuel burning equipment - particulate emission D-29
D-5 Process weight rate - particulate emission D-30
ix
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TABLES
Number Page
A-l Commercial Plant Emissions for Tract C-b A-ll
A-2 Estimated Atmospheric Emissions for the White River
Shale Project A-14
A-3 Estimated Solid Wastes Generated by the White River
Shale Project A-15
A-4 Estimated Emissions from the Colony Shale Oil Plant A-19
A-5 Estimated Solid Wastes Generated by the Colony Project A-20
A-6 Estimated Emissions from Union's Proposed Long Ridge
Experimental Shale Oil Project A-23
A-7 Estimated Emissions from Superior's Project A-26
A-8 Oxy Logan Wash Retorts 7 <5c 8 Air Emissions Rates A-30
B-l Summary of Methods Presented B-2
B-2 EPA Reference and Equivalent Methods Designated as
of December 21, 1978 B-4
C-l Air Quality and Meteorological Parameters,
Instrumentation, Sampling Frequency, and
Schedules of the Baseline Air Resources
Monitoring Program for Tract C-a C-4
C-2 Atmospheric Diffusion Sounding Test Results of
Baseline Air Resources Monitoring Program
for Tract C-a C-6
C-3 Air Quality Monitoring Schedule for the Modular
Development Phase Monitoring Program at Tract C-a C-9
C-4 Meteorological Parameter Monitoring Schedule for the
Modular Development Phase Monitoring Program at
Tract C-a C-ll
C-5 Meteorological Parameters Proposed to be Measured
in the Commercial Development Phase Monitoring Program
at Tract C-a C-l2
C-6 Location and USGS Identification Numbers for Stream-
and Rain-Gaging Stations at Tract C-a C-l5
C-7 Sampling Schedule Summary for Surface and Groundwater
Monitoring Program at Tract C-a C-l7
C-8 Drill Hole Completion Summary for Tract C-a and Vicinity C-20
C-9 Summary of Hydrology Monitoring Program for the Modular
Development Phase Program at Tract C-a C-25
C-10 Summary of Hydrology Monitoring Program for the
Commercial Development Phase Program at Tract C-a C-30
x
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Number
C-ll Schedule for Modular Development Phase Range Studies
at Tract C—a C—39
C-12 Monitoring Program Schedule for Modular Development
Phase Aquatic Ecology Studies C-43
C-13 Summary of Proposed Commercial Development Phase
Terrestrial Monitoring Program at Tract C-a C-47
C-14 Schedule of Field Events for Baseline Revegetation
Studies on Oil Shale—Tract C-a C-53
C-15 Summary of Seeding and Mulching Activities Performed
During Revegetation in 1978 at Tract C-a C-55
C-16 Three Seed Mixtures Used for RBOSC Revegetation
Activities During Fall 1978 C-56
C-17 Commercial Development Phase Solid Waste Monitoring
Program at Tract C-a C-58
C-18 Summary of Baseline Air Quality and Meteorology
Monitoring Program at Tract C-b C-65
C-19 Summary of Development Phase Air Quality and
Meteorology Monitoring Program at Tract C-b C-68
C-20 Development Phase Emission Monitoring at Tract C-b C-70
C-21 Summary of Surface Water and Groundwater Sampling
Schedule at Tract C-b C-73
C-22 Surface Water Monitoring Stations for the
Development Phase at Tract C-b C-80
C-23 Summary of Phytosociological Studies and Vegetative
Sampling in Baseline Vegetative Data Gathering
Programs at Tract C-b C-87
C-24 Schedule of Baseline Data Collection on Birds at
Tract C-b C-89
C-25 Summary of Development Phase Biological Resource
Monitoring Program C-95
C-26 Air Quality Parameters, Monitoring Instruments and
Total Root-Mean-Squared Accuracy of the Baseline Air
Quality Program for Tracts U-a and U-b C-107
C-27 Meteorological Parameters Monitored During the
Lease Suspension Period C-lll
C-28 Air Quality and Meteorological Parameters,
Instrumentation, Sampling Frequency and
Schedules of Proposed Commercial Phase Resource
Monitoring Program for Tracts U-a and U-b C-112
C-29 Water Quality Parameters Measured in Baseline,
Surface and Groundwater Data Gathering Program
for Tracts U-a and U-b C-115
C-30 Summary of Parameters to be Measured for the Proposed
Commercial Development of Tracts U-a and U-b C-12^
C-31 Laramie Environmental Technology Center
Priority Air Pollutant Monitoring Equipment Used
at DOE Rock Springs Sites C-132
C-32 Proposed Water Sampling Schedules at Rock Springs
Site 12 C-136
xi
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Number Page
C-33 Air Quality Parameters Measured During Thermal
Oxidizer Stack Monitoring C-140
C-34 Air Quality Parameters and Methods of Analysis for
Process Emission Monitoring at Anvil Points C-142
C-35 Water Quality Parameters and Methods of Analysis
Employed During Process Water, Surface Water and
Groundwater Monitoring at Anvil Points C-147
C-36 Water Quality Parameters to be Measured During
Operation of the BX (Equity) Oil Shale Project C-176
C-37 Water Quality Parameters to be Measured During
Operation of the Logan Wash Project C-180
C-38 Hydrological Instrumentation and Sampling Schedule
of Baseline Monitoring Program at Logan Wash Project
and Vicinity C-181
C-39 Parameters and Instrumentation Used in the
Meteorology Monitoring Program at Geokinetics
Oil Shale Project C-189
C-40 Surface Water Monitoring Stations for Geokinetics
Oil Shale Project C-190
C-41 Water Quality Parameters to be Measured for Each
Station in Water Resources Monitoring Program at
Geokinetics Oil Shale Project C-191
C-^2 Groundwater Monitoring Wells for Geokinetics
Oil Shale Project C-192
C-^3 Constituents to be Determined in Selected Water
Sample and Analysis Programs at Dow Development C-196
C-M Talley-Frac/Rock Springs Ambient Air Quality and
Meteorology Monitoring Sites and Parameters Measured C-200
C-45 Environmental Monitoring Techniques Used During
Operation of the Talley-Frac Oil Shale Development C-201
C-46 Analytical Methods for Schedule A Water Analysis at
the Talley-Frac Development C-203
C-W7 Analytical Methods for Schedule B Water Analysis C-204
D-l National Ambient Air Quality Standards D-3
D-2 Ambient Air Quality Standards-Wyoming D-4
D-3 Prevention of Significant Deterioration of Air
Quality (PSD) Standards D-5
D-4 Designated Class I Areas of Colorado, Utah and
Wyoming D-6
D-5 Summary of Colorado Water Quality Standards D-10
D-6 Numerical Standards for Protection of Beneficial
Uses of Water D-ll
D-7 Numerical Standards for Protection of Class 3C
Water Use D-l 3
D-8 Physical and Biological Parameters D-14
D-9 Inorganic Parameters D-l5
D-10 Metal Parameters D-16
D-ll Organic Parameters D-17
xii
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Number Page
D-12 Proposed Stream Classifications and Criteria
Exceptions - White River Basin D-I9
D-13 Proposed Stream Classifications and Criteria
Exceptions - Colorado River Basin D-20
D-14 Recommended Water Quality Criteria D-22
D-15 Promulgated Drinking Water Standards D-26
D-16 Proposed Secondary Drinking Water Regulations D-27
D-17 New Source Performance Standards for "Oil Shale
Related Facilities" D-28
D-18 Levels of Control Applicable to Existing Sources Under
1977 Amendments to FWPCA D-33
D-19 BPT Effluent Limits as Established in 40 CFR 419.52 D-36
D-20 BAT Effluent Limitations Per 40 CFR 419.53 D-37
D-21 Refinery New Source Performance Standards as Per
40 CFR 419.55 D-38
D-22 List of 129 Specific Pollutants Compound Name D-40
xiii
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ABBREVIATIONS
AAS
__
atomic absorption spectroscopy
ANSI
—
American National Standards Institute
AOSS
—
Area Oil Shale Supervisor
API
—
American Petroleum Institute
ARCO
Atlantic Richfield Company
ASTM
—
American Society for Testing Materials
BACT
—
best available control technology
BAP
—
benzo(a)pyrene
BAT
—
best available technology
BCT
—
best control technology
BLM
—
Bureau of Land Management
BOD
—
biochemical oxygen demand
BPD
—
barrels per day
bpi
—
bytes per inch
BPSD
—
barrels per stream day
BPT
—
best practicable technology
BTU
—
British thermal units
cal
—
calorie
CDM
—
Camp Dresser & McKee Inc.
CDO
—
colony development operation
CDOW
~
Colorado Department of Wildlife
CFR
—
Code of Federal Regulations
cfs
—
cubic feet per second
COD
—
chemical oxygen demand
COS
—
carbonyl sulfides
CRS
—
Colorado Revised Statute
DDP
—
detailed development plan
DO
dissolved oxygen
DOC
—
dissolved oxygen content
DOE
—
Department of Energy
DOI
—
Department of the Interior
EC
—
electrical conductivity
EDF
—
Environmental Defense Fund
EDTA
—
ethylene-diamine tetraacetic acid
EDXRF
—
energy dispersive x-ray fluorescence spectroscopy
EIS
—
environmental impact study
EMP
—
environmental monitoring program
EPA
—
Environmental Protection Agency
ERDA
—
Energy Research and Development Administration
FID
—
flame ionization detector
FWPCA
—
Federal Water Pollution Control Act
GC/MS
~
gas chromatograph/mass spectrometer
xiv
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GPM
—
gallons per minute
GPT
—
gallons per ton
ha
—
hectare
HC
—
hydrocarbons
IERL
—
Industrial Environmental Research Laboratory
in situ
—
in the original location
J.T.U.'s
—
Jackson Turbidity
kcal
—
kilocalorie
kmph
—
kilometers per hour
LETC
—
Laramie Energy Technology Center
LHD
—
load haul dump
mb
—
millibars
MDP
—
modular development phase
MDPMP
—
modular development phase monitoring program
MIS
—
modified in situ
MMC
—
Multi Mineral Corp.
mph
—
miles per hour
MST
—
Mountain Standard Time
MTB
—
methylthymol blue
NAAQS
—
National Ambient Air Quality Standards
NAS
—
National Academy of Sciences
NBS
—
National Bureau of Standards
NDIR
—
nondispersive infrared
NMHC
—
nonmethane hydrocarbons
NOIC
—
National Organization of Instrument Certification
NOx
—
oxides of nitrogen
NPDES
—
National Pollutant Discharge Elimination System
N5PS
—
New Source Performance Standards
NWS
—
National Weather Service
ORNL
~
Oak Ridge National Laboratory
OSHA
—
Occupational Safety and Health Administration
OXY
—
Occidental Oil Shale, Inc.
PAH
—
polycyclic or polynuclear aromatic hydrocarbons
pcf
—
pounds per cubic foot
pCi
—
picocurie
PIXE
—
particle-induced x-ray emission
POM
~
polycyclic organic matter
PPb
—
parts per billion
ppm
—
parts per million
ppt
—
parts per thousand
PSD
—
prevention of significant deterioration
PSIG
—
pounds per square inch (mercury scale)
RBOSC
—
Rio Blanco Oil Shale Company
RBOSP
—
Rio Blanco Oil Shale Project
RCRA
—
Resource Conservation and Recovery Act
SAR
—
Sodium Absorption Ratio
SCF
—
standard cubic foot
SCFD
—
standard cubic feet per day
SCMD
—
standard cubic meters per day
SCS
—
Soil Conservation Service
SGR
—
steam gas recirculation
SLM
—
sound level meter
XV
-------
SRM
— Standard Reference Material
SSU
— Saybolt seconds universal
TC
— total carbon
TCM
— tetrachloromercurate
TDS
— total dissolved solids
TFE
— tetrafluoroethylene
THC
— total hydrocarbons
TIC
— total inorganic carbon
TKN
— total kjeldahl nitrogen
TLC
— thin layer chromatography
TOSCO
— The Oil Shale Corp.
TPD
— tons per day
TPSD
— tons per steam day
TPY
— tons per year
TRW
— Thompson-Raymo-Woolridge
TSP
— total suspended particulates
TSS
~ Total Suspended Solids
USBM
— U.S. Bureau of Mines
USGS
— U.S. Geological Survey
uv
— ultraviolet
VTN
— Voorheis-Trindle-Nelson
WRSP
— White River Shale Project
xvi
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Prepared by The Pace Company Consultants
-------
Development Operation. A 6,400-tonne/day (47,000-bbl/day) project has been
proposed using TOSCO II retorting. Union Oil's project would employ a 1,224-
tonne/day (9,000-bbl/day) retort of the firm's own design. Superior Oil's commercial
multi-mineral recovery project would use a circular grate retorting process
developed by Superior and would have a capacity of 18,100 tonnes/day (24,000
tons/day) of oil shale. TOSCO plans to use its TOSCO II retorting technology and
underground mining on the Sand Wash project; the commercial plant, as proposed,
would include six 9,980-tonne/day (11,000-ton/day) retort modules.
A summary of the schedules for these projects is shown in Figure A-l. Several
companies (Union, Superior, Paraho, TOSCO, Lurgi) are conducting continuing
studies (on proprietary bases) concerning aboveground retorting. In addition to these
surface retorting studies, true or modified in situ development programs are being
conducted by Occidental, Geokinetics, Equity, Dow Chemical, and the U.S.
Department of Energy (DOE) Laramie Energy Technology Center, and Multi Mineral
Corp.
Occidental Oil Shale, Inc. currently has a cost-sharing contract with the DOE
to develop and demonstrate the technical feasibility of the company's vertical
modified in situ recovery process. Successful results from these field tests would
serve as the basis for modular large-scale development using the process on Federal
Tract C-b. Geokinetics, Inc., also has a cost-sharing contract with DOE to develop
an in situ recovery process. This technique would involve high-explosive
fragmentation of shallow deposits followed by true in situ retorting with a
horizontally moving fire front.
The project being conducted by Equity Oil Co. in Colorado is designed to
evaluate the feasibility of injecting superheated steam into the leached oil shale
zone in the Piceance Creek Basin to retort the oil shale in situ. Funding is being
provided through a cooperative agreement with DOE.
The Dow Chemical Co. has a contract with DOE to conduct a program to test
in situ processing of Michigan Antrim shale. Conventional fracturing, propping, and
leaching techniques will be employed, followed by horizontal in situ retorting. The
Laramie Energy Technology Center has been conducting field tests in true in situ
production of shale oil since 1966. Current tests involve a combination of steam and
air injection at the Wyoming test site near Rock Springs. Future testing will
concentrate on determining methods for producing sufficient porosity and
permeability for true in situ retorting.
A summary of the project schedules for these field tests is shown in Figure A-
2.
RIO BLANCO OIL SHALE COMPANY
Gulf Oil Corp. and Standard Oil Co. (Indiana) submitted the high bonus bid for
Tract C-a ($210 million) on January 8, 1974, at the first lease sale under the Federal
Prototype Oil Shale Leasing Program. The lease became effective on March 1,
1974. In March 1976, Rio Blanco Oil Shale Project, the joint venture formed by Gulf
and Standard for the purpose of developing the tract, submitted a Detailed
Development Plan (DDP) which called for open pit mining and surface retorting of
the oil shale reserves. Shortly thereafter, a one-year lease suspension was obtained
A-2
-------
PROJECTS UNDERWAY ACCORDING TO SCHEDULES SHOWN
PROJECT
1978 1979 1980 1981 1982 1983 198411985 1986 1987 1988
C-«
STOT. DCV. pns.
COMM. DEV. PNS.
C-b
MOO. DCV. PNS.
COMM. DEV. PMS.
CONST.
OP CKATION
, I ' ' ' , s
| MINE 4 FACILITY CONST I OPERATION t
PRIPNOOUCTION MINING
m
i i ¦
OPERATION |
| RETORT MINING > CONST.
operation
J-
PROJECTS HAVE NOT STARTED, BUT WOULD FOLLOW
GENERIC SCHEDULES SHOWN
YEARS FROM START
PROJECT
1
2
3
4
5
8
7
8
9
10
1 1
U-i/U-b
sinqls retort
COMMERCIAL
COLONY
MME DEVELOPMENT I MININQ
I I I I 1
| CONSTRUCTION | RETORT 0 PC RATION
|
MININQ
1 1 1 ! T
CONSTRUCTION | OPERATION
¦ 1 i i i i r
CONSTRUCTION |
OPERATION
UNION
I
CONSTRUCTION |
OPERATION
SUPERIOR
CONSTRUCTION
I
PUU. 3CALX OPERATION
TOSCO SAND
CONSTRUCTION
OPERATION
WASH
MULTI-MINERAL
MODULI TEST) NO
CONSTRUCTION
OPERATION
1 1 1
1 1
. 1 1 1 f
Figure A - 1. Project schedules for commercial oil shale projects.
A-3
-------
PROJECT
1978
1979
1980 | 1981
1982
OCCIDENTAL OIL
SHALE
BURN RETORT +•
EVAL-
UATION
GEOK1NETICS, INC.
EQUITY OIL
DOW CHEMICAL
LARAMIE ENERGY
TECHNOLOGY
CENTER
SITE EVALUATION
A DRILLING
r » <
OPERATE
RETORTS 7ft 8
DRILL, BLAST. RETORT
6-8 RETORTS (80X30'X80*)
DRILL, BLAST, RETORT
2-3 CLUSTER RETORTS ^
EXPERIMENTAL STARTUP
STEAM INJECTION
IN SITU WELL TESTING
IN MICHIGAN ANTRIM SHALE
PHASE 2
EXPERIMENTA
BURN
1
}
IN SITU FIELD RESEARCH AT ROCK SPRINGS, WYO.
Figure A - 2. Project schedules for field tests of oil shale projects.
-------
because of a number of environmental and operational considerations. DDP
modifications in May 1977 and August 1979, have resulted in the current plan which
includes a 10-year Modular Development Phase (MDP) to perfect modified in situ
retorting technology with at least three retorts to be developed and burned through
1981 (1,2,3). This phase would be followed by a 30-year Commercial Development
Phase at a planned capacity of 10,340 tonnes/day (76,000 bbl/day).
Since Rio Bianco intends to use a vertical modified in situ (MIS) retorting
technology which has not been proved in the field, the 10-year MDP will provide
operating experience and confirm process design, economics, and environmental
impacts.
Project Description
Access to the modular development area will be through a 4.6 m (15-foot)
diameter service production shaft and a 3 m (10-foot) diameter ventilation shaft and
the escape shaft all connected to the G level as shown in Figure A-3.
Shaft construction to a depth of approximately 295 m (970 ft) deep has been
completed and outfitting is progressing. The process development retorts will be
developed sequentially, so that the results from the previous retort could be
incorporated into the development and processing of the next retort. Retort 0
would measure 9.1 m (30-feet) square by 61.0 m (200 ft) high and will provide Rio
Blanco experience in rubblization and blasting techniques. There would be a
minimum of instrumentation. Retort 1 will be nominally 18.3 m x 18.3 m by 122.0 m
(60 ft by 60 ft by 400 ft) high and will be fully instrumented. It will be developed
from the G level of the MDP mine upward to near the top of the Mahagony Zone.
Retort 2 geometry will be decided from information obtained from rubblizing
Retort 1. Two alternatives being considered include a pair of nominal 122.0 m (400
ft) high retorts burned either in sequence or together as a single retort of larger
cross section. The remainder of the MDP will consist of burning additional retorts
as high as technically feasible up to 213.5 m (700 ft) to optimize commercial design
and operation plus developing a complement of commercial size retorts for
operation to begin in 1987.
During the MDP, diesel-powered load-haul-dump (LHD) units and twin boom
jumbos will create up to a 40 percent mined-out void. There will be no work under
unsupported roofs of large spans. The new retort geometries within the G level
eliminate the need for the C and E levels, and thus reduce raw shale storage by up
to 50 percent. Once the raw shale has been lifted to the surface, it will be hauled
by truck to the disposal areas where it will be contoured and revegetated.
Surface support facilities will be constructed during the MDP to provide
combustion air and steam to the MIS retort. The product gas, oil and water will be
separated underground and the individual streams pumped to the surface for
treatment. The retort product gas, totaling about 1.84 million m3/day (65 million
SCFD) for the largest developmental retort will be incinerated and scrubbed in a
sodium carbonate scrubber before being discharged to the atmosphere. The 102
tonne/day (750 bbl/day) of raw shale oil produced from the large retort will be
hauled from the site by tank truck to a market point. Any water produced during
retorting will be sent to a lined solar evaporation pond.
A-5
-------
DOWN-HOLE
BURNERS
ESCAPE
SHAFT
-------
Once operational and economic feasibility has been confirmed in the MDP, the
final size and configuration for the commercial retorts will be determined and work
will proceed. Access to the commercial mine would be made through a number of
shafts, and a new processing facility would be constructed to clean up and burn low
BTU gas and treat all water and waste streams before discharge. Data obtained
during the MDP will be used for commercial plant design.
CATHEDRAL BLUFFS SHALE OIL CO.
In February 1974, Ashland Oil, Inc., Atlantic Richfield Co., The Oil Shale
Corp. (TOSCO Corp.), and Shell Oil Co. submitted a high bid of $117.8 million for
Tract C-b. In December 1975, Atlantic Richfield Co. and TOSCO withdrew from
this joint venture, and on November 2, 1976, Shell Oil Co. announced its withdrawal
from the C-b Oil Shale Project. On November 3, 1976, Ashland Oil, Inc., announced
the formation of a new joint venture with Occidental Oil Shale, Inc. (Oxy) to
proceed with the development of Tract C-b. In this new joint C-b Shale Oil Venture,
Ashland granted Oxy a 50 percent interest (later increased to 75 percent) in the C-b
lease and tract in exchange for the right to use the Oxy Modified In Situ (MIS)
Process, which Oxy has developed and patented for the recovery of oil from shale.
On February 14, 1979, Ashland withdrew from participation in the project. In
September 1979, Tenneco joined Occidental as a 50 percent partner in the venture,
now known as the Cathedral Bluffs Shale Oil Co.
The C-b lessees submitted a DDP to the Area Oil Shale Supervisor on February
9, 1976, outlining plans to develop the tract using room-and-pillar mining and
surface retorts. Effective September 1, 1976 the lessees were granted a year's
suspension of operation for the purpose of considering alternative methods of
developing the tract. In February 1977, a modification to the DDP was submitted to
the Area Supervisor which called for development of the tract by the use of the Oxy
MIS process. The process consists of creating an underground chimney of broken oil
shale by expanding the shale into a previously mined-out volume using conventional
explosives. Tests have been conducted using both horizontal and vertical mined-out
slots. The Oxy process is shown schematically in Figure A-4. A flame front is
initiated at the top of the chimney and progresses downward, retorting the shale
ahead of it. The shale oil product collects at the bottom of the retort and is pumped
to the surface.
Project Description
Access to the mine will be through three shafts (production, service and gas),
each of which will be 10.4 m (34 ft) in diameter. The production shaft will be used
to remove mined shale as well as to serve as the main ventilation exhaust duct. The
service shaft will serve as an intake for process and ventilation air, and it will also
deliver men and materials to the mine production level. The gas shaft is for the
removed of product gas.
About one year will be required for start-up. Initially two retorts will be
started, then two clusters of four, and then full size clusters of eight retorts.
During commercial production, approximately 40 retorts will be in various stages of
processing at one time and will produce 7,752 tonnes/day (57,000 bbl/day) of shale
oil. A flow diagram of the commercial operation for Tract C-b development is
shown in Figure A-5. During retort operation, ventilation and process air flows will
A-7
-------
OVERBURDEN
l 0 N t
S •: 01L SHALE
5 /&*£
>0'O'00
£46.9
Lowar Mining L«v*l
Drillholtt for •xpfoiivtl
'and air Injection
It M«l*
Air & Propane
| Injection from Surface
Bulking to Within
1 or 2 Feet of
Predicted
9 3,000 to 4,000 'i
Tons of Broken
4 Oil Shale at
.15-25% Voids
t> »
o v
' ^ ». . b
• ' * »>
£ o tf , ^
<1j °' V
'«"»
- *
Retorted Shale
Combustion
Front
Oil to Sump
Oil to
Storage
1200 BBLS
Figure A - Occidental modified in situ retorting process.
(Source: References 8 and 9.)
A-8
-------
MINE
MINED SHALE
FILL
41,134 T/D
TO POND „
(OR ALTERNATEf
RETURN CONDENSATE-
MAKE-UP-
TO 6EN'L
FACILITIES
AIR —
'MINE WATER
1700 OPM
300 GPM
WATER
TREATMENT
3O0 0PM
100 TO 500 0PM
1874J MMSFD
'UTILITY USE
-AIR
100,000 LB/HR
999SMMSCFD
>
I
V0
F
STEAM
RETOR TING
848.000 LB/HR
OAS PRODUCT
STEAM
\GENERATI0N
PLUS THERMAL]
OXIDIZER
3454.0 MMSCFD
(TOTOLl
100 0PM
'STACK GAS
SLOWDOWN
TO POND
1573.2 MMSCFD (DRY) I
-TREATED 6AS
1570.7 MMSCFD (DRY)
GAS
TREATMENT
STARTUP OIL
92.2 LT/O
"¦ SULFUR
122 B/0
LIQUID PRODUCT
03,465 B/0
OIL/WATER
SEPARATION
561996 B/P
712 GPM
-PRODUCT OIL
56,874 B/D
WATER TO POND
From
THE RALPH U. MASON COMPANY
PASADENA, CALIFORNIA
Figure A - 5. Flow diagram of proposed commercial operation on Tract C-b.
(Source: Reference 7.)
-------
be induced by blowers taking suction on the product gas shaft and the production
shaft. Under these conditions, the retorts would be under negative pressure relative
to the inhabited levels of the mine, thus preventing short circuiting of the product
gas.
Vapors from the product gas blowers will be cooled and routed to the gas
treating facilities which will probably include a Stretford unit to remove H2S.
Treated gas will be used as a fuel to produce process and utility steam. Since the
total heat content of the product gas is considerably greater than that required for
steam production, electrical power generation may be included at a future date to
utilize excess gas. The product gas will have a heating value of only 534 to 623
kcal/m3 (60 to 70 BTU ft3). Hence, complete utilization of the product gas might
include low-BTU, gas-fired boilers, gas turbines, waste heat boilers, and steam
turbines. Potentially 300 to 400 megawatts of power could be produced for export
from the site.
Water produced during retorting will be removed from the product oil in
primary gravity separators followed by an electrostatic heater-treater. The crude
shale oil will then leave the site by means of a pipeline, possibly by routing to an
existing oil pipeline near Casper, Wyoming. No onsite upgrading is planned.
Additional surface facilities for the commercial mine will include a raw shade
conveyor system to move mined shale to disposal sites. The raw shale will be built
up in layers to its final height in small sections of the disposal areas to promote
rapid initiation of the revegetation program.
Emissions, Effluents, and Solid Wastes
Estimated atmospheric emissions from Tract C-b's commercial plant are listed
in Table A-1. Raw shale produced during mine development will be placed as fill in
Cottonwood Gulch on Tract C-b. This material will be transferred onto a covered
belt conveyor system, moved to selected areas in Cottonwood Gulch, and spread
over these sites by a conveyor placement system. The disposal areas will be built up
in layers to their final height. Since no spent shale will be disposed of on the
surface, the special problems associated with spent shale will not exist. Before any
fill is started, top soils in fill areas will be stripped and saved for later use as fill
cover to facilitate revegetation. The quantity of mined shale is estimated to be
37,194 tonnes/day (41,000 tons/day).
The modification to the original DDP did not estimate quantities of solid
wastes to be produced. The bulk of these wastes would be disposed of in the raw
shale disposal areas.
The developer anticipates that the quantity of water from dewatering the
mine during development of the commercial plant will be more than that required
during the early stages and somewhat less than that required after commencing fuil-
scale operation. Additional water required would be supplied from on-tract wells.
All water supplied to the power plants would eventually be consumed, recycled, or
released to the atmosphere by evaporation. A major consumptive use of water
would be the moisturization of shale, for which all wastewater streams not
otherwise recycled would be used. Water used for moisturizing shale for
reclamation or dust control would either evaporate, be permanently incorporated
A-10
-------
TABLE A-l. COMMERCIAL PLANT EMISSIONS FOR TRACT C-ba
Constituent
lb/hr
kg/hr
so2
174
79
NOx
588
267
Particulates
74
34
THC
15
7
CO
84
38
a
Source: Reference 7.
into the waste pile, or drain into the catchment basin below the pile for recycle.
Other consumptive uses would include steam generation for heating and process
requirements, use as drinking water, evaporation losses, and use as irrigation water
in revegetation (10).
WHITE RIVER SHALE PROJECT
The White River Shale Project was formed in June 1974 by the owners of the
Federal oil shale lease to Tract U-a, the Phillips Petroleum Co. and Sun Oil Co.,
(now Sunoco Energy Development Co.) and the owners of the Federal oil shale lease
to Tract U-b, Sohio Petroleum Co. (now the Sohio Natural Resources Co.). The
purpose of the project was to prepare and implement a plan for the joint
development of the two lease tracts. Phillips and Sun were awarded the U-a lease in
May 1974 for a bonus bid of approximately $75.6 million. The White River Shale Oil
Corp. (Phillips, Sun, and Sohio) was awarded the U-b lease for a bonus bid of
approximately $45.1 million, but the tract has since been fully assigned to the Sohio
Natural Resources Co.
The project has been suspended indefinitely by a court injunction suspending
the lease terms based on property title questions. The leases are in jeopardy due to
the existence of unpatented pre-1920 oil shale placer mining claims and by an
application for a State lease to the same property by Penninsula Mining associated
with Utah's in-lieu land selection procedure.
Project Description
The White River Project plans to follow a modular development approach in
commercializing oil shale operations on Tracts U-a and U-b. The first major
activity on the tracts would be to establish a room-and-pillar mine with its
attendant access drifts. This Phase I developmental mine would better define the
existing shale conditions on the tract that have an effect on future large-scale
mining and processing operations. During this initial mining operation, about 27,215
tonnes (30,000 tons) of shale would be mined for crushing and retorting evaluations.
A-ll
-------
During Phase II, the exploratory mine would produce about 9,070 tonnes
(10,000 tons) of oil shale per day, which would be crushed and fed to a single
commercial sized vertical retort, probably of the Paraho design. Phase II
development and operation would last for a period of about six years.
Successful initiation and operation of the single-surface retort would be
followed by engineering and construction of a commercial plant during Phases III and
IV. For the commercial plant producing 13,600 tonnes (100,000 bbl) of shale oil per
day, the mining operations would produce about R5,150 tonnes/day (160-,000
tons/day) of raw shale utilizing room-and-pillar techniques. The retort feed
preparation would reduce the raw shale to the required size ranges in stages of
crushing and screening, with primary crushing carried out in the mine. Coarsely
crushed raw shale would be lifted to the surface and further reduced in size by
secondary crushers. A stockpile of primary-crushed raw shale would be maintained
to ensure steady operations.
Most raw shale from secondary crushing would be processed in vertical retorts,
with direct-heated and indirect-heated retorts used to achieve the gas make and
composition required by subsequent upgrading operations and process heat balance.
The balance of the crushed raw shale would be processed in fines-processing retorts,
probably of the TOSCO II design. A flow diagram of the commercial plant is shown
in Figure A-6.
Spent shale disposal would be in Southam Canyon, a perennially dry drainage
about .8 km (.5 mi) west of the plant site. The processed shale would be conveyed to
the disposal area, where it would be placed and compacted by trucks. A small dam
would be constructed below the disposal area to control runoff.
Current revegetation plans call for crushing and compacting the top 1 to 1.3 m
(3 to 4 ft) of spent shale during disposal to control texture and reduce permeability.
Soil additives and phosphorus fertilizer would also be added, and the surface shaped
to create planting basins and water harvesting surfaces. Each planting basin would
contain a trench filled with topsoil reclaimed from the disposal site. The water
harvesting surface would be treated with sealants and stabilizers so that rain water
would be shed into the planting basins (11,12).
Emissions, Effluents, and Solid Wastes
Estimated atmospheric emissions from White River Shale Project operations
during the single retort operation, (Phase II) and the full-scale commercial plant
(Phase IV) are listed in Table A-2. These estimates include emissions resulting from
all mining, processing, waste disposal, and vehicular movement activities.
The estimated quantities of solid wastes requiring disposal during Phases II and
IV are summarized in Table A-3. During Phase II, waste collected in slurry form
would be used along with water to moisturize processed shale and would go to the
disposal area on the processed shale conveyor and processed shale-hauling vehicles.
Slurry waste would include raw and processed shale dust collected in wet scrubbers,
water treatment filter sludges, and Stretford unit sulfur. Other solid wastes, such
as trash and garbage from the mine and the plant area, would be accumulated in bins
or other appropriate containers and picked up regularly by collection vehicles and
transported to the disposal site. Digested biological sludge would be stored in drying
A-12
-------
LOW-0TU OAS
TO TREATMG
cnuoe
SHALE
OIL .
HK3H-BTU OAS
HIGH-BTU OAS
CRUDE
SHALE
OIL .
MXgQ OK SHALE
TO UPGHADWO^
WGW-BTU OAS
CRUOC
SHALE
01- _
TO MMMO
A NO CRUSHMO
SHALE
TO VERTCAL-TYPE
RETORTS TOR
OUST CONTROL
TO SOUR
WATER
STRIPPER
HOM-TDS
REUSE WATER • >
TO RAW WATER TWEATWQ
RAW WATER
TREATED WATER
SECONDARY
CRUSHING
AND SIZING
PROCESSED
SHALE
DISPOSAL
VERTICAL-TYPE
DIRECT HEATED
RETORT
VERTICAL-TYPE
INDIRECT
HEATED
RETORTS
FINES-TYPE
RETORTS
Figure A - 6. Flow diagram of proposed commercial White River
Oil Shale Project.
A-13
-------
Table A-2. ESTIMATED ATMOSPHERIC EMISSIONS FOR
THE WHITE RIVER SHALE PROJECT
Emission
Phase II
Phase IV
kg/hr
(lb/hr)
kg/hr (lb/hr)
so2
3.8
(8.4)
136 (300.4)
NOx
49.2
(108.4)
1227 (2,706.7)
Particulates
30.1
(68.0)
411 (906.6)
Hydrocarbons
0.5
(1.0)
52 (115.4)
CO
6.1
(13.5)
143 (314.4)
aSource: Reference 11.
beds for possible later use as a soil conditioner. Waste oils and chemicals would be
collected in drums and either fed to the retort, hauled offsite for reclamation (if
feasible), or buried in the processed shale pile.
Waste collection procedures used during the single retort operation phase
would be applicable throughout Phases III and IV. In the latter phases, provisions
will be made for handling increased quantities. Solid waste collected in the plant
and mine (except slurry waste) would be trucked to the processed shale disposal
area. As in the single retort operation phase, dust collected in various air pollution
control facilities — all in slurry form — would be added to the processed shale and
transported by covered or closed conveyors to the processed shale disposal area.
Solid waste would be landfilled using the same procedures as in the single retort
operations phase.
Spent catalysts containing material such as arsenic, nickel, and chromium
would be handled by catalyst manufacturers or licensors who have developed safe
handling procedures for disposal. Catalysts such as high nickel hydrotreater catalyst
would be transported offsite for reprocessing if suitable contracts can be arranged.
Otherwise, all catalysts would be buried.
The proposed wastewater management plan includes schemes for wastewater
"collection, treatment, and reuse. Wastewater streams would be segregated,
collected, and treated according to types of contaminant. The use of optimum
treatment systems is planned to achieve zero discharge through total wastewater
reuse. The treated wastewater is reused as makeup to the scrubbers for the
secondary crushers. Later the wastewater is reused again to wet the processed
shale. Figure A-7 shows a simplified overview of the proposed control plan (11,12).
COLONY DEVELOPMENT OPERATION*
The Colony Development Operation is a 60-40 partnership between Atlantic
Richfield and Tosco Corp., respectively. A 6,392-tonne/day (47,000-bbl/day)
operation is proposed using room-and-pillar mining and TOSCO II retorting
technology; however, development has been in abeyance since 1974.
*In August 1980, ARCO sold its interest in Colony to Exxon. Development by
Exxon and TOSCO is now in progress.
A-14
-------
Table A-3. ESTIMATED SOLID WASTES GENERATED BY THE
WHITE RIVER SHALE PROJECT*
Waste Phase II Phase IV
Raw and processed shale dust
from wet scrubbers
Elemental sulfur slurry
(50% moisture)
General trash & garbage
Spent HDN Catalysts
Hydrogen plant spent catalysts
Deactivated carbon filter cake
Spent Claus unit catalyst
Diatomaceous earth filter cake
Water treatment sludge
Skimmed Oils
135.9 tonnes/day
(149.8 tons/day)(wet)
4.2 tonnes/day
(4.6 tons/day)
0.36 tonnes/day
(0.4 tons/day)
10,054 tonnes/day
(11,082.8 tons/day)
154.2 tonnes/day
(170 tons/day)
6.4 tonnes/day
(7 tons/day)
1,187 tonnes/year
(1,308 tons/year)
— 371 tonnes/year
40.8 tonnes/year
51.7 tonnes/yr
(409 tons/year)
(45 tons/yr)
30.8 tonnes/year
(34 tons/year)
(57 tons/yr)
274.4 tonnes/day
(302.5 tons/day)
27.2 tonnes/day
(30 tons/day)
Source: Reference 11.
A-15
-------
OUST CONTROL AND SUPPLEMENTAL IRRIGATION
I SANITARY
| WASTEWATER
PROCESS AREA
STORM RUNOFF
PROCESSED
SHALE PLUS
SLUDGES ANO
WASTEWATER
LEGEND:
DUST CONTROL
FRESH WATER
WASTEWATER
TREATED WASTEWATER
SLUDGE
WHITE RIVER
POTABLE USE
PROCESSED SHALE
WETTING
PROCESS USE
WATER
TREATMENT
WASTEWATER
TREATMENT
PROCESSED SHALE
DISPOSAL SITE
Figure A - 7. Proposed water control plan for White River Shale Project.
(Source: Reference 11.)
A-16
-------
Tosco joined with Sohio and Cleveland Cliffs Iron Comp. in 1964 to form the
Oil Shale Venture. The official name of the group was later changed to Colony
Development Co. As a result of the successful operation of the small pilot plant and
favorable cost estimates, the group constructed a 900-tonne/day (1,000-ton/day)
semi-works plant in 1965 on private property 17 miles north of Grand Valley,
Colorado. Field operations were conducted for the next two years to demonstrate
the operability of the semi-works plant, and in 1968, a design study was completed
for a 59,870-tonne/day (66,000 ton/day) commercial-size complex.
Atlantic Richfield joined the Colony group in 1969, the same year a second
semi-works program was initiated. This program was designed to study scale-up
procedures and test environmental protection equipment required by the newly
enacted Federal legislation. The semi-works plant was modified and tested from
1969 until April 1972.
Following evaluation of operating data from the semi-works plant and
completion of a definitive engineering design and cost estimate for the commercial
plant, in 1974, the Colony partners announced that the project was being shelved
indefinitely because of economic uncertainty and the lack of a Federal energy
policy.
Project Description
In the Colony Project, oil shale would be mined using conventional room-and-
pillar methods at a design rate of 59,870 tonnes/day (66,000 tons/day). Run-of-mine
ore would be hauled in trucks to a primary crusher located on the mine bench. The
primary crusher would be rated at 4,082 tonnes/hr (4,500 tons/hr) and would operate
intermittently. Run-of-mine ore would be reduced to a nominal minus 22.9 cm
(9-in.) size. Coarse ore would be moved by belt conveyor through an inclined tunnel
from the primary crusher to a fine crushing plant consisting of 10 individual crushing
and screening operations designed to reduce the coarse ore to a minus 1.27 cm (0.5
in.) product. Fine ore would be transported by means of an enclosed conveyor to
three storage silos, which in turn would feed six pyrolysis trains. Each of the six
pyrolysis trains would essentially consist of a preheat system, a retorting section,
and a processed shale cooling and moisturizing section. Each preheat section would
be a dilute-phase fluidized bed arrangement that would utilize waste heat in retort
flue gases.
A steam superheater would be required for each retorting section, as would an
elutriator for the removal of residual spent shale dust from the ceramic balls.
Combustion gases from the superheaters would be used in the elutriators. Each
pyrolysis train would utilize a processed shale moisturizer to control dust and to
obtain proper compaction properties.
Liquid products from the retorting section would be fractionated before
upgrading. The upgrading section would include:
o A gas treating plant
o A sulfur recovery plant
o A hydrogen plant
A-17
-------
o Hydrotreating facilities
o An ammonia separation plant
o A delayed coking plant
o Tankage and utilities
Retort gases would first be sent to a gas-treating plant for removal of
hydrogen sulfide and carbon dioxide, and then consumed as fuel. Acid gas removal
would be accomplished by conventional diethanolamine absorption, with acid gases
sent to a Claus plant with a Wellman-Lord tail-gas cleanup unit.
Hydrogen generated by steam-methane reforming would be sent to separate
hydrotreaters to product naphtha and gas oil fractions. The ammonia separation
plant would recover ammonia from sour water produced in the hydrotreating
reaction. Hydrogen sulfide from the ammonia separation plant and sour gases from
the foul water stripper would be sent to the sulfur plant (13).
Emissions, Effluents, and Solid Wastes
Estimated emissions from the Colony plant during full-scale operation are
presented in Table A-k. These estimates are based on observed emissions from
Colony's semi-works plant and definitive engineering design by Colony (1^,15).
Along with the processed shale, Colony proposes to dispose of various catalytic
materials, carbon, small trees and brush cleared during construction operations,
sludge from various processes, probably coke, and sludge from processed sanitary
waste at the plant site. The specific method for disposing of spent catalyst and
arsenic removal waste material in the processed shale embankment has not been
firmly established. Colony's preferred alternative is to haul the material to the
disposal area separately, spread the material over a large area of the shale, and mix
it with the processed shale coming off the conveyor by spreading thin lifts of shale
and then compacting with a sheeps's foot roller. Table A-5 shows the latest
estimate of solid wastes to be generated by the plant and mine (15, 16).
Processed shale disposal would be carried out continuously at various locations
in Davis Gulch-a high, shallow valley in the northwestern portion of Colony's Dow
West Property. An embankment would be constructed of compacted, processed
shale, behind which the remainder of the processed shale would be placed and
compacted. A drainage system would be constructed to convey any surface water to
a catchment dam to be constructed below the disposal pile.
Water used in the processed shale moisturizing process would constitute a
major consumption of water. The processed shale pile would be the point of disposal
for wastewater streams that are not recycled. Other consumptive uses of water
would be the steam-reforming process to make hydrogen, drinking water, and the
revegetation program. Water used for dust control in mining and crushing
operations eventually would be released to the atmosphere by evaporation. Water
used for moisturizing processed shale or for dust control on the processed shale
embankment would either evaporate or become part of the processed shale
embankment.
A-18
-------
TABLE A-4. ESTIMATED EMISSIONS FROM THE COLONY SHALE OIL PLANT3
Total average emissions, all stacks
// kg/hr (lb/hr)
Source
so2
X
O
2
~ Hydrocarbons
Particulates
CO
Preheat stacks
23.1
(51 )
596.4
(1314.8)
122.5
(270 )
36.7
( 81 )
19.9
(43.9)
Process shale wetters
17.4
( 38.3)
Cold ball elutriators
42.8
( 94.3)
51.4
( 113.4)
0.1
( 0.3)
17.1
( 37.8)
1.3
( 2.8)
Sulfur plant
42.9
( 94.5)
0
( 0 )
0
( 0 )
0
( 0 )
0
( 0 )
Hydrogen furnaces
12.4
( 27.4)
37.3
( 82.2)
0.7
( 1.6)
5.2
( 11.4)
4.5
( 9.9)
Naphtha heaters
0.2
( 0.4)
0.6
( 1.3)
0.05
( 0.1)
0.1
( 0.2)
0.1
( 0.2)
Gas oil heaters
0.4
( 0.9)
0.3
( 0.7)
0.05
( 0.1)
0.2
( 0.4)
0.2
( 0.4)
Gas oil reboiler
1.7
( 3.8)
5.1
( 11.2)
0.1
( 0.2)
0.7
( 1.6)
0.6
( 1.4)
Coker feed heater
1.3
( 2.8)
3.8
( 8.4)
0.1
( 0.2)
0.5
( 1.1)
0.5
( 1.0)
Boiler
3.3
( 7.2)
9.8
( 21.6)
0.2
( 0.4)
1.3
( 2.9)
1.2
( 2.6)
Secondary crusher
14.9
( 32.9)
Fine ore storage
1.9
( 4.2)
Utility boilers
0.2
( 0.4)
0.4
( 0.8)
0
( 0 )
0.05
( 0.1)
U~\
O
•
o
( 0.1)
Primary crusher
3.3
( 7.2)
Portal transfer
0.2
( 0.4)
Transfer tower
2.3
( 5.0)
Reclaim tunnel
2.5
( 5.6)
Total:
128.3
(282.8)
706.0
(1556.4)
123.8
(272.9)
104.4
(230.2)
28.3
(62.3)
^Source: Reference 14.
Total tonnes/year (tons/year) are as follows: SO-, 1, 1,124 (1,239); NO , 6,184 (6,817); HC, 1,084 (1,195);
particulates, 914 (1,008); CO, 248 (273).
-------
TABLE A-5. ESTIMATED SOLID WASTES GENERATED BY THE
COLONY PROJECT3
Waste
Amount generated
Processed shale
i* 8,262
tonnes/day
(53,200
tons/day)
Raw and processed shale dust
1,264
tonnes/day
(1,393
(797-1017
tons/day)
Spent catalysts from upgrading,
723-923
tonnes/year
tons/year)
hydrogen, and sulfur units
Spent aqueous caustic from
2.2
tonnes/day
(2A
tons/day)
hydrogen unit
Diatomaceous earth from
195
tonnes/year
(215
tons/year)
gas treating unit
Deactivated carbon from
195
tonnes/year
(215
tons/year)
gas treating unit
Green coke from coke unit
726
tonnes/day
(800
tons/day)
Lime and alum flocculants
199
tonnes/year
(219
tons/year)
from water treatment
Coagulant aid from water
8.2
tonnes/year
(9
tons/year)
treatment
Source: References 13 and 16.
Water recovered from the various process units and water treatment facilities
within the plant complex would either be recycled within the retorting and
upgrading units or utilized to moisten processed shale.
The cooling water system would be composed of a complex network of piping
over the entire processing area. About 136,270 1/min (36,000 gpm) of cooling water
would circulate throughout the plant and would eventually return to a multiple-cell
cooling tower. The cooling tower would incorporate an induced-draft system and
would produce a visible water vapor plume. Cooling water blowdown would be used
to moisturize processed shale (15,16,17).
UNION OIL COMPANY
The Union Oil Co. of California has been involved in oil shale activities for
half a century, beginning in the 1920's with the purchase of 12,150 ha (30,000 acres)
of fee property in the Piceance Creek Basin, 8,100 ha (20,000 acres) of which are
oil-shale-bearing. The development of Union's oil shale retorting technology was
initiated in the early 19^0's, and three variations of an upflow vertical kiln process
have been developed:
o Retort A
o Steam Gas Recirculation (SGR)
o Retort B
A-20
-------
The Retort A process was tested in 1.8 and 45-tonne/day (2 and 50 ton/day)
plants, followed by construction and operation of a large demonstration plant in
Colorado in the late 1950's. This demonstration plant was designed for a 318
tonne/day (350 ton/day) capacity, but long-term operability was demonstrated at
rates of 635 to 900 tonnes/day (700 to 1,000 tons/day), with a peak rate of 1,088
tonnes/day (1,200 tons/day). Although demonstration of the Retort A process was
extensive and successful, most work was suspended because of a plentiful supply of
low-cost natural gas and imported petroleum.
Two improved versions of the upflow retorting process, the Retort B and SGR,
were developed in the 1970's in response to increasing energy demands and shortage
of fuel supplies. Both the Retort B and SGR have been carried through pilot plant
stages.
Given the proper economic and political climate, it is the Retort B process
that Union proposed to construct and demonstrate at a 9,000 tonne/day (10,000
ton/day) rate. The SGR technology may be retrofitted at a later stage of
development. This project is called the Long Ridge Experimental Shale Oil Project.
Project Description
The processing area for the demonstration plant is proposed for a five-acre
bench on the north side of the east fork of Parachute Creek. Conventional room-
and-pillar mining will be employed. Primary and secondary crushing will be done
underground. The Retort B process would be used to extract the shale oil from the
rock. Production would be 1,224 tonnes/day (9,000 bbl/day) from selectively mined
171 liter/tonne (41 gal/ton) shale.
Approximately 7,602 tonnes/day (8,380 tons/day) of retorted shale from the
retort at the mine mouth will be transported by conveyor and disposal chute to a
truck-loading hopper, loaded into 91-tonne (100-ton) bottom dump trucks, and laid
down in windrows along the canyon wall. The retorted shale will be compacted to
form a stable landfill.
Union Oil has estimated that 32 months will be required to design and
construct the experimental plant with all its auxilliary facilities. The operating
program will include an assessment of the technical, economical, and environmental
feasibility of the Retort B process.
Emissions, Effluents, and Solid Wastes
Retort makegas would be first sent to a Venturi scrubber for cooling and oil
mist removal. That portion of the 7,120 kcal/m3 (800 BTU/scf) gas not recycled
would be processed by compression and oil scrubbing to remove additional naphtha
and heavy ends, followed by hydrogen sulfide removal in a Stretford unit. The
sweetened makegas would be used as a plant fuel.
Product oil withdrawn from the retort would be treated sequentially for solids
and light ends naphtha removal. Solids removal would be accomplished by two
stages of water washing. Shale fines collected in the water phase would be recycled
to the water seal. The water seal is a Union Oil concept in which a water level is
maintained in a conveyor system for retorted shale removal to seal the retort
A-21
-------
pressure from atmosphere. For arsenic removal, a proprietary Union Oil process
employing an absorbent would be used to reduce the arsenic content of the raw shale
from 50 to 2 ppm. The shale oil would then be sent to a stripping column for
stabilization before shipment. The resulting crude shale oil would be characterized
as follows:
For the Retort B process, all the plant fuel requirements would be met by the
makegas produced. The principal pollution control devices in the Union Oil design
include the Stretford process for hydrogen sulfide removal from the retort makegas
and oil/water separation and sour water stripping for wastewater treatment. The
treated wastewater would be returned to the water seal for cooling and moistening
retorted shale to provide for dust control and proper compaction.
Union has conducted studies on the various environmental impacts to be
encountered in the Long Ridge Experimental Shale Oil Project. Among the control
technologies to be employed are the following:
o A dust suppression system will be used for dust from both mining and
crushing operations.
o Because of the oil seals on the feed inlet and water seals on the retorted
shale discharge, the retort will be essentially free of particulate
emissions. The plant will not discharge any wastewaters. All runoff that
has contacted retorted shale will be impounded and reused.
o Quenched and cooled retorted shale (29 percent moisture) will be
transported to the disposal site and compacted to a dry density of 1.5
g/cm* (93 lb/ft3). A collection ditch will gather disposal pile runoff and
discharge this water to collection ponds. Water impounded in the
collection ponds will be pumped to the retorting plant for use as process
water. The outer slopes and top of the retorted shale disposal piles will
be revegetated.
A summary of estimated emissions from Union's proposed Long Ridge
Experimental Shale Oil Project is given in Table A-6.
THE SUPERIOR OIL CO.
Superior Oil has owned some 2,632 ha (6,500 acres) of oil shale land in the
northern Piceance Creek Basin for nearly W years. In 1967, it began a drilling and
geological evaluation program and found that the deeper shales on the property
contained attractive quantities of nahcolite (NaHCOs> and dawsonite
(NaAKOH^COs), as well as oil shale. A research program was therefore initiated to
API gravity
Pour point
Nitrogen
Sulfur
Conradson carbon residue
22.7°
16°C (60°F)
1.7%
8.8%
1.75%
A-22
-------
TABLE A-6. ESTIMATED EMISSIONS FROM UNION'S PROPOSED
LONG RIDGE EXPERIMENTAL SHALE OIL PROJECT3
Estimated (design) emissions
kg/hr (Ib/lir)
Source S02 TSP NOx CO HC
Mining
Blasting
0
10.2
(22.5 )
6.1
(13.5 )
3.8
( 8.3 )
0 0
Drilling, loading, hauling
0
0
0.5
( 1.1 )
0
0
0
0
0 0
Crushing
0
0
2.0
( <*.3 )
0
0
0
0
0 0
Shale preparation
0
0
2.3
( 5.1 )
0
0
0
0
0 0
Adit screening
0
0
3.2
( 7.1 )
0
0
0
0
0 0
Retorting 4c product handling
Retort feed
0.06
( 0.13)
0.2
( 0.5 )
0
0
0
0
0 0
Recycle gas lieater
27.4
(60.3 )
0.3
( 0.6 )
29.5
(65 )
14.5
(32 )
0.5 ( 1.0 )
Steam boiler
8.7
(19.2 )
0.1
(0.3 )
8.6
(19 )
7.7
(17 )
0.1 ( 0.3 )
Fractiooator reboiler
0.6
( 1.35)
0.01
( 0.02)
0.7
( 1.5 )
0.6
( 1.4)
0.01 ( 0.03)
Process equipment
0
0
0
0
0
0
0
0
9.1 (20 )
Retort vent stack
0.06
( 0.13)
nil
nil
0.03
( 0.06)
0.03
( 0.06)
nil nil
Product storage
0
0
0
0
0
0
0
1.7 ( 3.8 )
Vapor disposal
0
0
nil
nil
0.2
( 0.4 )
0.1
( 0.2 )
nil nil
Retorted shale disposal
Transfer
0
0
0
0
0
0
0
0
3.2 ( 7.1 )
Wind erosion
0
0
0.5
( 1.0 )
0
0
0
0
4.9 (10.8 )
Total
36.8
(81.1 )
19.3
(<(2.5 )
4 5.1
(99.5 )
26.8
(59.0 )
19.5 (43.0)
Source: Reference 18.
bTotal tonnes/year (tons/year are as follows; S02> 322 (355); TSP, 169 (186); NOx, 196 (436); CO, 234 (258); HC, 171 (188).
-------
permit integrated recovery of these minerais and shale oil. Also included were
investigations into the development of a circular grate retort;
Superior's property is shaped like a long narrow "L". Since underground mining
is planned for the commercial project, their property is not amenable to optimum
layout of ventilation, haulage, and access systems. Thus, Superior applied to the
Bureau of Land Management (BLM) in 1973 for an exchange of 1,041 ha (2,572 acres)
of their land for some 828 ha (2,045 acres) of adjacent Federal land to block up a
more manageable tract for commercial development. A draft EIS has been prepared
by BLM on the exchange application.
Project Description
Superior's commercial multi-mineral project, as shown in Figure A-8, would
involve underground room-and-pillar mining to a depth of 610 m (2,000 ft), and
surface processing for the production of nahcolite, oil, alumina, and sodium
compounds. Average daily production of these products during full-scale operations
would amount to:
An average of 23,600 tonnes (26,200 tons) of oil shale per calendar day would be
mined, crushed underground, and transported by conveyor to the nahcolite recovery
unit. Nahcolite would then be separated from mine run material by a selective
crushing and photosorting technique (19).
Oil shale exiting the nahcolite recovery unit would then be fed in three
streams to a traveling circular grate retort. A commercial-sized module is
expected to be about 61 m (200 ft) in diameter, with a capacity of 19,960 tonnes
(22,000 tons) per day. Cooled shale from the retort would be fed to the leaching
plant for recovery of alumina and soda ash. Processed shale would then be returned
to the underground mine for disposal. Revegetation of spent shale would, therefore,
not be required. Most water requirements for the full-scale plant are to be satisfied
by utilizing saline water from the "leached zone" aquifer directly above the
proposed mine. This water would first be used in the alumina and soda ash leach
plant. Condensate ultimately recovered from the leaching plant would be used for
major plant water needs. Potable and supplies would be obtained from condensed
water from the soda ash and alumina processing units.
Emissions, Effluents, and Solid Wastes
Estimated air emission for Superior's commercial multi-mineral project are
presented in Table A-7. These are average values expected. Processed shale,
sludge, and collected dust would be backfilled in the mine to avoid surface disposal
and help retard degradation of mine pillars. Approximately 12,660 tonnes (13,950
tons) per day of processed shale, along with 2.3 tonnes (2.5 tons) of sludge from the
sewage treatment facilities, 1 tonne (1.1 ton) of lime sludge from the process water
treatment plant, 115 tonnes (127 tons) of dust from the baghouses and, 1,000 tonnes
(1,100 tons) of dust from crushing and screening operations would be returned to the
nahcolite
alumina
soda ash
shale oil
4,425 tonnes (4,878 tons)
526 tonnes (580 tons)
912 tonnes (1,005 tons)
1,576 tonnes (11,586 barrels)
A-24
-------
COOLING
WATER TO ATMOSPHERE
OUST & RETORT H2O TO DISPOSAL
AIR
TO
ATMOSPHERE
AIR
SHALE OIL
RAW SHALE TO
OIL RECOVERY
FUEL GAS
TO PANEL
BACK FILL
RAW SHALE 1/4* FINES
O £
RAW SHALE
HOT AIR
TO
ATMOSPHERE
ALUMINA
J5PENT SHALE > DUST
SODA ASH
AIR
DUST
NAIICOLITE
RAW SHALE
1/4* FINES
ec
ui
PROCESS
FUEL GAS
DUST & PULP TO DISPOSAL
FLUE GAS TO
ATMOSPHERE
MAKE-UP WATER
AIR
COOLING WATER
TO/FROM
OIL RECOVERY
BLOWDOWN
AIR LIMESTONE
PRIMARY
CRUSHING
CRUSHING
SECONDARY
MINING
PROCESS
WATER
TREATMENT
COOLING
WATER
SYSTEM
STEAM PLANT
& INERT GAS
GENERATOR
OIL
RECOVERY
NAHCOUTE
RECOVERY
SODA ASH &
ALUMINA
PROCESSING
Figure A - 8. Flow diagram of proposed Superior Oil project.
-------
TABLE A-7. ESTIMATED EMISSIONS FROM SUPERIOR'S PROJECT
ESTIMATED AVERAGE EMISSIONS
kg/hr (Ib/hr)
Source
SO
»2
NO
X
NMHC
CO
TSP
Steam plant
139.80
(308.20)
19.05
(42.00)
0.45
(1.00)
7.71
(17.00)
2.27
(5.00)
Nahcolite kiln
1.89
(0.16)
5 .44
(12.00)
0.02
(0.04)
0.10
(0.23)
1.43
(3.15)
Alumina kiln
6.90
(15.22)
3.87
(8.54)
0.07
(0.15)
0.38
(0.83)
6.80
(15.00)
Lime kiln
0.73
(10.43)
1.06
(2.33)
0.05
(0.10
0.27
(0.60)
2.27
(5.00)
Inert gas generator
0.17
(0.37)
.00 4
(0.008)
0.001
(0.003)
0.008
(0.017)
0.002
(0.005)
Oil storage tanks
—
—
6.80
(15.00)
—
—
Diesel exhaust (shale
storage area)
0.68
(1.50)
8.07
(17.80)
0.64
(1.40)
1.95
(4.30)
0.59
(1.30)
Gasoline exhaust
0.007
(0.015)
0.124
(0.273)
0.168
(0.371)
5.13
(11.30)
0.008
(0.017)
Product transportation
0.32
(0.70)
0.60
(1.33)
0.32
(0.71)
3.05
(6.73)
0.15
(0.32)
Employee transportation
0.02
(0.05)
0.21
(0.47)
0.20
(0.45)
1.91
(4.20)
0.05
(0.11)
Mine Vent
Diesel exhaust
Primary crusher
2.86
(6.30)
39.55
(87.20)
0.61
(1.34)
0.86
(1.90)
2.72
1.00
(6.00)
(2.20)
Secondary crusher
—
—
—
—
2.99
(6.60)
Storage dome
—
—
—
—
0.95
(2.10)
Tertiary crusher
—
—
—
—
0.67
(1.47)
Nahcolite screening
—
—
—
1.06
(2.33)
Photosorters
—
—
—
—
1.06
(2.33)
Oil recovery surge bin
—
—
—
—
1.95
(4.30)
Alumina/soda ash crusher
—
—
—
—
2.68
(5.90)
Conveyor belt, Misc. Handling,
and Product Load Out
. _
-
0.36
(0.80)
Fugitive Dust
—
—
—
...
5.07
(11.17)
Total 157.38 (3*6.95) 78.00 (171.95) 9.33 (20.36) 21.37 U7.ll) 34.07 (75.10)
Source: Reference 19.
-------
mine. Before being conveyed to the mine, the mixture would be wetted with about
697,500 liters (180,000 gallons) of water daily from the oil and water separation tank
associated with the oil recovery unit. Another 13.95 million liters (3.6 million
gallons) per day of mine water would be added to the mixture to bring the moisture
content of the resulting slurry to 50 percent. The slurry would then be pumped to
the mine panels for backfilling.
Drain pipes laid along the panel floors would collect the percolating water
drained from the slurry, which would then be pumped back to the slurry plant for
reuse. As a result of the natural down dip of the panels, each would be filled to the
roof and then sealed with concrete. Utilizing this disposal scheme all solid and
liquid wastes from the plant will be returned in slurry form to the mine.
TOSCO SAND WASH PROJECT
The TOSCO Corp. has leases on five tracts of land totalling 5,949 ha (14,688
acres) at its Sand Wash Oil Shale property about 56 km (35 miles) south of Vernal,
Utah. The company is in the second year of an eight year plan, under terms of a
unitization agreement with the State of Utah to prepare the leases for eventual
commercial development. In December 1978, the Utah Conservation Committee
and the State Division of Oil, Gas, and Mining issued permits for the TOSCO Corp.
to sink an experimental mine shaft on the Sand Wash properties.
The experimental mine shaft will have a diameter of 3.67 m (12 ft) and a depth
of 732 m (2,400 ft). Initial field work is scheduled to begin in 1979, with the shaft
estimated to be completed in 18 months to 3 years. An experimental mining
program will follow when the shaft sinking is completed. During this experimental
mining phase no onsite processing of the oil shale is planned, but shale samples will
be sent to TOSCO's Research Center near Golden, Colorado for retorting in a 104.3-
1/tonne (25-ton/day) T05CO II pilot plant. Information from the experimental
mining program will be used to help prepare final design criteria for a commercial
facility.
TOSCO recently completed a preliminary design and updated cost estimate for
eventually building a commercial-sized plant at Sand Wash. The proposed
commercial plant would use the company's aboveground TOSCO II Process to extract
petroleum liquids, gases and byproducts from crushed oil shale rock. Six 9,980-
tonne/day 411,000-ton/day) TOSCO II retort modules would be included, along with
equipment for product storage and loading, utilities, and disposal of spent shale.
Currently, a series of environmental studies are being conducted at the site
through TOSCO's Vernal office, including revegetation of spent shale, meteorology,
air quality, water resources, and surveys of flora and fauna. These studies are
directed toward the future preparation of an EIS for the commercial project.
OCCIDENTAL OIL SHALE, INC.
On September 30, 1977, Occidental Oil Shale, Inc. and the Energy Research
and Development Administration (now DOE) signed a cost-sharing contract, the
total estimate cost of which is $60.6 million. The government will provide 71
percent and Occidental, 29 percent for Phase I. The contract was effective
retroactive to November 1, 1976.
A-27
-------
The overall objective of this project includes engineering development (Phase
I), and technical feasibility demonstration (Phase II) of a vertical modified in situ oil
shale retorting process based on Occidental's design and prior R&D work. Another
objective is the determination of environmental effects from the recovery process.
Phase I evaluated two specific retort designs involving alternate means of
mining and rubblizing at a size configuration approximately equivalent to
commercial-sized retorts. The purpose of this evaluation is to select a particular
retort design to be utilized in the Phase II technical feasibility demonstration. Both
phases are being conducted at the D. A. Shale site near De Beque, Colorado. A
schematic of the site is shown in Figure A-9.
During Phase I, Occidental rubblized and processed Retort 5 (vertical slot,
with retort approximately 36.5 by 36.5 by 61 m or 120 by 120 by 200 ft) and Retort 6
(horizontal slot, with retort approximately 48.8 by 48.8 by 54.9 m or 160 by 160 by
180 ft) to determine the effect of retort configuration on gas flow patterns (as they
indicate void volume and particle size distribution), and pressure differentials. Also
studied will be the effect on oil yield of air/steam mixtures as the retorting
medium, off-gas composition and heating value, process water requirements, energy
requirements, and acceptable methods of retort ignition.
A comparison will be made between the two retort configurations to evaluate
the technical and economic differences in mining, blasting, and processing as well as
the differences in oil yield, off-gas composition and heating value, and process
water requirements.
Occidental will conduct an environmental research program to collect data
and evaluate the following:
o Hydrology and water resources of the area
o Meteorology, air quality, and gaseous emissions in the area
o Biological and health effects
o Societal influences
o Generation of research data required to obtain operating permits.
In November 1979, EPA issued the conditional PSD permit to operate Retorts
7 and 8. The approximate dimensions of these retorts are *f7.2 m by 64.1 m by 78.9
m (165 by 165 by 268 ft). Table A-8 details the air emissions allowed by the permit.
Oxy is required to enter into written agreement with EPA and DOE for the
performance of an air emissions research testing program on Retorts 7 and 8. At a
minimum, Oxy will provide a Stretford unit which will be operational on a slipstream
of the retort off-gas. Oxy is negotiating with the EPA, Colorado APCD, and DOE to
modify this test program to consist of a pilot combustor and pilot FGP system. Oxy
will also provide the opportunity to EPA and DOE for sampling and characterization
of this slipstream (21).
During Phase I, a market study for shale oil and a definitive design and cost
estimate for a 680-tonne/day (5,000-bbl/day) demonstration plant and a firm design
A-28
-------
RETORT 4
RETORT 6
RETORT 5
DRIFT FROM
RESEARCH
MINE
1 AIR BLOWERS (FORCE AIR
INTO TOP OF RETORT)
2 GAS BLOWERS (DRAW GAS
OUT OF BOTTOM OF RETORT)
3 CONTROL ROOM
BULKHEAD ON TOP OF RETORT
ENTRYWAY ON TOP OF RETORT 5 ^
BULKHEAD ON BOTTOM OF RETORT 4
BULKHEAD ON BOTTOM OF RETORT 5
Figure A - 9. Schematic of Occidental's Modified In Situ test.
-------
TABLE A-8. OXY LOGAN WASH RETORTS 7 & 8
AIR EMISSIONS RATES kg/hr (Ib/hr)
Location
so2
h2s
NOx
HC
Particulates
CO
Retort stack
nil
169.2 (376)
nil
69.3 (154)
nil
1,638 (3,640)
Other sources®
13.9 (31)
nil
23 .4 (52)
1.4 (3)
3.2 (7)
.9 (2)
Total
13.9 (31)
169.2 (376)
23.4 (52)
70.7 (157)
3.2(7)
1,638.9 (3,642)
Total tonnes/year
(tons/year)'5
81 (90)
986.4 (1,096)
135 (150)
410.4 (456)
16.2(18)
9,551.7 (10,613)
alncludes boilers, heater-treaters, hot water circulators, and mine vent.
^Based on 8 months of operation.
-------
and cost estimate of a 3^0-tonne/day (2,500-bbl/day) technical feasibility plant was
performed by Occidental.
Phase II originally involved construction and operation of the 340-tonne/day
demonstration plant at Tract C-b, contingent upon receipt of the necessary
approvals and construction permits. Phase II was modified to consist of operating
Retorts 7 Sc. 8 at the D. A. Shale property because of project schedule delays at
Tract C-b.
GEOKINETICS, INC.
On July 22, 1977, Geokinetics, Inc., signed a contract with the U.S. Energy
Research and Development Administration (now part of the DOE) for development
of a horizontal in situ process. The process involves high-explosive fragmentation of
very shallow oil shale deposits followed by in situ retorting with a horizontally
moving fire front. A conceptual diagram is shown in Figure A-10.
The work covered by the $9.2-million contract involves Phases III through VI of
the project and is expected to last five years. Phases I and II were already
completed by Geokinetics in laboratory and field work extending back to 1973. The
project site is located in Uinta County, Utah, the site of earlier field work by
Geokinetics.
From July 1975 through September 1978, 19 retorts have been drilled, 18 have
been blasted, and 11 have been burned. Geokinetics' recovery rate is 50 percent or
more of the in-place shale oil. Development of each retort has progressed in five
distinct steps, as follows:
o Drilling and blasting-This step included a pre-blast site evaluation
including topographic survey and core-hole analysis. New or existing
blasting configurations were designed to produce the desired formation
porosity. Surface displacement targets were filmed during blasting, and
a post-blast topographic survey was conducted.
o Re-entry drilling-Re-entry holes were drilled following the blasting to
evaluate the condition of the retorting and overburden zones. Additional
holes for combustion air, product gas recovery, production holes, and
instrumentation holes were also be drilled.
o Burn preparation and air injection tests-Surface equipment required to
conduct the combustion step were installed, and air flow and tracer
studies were run to determine the porosity of the retort zone.
o Ignition and burn-The retort was ignited with burning charcoal, and the
air rates, retort temperatures, pressures, and product off-gas rates were
monitored and controlled where necessary. Oil and water production
rates and analyses were also recorded.
o Post-burn examination-The retorts were re-entered or cored as
necessary to evaluate the degree of rubblization and pyrolysis occuring
in the retort zone. (Since many of the retorts were covered by a thin
A-31
-------
PLAN VIEW COMBUSTION OAS
EXHAUST WELLS
,+ o
OIL PRODUCTION
WELLS
AIR INJECTION
WELLS
+ 0
PRE-BLAST SURFACE
SECTION
i_SU[RFACE_Uf L|FX
Figure A - 10. Plan and section of a typical Geokinetics
horizontal in situ retort.
(Source: Reference 22.)
A-32
-------
layer of overburden, access was attained by digging axial surface
trenches with a bulldozer and backhoe).
Rubblization is achieved by detonating explosives within a pattern of
blastholes, whereupon the overburden is lifted. The bottom of the retort is sloped to
provide drainage into a sump from which product shale oil is pumped. Air injection
holes and offgas holes are drilled at opposite ends of the rubblized zone. The oil
shale is ignited at the air injection wells, and air is injected to establish and
maintain a burning front that occupies the full thickness of the fragmented zone.
As the front moves towards the offgas wells, oil shale ahead of the front is pyrolized
and product oil drains to the sloping bottom of the retort to the production wells.
Residual coke in the spent shale provides fuel for the burn front, the progress of
which is monitored by thermocouples set in wells.
As part of the scope of work, a number of environmental parameters are
being monitored. These include hydrology, meteorology, air quality, gaseous
emissions, biological and health effects, effects on land and reclamation, and
societal influences.
In addition to varying retorting parameters to achieve optimum shale oil
recovery, in the remainder of 1979 Geokinetics plans to burn a retort within the full
9.3 m (30 ft) thickness of the oil shale bed. A full-sized retort of 62 m by 62 m by
9.3 m (200 by 200 by 30 ft) will be blasted.
In 1980, rubblization of a cluster of three full-sized retorts is planned. This
cluster will be burned in 1981, and a second three-retort cluster will be burned
during 1981 and into 1982.
The overall program objective of developing and testing the process is
expected by mid-1982. If technical, environmental, and economic results are
favorable, Geokinetics hopes to construct a full-scale operating unit producing a
minimum of 272 tonne/day (2,000 bbl/day) (22).
EQUITY OIL CO.
The Equity Oil Co. entered into a cooperative agreement with the U.S. Energy
Research and Development Administration (now DOE) in May 1977 to conduct a 55-
month, $6.5 million project to evaluate the technical feasibility of a new in situ
shale oil production technology. The project will be conducted on Black Sulfur
Creek in the Piceance Creek Basin of Colorado and will involve injection of
superheated steam into the leached zone to retort oil shale in situ.
Equity's project is divided into four tasks: leached zone site evaluation,
laboratory experimentation, field project work, and an enviromental research
program. Site evaluation efforts will include the drilling and coring of two wells
through the entire leached zone adjacent to existing wells used by Equity in previous
field experiments. The cores will be visually inspected for evidence of retorting,
continuity will be marked, and an estimate will be made of void volume. Fischer
assays of specific intervals of the cores will be conducted. Tests will be performed
to determine if sufficient permeability exists in the two wells. An alternate site
may be selected if the permeability at the present location proves to be
unacceptable.
A-33
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The laboratory experimentation will include bench-scale tests designed to
simulate in situ retorting of oil shale in the leached zone to provide operational data
on the effects of steam pressure, temperature, and flow rate. The data will be used
to modify and improve the mathematical model, which will in turn be used to design
and optimize the field tests.
The field test involves eight injection and five production wells oriented in a .k
ha (1-acre) pattern, as shown in Figure A-ll. The production target will be the 168-
m (550-ft) thick leached zone. Because of the relatively low permeability of- the
center of the formation, superheated steam will be injected into two levels at the
rate of 16.1 million kcal/hr (6^ million BTU/hr), at a maximum pressure of 102
kg/cm2 (1,^50 psig), and a minimum temperature of M9°C (8^0°F). Figure A-12
shows a cross section of the process. A two-year injection period is forecast, to be
followed by a post-operation corehole program to evaluate the extent of retorting
that was achieved. Efforts through the end of 1978 consisted primarily of
constructing the surface facilities and drilling the process and instrumentation
wells.
The environmental research program will provide for the collection,
evaluation, and reporting of environmental data for the following:
o Hydrology and water resources of the experimental areas of influence
o Meteorology and air quality of the areas of influence
o Biological and health effects
o Effects on the land and reclamation
o Societal influences
o Generation of research data for operating permits.
MULTI MINERAL PROJECT
Multi Mineral Corp. (MMC), a subsidiary of the Charter Oil Co., has developed
the "Integrated In Situ Process," which would produce raw nahcolite, shale oil, fuel
gas, alumina, and soda ash in one integrated operation. In April 1979, MMC, the
USBM and BLM signed an agreement which permits MMC to conduct a one-year
experimental mining program at the USBM Horse Draw Facility in the Piceance
Creek Basin. This agreement also includes a second year process testing program to
be considered for approval after the completion of an Environmental Impact
Statement which is currently being prepared. Upon completion of the experimental
program, MMC hopes to enter into a three-year cooperative agreement with DOE
and DOI to construct and test a full scale module of the Integrated In Situ process.
Upon successful completion of this phase, MMC would bring the plant to commercial
production of <*,500 to 9,000 tonne/day (5,000 to 10,000 ton/day), raw nahcolite,
6,800 tonne/day (50,000 bbl/day) shale oil, 900 tonne/day (1,000 ton/day) alumina,
and *f,535 to 9,000 tonne/day (5,000 to 10,000 ton/day) soda ash in two additional
years.
A-34
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0
S3 0
0 0
15'
Legend-
0 injection Wtll
• Production Well
0
Figure A - 11. Well layout of Equity in situ test.
A-35
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STEAM
INJECTION WELL
ZONE OF LOWER
PERMEABUTY
PRODUCTION
WELL
NJECTK3N WELL
1000'
1100* —
1200* —
1300*
1400' —
WELL PERFORATION
IN CASING
Figure A - 12. Equity weil completion cross section.
A-36
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The experimental mining program has two fundamental objectives: to acquire
the geotechnical data on which commercial mining feasibility can be determined,
and to bulk-sample the nahcolite-dawsonitic oil shale horizons to provide material
for process plant engineering design. The first specific target in the plan is to
obtain a 4,535-tonne (5,000-ton) sample of 80 weight percent nahcolite product,
which will be done by excavating a test room in a bedded nahcolite horizon on the
570.m (1,84-0 ft) level. The second specific target is to excavate a stope block
within a lower nahcolite-dawsonite shale horizon to obtain experience and confirm
design data in blasting, pillar design, and rock stability in high-wall openings. This
work follows a rock mechanics program of investigation, which simultaneously will
produce some 13,605 tonnes (15,000 tons) of ore for processing research and
evaluation.
Project Description
The Multi-Mineral Integrated In Situ Process consists of three steps:
underground mining and nahcolite recovery, retorting and hydrocarbon recovery, and
leaching and soda ash/alumina recovery. The process involves creating large
underground chambers (stopes) by sequential blasting and removal of the oil shale
from the stope. Gravity flow extraction is through funnel-like openings at the base.
The stopes are separated by walls of unbroken oil shale. Their dimensions are
variable, depending on the rock character and zone thickness. Extracted oil shale is
crushed and screened into two sizes with the larger size being backfilled into the
stope. The smaller size is then crushed and screened to separate nahcolite from the
oil shale. Rejects from this operation are stored on the surface for future
processing.
After backfilling with the top size, the stopes, full of sized oil shale, become
underground retorts. The oil shale is retorted by hot gas introduced into the top of
the retort and extracted at the base. The shale oil formed, along with the pyrolysis
gas and water, is directed to a collection sump where the oil, water and gas are
separated. After the oil shale has been retorted, residual carbon is left on the spent
shale. The carbon is converted into a low-to-medium BTU gas which will be used for
onsite electrical power generation.
After the shale in the retort is cooled, soda ash and alumina are leached from
the stope by spraying water over the top of the retorted shale and collecting this
water as pregnant liquor at the base. This can be done in more than one stope
simultaneously in a countercurrent process. The pregnant liquor is then pumped to
the surface for recovery of the alumina and soda ash.
Emissions, Effluents, and Solid Wastes
MMC has not prepared an assessment of the impacts related to a commercial
complex. An EIS is expected to be required on this project because of the nature of
the land acquisition. Approval of such a statement should not pose the major
constraint facing other in situ projects, specifically degradation of subsurface water
by leaching of spent shale left underground after retort abandonment. Reason for
this is that the mining will be done in the Saline Zone where the oil shale beds are
relatively dry and unfractured. If water in encountered, the stopes can be sealed
using the mining access ways constructed during st6pe development. No outside
A-37
-------
source of water will be required in this process. Make-up water for processing will
be supplied from the Leached Zone.
DOW CHEMICAL CO.
Dow Chemical signed a contract with the U.S. Energy Research and
Development Administration (now DOE) in March 1977, to conduct a program to test
the feasibility of in situ processing of Antrim shale. The 48-month contract is
valued at roughly $14 million and will be conducted on a 32-ha (80-acre) site which
Dow owns in fee near the Midland, Michigan plant.
The program includes four tasks, as follows:
Task 1 - Shale characterization
Task 2 - In situ fracturing and assessment
Task 3 - In situ extraction trials
Task 4 - Environmental, public policy, and legal assessment
Task 1 is aimed at characterization of the Antrim shale both as to its
geochemical, lithological, and physical properties, and also its physical extent.
Included in this task will be a corehole drilling project in which three coreholes of 10
cm (4 in.) or larger diameter will be drilled on the Dow property. The coreholes
will provide samples from the overburden and underlying formations as well as from
the Antrim shale formation. Core and well cutting samples from other sources such
as the University of Michigan sample library will also be analyzed whenever
possible. In assessing the resource inventory, a number of maps will be prepared
that show the extent of the Michigan Basin Antrim shale formation.
Task 2 of the project involves evaluation of three in situ fracturing methods.
First, two wells will be drilled approximately 61 m (200 ft) apart to a depth of about
427 m (1,400 ft). These two wells will then be hydraulically fractured, sand-
propped, and refractured with chemical explosives. Once the extent and direction
of fracturing has been determined, four additional wells will be drilled and cored to
intercept the induced fracture system. The system will then be subjected to
comprehensive testing to determine permeability to gas flows between wells. A
second fracturing technique will use acid leaching of limestone stringers at the base
of the Antrim shale, followed by secondary fracturing with chemical explosives.
This central acid-leached well will be surrounded by up to six injection/production
wells that intercept the fracture system. The final rubblization technique evaluated
will be explosive under-rearming in which successive shots with chemical explosives
followed by well-bore cleaning are used to produce a rubblized shale cavity. This
well will also be surrounded by up to six injection/production wells. In all cases, the
permeability between wells through the fracture system will be evaluated.
To date, Dow has completed orientation coring, air injection tests, and
renovation of the original Dow in situ site. Experiments are being conducted on
conventional hydrofracing, chemical underreaming, and explosive underreaming. In
the chemical under-reaming tests, notching of the limestone stringers was achieved
and this is to be followed by a hydrofrac procedure. An evaluation is also being
conducted to determine if plans for a scheduled post-acid treatment seismic
monitoring can be modified so as to determine the extent of the present fracture
system.
A-38
-------
Task 3 will involve in situ production of oil and gas at the test site. Initially,
production will be attempted on a test site that has already been developed by Dow.
If retorting is successful, operations will be continued for up to six months, and
material and energy balances will be made on ail materials injected and products
recovered. The production period will be followed by a six-month observation period
in which any above or below ground changes will be monitored. This will be followed
by coring at the site to determine the extent of resource utilization. When this
information has been analyzed, one of the three test sites developed under the DOE
contract will be selected for an additional extraction trial.
Finally, Task 4 of the project will evaluate the environmental impacts of the
in situ project as well as determine the public policy and legal constraints that
might apply to commercial processing of the Antrim shale.
LARAMIE ENERGY TECHNOLOGY CENTER
The Laramie Energy Technology Center (LERC) has been conducting field
tests on in situ production of shale oil since 1966. Much of the work has involved
evaluation of various fracturing techniques aimed at increasing formation porosity
and permeability. Various combinations of electrofracing, nitrofracturing (using
nitroglycerin as the fracturing explosive), explosive fracturing using slurry
explosive, hydrofracing, and acid leaching have been tried in experiments conducted
at the project site near Rock Springs, Wyoming. Several combustion tests using air
injection have been tried, but with limited success. Although sustained combustion
was accomplished over extended periods only a small portion of the oil calculated to
have been retorted was able to be recovered through the production wells.
In Situ Site No. 1 was first drilled for tests of electrofracing experiments near
Rock Springs. The results of these tests were inconclusive because the formation
was found to contain substantial natural porosity as a result of a 5-cm (2-in.) layer
of volcanic tuff. The site was also used for preliminary tests of nitrofracing in
which ^7.3 liters (50 quarts) of nitroglycerin was injected into the naturally
permeable zone and detonated. Significant increases in formation permeability
were observed following detonation.
Both electrofracing and nitrof racing experiments were conducted at In Situ
Site No. 2. The results of the electrofracing tests indicated that electrofracing was
accomplished at all electrode spacings used, ranging from 1.2 to 37.8 m to 12^ ft).
After the electrofracing phase was evaluated, the fractures were subjected to a
series of nitrof racing experiments in which conventional well bore shots of
nitroglycerin were detonated at levels corresponding to electrode positions during
the electrofracing test. Air flow between boreholes increased appreciably after the
shots. Two in situ recovery experiments were tried on Site No. 2. The first
consisted of the injection of 7 kg/cm2 (100 psig) steam superheated to 650 to 704°C
(1,200 to 1,300°F). The formation plugged after one day of injection, and the steam
approach was abandoned. The second experiment consisted of the injection of a
heated inert gas. The gas (diesel engine exhaust) passed through a combustion
catalyst and was then compressed before injection at 650 to 760°C (1,200° to
1,400°F). This injection was run for a two-week period with a cumulative recovery
of about one gallon of oil, and the run was terminated.
A-39
-------
In Situ Site No. 3 was subjected to a series of nitrofracing tests that were
successful in improving the formation porosity. No combustion evaluation was made
at this site.
Electrofracing, hydrofracing, and nitrofracing tests were conducted at In Situ
Site No. 4 to improve formation porosity. While electrofracing was not successful in
creating additional permeability, hydrofracing and nitrofracing did create
substantial porosity at the five-spot formation.
At the conclusion of the fracturing tests, Site No. 4 was subjected to
combustion evaluation. This evaluation was essentially successful, in that
significant quantities of gas and oil were recovered. A total of 25.8 tonnes (190 bbl)
of shale oil was recovered. An analysis of the combustion project revealed that
approximately 97 tonnes (714 bbl) of shale oil had been produced. It was estimated
that a total of 1,062 tonnes (7,810 bbl) were present on the site.
In Situ Site No. 6 covered an area of approximately 45.7 by 91.4 m (150 by 300
ft) and included a 55-well pattern. The oil shale formation at Site 6 was
electrofraced and then explosively fractured to increase the permeability of the
formation. A 49-week combustion test at Site No. 6 was conducted without
recovering any significant amount of oil. At the conclusion of the test, it was
decided that the energy used in initiating the combustion experiment was so widely
dissipated that very little oil shale reached retorting temperature. 1
The primary objective of the In Situ Site No. 7 experiment was to study
problems associated with ignition of oil shale broken by hydraulic fracturing and by
detonation of explosives in well bores. The combustion phase of the test began in
April 1970 and was terminated as soon as it was established that the oil shade had
been successfully ignited.
In Situ Site No. 8 was used to evaluate electrolinking and acid leaching of the
resulting fractures. No combustion experiments were conducted at this site.
Initially, In Situ Site No. 9 involved a 9-spot well pattern that was
hydraulically fractured, followed by explosive fracturing with slurry-type explosives.
The oil shale bed was ignited on April 5, 1976. During 150 days of combustion, it
was apparent that considerable amounts of shale were being retorted underground.
However, repeated failure of the oil production wells, because of mechanical
problems resulted in only minimal recovery of shale oil. It was felt that
¦considerable quantities of shale oil had migrated past a production well, hence three
additional wells were drilled outside of the original pattern in an attempt to
intercept some of the produced shale oil.
Material balances at the site following the combustion experiment revealed
that of the 1,061 tonnes (7,800 bbl) of oil available, 147 tonnes (1,080 bbl) were
produced; however, only 8.2 tonnes (60 bbl) of shale oil were recovered.
Present work at the Rock Springs site involves using a combination of steam
and air injection at In Situ Site No. 12. Phase I involves a basic two-hole test to
gather information for modeling before a bigger burn, which will be conducted at an
adjacent site. Ignition was begun at Site No. 12 in November 1978.
A-40
-------
Future work will involve the use of large-diameter boreholes, under-reaming,
hydraulic mining, and possible other techniques in combination with slurry explosives
as a means of obtaining sufficient porosity and permeability to conduct in situ
retorting. . These fracturing methods will provide more volume for explosives and
will provide a free surface to facilitate rubblization by blasting.
Much of the data that aided LERC in conducting of the field tests discussed
above were acquired under controlled conditions at the Laramie facilities. In
addition to much laboratory equipment that may be used to simulate in situ
retorting, LERC also has 9-tonne (10-ton) and 136-tonne (150-ton) N-T-U retorts
available for testing. 5ince this aboveground process closely resembles a vertical
underground retort, data obtained from the N-T-U retorts can provide a better
understanding of the processes occurring in the in situ operation.
Extensive environmental monitoring is being conducted in conjunction with the
Rock Springs retorting tests. Water quality and quantity are monitored with both
wells and surface stations, and the chemical composition of the groundwater will be
analyzed before, during, and after retorting to determine chemical changes. Air
sampling is being conducted, including stack-gas sampling and an on-line gas
chromotograph for gas analysis.
REFERENCES
1. Gulf Oil Corp. and Standard Oii Co. (Indiana). Oil Shale Tract C-a-
Supplemental Material to the Revised Detailed Development Plan. U.S.
Geological Survey. 1977.
2. Gulf Oil Corp. and Standard Oil Co. (Indiana). Revised Detailed Development
Plan-Tract C-a, Rio Blanco Oil Shale Project. 1977.
3. Rio Blanco Oil Shale Co. Technical Modification to the Modular Development
Phase of the Detailed Development Plan. 1979.
4. Rio Blanco Oil Shale Project. Conditional Permit to Commence Construction
and Operate-Prevention of Significant Deterioration of Air Quality, Review of
New Sources. 1977.
5. Ashland Oil, Inc., and Occidental Oil Shale, Inc. Oil Shale Tract C-b -
Supplemental Material to Detailed Development Plan. U.S. Geological Survey,
Grand Junction, Colorado. 1977.
6. Ashland Oil, Inc. Detailed Development Plan and Related Materials-C-b Oil
Shale Project. 1976.
7. Ashland Oil, Inc., and Occidental Oil Shale, Inc. Modifications to Detailed
Development Plan-Oil Shale Tract C-b. 1977.
8. Baughman, G. L. Synthetic Fuels Data Handbook. Cameron Engineers, Inc.,
Denver, Colorado, 1978.
9. Cameron Engineers, Inc. Synthetic Fuels. 3une 1975.
A-41
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10. Ashland Oil, Inc., and Occidental Oil Shale, Inc. Environmental Baseline
Program: Final Report, Oil Shale Tract C-b. Hydrology 2: 1976.
11. Detailed Development Plan-Federal Lease Tracts U-a and U-b. White River
Shale Project. 1976. U.S. Department of the Interior
12. VTN Colorado, Inc. Federal Prototype Oil Shale Leasing Program: Tracts U-a
and U-b Utah. White River Shale Project. 1976.
13. U.S. Department of the Interior. Final Environmental Impact Statement for
Proposed Development of Oil Shale Resources by Colony Development
Operation. 1977.
14. Colony Development Operation. Proposed Conditional Permit to Commence
Construction and Operate-Prevention of Significant Deterioration of Air
Quality. 1979.
15. Colony Development Operation. An Environmental Impact Analysis for a
Shale Oil Complex at Parachute Creek, Colorado. 1974.
16. Public Service Company of Colorado. Power Line Environmental Analysis-
230,000 Volt Transmission Line from Rifle Substation to Colony Oil Shale
Plant and Related Facilities. Environmental Impact Analysis Appendix II.
1974.
17. Colony Development Operation. Processed Shale Revegetation Studies 1965-
1973. Environmental Impact Analysis, Appendix 6. 1973.
18. Union Oil Co. Proposed Conditional Permit to Commence Construction and
Operate-Prevention of Significant Deterioration of Air Quality. 1979.
19. U.S. Department of the Interior Draft EIS, Proposed Superior Oil Co. Land
Exchange and Oil Shale Resource Development. 1979.
20. Office of Technology Assessment. Draft Working Paper for a Case Study of
Oil Shale Technology-Oil Shale Retorting Technology. OTA, Washington, D.C.
1978.
21. The Pace Co. Consultants and Engineers, Inc. Synthetic Fuels. December
1979, pg. 2-3.
22. Cameron Engineers, Inc. Synthetic Fuels. June 1979, pg. 2-12.
A-42
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David C. Sheesley
Mike Pearson
APPENDIX B
PROCEDURES FOR AMBIENT AIR MONITORING
INTRODUCTION
This appendix provides an expansion upon the discussion of the sampling and
analysis techniques for ambient air monitoring presented in Section 5 of Volume 1.
This discussion is by no means complete and extensive research into the individual
method is required before it is selected or used. In the rural areas generally
characteristic of the oil shale areas, ambient values may fall below the detection
limits of the EPA reference or equivalent methods. For this reason, alternate
methods have been presented even when a Federal reference method or equivalent
method exists. A summary of the methods presented in this section is provided in
Table B-l. The EPA reference and equivalent methods are summarized in Table
B-2.
METEOROLOGICAL MEASUREMENTS
Meteorological information is critical for the assessment of environmental
impact resulting from new source emissions. It is essential that meteorological data
be representative of source conditions and primary receptor areas. The degree to
which the data are representative depends on complexity of the terrain, exposure of
the sensors, and the period of data collection. Although onsite data are preferred,
offsite data may be adequate for some applications (1). A minimum of 1 year of
meteorological data is required. If available, 5 years of data should be used to
minimize year-to-year variations.
Most meteorological parameters can be measured using standard National
Weather Service (NWS) equipment or its equivalent, and data values should meet
either NWS or EPA standards for accuracy. For certain applications (such as some
complex terrain models) higher quality equipment may be required. The parameters
measured depend on previous data available for the area, representativeness of that
data, and its intended application. Extensive information exists on required
meteorological inputs for standard computer air monitoring models and guidelines on
meteorological siting and instrument exposure. Data averaging over time periods
shorter than 1 hr is required for complex terrain modeling.
In addition to the parameter and siting requirements, meteorological
measurements should meet certain basic accuracy requirements. A number of the
common meteorological parameters and their corresponding EPA accuracy values
are listed below (2):
B-l
-------
TABLE B-l. SUMMARY OF METHODS PRESENTED
Parameter and Methods
Manual or
continuous
Range
SO
NO
2'
. a
Colorimetric
b
Flame photometric
Pulsed fluorescent
2'
Colorimetric
Chemiluminescent
Ozone:
Chemilumine scent3
b
UV photometric
Particulates:
Hi-Vola
Stacked filter
Dichotomous
CO, CH4> non-methane hydrocarbons;
a
Nondispersive infrared
Gas chromatography
Ammonia:
Colorimetric
Chemilumine scent
Manual
Continuous
Continuous
Manual
Continuous
Continuous
Continuous
Manual
Manual
Manual
5 to 13000yg/m~
26 to 2600yg/m"
13 to 1300pg/m"
9 to 752yg/m"
9 to 1880vig/m"
3 3
lOyg/m to 2mg/m
6 to 1960ug/m^
10
Continuous
Semi-continuous
Manual
Manual
28
16
20
to 1000yg/m"
to 1150yg/m
3
to 1300yg/m
to 700yg/m*
Federal reference method.
Equivalent method.
(continued)
B-2
-------
TABLE B-l (Continued)
Manual
or
Parameter and Methods
continuous
Range
H^S, mercaptans, organic sulfides:
Flame photometric
Manual
0.001
to
1.0 ppm
Sulfates:
Methylthymol blue (hi-vol)
Manual
.6
to
19yg/m3
Nitrates:
Cadmium reduction (hi-vol)
Manual
.03
to
7.4yg/m
Lead:
Atomic absorption (hi-vol)
Manual
.03
to
7.5yg/m3
Mercury:
Atomic absorption (silver wool)
Manual
5
to
500yg/m
Atomic absorption (cold vapor)
Manual
.015
to
10yg/m
Arsenic:
Atomic absorption (hi-vol)
Manual
0.1
to
2
lyg/m
Ci~c5 hydrocarbons •"
Gas chromatography
Manual
>.01 ppm
B a P:
Fluorometric (hi-vol)
Manual
0.02
to
2
0.8ug/m
PAH:
GC and UV spectroscopy
Manual
2
to
1000yg/m
POM:
GC and flame ionization detection
Manual
0.05
to
lCtag/m
GC and mass spectrometry
Manual
>0.1 ng/m^
B-3
-------
TABLE B-2. EPA Reference and Equivalent Methods Designated as of December 21, 1978
Manual
Equivalent
Automated
Reference
Equivalent
SO,
CO
1. Technicon I
2. Technicon II
1. Bendix 8501-5CA
2. Bechman 866
3. MSA 202S
4. Horiba AQM-10, 11, &12
1. Lear Siegler SM1000
2. Meloy SA185-2A
3. Thermo Electron 43
4. Philips PW9755
5. Philips PW9700
6. Monitor Labs 8450
7. ASARCO 500
8. Beckman 953
9. Bendix 8303
10. Meloy SA285E
1. Meloy OA325-2R
2. Meloy OA350-2R
3. Bendix 8002
4. McMillan 1100-1
5. McMillan 1100-1
6. McMillan 1100-3
7. Monitor Labs 8410E
8. Beckman 950A
1. Dasibi 10003-AH, 1003-PC
2. Philips PW9771
NO„
1. Sodium Arsenite
2. Sodium Arsenite/
Technicon
3. TGS-ANSA
1. Monitor Labs 8440E
2. Bendix 8101-C
3. CSI 1600
4. Meloy NA530R
-------
o Wind speed: Accurate to 0.25 m/s (9.8 in./sec) from the threshold of 0.5
(19.6 in./sec) to 5 m/s (196.8 in./sec). Above 5 m/s (196.8 in./sec), less
than 5 percent error, not to exceed 2.5 m/s (98.^ in./sec) error.
o Wind direction: Less than 3° of true 10-rrtin average.
o Temperature: Error less than 1.0°C (1.8°F).
o Dew point temperature: Error less than 1.0°C (1.8°F).
o Temperature difference: Error less than 0.003°C/m (5.4xlO~3oF/m).
o Radiation (solar and terrestrial): Accuracy of ± 596.
o Mixing height: Same accuracy as NWS radiosonde.
o Precipitation: Error less than 0.25 mm (9.8xl0~3 in.) liquid precipitation
per hour.
VISIBILITY
The Clean Air Act Amendments of 1977 declared the protection of visibility in
mandatory Class I Federal areas as a national goal. The NAAQS and PSD standards
require that a means of maintaining visibility in such areas be developed. During
1979, EPA will submit a report to Congress defining visibility, monitoring methods,
modeling data requirements, and permit review requirements. This report will
provide the guidelines required to establish regulations.
At this time, no universally accepted definition of visibility or visibility
monitoring methodology exists. However, four common methods for assessing
visibility related parameters appear promising and are likely to be included in the
report to Congress: (1) photography, (2) telephotometry, (3) nephelometry, and (4)
transmissometry (3).
Photography
Photography has been used for some time in assessing visibility. A photograph
of a scene is used to document visibility, and it can be evaluated qualitatively to
determine the degree of visibility degradation or to compare different scenes and
areas. Knowing the relationship between radiance and optical density of the film,
an operator can use a densitometer to measure the contrast between a target and
the horizon. This contrast can be related to the response of the eye in determining
a visual range.
Quantitative contrast measurements using photographs require extensive
quality control. The relationship between film optical density and radiance must be
evaluated for each type of film emulsion used. This relationship can also be altered
by the developing process. To help normalize this effect, a standard control object
should be photographed on each type of film. Lighting conditions, such as sun angle
or cloud cover, also have a significant effect on visual ranges determined at
different times and physical locations.
B-5
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Telephotometry
The telephotometer employs the same basic principles as photography. A
portion of an entire scene is viewed through a telescope. Instead of using film to
record the amount of light received from the target and horizon sky, a
telephotometer measures it directly. The ratio of target to horizon radiance can be
measured to + 1 percent. Color filters may be inserted to measure the amount of
light received in various wavelengths and used to assess both visual range and color
alteration.
Like photography, this method measures visibility over a long path, but it is
limited exclusively to daylight hours. It is also affected by lighting conditions such
as sun angle and cloud cover, which must be taken into account when data from
different times or locations are compared.
Nephelometry
The integrating nephelometer is used to measure the scattering coefficient of
an air sample collected at a single location. The air sample is drawn into a chamber
and illuminated by a light source. Photodetectors then measure the light scattered
by the sample. The resulting scattering coefficient is related to visual range by
means of a model. In Class I areas, a nephelometer capable of measuring scattering
coefficients of 10"5m"1 or less will be required.
The nephelometer has the advantage of being insensitive to exterior lighting
conditions and targets; however, it is a point measurement. Therefore, data
interpretation must assume a homogeneous distribution of aerosols in the local
atmosphere. The effect of absorption by atmospheric pollutants upon observed
visual range is not measured by this principle.
The integrating nephelometer can be calibrated using filtered air or Freon-12,
or by introducing a scattering medium of known characteristics. Calibration should
be frequent in order to assess the amount of zero point drift. This is especially
critical in the pristine West, where background concentration measurements tend to
approach the detection limits of commercial nephelometers. It is also necessary to
ensure that the humidity inside the nephelometer is equal to ambient humidity, since
changes in humidity will result in changes in the scattering coefficient measured. A
properly maintained and operated nephelometer can •'measure the scattering
coefficient with an accuracy of ± 1 percent.
Transmissometry
A transmissometer measures the attenuation (absorption plus scattering) of
light by the atmosphere. The device consists of an intense light source and a
photodetector. Light from the source passes through the atmosphere, where
scattering and absorption take place, and is focused on the photodetector. This
measurement of attenuation is related to visual range by means of a model. Errors
using this method are dependent on the path length of the transmissometer. In the
pristine West, a path length of at least 2.5 km (1.5 mi) is required to compute visual
ranges to within ± 10 percent. As the path length increases, the effects of
atmospheric turbulence become more significant. At present, transmissometers
have not been developed to perform consistent measurements over long paths.
B-6
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S02 METHODS
Colorimetric Analysis
Based on the Schiff reaction and West-Gaeke modifications, sulfur dioxide is
absorbed from ambient air volumes by a solution of potassium tetrachloromercurate
(TCM). The resulting dichlorosulfitomercurate complex is reacted with
pararosaniline and formaldehyde to form a colored dye. Absorbance of this colored
solution is measured spectrophotometrically (4). The EPA reference method is given
in the Code of Federal Regulations (5) and is called either manual or automated. A
revised standard of test also appears in the ASTM Book of Standards (6).
The mfethod has application in the ambient atmospheres in the range from 5 to
13,000 vg/m3 (0.002 to 5 ppm). Autoanalyzer techniques, absorption collection
efficiency of sampling, and manipulation of sample solution aliquot have lowered the
limit of detection to 5pg/m3 (7-9).
Sampling is accomplished by passing a calibrated volume of air through the
absorbing reagent while protecting it from both direct sunlight and temperatures
greater than 25°C (77°F). Samples solutions that are stored must be kept at a
reduced temperature 0°C (32°F).
Multipoint pg SO2 versus absorption calibration curves are required in the
analysis procedure when samples are received, following an analyzer malfunction, or
when control limits exceed 0.03 ± 0.002 absorption units/pg SO2. Calibration
should occur in the concentration range of 0.01 to 0.5 ppm in remote ambient areas.
Freeze-dried reference materials equal to about 8 to 60 yg (.003 to .024 ppm) of
S02 in TCM have been used in EPA audits nationwide to examine performance.
Within laboratory precision has been reported at 4.6 percent (10). Audit
performance measurement of 5O2 by EPA shows that there is no apparent bias
between the manual and automated methods, though the standard deviation is lower
for the automated method. Of 143 laboratories participating in the audit, the
average percent difference between reported and EPA results was 13 percent (6
pg/nrv* or .0024 ppm) (11).
Flame Photometric Detection
Ambient air is sampled continuously and supplied to a flame photometric
detector. An in-line H2S scrubber is required by the equivalent method under
designation by the U.S. EPA. SO2 is converted to an excited molecular species that
emits light near the 394 nanometer (nm) wavelength. The intensity of this light is
measured with an optically filtered photomultiplier tube. Response is approximately
equal to the square of sulfur atom concentration (12, 13).
Analyzers that chromatographically separate SO2 from other gases in ambient
atmospheres do not respond to changes in concentration as quickly as those that
monitor without prior separation. Concentrations over the range of 0.01 to 1 ppm
are measured in atmospheres containing low concentrations of gaseous sulfur and
C02. Ambient air is sampled at 200 ml/min (12.2 in.3/min) as determined by mass
or soap-bubble flowmeter. Properly maintained power and temperature are
important to continuous performance within quality control limits (13).
B-7
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Calibration should be performed weekly. Multipoint concentrations are
supplied to the ambient sampling manifold using the same air matrix required by the
flame photometric detector employing an NBS traceable SRM or secondary
standard. To minimize interference, it is necessary to account for environmental
C02 when calibration is performed. Performance audits are recommended
quarterly. Zero and five-point concentration is measured between 0.05 and 0.45 ±
0.01 ppm. There are no accuracy data for this ambient method for concentrations
near the limit of detectability (14).
Pulsed Fluorescent Detection
Ambient air is sampled continuously and supplied to a fluorescent chamber
where S02 is detected. Pulsating ultraviolet (uv) light is focused through a narrow
band pass filter into the fluorescent chamber. S02 molecules are excited and
fluorescent light is emitted and measured by a photomultiplier tube. The
fluorescent radiation is proportional to SO2 concentrations in ambient air. The
method is an EPA designated equivalent method (15).
The method has application where instrumentation is operated on the 0.5 ppm
full-scale range within a temperature range of 20° to 30°C (6S° to 86°F) and where
suitable power is available. Ambient atmospheres with concentrations greater than
5 ppb over a 24-hr period are measured with a rise and fall time of 4 min as
concentration is changed. The analyzer samples ambient air at 1.6 to 6.4 1/min (98
to 390 in.3 /min), and properly maintained power, ventilation, and temperature are
important to continuous performance.
Multipoint concentrations are supplied to the ambient sampling system at a
minimum 1.6 1/min (98 in.3/min) flow rate. Dilution air similar in composition to
the matrix being measured is recommended to minimize interference bias.
Within-laboratory repeatability or single-station operation is checked with
weekly zero and span checks to insure that performance is within the manufacturer's
specifications (performance specifications for automated methods for SO2 are given
in the Code of Federal Regulation, Reference 16). Control checks require a
precision of ± 0.01 ppm and corrective action if limits exceed 0.025 ppm.
Performance audits are recommended quarterly. Zero and five-point span checks at
concentrations between 0.05 and 0.45 ± 0.01 ppm should be made.
Impregnated Filter (Promising New Technology)
Battery-powered sampling pumps draw ambient air through filters impregnated
with tetrachloromercurate (II). Filter samples are transported to the laboratory for
analysis by the West Gaeke colorimetric procedure (17, 18). The method has
application in ambient atmospheres of less than 1 ppm SO2 concentration.
Sensitivity has been reported as 0.05 ppbv for ambient air volumes of 1 m3 (35.3
ft3). The principle can be applied to areas that do not have power available.
Typical applications have been to operate the sample flow rate at about 6 1/min (366
in. /min) for periods of up to 4 hr. Best results are achieved by co-locating filter
samplers at each monitoring site. Samples are transported in sealed petri dishes and
placed in a desiccator analysis.
B-8
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NBS permeation tubes are used to provide test atmospheres of SO2 for
calibration. Efficiency of sampling has been reported at 92 percent for samples
with ambient concentrations of 15 ppbv and flow rates of 6.5 1/min (397 in.3/min)
(17). Combined analytical and sampling precision at stated efficiency has not been
performed. Accuracy data from independent calibration with test atmospheres have
not been developed.
CO BY NONDISPERSIVE INFRARED METHOD
The principle of nondispersive infrared (NDIR) is based on the absorption
characteristics of CO at infrared wavelengths. The spectrometer measures the
absorption of CO using two parallel infrared beams and a selective detector over the
range of 1.2 to 115 mg/m3 (1 to 100 ppm) (19). This procedure is an EPA federal
reference method (20).
Application depends on the ambient atmosphere to be monitored, since the
degree of interference by water vapor can be equivalent to 11 mg of CO/m3 (10
ppm) (21). Hydrocarbons at concentrations found in suburban ambient atmospheres
do not ordinarily interfere since 325 mg methane/m3 (500 ppm) will give a response
equivalent to 0.6 mg/m3 (0.5 ppm) (22).
NDIR instruments usually sample continuously at about 0.5 1/min (30.5
in.3/min). Carefully controlled operational environments are required.
Many factors can affect the precision and accuracy of this method (22). Zero
and span checks are recommended daily using high quality zero air and span gas
cylinders with concentrations over the range of ambient concentrations (in urban
areas these ranges are usually 2 to 12 mg/m3 or 1.7 to 10 ppm). Multipoint
calibration should be performed following installation or malfunction and when span
changes exceed 2 mg/m3 (2.0 ppm) with a span concentration between 9 and 12
mg/m3 (8 to 10 ppm) (23, 24).
Accuracy should be determined quarterly with internal performance audits
using different standards and equipment than those used during routine calibration.
Analysis can be expected to produce a positive 3 ppm bias due to interferences and
uncertainty of calibration gas assay (22).
SUSPENDED PARTICLES BY HIGH-VOLUME SAMPLER
The principle of the high-volume particle sampler is filtration sieving from a
moving air stream. The glass fibers collect particles by interception and diffusion
mechanisms according to the size of airborne particulate being sampled.
Particles with diameters of less than 100 ym (3.94xl0~3 in.)(Stokes equivalent
diameter) are normally collected over a 24-hr period at a flow rate of 1.1 to 1.7
m3/min (38.8 to 60.0 ft3/min). The method is applicable in an ambient atmosphere
having concentrations_of suspended particulates in the 10 to 1000 y range (yg/m3)
(3.94X10'1* to 3.94xl0~2 in.)(25). Filter samples (20 by 25 cm or 7.9 by 9.8 in.) are
transported to a laboratory for gravimetric analysis using an analytical balance
capable of reading to 0.1 mg (2.2xl0~7 lbs) with a range of about 5 g (l.lxlO-2 lbs)
(26).
B-9
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The high-volume sampler is oriented into the prevailing wind direction. The
large particle collection efficiency (mass dominant fraction) will vary with wind
direction (27). Collection efficiency is a function of fiber diameter, and filter
efficiency is impaired by protracted periods of sampling in atmospheres containing
liquid aerosols (28). Any gaseous substance in the sampled atmosphere that is
reactive or absorptive on the filter or its collected matter will introduce artifacts
into the gravimetric or chemical analysis of the filter (29).
Calibration requirements include periodic flow measurements with reference
materials. The flow rate for each sampling period must be documented to establish
that the volume of sampled air is within ± 7 percent of the calibration curve (7),
and the time elapsed is within ± 2 min/24 hr.
A correction for barometric pressure change due to altitude is required (22).
Minimum requirements are to check filter weighing weekly. Randomly
selected exposed filters must be reweighed to ensure that repeatability is within ± 5
lig (l.lxlO-8 lbs)(31, 32). Two samplers for each network day must be collected.
Between-laboratory precision has been reported at 3.7 percent.
Accuracy of reported TSP data is dependent upon the airflow rate through the
sampler and the traceability procedures with NBS class S weights. The assessment
of accuracy is made by quarterly audits of the flow and weighing portions of the
measurement process.
OZONE METHODS
Ultraviolet Absorption
The principle utilizes the intensity changes of UV energy as the light beam
traverses a fixed pathlength occupied by a volume of air containing ozone (33). This
method is an EPA equivalent method. Continuous instrumentation utilizing the UV
absorption principle will measure concentrations from 6 to 1,960 yg/m3 (0.003 to
1.0 ppm).
Ambient monitoring is conducted continuously at 2 to 6 mg/m3 (1 to 3 ppm)
continuously in normal configurations (33, 3^). Interferences from olefins and
sulfides under some operating conditions have been experienced (35). Primary
pollutants at ambient concentrations do not interfere with measurement. Areas
containing ambient concentrations of mercury require modified sampling
procedures.
The signal-generating system from the UV detector is referenced to zero and
spans the instrument automatically. External calibration with zero and span is
required at least weekly (36). The precision for this method has been shown to be
1.7 percent (37). The accuracy depends on the frequency of calibration.
Calibration accuracy and multipoint (5 points) linearity are performed against a
separate UV absorption instrument (primary) and an ozone generator once each
quarter. This combination should be verified against the boric acid potassium iodide
technique for independent calibration. Evaluation of four ozone calibration
procedures have shown the UV photometric procedure to have no significant bias and
a reproducibility less than or equal to 3.4 percent (38).
B-10
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Chemiluminescence
5ample gases containing ozone and reagent ethylene are combined, and the
resulting chemiluminescent light is photometrically detected (39, 40). This is the
Federal reference method for photochemical oxidants. Instrumentation to monitor
ozone continuously in the ambient atmosphere is specified in the Federal Register
(41). A TFE fluorocarbon sampling probe with an in-line filter element to remove
particles from the air stream should be used.
Ambient atmospheres are monitored over the concentration range of 10
Ug/m3 to 2 mg/m3 (0.005 to 1.00 ppm). The chemiluminescent detection of ozone
with ethylene is not subject to interference from common gaseous air pollutants
such as N02, CO, NH3, and S02 at ambient concentrations.
An internal factory-calibrated ozone source should be verified weekly by gas
phase titration. Zero and span checks between 157 and 196 ± 49 ug/m3 (0.08 and
0.1 ± 0.025 ppm) are required weekly. Test atmospheres of ozone are provided at
the inlet at 98, 196, 392, 588, 882 ± 20 ug/m3 (0.05, 0.10, 0.20, 0.30, and 0.45 ±
0.01 ppm) during calibration (37). The precision of chemiluminescent procedures for
N02 is on the order of 6 percent. Zero and single point span are recommended using
an ozone generator that has been calibrated using a boric acid/potassium iodide
reference method of UV photometer. Quarterly performance audits by different
personnel using different equipment and standards are conducted in a similar manner
to assess accuracy (42). A negative bias of 5 percent has been observed in other
collaborative testing programs for chemiluminescent procedures (43).
NOz METHODS
Colorimetric Analysis
N02 is measured by specifically removing N02 with sodium arsenite through
reactions between nitrite ion (N02~~) and diazotizing and coupling reagents.
Analysis of the colored azo dye is performed with a spectrophotometer at 540 nm of
10 nm bandwidth (44). This is the EPA reference method for N02.
The method has application in ambient atmospheres in the range of 9 to 750
Ug/m3 (0.005 to 0.4 ppm) using 24-hr samples. Interferences are negligible in
ambient air quality monitoring when the procedure is applied in undeveloped areas.
NO and C02 have been found to be potential interferences in urban atmospheres
<45).
Sampling can be conducted continuously with an air flow rate of 200 to
300 ml/min (12.2 to 18.3 in.3/min) (46). Samples are protected from sunlight and
stored at reduced temperature (0°C, 32°F).
Calibration is performed using a standard nitrite solution to prepare a
calibration curve of N02 concentration versus absorption. Six data points are used
to construct a least squares fit of data to a straight line. The slope of the line must
be 0.48 ± 0.02 absorption units per yg N02. Calibration is to be performed when
control samples exceed + 2.2 ug N02 or when a new batch of reagents is prepared.
Within-laboratory standard deviation is 8 yg/m3 (.004 ppm), and between-laboratory
standard deviation is 11 yg/m3 (.006 ppm) over the range 60 to 300 Mg/m3 (.03 to
B-ll
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.16 ppm). The method has an average bias of -3 percent over the range of 50 to 300
Vig/m3 (.03 to .16 ppm) (47).
N02 BY Chemiluminescence
The chemiluminescence procedure for measuring NO2 uses the principle of gas
phase reaction of NO and ozone to form N02 and light. Detection of NOx (NO +
NO2) requires conversion of NO2 to NO since the reaction is directly proportional to
NO in the presence of excess ozone. N02 concentrations are determined by the
difference of NO and NOx. Typically, N02-to-NO converters are capable of
quantitative conversion for long periods before needing maintenance (48).
This is an EPA Federal reference method (20). This principle has the
application in ambient monitoring and automated monitoring networks in the range
of 9 to 1,820 yg/m3 (0.005 to 1 ppm) with linear response over these concentrations.
Chemiluminescence instruments sample continuously and have a rapid response (less
than 2 sec).
Gas phase titration is the recommended procedure in the concentration range
of 0 to 1,880 yg/m3 (0 to 1 ppm), and the calibration should be done monthly.
Typically, converter (N02 to NO) efficiency is checked at this time.
Instrumentation may be calibrated with N02 either from GPT of NO with ozone or
from an N02 permeation device.
Zero and span checks are required weekly to determine precision within
current guidelines (49). The weekly span check should provide N02 concentrations
between 150 and 188 yg/m3 (0.08 and 0.1 ppm) with a control limit of ± 47 yg/m3
(± 0.025 ppm).
Accuracy data are acquired with quarterly performance audits using different
standards and equipment at five concentrations. Precision is typically 9 yg/m3 (5
ppb) (50, 51), and comparison of N02 calibration data obtained using N02
permeation devices with proper control procedures should show agreement within +
5 percent (53, 54). Accuracy can be affected by small interferences from NH3 and
other compounds that can be converted to NO or may decompose to NO in the
sample converter. The NH3 interference is eliminated by operating the converter at
a temperature of less than 400°C (752°F).
CARBON MONOXIDE, METHANE, AND NONMETHANE HYDROCARBONS
BY FLAME IONIZATION DETECTION
Measured volumes of ambient air are delivered 4 to 12 times per hour to a gas
chromatographic column where hydrocarbons (HC), C02 and water are separated
from methane and CO. Methane (CHi») is transferred and measured by a hydrogen
flame ionization detector (FID). The CO is eluted to a catalytic reduction tube and
reduced to CHi* before passing through the FID. HC are also transferred
quantitatively to the FID, and nonmethane hydrocarbons (NMHC) are determined by
subtracting the methane from the total hydrocarbons (THC) value. This is the EPA
reference method (54).
B-12
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The method is applicable to the semicontinuous measurement of THC, CHi,,
and CO in ambient atmospheres over the range 0.033 to 1.31 mg/m3 (0.05 to 2.0
ppm) for THC and for CH^ and 0.033 to 0.55 mg/m3 (0.05 to 0.84 ppm) for CO (55).
Calibration gases of 5, 15, 40, and 80 percent of full-scale concentration range
are used to determine linearity of the FID response to each component. The
calibration gases consist of two component mixtures of CHi» and CO and are used
for all three components being analyzed, since each constituent is determined as
CHi».
Precision of repeated measurements of calibration gases is ± 0.5 percent of
full-scale response at higher concentrations. At lower concentrations, precision of
repeated measurement of calibration gases are ± 2 percent of full scale. Ambient
air for NMHC measurements, however, can vary 0.322 ppm on the average, and the
standard deviation can range from 0.217 to 0.454 ppm (56). Performance audits
using standard materials supplied by EPA have demonstrated that CO measurements
by FID over a range of 3.4 to 40.6 ppm produced an average difference of 2.3
percent (11).
HYDROGEN SULFIDE, MERCAPTANS, AND ORGANIC SULFIDES
BY FLAME PHOTOMETRIC DETECTION
A gas-chromatographic separation of substances is used in conjunction with
sulfur-specific detection by the flame photometric detector. The detector measures
sulfur-containing gases at the 399 ± 5 nm emission line of sulfur in a hydrogen-rich
flame, with a specificity ratio of sulfur to nonsulfur compounds of between 10,000
and 30,000 (57).
Sulfur-containing gases are sampled at -80°C (-112°F) by passing a known
volume of air through a glass U-tube trap containing Porasil-D. H2S, COS, SO2,
CH3SH, CS2, and (CHshS in the range of 0.001 to 1.0 ppm are desorbed from glass-
valved U-tubes at 40 to 100°C (104 to 212°F). The desorbed sample is injected onto
a polyphenyl ether/phosphoric acid column at 40°C (1Q4°F), and the eluted
components are detected by the flame photometric detector. Other gas
chromatography column materials have been found satisfactory, graphite,
conditioned silica gel, and treated porous polymers, for example (57).
Typical 1-ml (.06 in.3) volume samples may be stored no longer than 2 days
because of sample reactivity. Very low levels (0.1 ppt H2S) have been sampled and
transferred to Teflon-coated sample loops at reduced pressure for analysis.
Sampling was done on gold-coated sand.
A dynamic calibration system utilizing SO2 permeating tubes with rates of
0.003 to 0.1 jig/min (4.62xl0~8 to 1.54xl0"6 grains/min) is required to prepare
known atmospheres within the range of 5 to 1,000 ppb (58, 59, 60).
Precision within the range of 5 to 1,000 ppb should not be less than ± 1
percent of full scale. Reproducibility of thioacetamide standards analyses has been
found to be ± 4.9 percent. Relative standard deviation of similar procedures is
reported at 2.8 percent for less than 0.1 ng (1.54xl0~9 grains) of sulfur (61). The
limit of detection for H2S has been determined at 0.01 ng (1.54xl0"l° grains).
B-13
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LEAD USING ATOMIC ABSORPTION SPECTROSCOPY
Suspended particulates in ambient air are collected on a glass-fiber filter for
24 hours using a high-volume sampler. Lead is extracted from filter strips using
nitric acid and hydrochloric acid as an extracting solution and then sonifying for 30
minutes. The concentration of lead in the resulting solution is determined
quantitatively using flame AA spectrophotometry (62). This method has now been
designated as the Federal reference method (63).
Ambient air volumes of 2,400 m3 (84,756 ft3) are typical with a linear range of
analysis of 15 ug/ml (.12 grains/ft3). The method can be used for sample extracts
containing between 0.03 and 7.5 ug/m3 (1.31xl0~8 to 3.28xl0~5 grains/ft3) of
inorganic lead. More concentrated solutions can be diluted, extending the upper
limit of the range.
The sensitivity of flame AA for lead depends on many parameters, such as the
instrument, light source, and wavelength used. The sensitivity when monitoring the
absorption at 283.3 nm should be about 0.009 absorbance units per yg/ml (7.51 xlO"8
lbs/gal) lead. The lower detectable limit of this method has been established at 0.03
Ug/m3 (1.31xl0~8 grains/ft3) with 1 percent change in absorption at the 217 nm lead
absorption line. The average coefficient of variation or relative standard deviation
for 20 different levels of lead analyzed by this method is 1.0 percent. This gives an
average relative standard deviation of 3.7 percent over the range of 80 to 125
Ug/nrr (64).
MERCURY METHODS
Atomic Absorption Spectroscopy
Ambient air is drawn through silver wool in glass tubing where elemental
mercury is collected and later desorbed at high temperature for transfer to AA
analysis (65). This sampling procedure has application for atmospheres with
concentrations of 0.02 to 10 ug/m3 (8.74xl0~9 to 4.37xl0~6 grains/ft3) at collection
flow rates of 100 to 200 cm3/min (6.1 to 12.2 in.3) over a 24-hour period.
Five concentrations (multipoint) of mercury in air are analyzed weekly in the
same way as samples. Recovery of mercury from the sample collection train has
been 98 percent efficient over the range of 0.006 to 0.6 yg ± 4 percent (9.24x1,0"®
to 9.24xl0~6 grains) (66).
Cold Vapor Technique (Promising New Method)
Mercury in ambient air is determined by use of the cold vapor technique and
flameless AA spectrometry. The mercury is collected by amalgamation with gold or
silver. Then mercury vapor is released thermally and analyzed by AA spectroscopy.
Ambient mercury levels from 15 ng/m3 to 10 ug/m3 (6.56xl0~9 to 4.37x10 6
grains/ft3) can be measured. A detection limit of 0.3 ng (4.62x10"® grains) has been
achieved. Calibration curves from 0.5 to 594 ng (7.7xl0"9 to 9.14xl0~6 grains) Hg
are reproducible to within 11 percent at 0.5 ng and to 3 percent relative standard
deviation above 6 ng (924xl0"8 grains).
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ARSENIC USING A HIGH-VOLUME SAMPLER
Air is sampled by high-volume sampler using glass fiber filters for 24 hours to
collect particles. Arsenic and the more natural aerosol arsenic acid are extracted
from filter strips using 0.5 percent sodium hydroxide (NaOH) as an extracting
solution. The concentration of arsenic in the resulting solutions is determined using
graphite-furnace AA spectrophotometry. This method can be used for sample
extracts containing between 0 and 3 ug/ml (0 - 2.50x10"5 lbs/gal) arsenic. This
corresponds to a 10 m3 (353 ft3) sample of ambient air with arsenic in the 0.1 to 1.0
yg/rrr (4.37xl0~8 to 4.37xl0~)concentration range. More concentrated solutions
can be diluted and the upper limit of the range thereby extended.
The sensitivity of graphite-furnace AA for arsenic depends on the instrument,
gas flow, and volume of sample used. Therefore it is not possible to quote a single
value for the combined sampling and analytical procedure (67). The lower
detectable limit of the method has not been established. Preliminary work has
indicated that the average coefficient of variation when using this method is 4.0
percent.
METHODS FOR PARTICULATES
Stacked Membrane Filters (Promising New Method)
Ambient air is sampled, and particles in the air stream are physically
separated into two size fractions by two filters with different pore sizes, 12 ym and
0.2 ym (4.72X10""1* and 7.87xl0~6 in.); the filters are stacked in series (68, 69).
Typical mass loadings on the two filters suitable for subsequent analyses are 25 and
16 ug (9.84x10""'* + 6.30X10"1*) for the large and small size fractions respectively.
These procedures have application where concentrations of the ambient
atmospheric constituents are of the order of ng/m3. Sampling flow rate is adjusted
according to the face velocity required to meet calculated efficiency of collection
on membrane filters (70).
Filter samples are transported to a laboratory for analysis of large- and small-
size (relative) fractions by means of particle-induced x-ray emission (PIXE), which is
a nondestructive analysis of elements with atomic numbers greater than or equal to
sodium (71). Fluorescence or instrumental neutron activation analysis procedures
may also be performed (72, 73). Subsequent analysis through extraction with ion
chromatography and spectrophotometry is also feasible depending on minimum
detectable concentration (74).
Precision and accuracy data are not complete for this procedure. Independent
analysis by gravimetric and nondestructive procedures shows agreement within ± 5
percent. Monodispersive aerosol generation is used to test overall system sampling
efficiency and accuracy.
B-15
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Dichotomous Sampler (Promising New Method)
Ambient air is sampled, and particles in the air stream are physically
separated according to size by inertial impaction and collected by filtration. Filter
samples are transported to a laboratory where analyses of the size-fractionated
particulate matter may be carried out through a variety of analytical procedures.
Mass loading on the filters is sufficient for energy-dispersive x-ray fluorescence
(EDXRF) spectroscopy, ion chromatography, and spectrophotometric analysis (74,
75). Nondestructive EDXRF analysis may be followed by sonification extraction and
transfer with subsequent analysis (76). Hydrogen ion, sulfate ion by thorin
spectrophotometry, ion exchange chromatography and ammonium analyses may be
performed (74).
Ambient air is sampled for a period of time determined by the final analytical
procedure to be performed on collected fractions. Typical sampling rates are
adjusted from 14 to 50 1/min (3.7 to 13.2 gal/min). Pneumatic flow-rate control is
used to reduce uncertainty in total air sample volume for filter sets corresponding
to large and small particle-fraction concentration.
Calibration of each extraction and analysis has been performed according to
Stevens, et al (74). Transfer of extraction solutions with analysis has shown greater
than 95 percent efficiency with 2 percent or better standard deviation for size
fractions containing hydrogen ions and sulfate. Ion-exchange chromatographic
analysis in the lxl0~'t to lxlO-5 molar range for sulfate and nitrate ions has a
standard deviation of 1 to 1.6 percent.
Comparisons of data for various applications of this sampling and analysis
procedure for particulate show good agreement (76). However, accuracy statements
on standards traceable to NBS are not available.
SULFATES USING THE METHYLTHYMOL BLUE METHOD
Ambient sulfates are collected by drawing air through a glass/fiber filter on a
high-volume sampler (77). The filters are placed in H20, and the extract is
analyzed for sulfates by the methylthymol blue (MTB) method using a single channel
Technicon Autoanalyzer II system equipped with a linearizer (78). The MTB method
is based on the spectral difference that exists in basic solutions (pH 12.5 to 13.0),
between the barium ion (Ba++) complex of MTB and the free MTB. At this pH the
barium complex is blue and the free ligand is brownish-red (absorbs light at 460 nm).
Thus the solution containing both the free ligand and the complex appears gray. The
amount of free ligand, monitored colorimetrically at 460 nm, is a measure of the
amount of sulfate in the sample because the reaction of sulfate with MTB-Ba++
results in em equivalent amount of free ligand.
The method is applicable to the collection of 24-hour samples in the field and
subsequent analysis in the laboratory. The range of the analysis is 3.0 to 95.0 yg
SO^/ml (2.50xl0"s to 7.93x10"" lbs/gal). With a 50-ml (1.69 oz) extract from 1/12
of the exposed high-volume filter collected at a sampling rate of 1.7 m3/min (60
cfm) for 24 hours, the range of the method is 0.6 to 19 pg/m3 (2.62x~7 to 8.30xl0~6
grains/ft3. The lower range may be extended up to 10-fold by increasing the portion
of the filter extracted. Concentrations greater than 95 ug/ml (7.93x10"1*
grains/ft3) are determined after dilution with distilled water.
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Cations such as calcium, aluminum, and iron interfere by complexing the MTB.
These ions are removed by passage through a cation-exchange column. Cations such
as Ca 2 or Pb 2 form insoluble sulfates, which in sufficient concentrations cause a
negative interference.
Quality assurance procedures are set forth in Guidelines for Development of a
Quality Assurance Program Analysis calibration is done at the beginning of each
day's run and checked at the end. Calibration standards are run every tenth sample
and quality assurance audit samples are also analyzed blind throughout the day's run.
Relative standard deviation of quality assurance audit samples analyzed over several
months ranged from 2 to ^ percent. Percent recoveries for quality assurance audit
samples analyzed blind ranged from 91 to 99 percent.
NITRATES USING COPPERI2ED CADMIUM REDUCTION
Ambient nitrates are collected by drawing air through a glass fiber filter on a
high-volume sampler (77). Nitrates are extracted from the exposed high-volume
filters using water, and analyzed by reduction of the nitrate to nitrite using a
copperized cadmium reductor column. The nitrite is reacted with sulfanilamide in
acidic solution to form a diazo compound. This compound then couples with N-l-
naphthylenediamine dihydrochloride to form a reddish purple azo dye, which is
determined colorimetrically at 520 nm using a Technicon Autoanalyzer II (79).
The range of the analysis is 0.1 to 30.0 yg N03~/ml (8.34xl0~7 - 2.50xl0_l*
lbs/gal). With a 50-mi (1.69 oz) extract from 1/12 of the exposed high-volume filter
collected at a sampling rate of 1.7 m3/minute (60 cfm) for 24 hours, the range of
the method is 0.03 to 7A yg/m3 (1.31xl0"8 to 3.23xl0~$ grains/ft . The lower
range may be extended up to 10 fold by increasing the portion of filter extracted.
Concentrations greater than 30 yg are determined after dilution with distilled
water.
The sampling quality assurance program follows the criteria given in the EPA
Guidelines {25). Analysis calibration is performed at the beginning and end of each
day's run, and a calibration standard is analyzed every tenth sample. In addition,
blind analyses of audit samples are performed. The relative standard deviation audit
sample results over several months was in the range of 2 to 3 percent. Percent
recoveries for quality assurance audit samples (analyzed blind) ranged from 9k to
103 percent. Metal ions may produce a positive error. For example, divalent
mercury and divalent copper may form colored complex ions having absorption bands
in the region of color measurement.
FLUORIDE ON HIGH-VOLUME FILTERS
Fluorides are collected on glass fiber high-volume filters and extracted using
water. Fluoride concentrations are determined using a fluoride selective electrode
in conjunction with a standard pH meter with an expanded millivolt scale or
fluoride-specific ion meter. Electrode potentials are measured at 60-, 90-, and 120-
second intervals. Values extrapolated over long times are calculated and compared
with the calibration curve determined from standard fluoride solutions (80).
The detection limit is approximately 0.002 yg F"/ml (1.67x10"® lbs/gal). The
upper range for this procedure is 0.1 yg F"/ml (8.34xl0~7 lbs/gal). Samples with
B-17
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fluoride concentration above this upper working limit can be analyzed using
appropriate dilution techniques.
Samples should be analyzed immediately upon completion of the sampling
period. If storage is required, the sample should be stored in a dark cool place.
Standard solutions of fluoride in concentrations of 0.1, 0.0S, 0.04, and 0.01
yg/ml (8.34xl0~7, 6.68xl0~7, 8.34xl0~8 lbs/gal), are analyzed in random order to
determine the calibration curve for the method. The 60-, 90-, and 120-second
potential responses are recorded. These results are fit by least squares to a linear
relation as follows: Eobs = Zo + F/time immersed, where Zo and F are the constants
to be determined.
Water soluble samples are measured. The 60-, 90-, and 120-second intervals
are recorded, and an lo for the sample is calculated as described above. The
fluoride concentration of an unknown is determined via direct comparison of the
sample Zo value to the calibration curve. The precision of analysis of quality
assurance audit samples is in the general range of 5 to 10 percent relative standard
deviation. The accuracy of the analysis of quality assurance samples is within ± 5
to 10 percent of the audit sample prepared from National Bureau of Standards
synthetic rainwater.
Extreme pH ranges interfere in the measurement of F~ concentration; pH can
be controlled in the 5.0 to 9.0 pH range by use of an appropriate buffer. Polyvalent
cations complex the F". Use of a buffered chelating agent removes these cations.
Fluoride measurement with a millivolt meter is pH- and temperature dependent.
Analyses should be performed at 25°C (77°F).
AMMONIA METHODS
Colorimetric Analysis
Sampling is accomplished by pulling a known volume of air through a fritted
bubbler (81). The sampling train should be protected by the placement of a glass
filter in an ammonium-free filter holder before the bubbler. Atmospheric ammonia
is collected by drawing the air through a dilute sulfuric acid solution. Ammonium
sulfate is formed and then reacted with phenol and alkaline sodium hypochlorite to
form the blue dye, indophenol. Sodium nitroprusside is used as a catalyst to speed
up the reaction. After reaction is complete, the solution can be analyzed
spectrophotometrically (82). The mechanism of this reaction has been proposed by
Rommers and Vissor (83).
The range and sensitivity of the method is reported as 17 to 700 yg/m3 (0.025-
1 ppm), with a sampling rate of 1 to 2 1/min (.26 to .52 gal/min) over a sampling
time of one hour (84). The detection limit is 0.02 pg/m3 (8.74xl0~9 grains/ft3) (84).
Ferrous, chromous, and manganous ions cause positive interference if they are
present in milligram amounts. Copper ions inhibit color development. Addition of
ethylene-diamine tetraacetic acid (EDTA) removes these interferences (82). Nitrite
and sulfite interfere if they are present in excessive quantities (100 times that of
the NH3). Formaldehyde causes a negative interference (84). Particulate matter
B-18
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and ammonium compounds that may become entrained in the collecting solution are
removed by the glass prefilters.
Multipoint calibration curves of jig NH3 versus absorbance are required in the
analysis procedure. These curves should be prepared in a concentration range that
brackets expected sample solution concentrations. The precision of this test when
analysis is performed manually near the lower end of the range shows a variation of
30 percent (84).
Absorption and Chemiluminescent Principle (Promising New Method)
Ammonia is absorbed and preconcentrated from ambient air being passed
through a suitable teflon-bead substrate. The ammonia is desorbed from the
substrate in the laboratory and quantitatively oxidized to NO2 for analysis by
chemiluminescence. The method shows promise for application in remote areas
where ambient concentrations are low. Sample preconcentration is necessary to
produce meaningful response at these concentrations.
BENZO(a)PYRENE USING FLUOROMETRIC ANALYSIS
Ambient air is sampled by air passing through fiber glass filters and silver
membrane filters in series. Sample volume is determined by concentrations
expected in the atmosphere being examined. Flow rate control is recommended to
reduce sampling variability (85).
Blank filters and samples are shipped to the laboratory in light-proof
containers for analysis. The filters are removed from the filter holder and placed in
test tubes under benzene. The solvent extraction of organic sample is aided by
ultrasonic action.
The benzo(a)pyrene (BaP) fractions from the thin layer chromatography
separations are extracted, evaporated, and dissolved in sulfuric acid for quantitative
fluorometric measurement (85). Laboratory operations up to a point of fluorescence
measurement are conducted under yellow light to avoid inadvertent photooxidation
of any BaP in sample solutions.
The fluorometric final analytical step of the procedure is linear over the range
of 10 to 400 ng (1.54xl0~7 to 6.17xl0"6 grains) , and sample aliquot size from the
benzene extraction must be adjusted so that sample concentration falls in_this
analytical range. Typically, ambient air containing 0.02 to 0.8 ug/m3 (8.74xl0~9 to
3.50xl0~7 grains/ft3) would correspond to this range.
Pure internal standards are used to develop calibration factors in the spectro-
photofluorometer. Samples and standards are analyzed together. Fluorescence
intensity of the filters is calculated and corrected for BaP content of filter blanks.
The coefficient of variation of the analytical procedure is estimated to be ± 0.07 in
the range of 10 to 400 ng (1.54xl0~7 to 6.17x10"® grains) of BaP. Accuracy is
affected by sample handling, transfer procedures, and thin-layer chromatographic
extraction process and can be minimized if a controlled BaP standard is carried
through the whole analysis process.
B-19
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Cj THROUGH Cs HYDROCARBONS USING GAS CHROMATOGRAPHY
Ambient air samples are collected through grab sampling techniques using
plastic bags with air valves. The plastic bags are flushed three times with ambient
air and then filled for transport to the GC for analysis. Portions of the ambient air
in the bag are analyzed for Ci through C5 hydrocarbons by gas chromatography (86).
Analysis is performed on a single column at 0°C (32°F) with separated components
being detected by FID.
The method has applications in atmospheres containing 0.01 ppm. The lower
limit for C3 through C5 hydrocarbons can be extended by concentrating 100 ml (.026
gal) aliquots of sample in a freeze trap. This limit is 0.1 ppbv.
Preliminary screening of a representative sample provides a qualitative
analysis for each hydrocarbon to be measured. Calibration standards are then
prepared by dilution and transferred to a plastic bag. Retention times are
determined for each hydrocarbon and the standards are used for comparison to
samples. A response factor and FID response is used in calculations to calibrate
ambient concentration of Ci through Cs hydrocarbons.
ORGANICS BY ABSORPTION, PURGE, AND TRAP GAS CHROMATOGRAPHY
Ambient organic concentrations are determined on a semiquantitative basis by
sampling through specially designed cartridges mounted in place of the filter on a
high-volume air sampler. Absorbed organic material is quantitatively desorbed from
the cartridge with separation and identification by GC/MS (87).
The technique has application in ambient atmospheres with concentrations of
or panics ranging from baseline levels (low concentrations) to relatively high
concentrations when sampling for specific time periods al: 100-to250 Um.n (26 » to
66.0 eal/min) (88). Detection limits are typically 0.1 ng/m (4.37x10 grains/ft )
(89). Sample contamination and substrate interferences lead to error if the
procedures are not carefully specified.
Samples must be held at subzero temperatures in darkness to avoid absorptive
losses of organics on substrate to the sample container walls (90). Efficiency of
recovery from sampling containers depends on both vapor pressure and water
solubility of organic materials sampled.
Calibration of organic sampling and analysis procedures are performed by
quantifying error in all phases of the process. The procedure consists of efficiency
tests in collection, storage, separation, and concentration in the analytical phase of
the process, and definite quantification in the screening process through use of
standard materials. Uncertainty of the sampling extraction and analytic processes
is about 40 ng of C6 constituents for both the GC/MS analyses.
PAH USING UV SPECTROSCOPY
Sampling is conducted by passing air through either a membrane or glass fiber
filters with subsequent gas chromatograph separation of extraction mixtures. Filter
blanks and samples must be shipped to the laboratory in light-proof containers.
B-20
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Polynuclear aromatic hydrocarbons (PAH's) are collected from GC eluate and
analyzed by UV spectroscopy (85).
The method has a range of concentration from 2 to 1000 ug/m3 (8.74xl0~7 to
4.37xl0~4 grains/ft3), with sample volumes as low as 0.5 m3 (17.65 gt3). Detection
limits lie in the range of 0.2 to 2.7 yg/sample (3.09xl0~6 to 1.12xl0~lf grains) for
individual compounds as collected on membrane filters. At about 2 ppm, sampling is
performed with glass fiber filters in series with silver membranes. Ambient
concentrations in most oil shale development areas will require sampling periods of
24 hours.
Retention times are determined with the GC using pure O-terephenyl and
biphenyl internal standards and procedures (85). The UV spectrophotometer is
calibrated by recording the reference absorption spectrum of internal standard
solutions at four different concentrations. A calibration factor is developed for
each sample compound and the internal standard by dividing concentration by
absorbance.
Calculations to determine the weight of each PAH are started, using recovery
factors of internal standards through the separation and eluate fraction collection
procedure (91). The weight in micrograms of each compound is then calculated
using the absorbance and UV calibration factor for the polynuclear compound.
No method for either precision or accuracy has yet been determined for
collection of the sample, extraction, calibration, and final analysis. Duplicate
analyses of the same organic fraction show a precision of ± 10 percent (91).
POLYCYCL1C ORGANIC MATTER
Filter samples of particulate polycyclic organic matter (POM) are extracted
ultrasonically in CS2 or benzene solvent and the solvent solution is analyzed by FID
and GC. The method is not specific, and analysis is qualitative for classes of
compounds as defined in the Federal Register (92).
Glass fiber filters in polystyrene or polycarbonate filter cassettes are used to
sample air at 2 to 6 i/min (0.07 to 0.21 ft3/min), depending on ambient
concentrations for 8 hours or more (93). Exhaust flows should be isolated from the
sampling area to prevent sampling carbon from the pump. Ambient concentrations
of 0.05 to 10 mg/ml (4.17x10 to 8.34xl0~5) are measured in sampled air.
Anthracene, pyrene, chrysene, BaP, and 1,12 benzoperylene are dissolved in
solvent to provide a representative calibration curve of 3- to 6-ring compound
samples. Precision has been reported at + 5 percent by within-laboratory single
operation as seen in the ASTM Annual Book of Standards (93). Accuracy data are
not yet available.
ASBESTOS AND ASBESTOS-LIKE FIBERS
Ambient air is drawn through a membrane filter, and the filter is analyzed
optically (94, 95). The method is the method of test in the U.S. Public Health
Service criteria document on occupational exposure to asbestos (96, 97) and is listed
in the 1974 ASTM Annual Book of Standards (98). The method with suitable
B-21
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sampling periods has application in atmospheres containing concentrations of
asbestos and asbestos-like fibers over the range of 1 to 20 fibers/cm3 (.06 in.3).
Fibers longer than 5 \i m (1.97x10"'' in.) are counted.
Sampling is done at 1.0 to 2.5 1/min (.26 to .66 g/m) for a time period
sufficient for concentrations of sampled fibers longer than 5 pm to be analyzed.
Particulate matter with a length-to-width ration of 3 to 1 or greater and a length
greater than 5 pm can interfere if it has not been identified as asbestiform
material.
Sampling flow rate is calibrated against traceable standards once each month.
Phase contrast analysis of fibers is standardized using Porton reticule and stage
micrometers for size comparison. Reproducible results depend on accurate
screening of fibers greater than 5 ym and equal to or greater than 3:1 length-to-
width ratio. The Bureau of Mines shows that asbestiform minerals have an aspect
ratio between 10 to 1 and 20 to 1, and this will probably become a criterion in
defining asbestos or asbestos-like fibers (99).
Precision of counting fibers on membrane filters has been estimated at 16.2
percent (100). The procedure has a standard deviation of 21.4 percent. For samples
with a low concentration of fine fibers, the standard deviation is estimated at ± 45
percent at the 95 percent confidence interval. The National Institute of
Occupational Safety and Health (101) has estimated standard deviation for counting
at the 95 percent confidence interval at ± 30 percent. Geometric concentrations of
asbestos can be used to determine accuracy by use of a factor developed by
Thompson (102).
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51. Ellis, E. C., and J. H. Margeson. Evaluation of Gas Phase Titration Technique
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Park, N.C., 1975.
52. Rehme, K. A. Application of Gas Phase Titration in the Calibration of NO,
NO2, and Ozone Analyzers. ASTM, STP 598, American Society for Testing and
Materials, Philadelphia, Ps., 1975. p. 198-209.
53. Constant, P. G., M. C. Sharp, and G. W. Scheil. Collaborative Test of the
Chemiluminescent Method for Measurement of NOz in Ambient Air.
EPA-650/4-75-013, U.S. Environmental Protection Agency, Research Triangle
Park, N.C., 1975.
54. 40 CFR 53, Appendix E, July 1977.
55. Stevens, R. K. The Automated Gas Chromatograph as an Air Pollutant
Monitor. In Proceedings of a Conference on Environmental Toxicology,
AMRL-TR-70-102, U.S. Air Force, Wright-Patterson Air Force Base, Dayton,
Ohio, 1970.
56. McElroy, F. F., and V. L. Thompson. Hydrocarbon Measurement Discrepancies
Among Various Analyzers. EPA-600/4-75-010, U.S. Environmental Protection
Agency, Research Triangle Park, N.C., 1978.
57. Stevens, R. K., J. D. Mulik, A. E. O'Keeffe, and K. J. Krost. Gas
Chromatography of Reactive Sulfur Gases in Air at the Parts Per Billion
Level. Anal. Chem. 43:827, 1971.
58. O'Keeffe, A. E., and G. C. Ortman. Primary Standard for Trace Gas Analysis.
Anal. Chem. 38:760, 1966.
59. Scaringelli, F. P., S. A. Frey, and B. E. Saltzman. Evaluation of Teflon
Permeation Tubes for Use with Sulfur Dioxide. Amer. Ind. Hyg. Assn. J.
28:260, 1967.
60. Scaringelli, F. P., A. E. O'Keeffe, E. Rosenberg, and 3. P. Bell. Preparation of
Known Concentrations of Gases and Vapors with Permeation Devices
Calibrated Gravimetrically. Anal. Chem. 42:871, 1970.
61. Sampling and Analysis of Low Molecular Weight Sulfur Compounds in Process
Effluents. U.S. Environmental Protection Agency, Research Triangle Park,
N.C. (In press.)
62. Federal Register 42:63083-63086, December 14, 1977.
63. 40 CFR 50.12.
64. 40 CFR 50, Appendix B, July 1, 1975.
B-26
-------
65. Methods of Sampling and Analysis. 2nd edi., M. Katz, ed. APHA Intersociety
Committee, American Public Health Association, Washington, D.C., 1977. pp.
492-497.
66. Long, S. 3., D. R. Scott, and R. 3. Thompson. Atomic Absorption
Determination of Elemental Mercury Collected from Ambient Air on Silver
Wool. Anal. Chem 45:2227, 1973.
67. Walsh, P. R., 3. L. Fasching, and R. A. Duce. Matrix Effects and Their
Control During the Flameless Atomic Absorption Determination of Arsenic.
Anal. Chem. 48:7, 1976.
68. Spumy, K. R., 3. P. Lodge, 3r., E. R. Frank, and D. C. Sheesley. Aerosol
Filtration by Means of Nucleopore Filters - Aerosol Sampling and
Measurement. Environ. Sci. Tech. 3:464, 1969.
69. Spumy, K. R., W. Stober, E. R. Ackerman, 3. P. Lodge, 3r., and K. Spurny, 3r.
The Sampling and Electron Microscopy of Asbestos Aerosol in Ambient Air by
Means of Nucleopore Filters. In Proceedings of the Air Pollution Control
Assn., Denver, Colo. 3APCA 26:496-498, 1976.
70. Spurny, K. R., and 3. P. Lodge, 3r. Collection Efficiency Tables for Membrane
Filters Used in the Sampling and Analysis of Aerosols and Hydrosols. Vol. I:
Techniques and Discussion. NCAR-TN/STR-77, National Center for
Atmospheric Research, Boulder, Colo, 1972.
71. Cahill, T. A., L. L. Ashbaugh, J. B. Barone, R. A. Eldred, P. 3. Feeney, R. G.
Flocchini, C. Goodart, D. 3. Shadoan, and G. W. Wolfe. Analysis of Respirable
Fractions in Atmospheric Particulates via Sequential Filtration. 3. Air
Pollution Control Assn. 27:675-677, 1977.
72. Kowalczyk, G. S., C. E. Choquette, and G. E. Gordon. Chemical Element
Balance and Identification of Air Pollution Sources in Washington, D.C.
Atmos. Environ. 12:1143-1153, 1978.
73. Flocchini, R. G., T. A. Cahill, D. 3. Shadoan, S. Lange, R. A. Eldred, P. 3.
Feeney, G. Wolfe, D. Simmeroth, and 3. Suder. Monitoring California's
Aerosols by Size and Elemental Composition. Environ. Sci. & Tech. 10(1): 76-
82, 1976.
74. Stevens, R. K., T. G. Dzubay, G. Russwarm, and D. Rickel. Sampling and
Analysis of Atmospheric Sulfates and Related Species. Atmos. Environ.
12:56-68, 1978.
75. Stevens, R. K., and T. G. Dzubay. Dichotomous Sampler - A Practical
Approach to Aerosol Fractionation and Collection. EPA-600/2-78-112, U.S.
Environmental Protection Agency, Research Triangle Park, N.C., 1978.
76. Brosset, C., and M. Ferm. Manmade Airborne Acidity and Its Determination.
IVL Publications, B-34B, Gothensberg, Sweden, 1976.
77. Federal Register 36:8191-8194, 30 April 1971.
B-27
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78 Lazrus, A. L., K. C. Hill, and 3. P. Lodge. A New Colorimetric
Microdetermination of Sulfate Ion. In Proceedings of the Technicon Symposium
on Automation in Analytical Chemistry. Technicon, Inc., New York, N.Y,
1965.
79. Nitrogen, Nitrate - Nitrite (Automated Cadmium Reduction Method). In:
Methods 'for Chemical Analysis of Water and Wastes. EPA-625/6-74-003, U.S.
Environmental Protection Agency, Cincinnati, Ohio, 1974. pp. 207-212.
80. Methods of Air Sampling and Analysis. 2nd edi., M. Katz, ed. American Public
Health Association, Washington, D.C., 1977.
81. Axel rod, H. D., A. F. Wartburg, R. J. Teck and 3. P. Lodge, Jr. A New Bubbler
Design for Atmospheric Sampling. Anal. Chem. ^3:1916, 1971.
82. Milton, 3. A., and A. L. Wilson. An Absorption Metric Method for Determining
Ammonia in Boiler Feed Water. Analyst. 89:453-465, 1964.
83. Rommers, P. 3., and 3. Vissir. Spectrophotometry Determination of Micro
Amounts of Nitrogen as Indophenol. Analyst. 94:653-658, 1969.
8^. Methods of Air Sampling and Analysis. 2nd edi., M. Katz, ed. American
Public Health Association, Washington, D.C., 1977. pp. 511-518.
85 NIOSH Manual of Analytical Methods, Volumes 1-3, No. 186, 2nd edi. National
Institute of Occupational Safety and Health, U.S. Dept. of Health, Education,
and Welfare, Cincinnati, Ohio, 1977.
86. ASTM Annual Book of Standards, Part 26, D2820-78. American Society for
Testing and Materials, Philadelphia, Pa., 1978.
87 Lewis R. 3., A. R. Brown, and M. D. 3ackson. Evaluation of Polyurethane
Foam' for Sampling of Pesticides, Polychlorinated Biphenyls, and
Poly chlorinated Napthalene in Ambient Air. 3. Anal. Chem. 49:12, 1668-1672,
1977.
88 Sheesley, D. C., R. C. Neuscheler, M. LaHue, 3. P. Lodge. Atmospheric
Oreanics in the Humid Tropics. Proceedings of the 3oint Conference on
Sensing Environmental Pollutants, 71-1123, Palo Alto, Calif., 1971.
89. Accuracy and Trace Organic Analyses. EPA-600/3-76/078, U.S.
Environmental Protection Agency, Cincinnati, Ohio, 1977.
90 Sampling and Analysis Procedure for Screening of Industrial Effluents for
Priority Pollutants. 1977. EPA, Environmental Monitoring and Support
Laboratory, Cincinnati, Ohio.
91. ASTM Annual Book of Standards, D-2682-71. American Society for Testing
and Materials, Philadelphia, Pa., 1971.
92. Federal Register, Part 1910, November 21, 1972.
B-28
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93. ASTM Annual Book of Standards, Part 26. Gaseous Fuels: Coal and Coke.
Atmospheric Analysis. American Society for Testing and Materials,
Philadelphia, Pa., 1978.
94. The Measurement of Airborne Asbestos Dust by the Membrane Filter Method:
Technical Note. Asbestos Research Council, Dr. S. Holmes (Secy.), PO Box
<4-0, Rockdale Lancashire, Great Britain, 1969.
95. Federal Register 37:22142-22144, 1972.
96. Criteria for a Recommended Standard Occupational Exposure to Asbestos.
HSM-72-10267, National Institute for Occupational Safety and Health,
Rockville, Md., 1972.
97. 29 CFR 191093a.
98. ASTM Annual Book of Standards, Part 26. American Society for Testing and
Materials, Philadelphia, Penn., 1974.
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Selected Silicate Minerals and Their Asbestiform Varieties. Bureau of Mines
IC 8751. U.S. Dept. of the Interior, Washington, D.C., 1977.
100. Conway, R. E., and W. D. Holland. Statistical Evaluation of the Procedure
for Counting Asbestos Fibers on Membrane Filters. LFE Corporation,
Richmond, Calif., prepared for Asbestos Information Assn. North America,
New York, N.Y., 1973.
101. Recommended Criteria Document on Asbestos TR-83. National Institute for
Occupational Safety and Health. Cincinnati, Ohio, 1978.
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Air. In Proceedings of the International Symposium on Identification and
Measurement of Environmental Pollution. National Research Council,
Ottawa, Canada, 1971.
B-29
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Prepared by Jacobs Environmental,
a Division of Jacobs Engineering Group Inc.
APPENDIX C
ENVIRONMENTAL MONITORING ACTIVITIES - PAST, PRESENT, AND PROPOSED
TRACT C-a
Air Resources
Baseline Data Gathering Program—
The environmental baseline study was conducted in accordance with the
stipulations of the Oil Shale Lease C-20046 issued to Gulf Oil Corp. and Standard Oil
Co. (Indiana) in February 1974. The regional location of Tract C-a is illustrated in
Figure C-1.
The Rio Blanco Oil Shale Project (RBOSP) baseline environmental studies were
conducted between 1974 and 1976 by Gulf, Standard, and various subcontractors.
The published documents that have been used in the preparation of this report are
RBOSP Final Environmental Baseline Report for Tract C-a and Vicinity, May 1977,
Volumes 1 and 2 (1), and RBOSP Environmental Baseline Data Accumulation
Program C-a, Revised December 1975 (2).
Baseline air quality data were gathered at four monitoring sites around the
Tract C-a area. The approximate locations of these sites are presented in Figure
C-2.
Ambient air was measured for concentrations of THC, CHi,, SO2, H2S, NOx,
NO, CO, O3, and TSP; the latter were characterized for particulate size. The air
quality parameters measured at each site during baseline are presented in Table
C-l, together with the equipment used for instrumentation and measurement. High-
volume filter material (TSP) was also analyzed for the following trace elements:
Uranium
Dysprosium
Rhodium
Chromium
Thorium
Terbium
Ruthenium
Vanadium
Bismuth
Gadolinium
Molybdenum
Titanium
Lead
Europium
Niobium
Scandium
Thalium
Samarium
Zirconium
Calcium
Mercury
Neodymium
Yttrium
Potassium
Gold
Praseodymium
Strontium
Chlorine
Platinum
Cerium
Rubidium
Sulfur
Iridium
Lanthanum
Bromine
Phosphorus
Osmium
Barium
Selenium
Silicon
Rhenium
Cesium
Arsenic
Aluminum
Tungsten
Iodine
Germanium
Magnesium
C-l
-------
WYOMING
o
t
to
PLATTE DRAINAGE
iQuality
KANSAS
DRAINAGE
Coxvtrol
ReqiflTi >-
S3P
COLORADO DRAINAGE
Axr
Quality
_j \
Maintenance >,
Area S
ARKANSAS DRAINAGE
GRANDEV^ \ ^ l
/DRAINAGE
1 /
4-
COLORADO
NEW* AlEXl'cO
0 50 100
1 I I
Miles
Figure C-l. Tract C-a, regional location map.
-------
Miles
As
Tract C-a.
Figure C-2. Location map for Tract C-a air quality and meteorology monitoring stations.
-------
TABLE C-l. AIR QUALITY AND METEOROLOGICAL PARAMETERS, INSTRUMENTATION, SAMPLING FREQUENCY, AND
SCHEDULES OF THE BASELINE AIR RESOURCES MONITORING PROGRAM FOR TRACT C-a
Monitoring Monitoring Total approach
Parameters Instrumentation stations frequency (+ppm)
so2
Bendix 8200X
1
2,3,4
C
H2s
Bendix 8200X
1
2,3,4
C
NO
v
Bendix 8101-B
1
3
C
NO
Bendix 8101-B
1
3
C
THC
Bendix 8207
1
2,3,4
C
ch4
Bendix 8207
1
2,3,4
C
Ozone (O3)
Bendix 8002
1
3
C
CO
Bendix 8501-5CA
1
3
C
Suspended particulated
General Metal
1
2,3,4
B
Works Hi Vol
Hind speed
Climet
1
10,30,60 m) C
2
10,30
m)
3
10,30
m)
4
10,30
m)
Wind direction
Climet
1
10 m)
C
Temperature
Rosemont
1
10,30
m) C
2
10 m)
3
10 m)
4
10 m)
Change in temperature
1
10,60
m) C
Relative humidity
Weather Measure
1
10 m)
C
Evaporation rate
Pan
1
2,3,4
A
Snow depth
Ruler
1
2,3,4
A
Hater content
Grad. cylinder
1
2,3,4
A
Visibility
Camera
1
2,3,4
A
0.020
0.020
0.010
0.010
0.10
0.02
0.004
0.500
aA = Seasonal, annual; B = 24-hr composite every sixth day; C = Continuous.
-------
Tantalum
Hafnium
Lutecium
Tellurium
Antimony
Gallium
Zinc
Sodium
Fluorine
Oxygen
Nitrogen
Carbon
Boron
Ytterbium
Thulium
Erbium
Holmium
Lithium
Tin
Indium
Cadmium
Silver
Palladium
Copper
Nickel
Cobalt
Iron
Manganese
Beryllium
Climatological data were gathered from two sources during baseline data
gathering. Data that were already established around the Tract C-a area and data
created as part of the baseline data gathering program have been used to determine
climatological characteristics of the immediate locality. Meteorological data were
acquired at four locations around Tract C-a. These locations have been plotted and
are illustrated in Figure C-2. The main meteorological tower is at Station 1 and is
approximately 60 m (197 ft) high. The remainder of the towers are 10 m (33 ft)
high. The parameters being measured on a routine basis at each site are presented
in Table C-l. Seasonal and annual measurements include: evaporation rate, snow
depth and water content, and visibility. To assure reliability of baseline
meteorological data, a quality assurance program was established to meet
requirements specified under 10 CFR 50, Appendix D.
Upper air meteorological measurements were made over four 15-day quarterly
periods during 1974 and 1975. These periods were in the fall (October 1974), the
winter (January-February 1975), the spring (April-May 1975), and the summer (July
1975). A summary of the sounding experiment is presented in Table C-2.
Ambient temperdture soundings were made between 1,920 m (6,300 ft) and
3,962 m (13,000 ft) at 30.5 m (100 ft) increments. Wind speed and direction
soundings were made from about 610 m to 3,962 m at 91.5 m (2,000 ft to 13,000 ft
at 300 ft) increments. After the data were developed, an analysis of seasoned air
mixing was performed.
Tracer studies for the purpose of testing atmospheric diffusion were conducted
on 10 specific occasions, varying in length from 4 to 2k hr, for a total test time of
87 hr. In addition, the Rio Blanco Oil Shale Project (RBOSP) ran an air quality
dispersion model tailored to the Tract C-a site.
Interim Monitoring Program-
In September 1976, RBOSP was granted a suspension of operations for 1 year.
During that 1 year, an interim monitoring program was initiated to maintain a
continuous data base on critical parameters that had been studied in the baseline
program. This section will summarize the proceedings of that study as reported in
References 3, 4, and 5. The primary contractor for these studies was the NUS Corp.
During the interim study monitoring programs, one air quality station (Site 1)
was left operational and was equipped for the continual measurement of SO2, H2S,
NO, NOx, CO, O3, CHi», and THC. The location of this monitoring site is shown on
Figure C-2. The instruments used represented the state-of-the-art in automatic
instrument pollutant monitoring. In addition, particulates were sampled by two
high-volume samplers, one at ground level 1.5 m (5 ft) and the other at 7 m (23 ft)
C-5
-------
TABLE C-2. ATMOSPHERIC DIFFUSION SOUNDING TEST RESULTS OF BASELINE
AIR RESOURCES MONITORING PROGRAM FOR TRACT C-a
Average mixing layer height for a 300-ft stack
Sounding 1
Sounding 2
Sounding 3
Sounding 4
Time
of
measurement Height Freq. of Height
period (ft) occurrence (ft)
Freq. of Height Freq. of Height Freq. of
occurrence (ft) occurrence (ft) occurrence
Mean time
to inversion
breakup
(MST)
Fall
642
0.67
400
0.09
7:50
Winter
2,371
0.47
950
0.27
2,900
0.13
2,788
0.27
11:45
Spring
3,067
0.20
6:50
Summer
588
0.20
7:00
Annual
1,477
950
2,788
aData only considered for inversions above level of tract (7,200 ft).
b
Based on fewer than three occurrences.
-------
aboveground. Wet chemical determinations were made for S02, H2S, NO, NOx, and
O3 for purposes of comparison with automatic ambient data.
During this study a complete and accurate set of program documentation was
generated. Several major pieces of equipment were reconditioned. The magnetic
tape deck and station teletype were reconditioned, the standby-emergency power
supplies were serviced to reduce station noise levels and repair electronic
component damage apparently caused by lightning. Frequent, short-term
interruptions in commercial primary power continued to be a problem. The "360°
wind direction sensors were replaced with NOIC certified 540° units to eliminate
problems with the back-up strip chart recordings of wind direction.
The monitoring site was visited on an average of every other day by the site
technician. A station checklist was completed for each week of operation. A zero
and span test of the gas monitoring instruments was conducted weekly. Control
charts were made to evaluate instrument stability and performance. During the
interim monitoring period the site was subjected to voluntary EPA audits under the
Western Energy Quality Assurance Program. The performance of the NUS Rockville
air quality laboratory was also subjected to audit through a collaborative
inter laboratory testing program.
The 60 m (197 ft) tower at Site 1 was also used to monitor meteorology during
the interim program. The parameters measured on the tower included temperature,
wind speed and direction (10 m, 30 m, and 60 m or 33 ft, 99 ft, and 197 ft), relative
humidity, wind sigma, differential temperature (10 m, 60 m or 33 ft, 197 ft), and
solar radiation.
The precipitation monitoring program was the same as the one employed
during baseline monitoring except for the precipitation chemistry monitoring
program which was added during interim monitoring. Precipitation chemistry was
measured on samples of rain and snow collected in specially cleaned containers.
Once the sample was taken it was transferred to nalgene containers and analyzed
for: arsenic, cadmium, chromium, copper, lead, molybdenum, mercury, selenium,
bromide, calcium, chloride, magnesium, potassium, sodium, iron, pH, fluoride,
sulfate, total dissolved solids, bicarbonate, carbonate, total nitrogen, and silicon
dioxide.
Modular Development Phase Monitoring Program-
On January 1, 1978 the Rio Blanco Oil Shale Project (RBOSP) was renamed the
Rio Blanco Oil Shale Company (RBOSC). Since this change took place during the
modular development phase, all references to the Tract C-a development will be
RBOSC.
Environmental studies that are presently taking place are part of a 4-year and
4-month period program entitled the RBOSC modular development phase monitoring
program (MDPMP). The program is set up to operate in accordance with the
guidelines set up in the RBOSP detailed development plan, May 1977. The program
schedule is as follows:
Year 1 September - December 1977 (4 months)
Year 2 January - December 1978 (12 months)
C-7
-------
Based on results of the baseline, interim and modular development phase
monitoring programs (years 1 and 2), a revised program has been developed to
address adequately the period during which RBOSC will be constructing modular
development phase retorts and associated support facilities for the ignition and burn
of five modular development phase retorts. The time period to be covered includes
the following:
Year 3 January - December 1979
Year 4 January - December 1980
Year 5 January - December 1981
Since only hydrocarbons and ozone were found in significant quantities during
baseline studies, special attention is being paid to the monitoring of these
pollutants in the second half of the modular development phase air resources
monitoring program.
The modular development phase monitoring program has been set up as a
dynamic program. This means that it is subject to alteration at any time upon
conference and agreement with the Area Oil Shale Supervisor. The outline of this
program is not to be taken as program guidelines. The primary contractor for this
program is the NUS Corp. The documents that have been used in preparation of this
section are References 6-10.
The monitoring of gaseous pollutants in the Tract C-a area is presently being
carried out by automatic instrumentation at monitoring Sites 1 and 3 during the
modular development phase monitoring program. Monitoring at Site 5 will follow at
a later date. The locations of these monitoring stations are presented in Figure C-2.
A description of the parameters being measured, the date of program institution,
and the sampling frequency for each site is shown in Table C-3.
The system at Site 1 is continuous and one that automatically scans all
parameters at each site approximately 3.6 times/min and computes a running 15-
min, 1-hr average. The data are recorded on magnetic tape. When the instruments
are serviced and maintained on a regular basis, data recovery should be close to 90
percent annually. The detection techniques in use in the tract instrumentation meet
the requirements of reference methods specifications. Calibration of the air quality
instrumentation is performed at least once each season (90-day period). Once the
data is placed on strip charts and magnetic tapes, it is transferred to the NUS data
reduction group on a biweekly basis. Finally, the air quality data will be examined
for frequency of occurrence and interpreted graphically.
Particulates are being monitored at three (1, 2, and 3) air quality monitoring
sites on Tract C-a. The locations of these particulate monitoring sites are shown in
Figure C-2.
Particulate samples are being taken at all points by high volume General Metal
Works particulate samplers, which are situated approximately 6 m (20 ft) above
ground level. One 24-hr volume sample is taken by each of the five samplers every
third day. The schedules for each sampling site are summarized in Table C-3. The
C-8
-------
TABLE C-3. AIR QUALITY MONITORING SCHEDULE FOR THE MODULAR DEVELOPMENT
PHASE MONITORING PROGRAM AT TRACT C-a
Parameter
Sampling
location
Starting date
Sampling
frequency
Sulfur dioxide
Site 1
Sept
. 1977
Continuous
Site 3
Jan.
1978
Continuous
a
Sites 2,5
Sept
. 1979
Continuous
Hydrogen sulfide
Site 1
Sept
. 1977
Continuous
Site 3
Jan.
1978
Continuous
Site 2a
Sept
. 1979
Continuous
Nitric oxide
Site 1
Sept
. 1977
Continuous
Site 3
Sept
. 1979
Continuous
Nitrogen oxides
Site 1
Sept
. 1977
Continuous
Site 3
Sept
. 1979
Continuous
Carbon Monoxide
Site 1
Sept
. 1977
Continuous
Site 3
Sept
. 1979
Continuous
Ozone
Site 1
Sept
. 1977
Continuous
Site 3
Nov.
1979
Continuous
Particulates
Sites 1,2,3
Dec.
1977
Continuous
Site 6^
Nov.
1977
Every 3rd day
aProposed for modular development phase operation,
b
Discontinued by permission.
-------
high-volume sampler flow rates are calibrated quarterly with a standard orifice
plate.
Meteorological parameters are being measured at Sites 1, 2, and 3. The
locations of these three sites are shown on Figure C-2.
The parameters to be measured are wind direction, wind speed, wind sigma,
ambient temperature, temperature, precipitation, solar radiation, and dewpoint.
The frequency with which these parameters will be measured and the date of
program initiation for each sampling site is summarized in Table C-4.
The data acquisition system scans each parameter approximately 3.6 times
every minute and computes a 15-min average, from which a 1-hr average is derived
during data reduction. All instrumentation is maintained and serviced on a regular
basis to assure accuracy. The data are recorded on magnetic tape that is returned
to NUS for computer listing, scaling, and strip-chart reduction.
The Clean Air Act as amended in 1977 declares that prevention of visibility
impairment from manmade air pollution is a national goal in mandatory Federal PSD
Class I air quality areas.
A visibility program will be made part of modular development phase
monitoring. Measurements will be taken over both long and very short pathlengths,
utilizing, most likely, a telephotometer.
Proposed Commercial Development Phase Monitoring Program-
Construction on commercial operation facilities is intended to begin in 3une
1982, and commercial operation is intended to ensue in February 1987. The
Commercial development phase monitoring program will be active during this time
period, from June 1982 until completion of the project.
Details of the proposed commercial phase monitoring program were provided
in the RBOSP Revised Detailed Development Plan: Tract C-a, May 1972, Vol. 3
(11). The monitoring program as. proposed in the revised DDP and as summarized
here is very tentative due to changes in the engineering plan, improvements in
monitoring technology, and changes in applicable regulations.
Air quality parameters will be monitored at four locations around the Tract
C-a area during commercial operation. Monitoring Site 1 will be situated in a
position that represents the area of maximum impact. Site 2 will be maintained in
an area representing the upwind side of the tract, and Site 3 will be at the downwind
tract periphery. The locations of these sites is presented in Figure C-2.
The Tract C-a long-term monitoring program will monitor atmospheric
suspended particulates, sulfur dioxide, nitrogen dioxide, oxidants (as ozone),
hydrogen sulfide, methane, nonmethane hydrocarbons, carbon monoxide, and
visibility. Along with the monitoring done at established sampling Sites 1, 2, and 3,
one additional high-volume sampler may be operated in an area of high vehicular
traffic at 3 m (10 ft) aboveground. The monitoring site is to be equipped with a
sulfur dioxide detector, a high-volume sampler, and a nonmethane hydrocarbon
detector. These three pollutants are the most likely to be emitted, and hence they
C-10
-------
TABLE C-4. METEOROLOGICAL PARAMETER MONITORING SCHEDULE FOR THE MODULAR
DEVELOPMENT PHASE MONITORING PROGRAM AT TRACT C-a
Parameter
Sampling location
Starting date
Sampling frequency
Wind direction (10m)
Sites 1,2
Sept. 1, 1977
Continuously
Site 3
June 1, 1979
Continuously
Wind direction (60m)
Site 1
Sept. 1, 1977
Continuously
Wind speed (10m)
Sites 1,2
Sept. 1, 1977
Continuously
Site 3
June 1, 1979
Continuously
Wind speed (60m)
Site 1
Sept. 1, 1977
Continuously
Wind sigma (10m)
Site 1
Sept. 1, 1977
Continuously
Ambient temperature (10m)
Sites 1,2
Sept. 1, 1977
Continuously
Site 3
June 1, 1979
Continuously
Temperature (10 & 60m)
Site 1
Sept. 1, 1977
Cont inuou sly
Precipitation (tipping)
Site 1
Sept. 1, 1977
Continuously
bucket & recording guage
Solar radiation
Site 1
Sept. 1, 1977
Continuously
Dewpoint
Site 1
July 29, 1979
Continuously
-------
are considered good overall indicators of the diffusion of pollutants from the
operations.
Site 1 will be equipped with a system capable of collecting continuous data
scans and recording data as hourly averages for each gaseous pollutant. Hourly
averages may be computed for all stations. Data will be analyzed quarterly (end of
each season) and summarized annually. Suspended particulates would be sampled
every sixth day. Calibrations will be performed quarterly, or whenever is necessary.
The calibration report will be a part of the quarterly data analysis report.
The specific requirements of a source emission monitoring program have not
yet been defined. Source monitoring and stack sampling that will be necessary for
permit compliance will be included in the final design and all necessary access
facilities will be installed. During the modular development phase, a trace element
analysis will be made of the thermal oxidizer flue gas.
Meteorological parameters of the Tract C-a area will be monitored at three
sites located at air quality monitoring stations 1, 2, and 3 (see Figure C-2).
Meteorological parameters will be measured with an automatic data
acquisition system and will be recorded separately on strip chart recorders with
15-min and hourly average values. The meteorological parameters to be measured
by each monitoring site are listed in Table C-5.
TABLE C-5. METEOROLOGICAL PARAMETERS PROPOSED TO BE
MEASURED IN THE COMMERCIAL DEVELOPMENT
PHASE MONITORING PROGRAM AT TRACT C-a
Sites
Parameter
Wind direction at 10 m (33 ft) X
Wind direction at 60 m (197 ft) X
Wind speed at 10 m X
Wind speed at 60 m X
Ambient air temperature at 10 m X
Dewpoint at 10 m X
Total precipitation (heated gauge) X
Solar radiation level at 2 m (6.6 ft) X
Differential vertical temperature
gradient at 10 m X
Differential vertical temperature
gradient at 60 m X
Wind sigma metered at 10 m X
C-12
-------
A significant part of the data analysis program will be spent in data validation
to assure original data accuracy.
Water Resources
Baseline Data Gathering Program—
The baseline surface and groundwater data gathering program was conducted
from March 1974 to September 1976. Much of the surface water data were
gathered from U.S. Geological Survey (USGS) stream-gaging stations. The primary
environmental contractor in the program was Limnetics. The main source of
information on the program was supplied by the Final Environmental Baseline
Report (1).
All collection procedures were designed for compliance with RBOSP needs, the
Oil Shale Lease Environmental Stipulation, the Federal Register (Volume 39,
Number 230, Part 3), the Tract C-a Exploratory Plan of May 1974, and subsequent
conditions of approval from the Area Oil Shale Supervisor.
Surface water—Surface water flow and quality had originally been monitored
at seven stream sites by USGS. Two of the seven had continuous flow and the other
five had periodic flow. Three additional stream-gaging stations were implemented
as part of the baseline program to monitor drainages in the proposed processed shale
disposal site on 84 Mesa. The locations of these stations are presented in Figure
C-3. Each station was equipped with a structure and automatic recording
equipment for flow rate, temperature, and conductivity. Automatic sediment
samplers were also installed at each station. In areas of relatively constant flow,
automatic water quality samplers were set up to grab samples at regular intervals.
The remaining streams had been set up to be sampled manually. The locations and
USGS identification numbers for stream and rain-gaging stations during the baseline
study are described in Table C-6.
Six rain gages were operated on and around Tract C-a for the purpose of
collecting precipitation data. All six stations were operated by the USGS. The
locations of these stations are shown in Figure C-3. Three of the gages were
manually operated storage-type rain gages. The precipitation was measured at
regular intervals. The other three gages were recording-type gages that recorded
cumulative precipitation as well as precipitation rate over 5-min intervals.
Thirty-seven springs and seeps were identified and mapped (Figure C-4). Six
of the 37 springs and seeps were analyzed for water quality and hydrology. The
frequency of flow and quality measurements are not provided. The stations were
monitored for the water quality parameters listed in Table C-7.
The three aquifer systems (upper and lower oil shale aquifers and the alluvial
aquifers) were sampled using three methods. Water quality samples were collected
from the circulation line generally four times during the drilling or coring of each
hole. Samples were also collected for analysis during the aquifer testing program.
Most of the water quality information, however, was derived from the monitoring
program, where samples were collected by bailing. The results of wet chemical and
spectrographic chemical analyses are stored on a computerized data base for ease
in retrieval and analysis. The water quality data base consists of about 600
individual analyses so that, for meaningful interpretation, statistical methods were
c-13
-------
R 37 VI
R 98 Vf
R 93 W
R 100 W
"r cttxt
J
«...
»•»
TT
l«o
LEGEND
Surface-Watei?- Gaging_station
A Continuous Flow
C± Sporadic Flow
O Storage Type Rain Gage
• Recording'JType Rain Gage
® Alluvial Aquifer Test Hells
\ k
Figure C-3. Stream-gaging stations, rain-gaging stations, and
alluvial aquifer monitoring holes at Tract C-a.
C-14
-------
TABLE C-6. LOCATION AND USGS IDENTIFICATION NUMBERS FOR
STREAM- AND RAIN-GAGING STATIONS AT TRACT C-a
USGS
identification
number and
type of station
Location
Stream-gaging stations:
09306237
09306235
09306240
09306242
09306230
09306255
09306241
09306248
09306250
09306246
09306244
Rain-gaging stations:
Storage-type rain gages:
09306235
09306237
09306240
Rainfall intensity and
recording rain gages:
09306230
09306255
No number
Dry Fork near west line Tract C-a
Corral Gulch near west line Tract C-a
Box Elder Gulch near west line Tract C-a
Corral Gulch east of Tract C-a
Stake Springs Draw near confluence with
Corral Gulch
Yellow Creek near White River, Colorado
Rinky Dink Gulch near east line Tract C-a
Upper Big Duck Creek north of 84 Mesa
Lower Big Duck Creek north of 84 Mesa
Tributary to Yellow Creek east of 84 Mesa
Corral Gulch south of 84 Mesa (near 84 Ranch)
Corral Gulch near west line Tract C-a
Dry Fork near west line Tract C-a
Box Elder Gulch near west line Tract C-a
Stake Springs Draw near confluence with Corral
Gulch
Yellow Creek near White River, Colorado
Cathedral Bluffs located in NW1/4, NW1/4,
Sec. 14 T2S, R100W
C-15
-------
• » •
•4 'f -lt
v • . ¦
LEGEND
/•>
Perennial Springs and Seeps
A Other Springs and Seeps
Miles
Figure C-4. Location map for Tract C-a baseline spring and seepage sampling sites
-------
TABLE C-7. SAMPLING SCHEDULE SUMMARY fOR SURFACE AND GROUNDWATER MONITORING PROGRAM AT TRACT C-a"
BaBaling program Interla ptogra Modular development phage Comaerclal development phage (proposed)
Groundwaf r
Surface
First
Second
Surface
Surface
Surface
Ptraaeter
water
year
year
water
Groundwater
water
Groundwater
water
Groundwater
Alkalinity (ag/1)
M
AM, DM
AQ,DS
0
QS
AQS,DS
2s
AQS,DS
Aluiinui ( g/1)
H
AM,DM
AQ,DS
0
S
AS,DS
S
AS,OS
taaooU (HH4) (ag/1)
N
AM, DM
AQ,OS
O
S
AS,DS
S
AS,DS
Xratnle ( g/1)
H
AM,DM
AQ,DS
S
0
s
AS,DS
S
AS,OS
Bariua ( g/1)
H
AM, DM
AQ,DS
O
s
AS,DS
s
AS,DS
Berylliu ( g/1)
M
AM, DM
AQ,OS
0
s
AS,DS
s
AS, DS
BicirboMtt (ag/1)
N
AM,DM
AQ.OS
8
0
s
AS, DS
s
AS,OS
Dimuth ( g/1)
M
AM, DM
AQ,DS
0
8
AS,DS
s
AS,OS
BOD (ag/X)
M
AM,OM
AQ,DS
0
8
AS, DS
s
AS,DS
Boron | g/1)
M
AM,DM
AQ,DS
s
O
8
AS,DS
s
AS,OS
Broadda (ag/1)
M
AM,DM
AQ,DS
0
S
AS,OS
s
AS,OS
Cadaina ( g/1)
N
AM, DM
AQ,OS
6
O
8
AS,DS
s
AS,06
Calclw (ag/1)
M
AM, DM
AQ,OS
S
O
QS
AQS,DS
QS
AQS.DS
Carbonat* (ag/1)
N
AM,DM
AQ,OS
8
0
08
AQS,DS
QS
AQS,DS
Chloride (ag/1)
N
AM,DM
AQ,OS
S
0
QS
AQS,DS
QS
AQS,0S
Chvoalua ( g/1)
M
AM, DM
AQ,06
s
0
s
as;ds
S
AS,DS
COO (ag/1)
N
AM,DM
AQ,OS
0
8
AS,DS
S
AS,DS
Coliforij ftcil (Col/100 ml)
M
AM,DM
AQ,OS
0
8
AS,OS
S
AS,DS
Collfora, total (col/100 al)
N
AM,DM
AQ,OS
0
S
AS,DS
s
AS,DS
Color (VCIl)
N
AM, DM
AQ,DS
0
S
AS,DS
s
AS,DS
Conductivity, Spec. ( shot)
CM
AM,DM
AQ,DS
CS
AS
CS
AS,DCS
CS
AS,DCS
Copper | g/1)
N
AM, DM
AQ,OS
s
0
s
AS,DS
s
AS, OS
Cyanide (ag/1)
M
AM,DM
AQ,D8
0
s
AS,OS
8
AS,DS
Oiaeolved oiygta (ag/1)
N
AM, DM
AQ,OS
8
0
8
AS,OS
s
AS,OS
fluorlda (a»g/l)
N
AM,DM
AQ, DS
8
0
QS
AQS,OS
QS
AQ8,US
Galliua ( g/1)
N
AM,DM
AQ,D8
0
S
AQS,DS
s
AS,DS
CenuiiiB ( g/1)
M
AM,DM
AQ,DS
0
8
AS,DS
s
AS,OS
Kardneaa (Ca, Mg) (ag/1)
N
AM, DM
AQ,OS
0
8
AS,DS
8
AS,OS
Iron ( g/1)
M
AM, DM
AQ.D8
0
8
AS,OS
8
AS,0S
Kjeldahl nitrogen (ag/1)
N
AM,DM
AQ,OS
0
8
AS,OS
8
AS,DS
Laad ( g/1)
N
AM,DM
AQ,DS
8
0
S
AS,DS
8
AS,OS
Lithiua ( g/1)
M
AM,DM
AQ,DS
0
S
AS,DS
s
AS,DS
Kagnaaiua (ag/1)
M
AM,DM
AQ,OS
8
0
QS
AQS,DS
QS
AQS,06
Manganeae ( g/1)
M
AM,DM
AC# OS
0
S
AS,DS
s
AS,DS
NBAS (ag/1)
N
AM,DM
AQ,DS
0
s
AS,DS
s
AS,DS
Mercury ( g/l)
M
AM, DM
AQ,DS
8
0
s
AS, DS
s
AS,DS
Molybdenua < g/1)
M
AM, DM
AQ,DS
0
s
AS,DS
s
AS,0S
Nickel ( g/1)
N
AM,DM
AQ,DS
0
8
AS,DS
s
AS, DS
Nitrate (N03) (ag/1)
N
AM,DM
AQ,OS
8
0
8
AS,DS
s
AS, DS
Nitrite (NO Hag/1)
N
AM, DM
AQ,OS
8
0
8
AS,OS
s
AS,DS
Mltrlte plue nitrate (M)(ag/1)
M
AM,DM
AQ,D6
0
8
AS,DS
8
AS, 06
aA ¦ Alluvial a quifar
D - Deep and shallow
Oil Shale Aquifer
C ¦ Continuously
S - Baal annually
Q ¦ Quarterly
N « Monthly
O - No aanpling
(continued)
-------
TABU C-7. (continued)
B»wUm progran Inter lji prograa Modular development phase Co—erclal development phase (proposed)
Groundwater
Far Meter
Surface'
enter
First
year
Second
year
Surface
water
Groundwater
Surface
water
Groundwater
Surface
water
Groundwater
Nitrogen, Monli. (ag/1)
M
AM,DM
AQ,DS
0
s
AS, DS
S
AS,06
Nitrogen, Organic (m)/1)
M
AM, DM
AQ,DS
0
s
AS,DS
S
AS,DS
Odor (severity)
M
AM,DM
AO,OS
0
s
AS,DS
s
AS,DS
Oil ft grease (ag/1)
H
AM, DM
AQ,DS
0
s
AS, DS
s
AS,DS
Organic tirbon (ag/1)
H
AM, DM
AQ,DS
0
s
AS,DS
s
AS,DS
Dissolved
.M
AM,DM
AQ,DS
8
o
s
AS,DS
s
AS,DS
Suspended
M
AM, DM
AQ,D8
o
s
AS,DS
s
AS,DS
total
H
AM, DM
AQ,Dfl
0
s
AS, DS
s
AS,DS
Pesticides iw/l)
N
AM,DM
AQ,DS
0
s
AS,DS
s
AS.DS
PH
CM
AM, DM
AQ.DS
CS
0
CS
AS,DCS
CS
AS,DCS
Phenols (119/I)
H
AH,DM
AQ,DS
0
S
AS,DS
s
AS,OS
Phosphate (iq/1)
M
AM,DM
AQ,DS
o
s
AS,DS
s
AS.DS
Dissolved (PO.)
N
AM, DM
AQ,0S
0
s
AS,DS
s
AS.DS
Ortho (P)
M
AM,DM
AQ,DS
o
s
AS,DS
s
AS,DS
Total (P)
N
AM, DM
AQ.OS
S
0
s
AS,DS
s
AS.DS
Potassiusi (mj/1)
H
AM,DM
AQ,OS
s
o .
OS
AQS,DS
OS
AQS,DS
Radioactivity
M
AM, DM
AQ,DS
0
8
AS,DS
s
AS.DS
Gross alpha Cpc/1)
N
AM,DM
AQ,DS
o
s
AS,DS
s
AS,DS
Radios 236 fpc/1)
M
AM,DM
AQ,DS
0
8
AS.DS
G
AS, DS
Natural uranltsi (pg/1)
M
AM,DM
AQ,DS
0
s
AS,D6
s
AS,D6
Gross Beta (pc/1)
M
AM, DM
AQ.DS
0
6
AS,DS
s
AS,D8
Strontiisi 90 (pc/1)
M
AM, DM
AQ,DS
0
6
AS,DS
s
AS,DS
Ceaius 137 (pc/1)
M
AM, DM
AQ,DS
0
S
AS,DS
s
AS,DS
Selenim (pg/1)
M
AM,DM
AQ,DS
5
0
S
AS.DS
s
AS,DS
Silica (SiO2)0sg/l>
N
AM,DM
AQ,DS
o
s
AS ,DS
s
AS,DS
silver (pg/1)
H
AM, DM
AQ,DS
0
s
AS,DS
s
AS, DS
Sodiua («3/l)
K
AM,DM
AQ,DS
S
o
QS
AQS,DS
OS
AQS,D6
Soditai adsorption Ratio
M
AM, DM
AQ,DS
0
s
AS,DS
s
A5,D6
Solids, dissolved («gA)
M
AM,DM
AQ,DS
S
0
B
AS,DS
s
AS,DS
Strontiua (ug/l)
M
AM, DM
AQ,DS
0
s
AS,DS
s
AS,DS
Sulfate (ag/1)
H
AM, DM
AQ,06
S
0
QS
AQS,DS
OS
AQS, DS
Sulfide (vg/1)
H
AM, DM
AQ,DS
0
s
AS,DS
s
AS,06
Teaperature (*C)
CM
AM,DM
AQ,DS
CS
AS
CS
AS,DCS
CS
AS,DCS
Tin (pg/1)
M
AM, DM
AQ,DS
0
s
AS, DS
s
AS,DS
Titaniua (pg/l)
N
AM,DM
A0,D6
o
s
AS,DS
s
AS,OS
Turbidity (JTU)
H
AM,DM
AQ,DS
0
s
AS,DS
s
AS,DS
Vanadiun (i*g/l)
M
AM,DM
AQ,DS
0
s
AS,DS
s
AS.DS
Zinc (119/I)
N
AM,DM
AQ,DS
0
s
AS,DS
s
AS,DS
zlroonliai (iig/l)
M
AM, DM
AQ,D6
0
s
AS,DS
s
AS,DS
A - Alluvial aquifer C - Contlnuoualy N - Monthly
0 - Deep and shallow s . Semiannually 0 - Mo aaapltng
Oil Shale Aquifer Q - Quarterly
-------
necessary. The results of wet chemical analyses of monitoring program samples
were subjected to several quality assurance techniques. The balance between anion
and cation totals was checked and found to be within 10 percent for most samples.
For those samples where this 10 percent tolerance level was exceeded, the lab
reports and lab workbooks were checked to assure that the difference was not result
of a clerical error. As an additional check on the accuracy of the analyses, a
comparison was made between calculated (sum of constituents) dissolved solids and
residue on evaporation of filtered samples. The ratio of TDS to conductance was
also examined, since specific conductance was measured in the field. To avoid the
introduction of variance resulting from the sampling method, only those samples
collected from the monitoring holes by bailing were used for population estimates.
This was done because there is a high probability that many initial samples
collected during the drilling and aquifer testing do not represent natural water
quality in the aquifer.
Groundwater—Fifteen holes were dug in alluvium around Tract C-a, of which
eight encountered water. Those wells were: G-S S7, G-S S8, G-S SI 1, G-S S12,
G-S SI9, G-S S22, G-S S23, and G-S S24. Continuous water level recorders were
installed at four of the wells (S7, S8, SI 1, S12). Water quality samples were taken
at all four sites during the monitoring program by bailing methods. The water
quality parameters measured are listed in Table C-7. The samples were taken
monthly during the first year. This frequency was decreased during the second year
to quarterly sampling, except in the flash flood season when monthly sampling was
necessary. The sampling schedule is summarized in Table C-7.
Twenty-five (upper and lower aquifer) water monitoring holes were drilled
to levels between the stratigraphic limit above the Mahogany Zone to the top of
the R-5 Zone. This has been noted as the Upper Aquifer Zone. The locations of
these holes are shown in Figure C-5. Water level changes in the upper aquifer were
determined using hydrographs, curve fittings, and residual analysis. Water quality
analysis procedures were the same for upper aquifer testing as for alluvial aquifer
testing. Water quality sampling began in July 1974 with core and drill sampling
and continued on a monthly basis for 6 months. After 6 months, the sampling
frequency was changed to once every 6 months (see Table C-7). The water quality
parameters being measured were the same as for alluvium (see Table C-7).
The deep aquifer water monitoring program began in December 1974. Water
samples were collected, and water levels were recorded monthly at 22 lower aquifer
wells (22 dual upper and lower and 5 lower). Water samples were collected
quarterly from March to August 1975 and semiannually thereafter. A listing of all
the wells, upper and lower aquifer, is presented in Table C-8. The well locations
are plotted in Figure C-5.
In addition to water quantity and quality measurements made on groundwater
resources of the Tract C-a area, an analysis was performed to determine aquifer
interrelationships including groundwater flow direction and storage capabilities.
Interim Monitoring Program—
The interim monitoring program was conducted during the lease suspension
period from September 1976 to September 1977. The sources of information
relating to the interim monitoring procedures were References 3, 4, and 5.
C-19
-------
TABLE C-8. DRILL HOLE COMPLETION SUMMARY FOR TRACT C-a and VICINITY
Drill hole
Comoletion
5 on-tract holes:
G-S 1
Upper and lower aquifers
G-S 2-3
Upper and lower aquifers
G-S 4-5
Upper and lower aquifers
G-S 6
Upper and lower aquifers
G-S 7
Plugged and abandoned
G-S 8
Lower aquifer only
G-S 9
Upper and lower aquifers
G-S 10
Upper and lower aquifers
G-S 11
Upper and lower aquifers
G-S 12
Upper and lower aquifers
G-S 13
Upper and lower aquifers
G-S 14
Upper and lower aquifers
G-S 15
Upper and lower aquifers
Am 4
Plugged and abandoned
CE-701
Upper aquifer pumping test
CE-702
Upper and lower aquifers
CE-703
Plugged and abandoned
CE-705-A
Upper aquifer pumping test
CE-707
Upper and lower aquifers
CE-708
Upper and lower aquifers
CE-709
Upper and lower aquifers
TO 1
Upper and lower aquifers
TO 2
Upper and lower aquifers
TO 3
Upper aquifer pumping test
G-S D16
Lower aquifer pumping test
G-S D17
Lower aquifer pumping test
G-S D18
Lower aquifer pumping test
G-S D19
Lower aquifer pumping test
off-tract holes:
G-S Ml
Upper and lower aquifers
G-S M2
Upper and lower aquifers
G-S M3
Upper and lower aquifers
G-S H4
Upper and lower aquifers
G-S M5
Aquifers, Uinta formation
>talsi
22
Upper and lower aquifers
3
Upper aquifer only
5
Lower aquifer only
1
Uinta formation aquifers
4
Plugged and abandoned
35
Total number of holes
*Holes temporarily modified for upper aquifer pumping test.
C-20
-------
0
1
to
Et
8 3 9 W
wc*
I
/
JII
CC 701
oirAro i
cc ten
C-I lla
LEGEND
£ j6 * n 8-S It
r •*»»* «
Miles
O Shallow Monitoring Holes
Deep Monitoring Holes
Figure C-5. Location map for Tract C-a shallow and deep groundwater test wells.
-------
Surface water—Eleven surface-water gaging stations were left operational
during the first half of the interim monitoring program. Figure C-6 illustrates the
locations of these sites, and they are identified in Table C-6.
The program called for the continuous monitoring of temperature,
conductivity, flow, and sediment load. The parameters listed in Table C-7 were
measured semiannually at the same 11 sites. Analytical methods followed the same
format employed during the baseline program. During the second half of interim
monitoring, only two gaging stations were monitored, Corral Gulch and Yellow
Creek. A summary of the interim water quality monitoring sampling schedule is
presented in Table C-7.
Groundwater—Water quality and quantity were measured at eight
water-bearing alluvial aquifers during the interim program. The locations of these
monitoring sites are shown in Figure C-6. Temperature, specific conductance, and
static water level were recorded at all eight alluvial wells on a semiannual basis. In
addition, water level was recorded continuously at one site (G-S SI 1) by a Stevens
type F Model 68 recorder.
In the event that conductivity and/or temperature is less than 88 percent of
the minimum value or more than 120 percent of the maximum value recorded for
that alluvial well during the same season in the baseline period, a sample is taken
and analyzed for the baseline parameters in Table C-7.
Static water levels were recorded on a semiannual basis at most wells, the
exceptions being G-S 4 and 5. Both the upper and lower aquifer levels were
monitored at these holes on a continuous basis by onsite recorders. The deep aquifer
water level was measured by electronic recorders that were calibrated and serviced
monthly. The locations of these holes are shown in Figure C-5. Water quality
measurements on deep aquifer monitoring sites were discontinued after the baseline
study.
Modular Development Phase Monitoring—
The modular development phase environmental studies commenced in
September of 1977 and was to run for approximately 2J4 years before a new scope of
work was to be developed for implementation in Years 3, k, and 5 of the program.
The following is a discussion of the modular development phase water resources
monitoring program for years 1 through 5. The program is dynamic and is
consequently subject to change at any time. Published information on the study
includes References 6-10.
Surface water—Surface water quality and quantity are measured at six surface
water-gaging stations throughout the Tract C-a area (Station 09306230, Stake
Springs Draw is deleted). These six stations are located in the areas shown in Figure
C-7. Conductivity, temperature, and flow were monitored on a continuous basis,
and the major ions (Ca, Mg, SOi,, CI, K, HCOa, CO3, and Na), fluoride, silica, pH,
and alkalinity were measured quarterly during the first half of modular development
phase monitoring. The complete set of baseline parameters was also monitored
every 6 months. A summary of the parameters being measured and the sampling
schedule for each monitoring site is presented in Table C-9. A more detailed
sampling schedule summary for modular development phase sampling at each site is
presented in Table C-7. Chemical and physical parameters undergo correlation. If
C-22
-------
R 100 W
R 97 W
R 98 W
R 99 W
1SJ4.SI
tr.tui
C»ttm
/ TRACT C
- -N* ,
^7X /
~"
Miles
Surface-Water-Gaging- Station
O Storage^Type Rain Gage
9 Recording-Type Rain Gage
• Alluvial Aquifer Test Wells
£ NUS Sample Sites
| NUS Multiple Sample Sites
Figure C-6. location map for Tract C-a interim surface-water-
gaging and alluvial test wells.
C-23
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0
1
S3
nVVfl
*• /
S* mouth
YtHow
OVCK
j-S M4
G-S Ml
ORY FORK
<£s S6
L
S S14
S-250
Water-Bearing Alluvium
— Dry Alluvium
A Stream Gages
O Alluvial Holes
¦ Dual Monitoring Holes
©
Figure C-7. Locations of monitoring stations for hydrology
studies during the modular development phase.
-------
TABLE C-9.
SUMMARY OF HYDROLOGY MONITORING PROGRAM FOR THE
MODULAR DEVELOPMENT PHASE PROGRAM AT TRACT C-a
Typ'
e of water
Continuously or
automatically
Sampling frequency
Quarterly
Semi-
annually
Periodically
Surface water:
Stream-gaging stations:
Sediment (periodically)
Conduct!vi ty
Temperature
Flow
Limited water quality
Baseline water quality
{<6)
(6)
(6)
(6)
.(6)
,(6)
Springs and seeps:
Flow
Conductivity
Temperature
pH
(6)
(6)
<6>
(6)
-Groundwater:
Alluvial holes:
Hater levels
Limited water quality
Baseline water quality
Dual aquifer monitoring holesi
Hater levels
.(3)
,(8>
5(S)
(8)
,(8)
Dewatering Wells:
Flow
Sediment
P«C
Temperature
Conductivity0
Hater level alarm
(12)
(12)
Reinjection Wellsi
Hater level alarm
Baseline water quality
,(12)
*When water is present.
b() Indicates the number of sampling sites.
CComposite sample before reinjeetion.
Note: Samples will be retained 30 days following submission of year-end report.
C-25
-------
the continuously recorded parameters exceed the 1-percentile value for the
cumulative frequency distribution of baseline for more than 3 days, the water is
sampled and analyzed for the quarterly measured parameters in order to determine
the aquifer source from which the anomaly originated. If the cause of the problem
is determined to be due to some other occurrence, the complete set of baseline
parameters will be measured.
Monitoring is carried out on six springs and/or seeps around the Tract C-a
area. The locations of these monitoring sites is plotted on the map in Figure C-8.
Flow, conductivity, temperature, and pH are measured quarterly at all six stations.
Flow is measured by using a weir or flume. The data are recorded on 800 bpi
magnetic tapes and analyzed to determine seasonal trends and the possible influence
of dewatering/reirijection programs. The sampling schedule is illustrated in Table
C-9.
Groundwater—Alluvial aquifers are monitored at eight locations around the
Tract C-a area (Figure C-7). Water levels are measured continuously at three
alluvial monitoring holes (G-S 57, G-S S26, G-S S27). The parameters measured
quarterly are: water level, alkalinity, temperature, pH, conductivity, sodium, silica,
fluoride, and the major ions (Ca, Mg, SOi,, CI, K, HCO3). The sampling schedule is
illustrated in Table C-9. Two of the alluvial monitoring holes are new and are
located in positions downstream of project development areas (mine shaft retention
pond, surface disturbances). This allows for water quality deterioration
determinations. The relationship between chemical and physical parameters will be
subjected to correlation analyses.
During the second half of MDP monitoring (Years 3, k, and 5) the alluvial wells
monitoring program will be restructured to provide for monitoring of the parameters
listed in Table C-7. The parameters will be measured at the following alluvial wells.
Continuously;
G-S S7, G-S S11, G-S S26, G-S S27
Quarterly:
G-S S6, G-S S8, G-S S13, G-S S14, G-S S25
Quarterly and Semi-Annual:
G-S S6, G-S S7, G-S S8, G-S Sll, G-S S13, G-S S14, G-S S25, G-S
S26, G-S S27
Deep groundwater levels are measured at six locations around Tract C-a. The
locations of these six well holes are illustrated in Figure C-5. Deep groundwater
quality measurements will be taken from dewatering well and mine discharges. Both
the groundwater level and quality measurements will be made continuously. The
quality parameters of the mine drainage to be measured continuously are: sediment,
pH, conductivity and temperature. A composite dewatering well discharge will be
measured semiannually for the baseline parameters listed in Table C-7. Flow
meters will be utilized to determine dewatering rates. All chemical and physical
parameters will undergo correlation.
C-26
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• -Stfvx jr./* (?'%¦ -;%>%ha3CSsgr^3^>&^ r}-t MT1 <^K } /*s
mfezwtifrfv,
lef?;">; feA^'S^ ( (/\l$i5/ w" \/j v> . -' Vvij
Wm\/( j^#<
• vv- •'; '^;i Jo:•!!^ 1 3 -/®fe'? /i^^A / iu:' w-/Vi r* i . 5*
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•""™fe^fcr lllWM'I'
r4mm^
LEGEND
A Springs and Seeps To
Be Monitored During
the Modular Development
Phase Program
Figure C-8. Location map for major Tract C-a spring and seep sampling stations.
-------
At the conclusion of year 2 of the modular development phase, the deep
groundwater monitoring program was conducted according to the schedule in Table
C-9, and the following listing.
Continuously:
Upper Aquifer Holes Am3, G-S Ml, G-S M2, G-S M3, G-S M4, G-S
M15 Upper, G-S SI5 Lower
Annually (July):
All water quality parameters listed in Table 8 will be measured at:
Am-3, G-S Ml, G-S M2, G-S M3, G-S M4, G-S 15 Upper and G-S 15
Lower
During modular development phase retort operations, water that is reinjected
into the aquifers will be monitored to detect any parameters that exist in excess of
the limitations set by the Subsurface Disposal Permit. To accomplish this task, five
surface-water gaging stations, eight alluvial aquifer monitoring holes, 12 upper
aquifer holes, one lower aquifer monitoring hole and the composite reinjection water
will be monitored according to the schedule in Table C-9. The monitoring locations
are illustrated in Figure C-7. NPDES permit and modular development phase pump
test monitoring are also being conducted.
Proposed Commercial Development Phase Monitoring Program—
The commercial development phase monitoring program will begin just before
commencement of commercial construction operations in 1982. Details of the
proposed monitoring program are presented in the RBOSP Revised DPP (11).
Surface water—Surface water monitoring would be accomplished with the
same stream monitoring stations used during the modular development monitoring
programs. Their locations are shown on the map in Figure C-9. Conductivity,
temperature, and flow may be monitored continuously, and sediment discharge will
be monitored automatically. Water quality will be monitored on a limited basis
(quarterly), and on a baseline parameter basis (semiannually). The water quality
parameters should be those illustrated in Table C-7. A summary of the commercial
development phase hydrology monitoring schedule is provided in Table C-10.
Flow may be measured at six major springs and/or seeps in the Tract C-a area.
The proposed locations of these gaging stations are illustrated in Figure C-9. Water
flow will be measured by means of a weir or flume. Conductivity may also be
measured at these points. The sampling will be done on a periodic basis. A
summary of the entire proposed hydrology monitoring program is presented in Table
C-7.
Groundwater—Alluvial aquifer water level and quality may be monitored at
the same seven locations that were employed during the modular development
programs. In addition to those, two alluvial holes are intended to be added
downstream of the proposed retention ponds for the surface processing and mine
shaft areas. The proposed locations of these monitoring holes are illustrated in
Figure C-9. Continuous water level recorders may be installed in the two new holes
and in G-S S14. Water quality samples will be analyzed quarterly for conductivity,
C-28
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LEGEND
0 5 10
1 I I
Miles
0 Upper & Lower Aquifer Observation Well & Number
O Upper Aquifer Observation Well & Number
V Precipitation Gage & Number
¦ Surface Stream Gage & Number
Figure C-9. Location map for Tract C-a proposed commercial
development phase groundwater test wells.
C-29
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TABLE C-10. SUMMARY OF HYDROLOGY MONITORING PROGRAM FOR THE COMMERCIAL DEVELOPMENT PHASE
PROGRAM AT TRACT C-a
Sampling frequency0
Type of water
Continuously or
automatically
Quarterly
Semi-
Annually
Periodically
Surface water:
7 Stream-gaging stations
Sediment
Conductivity
Temperature
Flow
Limited water quality
Baseline water quality
6 Springs and seeps
Flow
Conductivity
Groundwater:
10 Alluvial holes
Water levels
Limited water quality
Baseline water quality
11 Dual aquifer monitoring holes
Water levels
14 USGS monitoring holes
Water level
Dewatering wells
Flow
Conductivity
Pumping water level
Baseline water quality
X
X
X
X
X
X
X
(8)
,(1D
X
X
X
X
X
(10)
X
X
Samples will be retained 30 days following submission of year-end report.
( ) Indicates the number of sampling sites.
-------
temperature, and the major ions. The baseline constituents will be measured
semiannually (see Table C-7).
Deep oil shale aquifers are intended to be monitored at 11 RBOSP monitoring
holes and 11 USGS observation holes. The dual aquifer monitoring hole being
utilized during modular development monitoring will also be used on occasion. The
locations of these holes are illustrated in Figure C-9. New monitoring holes would
also be established before the elimination of C 702, G-S 6, and G-S 10 by mining.
Measuring devices will be used to measure pumping water levels in each
dewatering well. Flow meters will also be installed to determine dewatering rates.
Dewatering well and mine drainage discharges are intended to be monitored
continuously for conductivity and temperature before reinjection. Initially, the
baseline parameters will be analyzed on a monthly basis until a trend or stabilization
of conditions is observed. Thereafter, baseline parameters will be monitored
semiannually or when significant changes are observed in the conductivity values.
Biological Resources
Baseline Monitoring Program-
Information for this report was taken from two published documents—the
RBOSP Final Environmental Baseline Report (1) and the RBOSP Environmental
Baseline Data Accumulation Program (2). The baseline biological resource
monitoring program was conducted from 1974 to 1976. The purpose of this program
was to establish a data base on the abundance and diversity of vegetation,
terrestrial vertebrates and invertebrates, and aquatic biota. The main
environmental contractors on the project were NUS Corporation and Ecological
Consultants, Inc.
Vegetation—Major vegetation types on Tract C-a were identified by aerial
survey. In addition, vegetation sampling sites were selected for field verification.
Each vegetation type was surveyed, and the most prevalent variants (such as pinyon-
juniper with a sagebrush understory) were identified. The largest block of
homogenous vegetation was selected for sampling. Sixty-two 106- x 6-m (348- x
20-ft) transects were established for sampling around Tract C-a, of which 35 were
retained for sampling of herbaceous layers during later sampling periods. The
sampling program was carried out during May, July, and September for the years
1975 and 1976.
Phytosociological data pertaining to the tree, shrub, and herbaceous strata
were gathered and recorded from each transect. The phenologic condition of major
plant species was recorded.
Plant specimens that were collected were identified according to plant
species, date, location, habitat, elevation, and taxonomy. The plants were also
preserved by pressing.
Range Studies—Field sampling was conducted to determine range, soil
condition, and trend on the Tract C-a area. Dominant vegetation was verified by
groundchecks. At the same time, plant composition, density, vigor, and soU
condition trend were determined by direct observation.
C-31
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Range utilization was also determined during the baseline biological resource
program. Vegetation protection cages were distributed in pinyon-juniper, sagebrush,
mixed brush, and grass vegetation types to supply protection to plants during the
growing season. At the end of the growing season, these carefully positioned cages
were removed, and the vegetative material inside was clipped, weighed, and
compared to other vegetation plots that were similar in composition and position but
that had been subjected to browsing and grazing.
Browse condition and utilization studies were conducted on a minimum of 100
sampling locations predetermined to support a preponderence of key species of
particular interest. The analysis program was adapted from National Park Service
methodologies (12).
A grazing exclosure was established on Tract C-a to monitor vegetation
responses to exclusion of particular groups of grazing or browsing herbivores. An
exclosure was constructed on the southwest quarter of Tract C-a. The structure
contained three compartments, each designed to exclude particular groups of
herbivores. Observation of the incremental forage production resulting from the
protection being afforded made it possible to determine the relative importance of
individual plant species to wildlife and to domestic and feral livestock and
consequently allowed for definition of priorities for reestablishing plant species
after disturbance.
Photoplots and remote sensing were used to monitor vegetation-type boundary
changes.
Terrestrial Vertebrates and Invertebrates—Small mammals were collected for
species identification, dominant habitat densities, and important species
designation. The animals were collected by means of live and pitfall trapping
systems. Trapping grids were designed to aid in determining population densities
and ranges of the various animals. Small mammals were collected for identification
of species, growth, abundance, etc., and were examined in the laboratory for
stomach contents and reproductive efforts. In addition to trapping, small animals
were monitored by night spotlight census. Bat investigations were also carried out
during the summer months.
Aerial surveys for larger mammals were conducted along standardized
transects during the months of October to April and June to September. The
purpose of the survey was to estimate the distribution and abundance of mule deer,
elk, and feral horses. Pellet groups were also analyzed to determine even more
precisely the distribution, abundance and relative use of the area to mule deer. In
addition, predators were monitored by use of scent-station visitation techniques,
coyote siren census, live traps, aerial surveys, general observation, and winter track
counts.
General avifauna were surveyed using the Emlen strip census procedure
wherein an observer walks a line, records observations and locates observed avifauna
in relation to the strip line. Upland gamebirds were censused using a vehicle to
flush the birds in the early morning hours during the height of breeding season.
Waterfowl were observed by monitoring the local ponds. Raptors were surveyed by
use of aerial and ground surveys.
C-32
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Reptiles and amphibians were observed by use of the line transect method and
direct visits to breeding sites.
Terrestrial invertebrates were sampled using an assortment of trapping
techniques, ranging anywhere from pitfalls to vacuums. Major taxa were identified
and counted in the laboratory.
Domestic livestock were surveyed by means of aerial survey and utilization of
existing information from the Bureau of Land Management. The possible presence
of threatened and endangered species was investigated.
Aquatic Ecology—The aquatic biota baseline program covered the areas of
physical and chemical water quality, plankton, periphyton, benthos, fish, and rare
and endangered species. A total of 35 sampling stations was established for the
sampling program. Samples were collected 12 times over the period of 2 years
during the months of April, June, 3uly, August, September, October, November, and
December.
Phytoplankton was collected in a pump-type or bottle-type sampler
concurrently with chemical samples. The samples were put in opaque bottles and
preserved with Lugol's preservative until processed. Zooplankton samples (100 1 or
26.5 gal or more) were pumped from a sampler into a carboy and filtered through a
Wisconsin net (//25 mesh) and preserved in 5-percent neutralized formalin for
laboratory analysis. Periphyton was collected by scraping selected substrates, and
laboratory analysis was carried out for biomass, cell number, and chlorophyll
determination. Periphyton samples were generally collected from natural
substrates, but when this was not possible, artificial substrates were employed
(styrofoam or glass). Benthic organisms were collected with either the modified
Surber sampler, an Ekman grab, or a D-frame sampler. They were washed in a
bucket fitted with a #30 sieve and preserved in neutralized 10-percent formalin.
Standard methods of sample processing were used in the laboratory. Macrophytes
were sampled using a random transect line system as outlined by Jessen and Lound
(13). Fish were collected by electro fishing and/or seining. The fish were identified,
and their reproductive efforts qualified. Efforts were made to determine the
absences or presence of rare and endangered fish in the Tract C-a area.
A statistical analyses was performed on all gathered data.
Interim Monitoring Program—
The interim biological resource monitoring program was conducted for one
year, from 1976 to 1977. The main purpose of the program was to keep current the
data base that had been created during the baseline program. The sources of
information on this program used here were References 3, 4, and 5.
Range Studies—Thirty sampling sites were established in areas of varying
vegetation type (10 pinyon-juniper, 15 sagebrush, and five mixed brush) on Tract C-a
and the 84 Mesa Study area to study range productivity and utilization
(Figure C-10.)Two protected plots (0.9 m2 each or 9.5 ft2) and eight unprotected
plots (permanently marked) were established at each sampling site. Range
productivity and utilization were obtained by using the double sampling method. A
visual estimate was made of production (weight to the nearest gram) of grass and
forb species within the loop. Each species within the protected plots was dipped,
C—33
-------
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t
CO
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¦ -K^L TRACT C-a ivi
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-------
bagged separately, and weighed green. The weights were recorded. Species
providing less than 1-percent of the biomass were recorded as present but were not
weighed. Correction factors were calculated from the estimated green weights and
actual green weights of the clipped plots.
Correction factor = Actual Bree" weight
Estimated green weight
This correction factor was used to correct all estimated values. Clipped
samples were air-dried for approximately 30 days and weighed to obtain moisture
percentages. Air-dry forage productivity estimates were then computed from the
moisture percentages and corrected estimates.
Percent utilization was calculated as follows:
Average Productivity Average Productivity
% per ungrazed plot X per grazed plot
Utilization
Average productivity
per ungrazed plot
Field measurements were made at the end of the growing season in August
1977.
Browse condition and utilization studies were conducted on the same sampling
sites as for the range production and utilization study. Browse plots were
established within these site areas and examined before and after 1 year of use to
measure utilization by deer and domestic cattle. At each sampling site, 25
individual key browse plants were examined. Sampling sites were established by
arbitrarily selecting a shrub and permanently marking it. Subsequent shrubs were
located along a transect by selecting the closest shrub within a 180° area oriented
E-W of the center of the selected shrub.
During field sampling, five parameters were examined and recorded. They
were: form classes, age classes, leader use estimates, hedging classification, and
availability.
Terrestrial Vertebrates—Transects were established in the sagebrush, mixed
brush, and pinyon-juniper areas in and around Tract C-a to study mule deer
abundance and density. The approximate locations of these transects are illustrated
in Figure C-10. Each transect included 25 circular plots of 1.13-m (3.71 -ft) radius
nr or 43 ft2) each. Sample points were established every 20 m (65.6 ft) along the
transect, and a search was made up to 6 m (19.6 ft) around each point to locate the
center of the nearest pellet group. If a pellet group was not found, the transect
point was considered the plot center. Slope, aspect, and phytosocioiogy of the area
were noted for each plot location. All transect points and all plots were marked
with 1-cm x 25-cm (.4-in. x 9.8-in.) steel rebar stakes. The transect points were
marked with waterproof ink on durable tags according to vegetation type (S for
sagebrush, MB for mixed brush, and PJ for pinyon-juniper) and sequentially
numbered from 1 to 25 in each vegetation type. The identification tags were
attached to the stake on the side toward the pellet group plot to facilitate future
plot location. All transect points were marked with fluorescent pink flags. Pellet
C—35
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groups were sprayed with orange enamel paint, and a similarly painted rock was
placed in each group. The pellet plots were inspected in May and August 1977. New
pellet groups and status of old groups were recorded. After each data collection
period, estimates of deer density in each vegetation type were calculated on the
basis of pellet group counts. Density data were compared with the browse
utilization data and with the mule deer pellet group and aerial survey data from the
baseline studies.
To study the number of small mammals in the Tract C-a area, 40 trapping
stations were set up along two parallel lines, and each trapping station was equipped
with three Sherman live traps. The locations of these faunal sampling sites are
illustrated in Figure C-10. The mammals were trapped once in the late spring of
1977. All traps were prebaited at least 24 hr prior to the initiation of trapping. All
traps were set and checked in the morning and evening. Trapping was conducted for
three consecutive 24-hr periods. If on the third day, captures of new individuals of
predominant species equaled or exceeded 50 percent of total captures for that day,
the scope of work was amended with RBOSP approval to extend trapping until the
number of new captures fell below 50 percent of total captures for each additional
day (not to exceed 3 additional days of trapping). All animals captured were marked
(if previously unmarked) with a unique toe clip combination and released. Data
recorded for each individual animal captured included species, sex, toe clip number,
reproductive status, and trap location. Three sets of trap lines were established
during interim monitoring, one in each of the three major vegetation types (i.e.,
sagebrush, pinyon-juniper and mixed brush) on Tract C-a.
A 12-ha (30 acre) study plot was created in each vegetation type near the mule
deer transects to study the avifaunal characteristics of the Tract C-a area. The
study plot was divided into 1-ha (2.5 acre) units.
Each corner of the 1-ha (2.5 acre) units was marked for easy mapping, and the
area was surveyed by a qualified observer. Data such as species encountered,
location, nest location, nest contents, reproductive status of avifauna, wind speed,
precipitation, and cloud cover were recorded. The results were intended to help
determine the species density, territory sizes, and reproduction efforts of avifauna
in the area.
Ground surveys on foot and vehicle were conducted during the sandhill crane
migration period for the purpose of establishing use of the area by this species which
when nesting in Colorado, is on the Colorado endangered species list. Observations
as to weather conditions, behavioral patterns, etc. were noted and reported to
RBOSP, Colorado Department of Wild Life, and the U.S. Fish and Wildlife Service as
soon as was practical. Areas surveyed included Tract C-a, 84 Mesa, State Springs
Pond, State Springs Draw, and Yellow and Duck Creeks.
Aquatic Ecology—During baseline studies it was determined that, because of
the low abundance and species composition of phytoplankton, zooplankton, and
macrophytes, these groups are of limited significance in the local aquatic
ecosystems. Periphytic algae and benthic macroinvertebrates were determined to
be important to the local aquatic ecosystems, and hence the monitoring of these
communities was continued in the interim program.
C-36
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Periphyton samples were collected from suitable spots located in three water
channels (White River, Yellow Creek, and Corral Gulch) during the interim
monitoring program. Samples were collected once in the spring and once in the fall
and coordinated with water quality sample collections when possible. Samples were
collected in duplicate fronri flat rock surfaces (50 cm2 or 7.8 in.2) with a knife and
toothbrush and preserved for laboratory analysis. The analysis consisted of cell
density, species composition, and relative abundance. The results were then
compared to appropriate data from the baseline program. The preserved periphyton
samples were diluted to a constant volume, and an aliquot was removed,
centrifuged, and washed with distilled water. The samples were then dehydrated
and stained in the centrifuge, using successive spinnings and decantings. The
following (stain, steps, and alcohol) were used for the periphyton preparation:
a. Water rinse
b. Acid fuchsin stain (aqueous)
c. Water rinse
d. 50 percent isopropanol
e. 90 percent isopropanol
f. 100 percent isopropanol
g. 100 percent isopropanol
h. xylene rinse
i. xylene rinse
A number of drops of the final xylene-periphyton suspension were placed on a
microscope slide with Hyrax, heated gently, and covered with an ultra-thin cover-
glass. The final mounts were retained in the permanent voucher collection.
Periphyton were counted from one randomly chosen transect at a magnification of
lOOOx (oil immersion). All organisms appearing in this field were identified and
counted. The whole slide was then surveyed at lOOx to identify and enumerate
larger rare species. Counts were expressed as cells per unit area, and these data
were used to compute relative abundance and species diversity.
Benthic samples were collected in replicate along three watercourses (White
River, Yellow Creek and Corral Gulch) during the interim program. Samples were
collected with a modified Surber sampler, washed through a U.S. Standard #30 sieve,
and the retained specimen preserved with buffered 10-percent formalin. Standard
methods of sample processing and analysis were used in the laboratory. The benthic
samples were first agitated, and the organisms rinsed with a low-pressure fine spray
into 20 cm (8 in.) #60 sieves to remove any fine sediments. The samples were then
hand-sorted under dissection microscopes at 6X magnification. Samples were
systematically searched, pushing examined portions aside, and the benthic organisms
were removed with forceps. All organisms removed were stored in plastic capsules
and 4-dram (0.25-oz) vials in 70 percent ethanol. With few exceptions, benthic
organisms were identifiable to generic level without special preparation. The
C-37
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standard procedure was to identify the organisms to the lowest taxon possible.
Identifications of individuals were usually made under the dissecting microscope or
with temporary slides (under water) and a compound microscope. After
identification and enumeration, specimens were stored in 70 percent ethanol in
sample jars, collectively by sample replicate. A special reference or voucher
collection was maintained apart from the other specimens. Only those individuals
that were living at the time of collection, as indicated by presence of fleshy tissue,
were enumerated for the purpose of estimating populations. Empty mollusc shells,
exuvia, reproductive structures, etc. were retained as aids in identification - and
compilation of qualitative species lists, but they were not used for estimates of
population densities. Benthlc samples were taken twice a year (once in spring and
once in fall) and coordinated with data from the water chemistry samples.
Modular Development Phase Monitoring Program—
The modular development phase biological resources monitoring program is
currently taking place. It began in September 1977 and will run approximately ^
years. The NUS Corporation was the major consultant for the initial stages of the
modular development phase. Documents reporting results of this program are
References 6-10. A new program, the environmental monitoring program (EMP) was
approved on April 26, 1979. The EMP does differ somewhat from the program
described here.
Color aerial photography is taken of the Tract C-a area every 3 years, and
these photographs are compared to earlier photos to determine any changes in the
distribution of vegetation types. Color infra-red photography (1 cm = 79.2 m scale)
is taken annually of the Tract C-a area to determine major vegetation stress areas.
If stress conditions are noticed, additional sampling of the damaged area will be
performed. Phytosociological studies are performed to determine herbaceous cover.
Range Studies—Thirty range sampling transects are established in various
vegetation types (10 mixed brush, 10 pinyon-juniper, 10 sagebrush) to monitor range
production and utilization in the Tract C-a area. The sites have been chosen at
random in the same general location as the browse transects, and their locations are
shown in Figure C-10. The sampling intensity should achieve a minimum accuracy
of ± 25 percent of the mean 90 percent of the time.
Two caged plots (0.9 mz or 9.6 ft2 in size) and eight unprotected plots are
located at 10-m (33-ft) intervals along each sampling tansect. Forage is measured
annually at the end of the growing season by using the double sampling method. All
methods of sampling and analysis follow those outlined in the interim range study.
The schedules of range monitoring programs are outlined in Table C-ll.
Browse condition and utilization are measured along 30 transects (10 mixed
brush, 10 pinyon-juniper, 10 sagebrush) located in the same general vicinity of the
range transects. The approximate locations of these sampling sites are presented in
Figure C-10. Browse sampling is visuaily performed in early May after deer have
migrated through the Tract C-a area. All methods of sampling and analysis are
comparable to those outlined in the interim range study.
C-38
-------
TABLE C-ll. SCHEDULE FOR MODULAR DEVELOPMENT PHASE RANGE
STUDIES AT TRACT C-a
Parameter
measured
Starting
date
Sampling
frequency
Trace metals (collection
-------
Plot
1 '2
8
Sample Unit (
(1/2 mile square)
Q
t
¦u
o
Block
0.
1.
ll.Jl'llll6
7| 1 1 | 112
BlJJJJli
ieLU _U24
25iJJ__|_|30
3l|32|33|34|35|36
2
3
4
L
RBOSP
Tract
5
C-a
6
7
8
9
Plot
Sample unit
Block
LEGEND
ca. 100 sq ft^ (1/1000 ha)
160 acres (ca. 64 ha)
9 square miles
20 plots per sample unit
36 potential sample units
per block
9 blocks in the RBOSP
study area
Figure C-ll. Study area for mule deer pellet-group counts (RBOSP modular
development phase monitoring program).
-------
summer and during the migration and wintering periods. All pellet groups are
removed from the plots as they are counted.
Aerial surveys are flown annually during the month of January to study feral
horses. Transects along the same study area as for mule deer are flown, and feral
horses are counted and their locations recorded. The aerial census is supplmented
by general observations during terrestrial studies. This information will assist in
the State's determination of feral horses in the area.
Aquatic ecology—A survey is conducted at six stations along stream courses in
the Tract C-a area to determine what aquatic resources are available for the
propagation of aquatic organisms. The locations of these sampling sites are shown
in Figure C-12. The parameters being evaluated in this program include stream
velocity, turbidity, pH, specific conductance, dissolved oxygen, total alkalinity,
water temperature, depth, width, and stream substrata. These measurements are
taken six times a year. The program schedule is summarized in Table C-12. The
methods used for measurement of the parameters are:
Stream velocity
Stream substrata
Turbulence
Dissolved oxygen
pH
Specific conductance
Water temperature
Depth
Width
Total alkalinity
Gurley flowmeter
Visual classification
Hach photometric turbidimeter
Alsterberg/Winkler method
Portable meter
Portable meter
Therm ister
Chlorimetric (1*0
Chlorimetric (1<0
Chlorimetric (1<0
In addition to these parameters, certain water quality criteria are measured
with the same frequency. These measurements are conducted at two sampling sites
(Stations 27 and 29).
The monitoring for periphyton will be accomplished at the six sampling sites
shown in Figure C-12. Sampling will be carried out six times a year. The methods
of sampling and analysis are identical to those employed during the interim
periphyton sampling program. Data are stored on magnetic tape. To achieve the
objectives of the study, hypotheses are being tested using analysis of variance
techniques. Sampling is intended to achieve an accuracy of ± 25 percent of the
mean 95 percent of the time.
Benthic organisms are being sampled and analyzed from the same six sampling
sites that are presented in Figure C-12. Sampling will be accomplished six times a
year. During this program, benthos species diversity, density, and composition are
being determined. The methods of sampling and analysis are identical to those
implemented during the interim program. The data are stored on 9-track 800 bytes
per inch, magnetic tapes. To fulfill the objectives of the study, several hypotheses
are being tested using analysis of variance techniques. Sampling is intended to
provide semiquantitative data which, when related to the physical, chemical and
periphyton studies, will provide an overall assessment of the changes in the aquatic
habitats on and near Tract C-a:
C-41
-------
n
R »7W
t*W
II IOOW
I
¦<8>
-7.L
LEGEND
n i 5
A Aquatic Modular Development r »
Phase Study Sampling Locations Miles
| Multiple Aquatic Modular Development
Phase Study Sampling Locations
Figure c-12. Sampling site locations for aquatic ecology studies
during the modular development phase.
C-42
-------
TABLE C-12. MONITORING PROGRAM SCHEDULE FOR MODULAR DEVELOPMENT PHASE
AQUATIC ECOLOGY STUDIES
Parameter
Location
Start date
Sampling frequency
Abiotic:
Physical measurements:
Stream velocity
Stations 13, 14
Oct. 1977
6 times/year
Turbidity
20, 21, 27, 29
(April, May, June,
Dissolved oxygen
(See Figure 6)
July, Aug., Oct.)
PH
Specific conductance
Water temperature
Depth
Width
Stream substrate
Water quality measurements (White River):
Boron
Stations 27, 29
Oct. 1977
6 times/year
Calcium
(See Figure 6)
(April, May, June
Chloride
July, Aug., Oct.)
Fluoride
Magnesium
Nitrate
Orthopho sphate
Potassium
Total phosphate
Silica
Sulfate
Sodium
Alkalinity
Total dissolved solids
Biotic:
Periphyton
Stations 13, 14
Oct. 1977
6 times/year
20, 21, 27, 29
(April May, June,
(See Figure 6)
July, Aug., Oct.)
Benthos
Stations 13, 14
6 times/year
20, 21, 27, 29
(April, May, June,
(See Figure 6)
July, Aug., Oct.)
-------
Soil studies—Particulate releases 5 kg/hr (11 lb/hr) during the modular
development phase will be quite low, and maximum concentrations are not expected
to be sufficient to affect the soil stratum. However, accumulation over several
years may result in measurable increases in these constituents. Therefore the
following study is proposed.
Soil and vegetation samples will be collected before the first retort burn and
stored. Samples will be collected annually (August) thereafter and stored.
Concurrently, stack sampling of emission will be carried out.
If analysis of the samples taken after the burn of Retort 5 does not reveal a
significant increase in trace metal content of affected area soils over the control
area soils or over baseline samples, no further analysis of stored samples will be
carried out. However, if significant increases are verified, then samples will be
analyzed in decreasing order by age to determine the rate of increase by year.
Three control and three impact (treatment) sites will be selected for sample
collection (Figure C-13). Control sites will be placed outside the tract and
potential dispersion patterns. The impact sites will be located northwest and
southwest of the emission sources in areas of predicted maximum short-term and
annual concentrations. The sampling locations will be of sufficient size to
assure thorough coverage of the potential impact zones. Locations of sampling
sites will be reevaluated periodically on the basis of modeling data and source
locations. If necessary, the sites will be relocated.
Ten soil samples will be collected during August of each year from the surface
soils (0 to 10 cm or 0 to 4 in.) of each site. Five composite vegetative samples
each of sagebrush and a metal-concentrating plant (e.g., Astragalus) will be
collected at each site from the current year's growth.
If significant levels of trace metals are released from stacks, then soil samples
will be immediately analyzed for those elements identified in the emissions (e.g.,
Sb, As, B, Cd, F, Hg, Se, Mo, and V). If trace metal levels in the impact site soil
samples are shown to be significantly greater than levels that were present during
the baseline studies or in the control samples, then vegetation samples will
be analyzed to determine if trace metals have been taken up into the food chain.
Modeling efforts indicate that the maximum concentrations of salt drift are
expected to occur immediately adjacent to the cooling tower . The areas
of maximum deposition are limited to within the tract boundaries. Large deviations
from the projected dispersion pattern are not expected because of the large size of
the salt droplets. Therefore, specific control and impact sites (0.8 x 0.8 km or 0.5 x
0.5 mi, Locations 5 and 6) have been selected in the expected maximum and
minimum salt deposition areas (Figure C-13).
The control site was selected in an area where soils (Rentsac and Rentsac-
Piceance) are similar to those in the impact area. Baseline studies indicate that
both soil series have low soil conductivities (Rentsac = 1.6 p mhos/cm (^.1
pmhos/in.); Piceance = 1.3 nmhos/cm (3.3 ymhos/in.) based on a saturated paste
sample). Therefore if appreciable salt deposition occurs, detection of a change in
soil conductivity should be possible.
C-44
-------
JZ:
0
1
tn
iU' £
, ^ ><7 v—(rS/il ! Lv , •--, f\
' ^ M /' •'^-^1' ?''A OI^cT-BouNdary^ /
' i ¦:* '' S^i >i/'L
..•' • \ ^ ij \t L V ^-h * ^--V Cv^Ja (A tbi
/i ¦ A A l i". V>
•F*T
K09 -*5*
^5*fcai
. I* % M/
y A Sj ffsoo
J^W^iod
* j—J
'Z'^XJf ,/V/
v -v C —-
\ ':. -• \ A ^
Q Impact site
Control site
~/
Figure C-13. Tentative locations
accumulation sites,
represent predicted
of soil sampling sites; Nos. 1 through 4 are trace metal
and 5 and 6 are conductivity sampling sites. Isople^hs
pattern of salt disposition from cooling towers (g/rt ).
-------
The conductivity control site was selected in an area that will also be the
control site for other vegetation, small mammal, and avifauna studies. The
multiple use of this control site will permit analysis of interrelationships among
soil, vegetation, and faunal parameters.
Twenty soil samples will be collected randomly from the Rentsac or
Rentsac-Piceance soils in each of the control areas. Samples will be collected each
August beginning in 1981, or the year before commercial development. Soil samples
will be collected from the surface soils (0 to 10 cm or 0 to 4 in.) of each site. These
samples will be analyzed by a commercial laboratory to determine electrical
conductivity.
The soil material remaining after analysis will be stored. If a significant
change in electrical conductivity is detected in samples after operation of the
cooling towers begins, the stored samples will be analyzed to identify those
elements contributing to the increased conductivity (e.g., chloride, gypsum, etc.).
In addition, if conductivity levels approach 6 mmhos/cm (15.2 mmhos/in) (medium
salt tolerance) then vegetation composition studies will be initiated.
Proposed Commercial Development Phase Monitoring Program—
The commercial development phase biological resources monitoring program
will be initiated before commercial construction in 1982. An outline of the proposed
program is presented in the RBOSP Revised Detailed Development Plan (11). It
should be noted here that plans for commercial development have changed a great
deal since the original monitoring plan was designed. For this reason the actual
monitoring program instituted may differ from the one described below.
Vegetation--An annual survey of the vegetation types and quantities by means
of aerial survey is proposed. The aerial surveys will be by color infrared
photography (1 cm = 240 m scale or 1 in. = 2,000 ft). The photographed area will
include the Tract C-a area and a 8-km (5-mi) radius surrounding it. A summary of
the vegetation studies is outlined in Table C-13.
Range studies—Range productivity and utilization studies will be accomplished
by surveying vegetation in three major areas: mixed brush, pinyon-juniper, and plant
sagebrush. The sampling program will employ 10 transects/area (10 plots/transect),
or a total of 100 plots. The locations of these sampling plots are illustrated in
Figure C-14. The forage will be measured before development and annually after
development at the end of the grazing season. The double sampling method will be
used. Details on the methods of sampling and analysis are presented in the interim
and modular development monitoring description.
Browse condition and utilization will be studied by sampling and analyzing
vegetation. Use in the same two areas as described in the previous section are
analyzed.
Transects may be selected randomly (10 transects/site) and samples will be
taken from 25 individual shrubs. Browse species to be sampled include: juniper,
pinyon, antelope bitterbrush, snowberry, big sage brush, and true mountain
mahogany. Transects will be selected randomly. Sampling will be conducted in
early May, after deer migration. Form, class, age, leader use, hedging, and
availability will be measured.
046
-------
TABLE C-L3. SUMMARY QP PROPOSED COMMERCIAL DEVELOPMENT PHASE TERRESTRIAL MONITORING PROGRAM AT TRACT C-a
Sampling
proqram -
Parameter
Sampling
frequency (years
Saapling
technique
Sampling
intensity
Data
analyses
Vegetation
Distribution of
vegetation type
Before, 1, 2f
4, 5
3,
Aerial photographs
Tract C-a and 8 km
radius
Preparation of vegetation
map» ground truthing
Productivity 6
utilization
Before, 1, 2,
4, 5
3,
Double sampling
method
10 Transects/saaple site
Analysis of variance
multiple range test
Browse condition
£ utilisation
Before* 1, 2,
4, S
3,
Cole (16)
10 Transects/sample site
Analysis of variance
multiple range test
Sol Is
Conductivity
Before, 1, 2,
4, 5
3,
Soil cores (0-10 en)
20 Sanples/sample site
Analysis of variance
Trace elements
(As, B, Se, etc.)
Before, 1, 2,
S5
3,
Soil cores (0-10 cm)
20 Samples/sample site
Analysis of variance
Fauna
Small manmals
Species composition
Index of abundance
Before, 1, 3,
S
Pit trapping,
live trapping
5 Groups (2 transects of
10 traps/group)
*
Regression analysis; F-testj
analysis of variance
(index of abundance)
Avifauna
Species composition
Before, 1, 3,
s
Breeding bird Mapping
technique
12-45 ha (30-105 acres)
(depending on size of
area)
Regression analysis;
analysis of variance
(for density only)
Map of territories
Density of breeding
Graul (IS); Hall (16);
Bobbins (17)
Divided into 1-ha subunits^
t replicates of subunits
Birds
Mule deer
Density estimates
Before, 1, 2,
4, 5
3,
Pellet group counts
23 km-sq study area
divided into blocks|
quarter-sections within
blocks include 20 plots
F-test; regression analysis;
analysis of variance
Feral horses
Before, 1, 2,
4, 5
3,
Aerial census
Mule deer study area
Report observations
2
Sampling intensity will be determined during the first year of study.
-------
<-rv j? "S
R39WC/ J
LEGEND
J i Impact
^ ' Control
PJ Pinyon-Juniper
Jps MB = Mixed Brush
N^>'r S = Sagebrush
Figure C-14. Location map for Tract C-a vegetation monitoring sites for the proposed
commercial development phase biological resource monitoring program.
-------
Terrestrial vertebrates and invertebrates—Sherman live traps and pit traps
may be utilized to monitor the abundance of small mammals in the area. The total
number of traps and number of sampling days required is yet to be determined.
Traps will be checked in the morning and evening. Animals captured will be
identified, sexed, aged, and released at the capture point.
The breeding bird mapping technique is intended to be utilized to determine
the location, species, and breeding activity of observed avifauna. Each study unit
will be divided into 1-ha (2.47-acre) subunits. An observer will walk the area" and
record the required information. This information will be documented on maps.
Additional information will be collected by general observation. The frequency of
monitoring activities has not yet been determined. -
Mule deer inventories will be conducted on Tract C-a by means of pellet group
counts. Tract C-a will be in the center of a 15- x 15-km or 225-km* (9- x 9-mile or
81 sq mi) study area which will be divided into blocks (approximately 2.6 sq. km or 1
sq mi each). Quarter sections (64 ha or 160 acres) will be randomly selected from
each block. The number of quarter sections to be used will be determined after
results of the baseline studies can be observed. The methods of sampling and
analysis are identical to the methods described in the baseline program. The
program will be started before modular development phase construction and will
continue annually thereafter.
t
The abundance of feral horses occurring in the Tract C-a area will be
determined by general observations, aerial overflights, and State and Federal
agencies. The information will be collected and compiled annually.
The number of cottontails and jackrabbits will be determined by visual search
and observation. Predetermined routes will be driven at a speed of 16 kmph (10
mph).
Aquatic ecology—On and near Tract C-a, two aquatic habitat types have been
observed—ponds and spring brooks. Based on baseline observation, 10 sampling sites
have been selected for the monitoring of RBOSC water control effectiveness and for
determination of possible impacts. The locations of these sites are the same as
described in the modular development phase program.
Selected physical characteristics of streams in the Tract C-a area will be
measured at the sites. The parameters to be measured include: stream velocity,
turbidity, substrate, dissolved oxygen, pH, specific conductance, water temperature,
depth, width, and alkalinity. The proposed method of measurement for each
constituent is illustrated below. Sampling frequency will be five times a year.
Velocity
Turbidity
Stream substrate
Dissolved oxygen
pH
Specific conductance
Water temperature
Gurley flowmeter
Hach photometric turbidimeter
Visual observance
Alsterberg/Winkler method
Portable meter
Portable meter
Thermister
c-49
-------
Depth
Width
Alkalinity
Colorimetric (14)
Colorimetric (14)
Colorimetric (14)
Water quality—Water quality parameters in the aquatic biological resources
areas of Tract C-a may be measured at the locations described in Figure C-12. The
parameters would be measured five times a year. The constituents to be measured
will include calcium, chloride, boron, fluoride, magnesium, potassium, sodium,
sulfate, nitrate, orthophosphate, total phosphate, and silica.
Periphyton samples will be taken from the sampling points illustrated in Figure
C-12. Replicate samples will be taken from natural substrates five times a year and
will be analyzed to determine relative abundance, diversity, and biomass. Field and
laboratory studies will be the same as those used during baseline studies.
The composition, abundance, and diversity of benthic species will be monitored
at the sites described in Figure C-12 five times a year. Samples will be collected
with a modified Surber sampler or an Ekmen grab. The samples will be washed in
buckets with a U.S. Standard No. 30 sieve bottom and preserved with neutralized 10
percent formaline. Methods of laboratory analysis will be identical to those used
during baseline, interim, and modular development monitoring.
Soils studies—Sampling of soils for trace elements will be done at two sites in
the Tract C-a area. The locations of these sites are presented in Figure C-13. The
two sampling sites are 2.4 x 2.4 km (1.5 x 1.5 miles). They represent the greatest
impact and no impact areas. From these sites, 20 surface soil (0 to 10 cm or 0 to 4
in.) and 20 leaf samples will be collected annually for analysis in the laboratory. If
significant amounts of the trace elements are detected in the source monitoring
program, the soil and vegetation samples will be analyzed for As, B, Cd, F, Hg, Se,
Mo, and V.
Measurements of soil conductivity may be carried out at two locations in the
Tract C-a area (Figure C-13). These two sites (.8 sq km or 0.5 sq mi) should
represent areas of maximum cooling tower salt drift impact and no impact. Twenty
random samples will be collected annually during August. Methods of analysis will
be conducted in the same manner as was done in the baseline, interim, and modular
development phases.
Solid Waste Disposal, Revegetation
Baseline Data Gathering Program-
In 1975, a 3-year experimental revegetation program was initiated by RBOSP.
The program included three successive plantings—two in 1975 and one in 1976. The
first two plantings (1975) are included in the baseline environmental program and
hence will be described here. The sources of information on these planting programs
are References 1 and 18.
The revegetation plots initiated in 1975 are located in the north and south
slopes of Wolf Ridge and are labelled Rx and R2 (Figure C-15). Sixteen treatments
were applied at random to 10- x 10-m (33- x 33-ft) plots and replicated in three
complete blocks. Since each plot was assigned a 3-m (10-ft) buffer zone, the total
area of the site was 55 x 165 m or 9,075 itT (180 x 540 ft or 97,200 ft2) bringing the
C-50
-------
Miles
Figure C-15. Location map for Tract C-a revegetation test' plots
for the baseline solid waste data-gathering program.
C-51
-------
total area of disturbance for each site to 1.7 ha (4.3 acres). Within each 10- x 10-m
plot (33- x 33-ft) four 1- x 0.5-m (3.2- x 1.6—ft) subplots were established for
observation. Native vegetation was scraped from the plots, and topsoil (about the
upper 15.2 cm or 6 in. of soil) and other material was stockpiled separately. The
underlying bedrock (calcareous sandstone) was fractured to a minimum thickness of
61 cm (24 in.) and the subsoil and topsoil were replaced and graded. A composite
mixture of grasses, forbs, and woody plants was drilled in rows 13 to 18 cm (5 to 7
in.) apart. Approximately 3 kg/ha (16 lb/acre) of this seed combination was sown in
equal proportions. A total of 16 treatments was applied, with all possible
combinations of the following variables: no mulch, hydromulch with wood fiber,
straw mulch followed by crimping, straw mulch with netting, no fertilizer, fertilizer
at the time of sowing, and fertilizer at the beginning of the first full growing
season. A summary of the schedules for field events in the revegetation study is
presented in Table C-14.
1976 revegetation studies—The 1976 revegetation site was a 53- x 53-m or
174- x 174-ft (0.3-ha or 0.70-acre) plot located in the south slope of Wolf Ridge (see
Figure 15). The purpose of this revegetation experiment was to test the artificial
soil profile that will cover the processed shale disposal pile during the commercial
operation and disposal. Approximately 1 ha (2.5 acres) was disturbed by the 1976
revegetation experiments. Eighteen treatment combinations were applied to the 36
plots within the 1976 revegetation site. Within each 6 x 6 m (20 x 20 ft) plot, a
minimum of three 1.0- x 0.5-m (3.2- x 1.6-ft) subplots were randomly established
and marked for data collection. The simulated artificial soil profile was prepared by
separately stockpiling topsoil (15.2 cm or 6 in.), subsoil (30.5 cm or 12 in.), and
excavated sandstone (30.5 cm or 12 in.). An additional 91.4 cm (36 in.) of rock and
soil material was excavated from the revegetation site and stockpiled. A plastic
sheet was placed into a prepared area 1.7 m (5.5 ft) deep to reduce the possibility of
contamination to groundwater and to facilitate collection of any leachate for
analysis. Perforated plastic pipe was placed in three locations for collection of
leachate: (1) at the top of the compacted shale; (2) beneath the compacted shale;
(3) beneath the sandstone material on the control side of the experimental plot.
Because of the limited availability of TOSCO II processed shale, 50.8 cm (20 in.) of
processed shale was placed on top of the plastic sheet. The processed shale was
compacted to prevent penetration or leaching and to simulate the 1.5 m (5 ft)
surface layer of the compacted processed shale of the proposed disposal pile
configuration. The control plot was underlaid by approximately 50. 8 cm (20 in.) of
sandstone that had been excavated from the revegetation site and that had
previously been stockpiled. After the processed shale was compacted, 1 m (3 ft) of
overburden (30.5- x 0-cm or 12- x 0-in. size) was bulldozed over the processed shale
and the excavated sandstone of the control plot. The topsoil and subsoil were
replaced in proper sequence. Grass, forb, and shrub seed were sown as a composite
at 2 cm (.8 in.) depth and 12.7- to 17.8-cm (5- to 7-in.) spacing. The eighteen
treatments included three seeding intensities (low, ^2.75 kg/ha or vr 15 lb/acre;
medium, »r3.67 kg/ha or 20 lb/acre; high, »r4.59 kg/ha or 25 lb/acre) as well as three
mulch and two shale and no shale substrates resulting in the following combinations:
c-52
-------
TABLE C-14. SCHEDULE OF FIE1X) EVENTS FOR BASELINE REVEGETATION STUDIES ON OIL SHALE—TRACT C"a
Field event
1975*
1976
1977
1978
J A S O N D
JFMAMJJASOND
JFMAMJJASOND
JFMAMJJASOND
Site Selection
4
Field works
Seedbed preparation
A
A
A
Planting
A
A
A
Measurements of plant
response to treatments
A A
A A
<1
<
Soil analysest
Saaple collections
A
A
A
Moisture determinations A AAA A A A AAA
Salinity determinations AAA
^Months of the year are indicated, in order, by their first initial.
-------
Seeding
Substrate
intensity
Mulch
Shale
Low
None
Shale
Medium
None
Shale
High
None
Shale
Low
Hydromulch
Shale
Medium
Hydromulch
Shale
High
Hydromulch
Shale
Low
Straw
Shale
Medium
Straw
Shale
High
Straw
No shale
Low
None
No shale
Medium
None
No shale
High
None
No shale
Low
Hydromulch
No shale
Medium
Hydromulch
No shale
High
Hydromulch
No shale
Low
Straw
No shale
Medium
Straw
No shale
High
Straw
The following plant response parameters will be measured for each treatment:
(1) number of emerged seedlings per lot; (2) number of surviving seedlings per plot;
(3) percent cover. Additional information concerning the experiments initiated in
1976 is presented in the RBOSP Progress Report 9 (19), and the 1976 and 1977
Annual Revegetation Reports (18).
Tubelings are being grown by the USD A Shrub Science Laboratory from the
same seed lots that were used for direct seeding. Five shrub species (excluding
Amelanchier alnifolia) and pinyon pine will be utilized for the tubeling treatment.
Tubeling size will be 294 cm3 or 5.1 x 3.8 x 15.2 cm (18 in.3 or 2 x 1.5 x 6 in.). The
tubelings were planted by hand in each treatment plot (R3) in early or mid-3une at a
rate of 18 tubelings/plot (728 tubeling/ha or 1,800 tubelings/acre); three tubelings of
each of the six species was used.
Monitoring Programs for the Interim and Modular Development Phases—
During construction in the modular development phase, approximately 63 ha
(155 acres) were disturbed (1977-78), 2k ha (60 acres) of which have been
revegetated. A summary of the seeding and mulching activities is presented in
Tables C-15 and C-16.
In addition, 1979 marked the last year of the RBOSC 3-year experimented
revegetation program. Percent cover and biomass were measured at Sites Ri and
R2 (Figure C-15) during the third growing season in 1978. Percent cover was
estimated by visual estimates, and biomass by harvesting. An analysis of variance
was performed to determine if significant differences existed between mulch,
fertilizer treatments, and plant species. Percent cover, height, and diameter of
shrub seedlings were also measured during the third growing season of 1978 at Site
R3. An analysis of variance was also performed at R3.
C-54
-------
TABLE C-15. SUMMARY OF SEEDING AND MULCHING ACTIVITIES PERFORMED DURING REVEGETATION IN 1978 AT
TRACT C-a
Disturbed area
Seeding
mixture
Seeding
method
Hydro-
mulched
Seeding rate
(lb PLS/acre)3
Access road berms
1
H
X
38
Water reinjection
1
H
X
38
West settling basin
2
D
16
Ore disposal area
2
D
16
Soil storage
2
D
16
Plant site/mine service area
Blowdown/retention ponds
2
H
X
32
Plant side slopes
3
H
50
Area near hunting club
1
D
X
19
Area between water tank
and plant site
1
D
X
19
Diversion system
2
H,B
32
Equipment yard
1
D
19
Reservoirs/soil piles
Hunting Road clay pit
2
D
16
Meteorological Site 4
1
D
19
aH - Hydroseed
D - Drill
B - Broadcast
PLS - Pure live seed
-------
TABLE C-16. THREE SEED MIXTURES USED FOR RBOSC REVEGETATION ACTIVITIES DURING FALL 1978
Seeding rate
Seed mixture
Plant species
Approximate {lb PLS/acre)
1 - Permanent
Luna pubescent wheatgrass
2.5
Western wheatgrass
3.5
Sodar streamband wheatgrass
2.0
Indian ricegrass
1.5
Green needlegrass
1.5
Manchar brome
1.5
Cicer miIkvetch
1.5
Madrid yellow sweetclover
0.75
Lewis flax
1.0
Winterfat
1.0
Fourwing saltbush
1.0
Bitterbrush
1.0
Total
18.75
2 - Temporary
Yellow sweetclover
1.0
Barley
1.0
Western wheatgrass
6.0
Luna pubescent wheatgrass
8.0
Total
16.0
3 - Temporary
Yellow sweetclover
4.0
Crested wheatgrass
8.0
Barley
8.0
Luna pubescent wheatgrass
5.0
Total
25.0
a
Based on drilling rate; rate for broadcasting is doubled.
kpLS - pure live seed,
c
Bitterbrush was included in seed mixture for Airplane Ridge Road and areas near the Hunting Club.
-------
Soil moisture measurements were also made at Ri, R2, and R3 during June,
August, and October 1978. Soil conductivity was measured at 0-, 25-, and 50-cm
(0—, 9.8-, and 19.7 in.) depths at R3.
Proposed Commercial Development Phase Monitoring Program-
Data gathering during the baseline, interim, and modular development phase
revegetation program will determine which agricultural practices are the most
appropriate for re vegetating disturbed soil in the Tract C-a area. The practices to
be determined include those relating to seedbed preparation, seeding, use of mulches
and fertilizer, irrigation, biotic influences and interaction, and management. At the
conclusion of modular development revegetation monitoring, the most appropriate
methods of utilizing the above-mentioned agricultural practices will be determined
and employed in the revegetation of shade disposal piles.
All revegetation will take place 1 year after land disturbance. Revegetation
of raw shale will be delayed until disposal is completed. Revegetation of processed
shale will take place in sections as the shale is disposed of. In small-surface
disturbed areas a mixture of grasses and forbs will be seeded. In larger disposal
areas, a mixture of grasses, forbs, and shrubs will be seeded to provide for more
rapid introduction of browse and forage for domestic and wildlife species.
A sampling program will be conducted on revegetated soils to determine the
success of growth, range productivity, browse utilization, species composition, soil
properties, small mammals abundance, and avifauna. The program will take place
during the first five growing seasons after seeding. The parameters, sampling
techniques, sampling frequency, and sampling intensity to be used are summarized in
Table C-17.
Noise
Baseline Data Gathering Program-
There have been two studies of ambient noise levels that can be considered
part of the baseline data gathering program at Tract C-a. The first program took
place during the period of August through December 1975. The data from this
program have been reported previously in the RBOSP DDP in 1976 (11). During the
summer of 1976, a second 3-day study was conducted. This program has been
outlined in the Final Environmental Baseline Report (1). Sound levels were
measured and recorded at the four air quality monitoring sites with a frequency of
once every 20 min during the four divisions of the day—morning (0700 - 1200),
afternoon (1200 - 1800), evening (1800 -2200), and night (2200 - 0700). The tape
recordings were analyzed at a later date. Data were not used if the wind speed was
greater than 6 m/sec (19.7 ft/sec), and wind pops and aircraft overflight were edited
from the tape. Data were not recorded when the wind speed or relative humidity
was high (more than 90 percent relative humidity) at the beginning of a 20-min
period. Computations were made to determine the cumulative frequency of
occurrence of specific noise levels: the noise level exceeded 95 percent of the time,
the noise level exceeded 5 percent of the time, the integrated 24-hr average, the
constant noise equivalent of the integrated noise recording, and the A-weighted
noise intensity. (The A-weighted measurement represents that which would be
perceived by the human ear, as opposed to the absolute pressure of the sound waves,
represented by the other measures.)
C-57
-------
TABLE C-17. COMMERCIAL DEVELOPMENT PHASE SOLID HASTE MONITORING PROGRAM AT TRACT C-a
Sampling SwpUnf Sampling Stapling Data
prograi Par—eter frequency techniques intensity analyses
Vegetation
Species composition
Before revegetation,
Year 3, 5...
Quadrat (9.6 ft^)
0.89 a2
1 Transect/40 ha (100 acres)
(10 quadrats each - 10 m
intervals)
Coefficient of coouinity
Percent similarity
Pielou (20)
Percent cover
Before revegetation.
Year 3, 5...
Quadrat (9.6 ft2)
0.89 m2
1 Transect/40 ha (100 acres)
(10 quadrats each - 10 m
intervals)
Coefficient coomnity
Percent similarity
Pielou (20)
Productivity S
utilisation
Before revegetation,
Year 3, 5...
Double sampling
method (USD*. 1970)
1 Transect/40 ha (100 acres)
(10 plots each)
Analysis of variance
Multiple range test
Browse condition
( utilization
Before revegetation.
Year 3, 5...
Cole (12)
1 Transect/40 ha (100 acres)
(25 individual)
Analysis of variance
Multiple range test
Soils
pa
Hacronutrients
(N. P, K)
Micronutrients
(CI. Ca. Ha)
Year 1, 3, S...
Soil cores -
(0-10 cmi 30-40 cm)
1 Somple/40 ha (100 acres)
Qualitative
Analysis of variance
Multiple range test
Conductivity
Trace elements
(Ar, B, Zn, Se, etc.)
Year 1. 3, 5...
Soil cores -
(0-10 cmj 30-40 cm)
1 Sample/40 ha (100 acres)
Analysis of variance
Multiple range test
Fauna
Small uwli
Species composition
Index of abundance
Before revegetation.
Year X, 3, S...
Pit trapping
Live trapping
5 Transects/unit
(2 transects of 10
traps/group)
Regression analysis; F-testi
Analysis of variance
(index of abundance)
Avifauna
Species composition
Map of territories
Density of breeding
Birds
Before revegetation.
Year 1, 3, 5...
Breeding bird mapping
technique
Graul (15)| Hall (16),
Bobbins (17)
12-45 ha (30—105 acres)
(depending on size of
area)
Divided into 1-ha subunlts^
8 replicates of subunlts
Regression analysis.
Analysis of variance
(for density only)
'Adequate &aaple size will be determined during the first year.
-------
Interim Monitoring Program-
Noise levels were not expected to change from the baseline period to the
modular development period, and hence this parameter was not measured during the
interim monitoring program.
Modular Development Phase Monitoring Program-
Noise measurements are being made at 16 locations on a quarterly basis.
These locations represent a series of concentric circles from the construction area
out to the borders of Tract C-a (Figure C-16). Each permanent site will be flagged
and visited once each quarter. In addition to these quarterly measurements,
opportunistic readings will be taken in construction or mining areas and at several
selected off-tract locations during peak levels of activity to determine the sources
and levels of noise and the distances at which the sounds can be heard.
Sound level readings will be taken with a Bruel and Kjaer Sound Level Meter,
Type 2205. The accurate range of this instrument is 20 to 130 decibels. A
Condenser Type 1, ANSI SI.12 omnidirectional microphone will be used to receive
noise impulses. The sound level meter will.be calibrated as necessary with a Bruel
and Kjaer Sound Level Calibrator, Type ^230, operating on a frequency of 1000
Hz± 1 percent. Wind speed will be determined with a Taylor Instrument Company,
handheld anemometer. Wind direction will be estimated with the aid of a compass.
The sound level meter will be calibrated using the Sound Level Calibrator
before each survey. Wind speed (mph), wind direction (degrees), and time will be
recorded at the start of each survey. Highest and lowest values on the meter during
a 20-sec period will be recorded for each site. Measurements will be repeated five
times. Comments noting unusual circumstances (i.e. jet overhead) and general
conditions during the reading will be recorded.
Sound level readings will be reported as highest and lowest range for each of
the five readings at each site and as the sound level average of all five sites.
Averages will be determined by adding all 10 values for each site and dividing by 10.
Values will be reported in decibels, A weighting (dBA).
Commercial Development Phase Monitoring Program—
During the commercial development phase at Tract C-a, noise will be
monitored. The program outline is presented in the revised DDP (11). Again it
should be noted here that this monitoring program may be changed.
During commercial operation, noise levels will be monitored in both the
working areas and in the project's surrounding environment. Ambient noise levels to
which workers might be exposed will be performed semiannually, or when
significantly different noise sources are installed or put into operation. These
surveys will be made in accordance with American National Standards Institute
Standard SI-41971. Semiannual measurements will be made of the ambient noise
levels around the project until a constant level of activity is achieved. At that
time, the program will be geared completely toward occupational safety.
c-59
-------
9)99^9jm
R99W
Firsr
Road'
¦vtv
Ywm
mm
//jmrn-A
Miles
— Tract Outline
=¦= Roads
9 Sound Survey
Sites
Figure C-16. Environmental sound-level monitoring sites, RBOSC Tract C-a.
C-60
-------
Radioactivity
Baseline Data Gathering Program—
During the baseline data gathering program at Tract C-a, radioactivity was
measured in soil profiles, processed shale, surface water, and groundwater. The
documents from which information was gathered for this report include References
1, 2, and 21.
Processed shale was analyzed at one time for uranium, equivalent uranium,
equivalent thorium, potassium, and radium-226. The local soil series were also
analyzed for the above-mentioned radioactive constituents.
In addition, the surface water and groundwater were both analyzed for gross
alpha and gross beta. The frequency with which these parameters were measured is
outlined in the baseline water resources monitoring program (see subsections on
surface water and groundwater under Tract C-a, Water Resources).
Interim Monitoring Program-
Radioactivity was not measured during the interim monitoring period in either
the water or the ambient air.
Modular Development Phase Monitoring Program—
During the modular development phase, radiation was monitored at Tract C-a
only in the surface and groundwater. The main sources of information relating to
this monitoring program are the Modular Development Phase Monitoring Reports
One, Two (6 and 7), and the Tract C-a Supplement to the DPP (8T^
Water from surface streams, alluvial aquifers, and deep oil shale aquifers were
monitored semiannually for the following: Gross alpha (if >4 pCi/1 then Ra226 or
>15 pCi/gal, natural uranium), gross beta (if >100 pCi/1 or >379 pCi/gal, then Sr90,
Ce ).
Proposed Commercial Development Phase Monitoring—
It is proposed that radioactivity be measured during the commercial phase
development monitoring program. The program description has been outlined in the
Revised DDP (II). This monitoring program may change.
Radiation will be analyzed in the surface water, alluvial water, and deep oil
shale aquifer water quality analyses. The monitoring stations are located in the
same positions described under Tract C-a Water Resources in the Subsection
Proposed Commerical Operations Water Monitoring Schedule. Gross alpha, natural
uranium, and gross beta measurements will be taken semiannually in surface and
alluvial aquifer waters. The same parameters will be measured in the deep oil shale
aquifers on a monthly basis at the outset and semiannually after consistent
measurements are found.
Surface Subsidence
Baseline Data Gathering Program-
No ground subsidence measurements were made during the baseline data
gathering program.
C-61
-------
Interim Monitoring Program-
No ground subsidence measurements were made during the interim monitoring
program.
Modular Development and Commercial Development Phase Monitoring Program--
During the modular development phase, a surface subsidence monitoring
program was initiated to study the subsidence over the modular development burn
area. The main source of information on this subject is the Supplement to the
Revised DPP (22). A surface subsidence monitoring program will be performed
during commercial development also. The source of information on this subject is
the Revised DDP (11).
During the modular development phase, 30 monuments were placed in 1978
above planned retorts, and other areas were expected to experience subsidence. The
monuments were constructed of steel-reinforced bars up to 25A cm (10 in.) long,
driven to the ground past soil horizons and into bedrock shale. A benchmark was
established at a sufficient distance from the retort area to assure that it would not
be affected. Subsidence monitoring ensued in March 1978.
Subsidence in the ground surface over the modular development phase retort
area will be monitored during and after completion of the burn. The horizontal and
vertical relationships of these monuments to an unaffected benchmark will be
determined. During and after the burn, the position of the monuments will be
recorded periodically. If any significant change takes place, the altered topography
will be mapped. The behavior of these modular development phase retorts after the
burn will be observed to serve as an indicator of what can be expected from the
commercial phase retorts. The top of some of the modular development phase
retorts will be reentered, if possible, to quantify shrinkage of the rubble zone.
Because subsidence tends to be a long-term effect, subsurface monitoring of the
rock integrity above the most subsidence-prone retorts will be performed. This will
be done either by borehole instruments, access drifts, or seismic methods. The
behavior of the retort roof after the burn will be observed by the methods found to
be the most effective.
The monitoring of subsidence over the commercial phase retorts will consist
solely of the placement of a monument or a monument grid over each retort to
record vertical and horizontal displacements at appropriate intervals. This practice
may be discontinued if no subsidence takes place or if mitigative measures prove to
be uniformly successful.
f RACT C-b
Air Resources
Baseline Data Gathering Program—
The Tract C-b baseline study was performed from November 197^ to
November 1976. The published documents that have been used as reference in the
preparation of this report are the Tract C-b First Year Environmental Baseline
Program: Annual Summary Report (23) and the Final Environmental Baseline
Program Report (2^11
C-62
-------
Five sampling stations were established during the baseline program to
monitor ambient air quality around Tract C-b. The meteorological monitoring
network consists of three mechanical weather stations, a 60-m (200-ft)
meteorological tower, two acoustic sounders, and one location for measuring
areawide visibility. The locations of these sampling sites are presented in Figure
C-17.
The air quality and meteorological parameters measured and the frequency of
sampling at each monitoring site are presented in Table C-18.
Sulfur dioxide, hydrogen sulfide, and suspended particulates were measured at
all air quality stations. Hydrocarbons, methane, nitrogen oxides, ozone, and carbon
monoxide were measured at two stations. Each of the sampling sites were equipped
with four high-volume samplers for the monitoring of suspended particulates. The
samplers were situated approximately (4.6 m or 15 ft) above ground level and geared
to take samples for 24 hr every day. In addition, particulates were analyzed on a
quarterly basis for alpha and beta radioactivity and trace metals.
Visibility was measured by Tract C-b and C-a in a conjunctive program from
September 1975 to September 1976. Photographs were taken seven times a day
every sixth day. Continuous wind data were accomplished at the mechanical
weather stations on the tract. Pibal balloons, the weather tower, aircraft, and
tethersondes were utilized to determine the vertical structure of wind patterns.
Solar radiation and relative humidity were monitored at one air quality station while
barometric pressure was monitored at two stations (Table C-18).
Interim Monitoring Program—
The interim air quality and meteorology monitoring program took place from
November 1976 through March 1978. During this time period, environmental
monitoring was scaled down to a large degree from the baseline program. A
detailed summary of the air resources monitoring program criteria was not
submitted and published. Monitoring data were reported in two periods: November
1976 through August 1977, and September 1977 through March 1978, in Tract C-b
Interim Monitoring Report Nos. 1 and 2 (25,26).
Figure C-18 shows the location of the interim air quality network, which
includes the following:
o One air quality trailer at Station 023 that has been in continuous
operation since September 1974 (before the 2-year baseline program)
o A 60-m (200-ft) meteorological tower at Station 023 that also has been in
continuous operation since September 1974.
o Weighing-bucket rain gages at Stations 020 and 023
o Pibal launches twice a day every other day (in a cooperative program with
the EPA) have been made at Station 024 since October 1977.
o A continuously recording acoustic radar instrument that has been in
operation since October 1977 at Station 020.
C-63
-------
R95W
H96W
R96W
R97W
R97W
032 041
LEGEND
@ Air Quality Trailers
O 200-ft Meteorological Tower
A. Acoustical Sounders
# Ground-Level Meteorological Stations
E3 Visibility Site-Lines Show Sector Covered
Figure C-17. Baseline air quality and meteorological monitoring network at Tract C-b.
-------
TABLE C-18. SUMMARY CP BASELINE AIB QUALITY AND METEOROLOGY MONITORING PROGRAM AT TRACT C-b
Basalipe Monitoring proqraa"
Air quality and Betaorology Air quality station Meteorological tower
ptraaateri
020
021
022
023
024
1
2
3
8 ft
10 ft 100 ft 200 ft
Sampling instrumentation
so.
X
X
X
X
X
Neloy Model SA185-2 (flame photometric)
Hji
X
X
X
X
X
Heloy Model SA165-2 (flue photometric)
PirtlcuUtM
0
0
0
0
High volume samplers
THC
4
4
Bendik Model 0200 (gas chrometograph)
CH
4
4
Bendix Model 8200 (gas chrcmatograph)
MHHC
X
X
2*
X
X
Meloy Model OA 350 {chemilumlnescent)
X
X
Meloy Model HA 520 (chemi 1 wineecent)
MO*
X
X
Meloy Model NA 520 (chemilumlnescent)
NO-
X
X
Meloy Model NA 520 (chemilumlnescent)
CO
X
Bendix Model B200 (gas chromatograph)
Horizontal wind speed
X
X
X
X
X
2
2
2
X
XXX
Weather Measure 103/3 and -04-2
Horizontal wind direction
X
X
X
X
X
2
2
2
X
XXX
Meteorology Research Inc. 1674*2
Blvanca wind tpdad
XXX
Model 21002 Gil Anemometer Vsne
Bivance horitontil wind direction
XXX
Model 21002 Gill Anamometer Vane
Bivance vertical wind direction
XXX
Texas Instruments Model 2013
Relative humidity
X
X
X
X
X
X
XXX
Texas Instruments Model 2013
Air temperature
X
X
X
X
X
2
2
2
X
XXX
Weather Measure Model 7621-TP16X
precipitation
X
X
X
X
X.
Weather Measure Model P511-E
Barometric pressure
X
X
Weather Measure B242 Barometer
Solar radiation
X
MM Model 840
Teaperature difference 1
Acouatlc echo
vlalblllty
Lsgendi
X - Saapled every 10 aao.
4 - Sampled evsry 5 ala.
0 - Sampled every third day
2 ¦ Saaplad continuously
1 • Standard deviation calculated
-------
-=T
*S\i *
'JM*
Q£i&
«
TRACT C-b
.
-------
o Mechanical weather stations coupled with hi-vol particulate samplers that
have been in operation since February 1978 at Stations 042 and 056.
Development Phase Monitoring Program—
The development phase monitoring program to be discussed here covers the
time period from February 1978 through commercial development. The sources of
information for this report were References 20, 27-29.
Gaseous Pollutants and Particles-
There have been five air quality and meteorology monitoring stations set up
around Tract C-b. As of February 1978, two of the five stations (Stations 020 and
023) are sampling for air quality analyses. The locations of all air quality sampling
stations developed for the development monitoring program are presented in Figure
C-18. The sampling schedule and parameters being measured as part of the
developmental phase monitoring program are presented in Table C-19. Air quality
parameters are measured at two stations (020, 023). Monitoring at Station 024 is to
begin in 1980. Particulates are measured at five stations, three on the tract and
two off. Baseline station 021 and 022 are discontinued. Minimum data reporting
frequencies consist of 1-hr averages. One-, 3-, 8-, and 24-hr averages will continue
to be computed as necessary for comparison with standards.
During operation of the development phase retorts, stack emissions monitoring
will be carried out as part of the PSD permit requirements. An outline of this
emission source monitoring program at Tract C-b is presented in Table C72O.
Visibility—Area-wide visibility is measured from one vantage point at Hunter
Creek. Four views are obtained by camera seven times a day, every sixth day for 10
days in spring and 10 days in fall. Hourly maximum and minimum visual ranges, and
means and standard deviation by variable are calculated.
Meteorology—Air temperature, relative humidity, barometric pressure, solar
radiation, evaporation, precipitation, horizontal wind speed (10 m, 30 m, 60 m or 33
ft, 100 ft, 200 ft), horizontal wind direction (10 m, 30 m, 60 m or 33 ft, 100 ft, 200
ft), vertical wind speed, A temperature (10 m, 60 m or 33 ft, 200 ft) mixing layer
height and winds aloft are all measured as part of the development meteorology
monitoring program. Station 023 is the most heavily instrumented trailer utilizing a
60-m (200-ft) meteorological tower and containing all tower data channels. The
schedule for this program beginning in February 1978 is illustrated in Table C-20.
Proposed Commercial Development Monitoring Program-
As part of the commercial development at Tract C-b, monitoring of ambient
air quality and meteorology will continue along much the same line as has been
outlined for the developmental phase. In addition to ambient monitoring and as part
of the commercial development monitoring program, emission source monitoring
will also be conducted to be in compliance with PSD regulations.
The emission source monitoring program that has been developed for Tract
C-b is summarized in Table C-20. In addition, air diffusion modeling will be
validated after the onset of commercial operation. Tracers will be utilized to allow
for easier ground concentration measurement.
C-67
-------
TABLE C-19. SUMMARY fif DEVELOPMENT PHASE AIR QUALITY AND METEOROLOGY MONITORING PROGRAM AT TRACT C-b
O
I
&
CO
Sampling
station
Monitoring
date
Particulates
NO
NO
Horizontal
wind speed
Horizontal Vertical
wind wind
direction speed
Air-quality
trailer:
020
021
023
024
026
Heather station &
hi-vol sampler:
042
056
Met. Tower #
3 ¦
10 m
30 a
60 a
Upper air studies:
Minisonde
Acous. sound.
Visibility, station
Tracer studies
020
060
a)
b)
c)
a)
b)
Jan. '76
July *78
19B0
Systems-
dependent
74
Nov.
1980
1981
Systems-
dependent
Peb.
Feb.
Nov.
Nov.
Nov.
Nov.
Oct.
Oct.
Apr.
Fall
•78
•78
*74
•74
'74
'74
•77
.77
'78
•78
Legend:
X » Saapled every 10 s
Y » Saapled every 5 Bin.
2 * Saapled continuously
0 ¦ Saapled every third day
2 ¦ Saapled every 10 s
H * Saapled every 30 s
0 « Saapled every 14 s
V » Saapled seven tiaes per day
every sixth day for 20 days in
spring and fall
T * Saapled continuously for 2 days
S * Saapled weekly
Also size distributions during
visibility study.
cStd. deviation calculated,
d
These stations also used to
obtain water quality of ppt.
measurements.
• 4 1
(1)
(N02> - (NO^) - (NO)
(continued)
-------
TABLE C-19. (continued)
Sampling
station
Monitoring
date
Relative Air
huiidity temperature
Precipitation Evaporation Barometric Solar
Temperature Mixing Visible Height SF
pressure radiation difference height range
Air-quality
trailer:
020
a)
b)
c)
a)
b)
021
023
024
026
Heather station £
hi-vol saapler:
042
056
Met. Tower 6
3 ¦
10 m
30 a
60 a
Upper air studies:
Minisonde
Acous. sound.
Visibility* station 060
Tracer studies
020
Jan. *78
July *78
1980
Systeas-
dependent
Hov. *74
1980
1981
Systeas-
dependent
Peb. *78
Feb. 178
Nov. *74
Nov. '74
Nov. '74
Nov. *74
Oct. *77
Oct. '77
Apr. *78
Pall *78
aLegend:
X » Sampled every 10 s
Y ¦ Sailed every 5 Bin.
2 ¦ Saapled continuously
0 » Saapled every third day
2 ¦ Saapled every 10 s
W * Saapled every 30 s
U * Saapled every 14 s
V • Saapled seven tiaes per day
every sixth day for 20 days in
spring and fall
T * Saapled continuously for 2 days
S * Saapled weekly
**Also size distributions during
visibility study.
c
Std. deviation calculated.
d
These stations also used to
obtain water quality of ppt.
aeasureaents.
Mil
(1)
-------
TABLE C-20. DEVELOPMENT PHASE EMISSION HCKITODING AT TRACT C-b
(Under EPA PSD Permit)
Typa of minion
Typa of tttck Kit in* so2 HjS Particulate CSj COS He i cap tan HO^ 00j CO Flow Rata Tsaf> Hoiiture Opacity
Tharaal oxidiiar XX X
Stratford la XX XXX XXX
Stratford out XX XXX XXX
Mlna vant XX X
Hina ahaft tranafar X X
Butt conveyor x X
BON ore handling X X
Stua hollar XX X X X X X
-------
Water Resources
Baseline Data Gathering Program-
Surface water gaging stations were constructed at 13 locations on or near
Tract C-b through a contract arrangement with the U5GS and the Colorado River
Water Survey and the Colorado River Water Conservation District. The locations of
these stations are shown on Figure C-19. Under this contract, the USGS Water
Resources Division Sub-District office in Meeker was responsible for operation and
maintenance of these stations.
Four of the 13 stations were located on perennial streams, and consequently,
sampling on these streams could be carried out on a uniform frequency. Sampling on
the remaining nine streams was opportunistic, however, and could only be done
during periods of stream flow. The surface water gaging stations are maintained
and operated continuously, either automatically or manually. A site log is kept at
each station to assure accurate sampling records.
Water quality—
Initially, water quality samples were obtained and analyzed every 2 weeks.
After the first year's baseline data were gathered and analyzed, the frequency of
sampling was changed to monthly, except for the analysis of trace elements and
insecticides, which was conducted quarterly (Table C-21).
Depth integrating samplers are used to collect water samples for analyses of
nonvolatile constituents and those unaffected by aeration. Some samples are
filtered through a 0.45-vim filter to remove turbidity. From the untreated filtrate,
the following determinations are made:
A second sample was filtered and acidified in the field with double-distilled,
reagent-grade nitric acid (HNO$) to obtain a pH of 3.0. The following
determinations were then made:
Chloride
Fluoride
Hardness
Lithium
Boron
Nitrogen nitrate
Nitrogen nitrite
Phosphorous
Potassium
Selenium
Silica
Sodium
Solids (dissolved)
Sulfate
Barium
Cadmium
Calcium
Nickel
Potassium
Silver
Aluminum
Arsenic
Chromium
Manganese
Molybdenum
Cobalt
Copper
Iron
Lead
Lithium
Magnesium
Sodium
Strontium
Vanadium
Zinc
C-71
-------
930600}
8
TRACT
Surface Water Gaging Station
Figure C-19. USGS stream gaging stations and springs and seeps utilized
during surface-water monitoring program at Tract C-b.
C-72
-------
TABLE C-21. SUMMARY OF SURFACE WATER AND GROUNDWATER SAMPLING SCHEDULE AT TRACT C-b
Baseline date gathering program
Development monitoring proqrai
Paraiseter
Surface water Springs £ seeps Groundwater
Surface water Springs £ seeps Groundwater
Aluminum
V
SA
Q (Z)
Q (A)
Q (Al), SA (Aq)
Alkalinity
M (Z)
Q (A)
Q (Al), SA (Aq)
Anmonia
S
V
SA
Q (Z)
M
0 (Al), SA (Aq)
Arcoatics, Polycyclic
Q (Z)
Q
-------
TABUS C-21. (continued)
Baseline data gathering program Development monitoring program
Parameter
Surface water
Sprinqa ( seeps
Groundwater
Surface water
Springs
£ seeps
Groundwater
Phenol
V
e
(PC)
Q
(A)
0 (Al), SA (Aq)
Potassium
S
V
SA
M
(Z)
Q
(A)
Q (Al), SA (Aq)
Radiation, alpha
8
V
SA
e
(PC)
S
SA (Al), SA (Aq)
Radiation, beta
Q (21
V
SA
0
(PC)
s
SA (Al), SA (Aq)
Rubidioi
V
Scandium
V
SA
Sediment
w
SA
Selenium
S
V
SA
0
(PC)
Q
(A)
Q (Al), SA (Aq)
Silica
S
V
H
(Z)
N
Silicon dioxide
SA
Silver
V
e
(A)
g (Al), SA (Aq)
Sodium
s
V
SA
H
(Z)
Q
(A)
Q (Al), SA (Aq)
Strontium
V
SA
Q
0
(Z)
Gross Alpha
c
(Z)
Gross Beta
Q
(Z)
A * Annually
SA • Sealannually
S ¦ Semimonthly
Q « Quarterly
M ¦ Monthly
C ¦ Continuous
X " Continuous when possible
V ¦ Variable schedule
(Z) ¦ Major gaging stations only
(0) » All gaging stations except
major stations
(PC) ¦ Piceance Creek gaging stations
(Al) » Alluvial wells
(Aq) ¦ Deep Aquifers
(A) = All springs and seeps (S-l, S-2, S-3, S-4, S-6, S-7, S-8,
S-9, S-10)
-------
An unfiltered and untreated third sample was allowed to settle its suspended
material in a cool, dark, place. The clear supernatant was analyzed for acidity,
alkalinity, color, pH, and C02.
Another unfiltered sample was well mixed and used to determine the
following:
This sample was kept chilled to prevent decomposition. Field determinations
include: (1) temperature, (2) pH, (3) dissolved oxygen, (<0 specific conductance, and
sometimes, (5) acidity and (6) akalinity. A summary of the surface water quality
analytical program requirements is presented in Table C-21.
Stream Flow-
Stream flow baseline data for Tract C-b were gathered at all 13 stream gage
stations. All stream gage stations were equipped with Leopold Stevens A35
recorders and analog strip charts. All recorders are weight drive and have stilling
wells located on the stream bank, connected to the stream by 5-cm (2-in.) pipes.
Springs and Seeps—
There are nine springs and/or seeps in and around Tract C-b that were
monitored during the baseline program for water quality and volume. Many of these
springs have also been monitored in the past by USGS and the Colorado Division of
Water Resources. A map showing the locations of springs and seeps in the Tract C-b
area is presented in Figure C-19.
Samples of water for chemical analysis were obtained from all the springs in
the area. Two springs, S-3 and S-9, were selected for detailed study and sampled in
February, April, May, June, July, August, and October of 1976 so that short-term
fluctuations could be analyzed. Spring flow measurements were made with Standard
Parshall flumes. In the case of spring S-9, a more precise measurement was made
by installing a turbine-type flowmeter downstream of the flume. Samples for
chemical analysis were drawn from Parshall flumes close to the spring itself, except
in the case of spring S-3. Because of the shallow depth at this sampling site, water
samples had to be drawn at a point further upstream. During the two-year baseline
program, a total of 30 samples was taken for water quality analysis. The water
quality parameters measured are listed in Table C-21.
Precipitation—
A precipitation recording network was created on and around Tract C-b
consisting of five water quality stations, four micro-environment stations, and five
modified air quality stations. The locations of these stations are presented in Figure
C-20. The stations were equipped with automatic tipping bucket snow-rain gages
(with heaters), cumulative precipitation storage gages, or small forestry gages.
Samples were taken of snow and rain at two locations around the tract.
Nitrogen, ammonia
Nitrogen, organic
Oxygen demand, chemical
Cyanide
Phosphorous
Solids, suspended
Solids, volatile
C-75
-------
<
i
AO
oai
wo
WLLOW CRCCK
NCAR MO 81>MC(
wa
STEWART OULCH
VABOVg WCST FORK
. N>*AH mo BLANCO
w
w
MICRO
SCAX5ARO \
-------
Water Level Records-
Water table levels were measured and recorded at 12 alluvial wells and 23
deep wells on and around Tract C-b (Figure C-21). Monthly level measurements
were taken with manually operated well sounders such as the Powers, M Scope, and
Soil Test models. These systems basically consist of two-strand conductive wire
marked at 3-m (10-ft) intervals, a reel and handle for winding, and a meter to
indicate electrical contact when water fills the gap between two exposed ends of
the wire. Initially, 15 wells were equipped for continuous monitoring with a
transistorized, level-seeking motor and reel assembly, a Stevens digital tape
recorder, and a clock mechanism to punch in hourly measurements. After 1 year,
continuous monitoring of wells was discontinued at all but two locations.
Water quality-
Samples for water quality analysis were drawn from the same wells used for
groundwater level determination. For the first year, both alluvial and deep wells
were sampled every 6 months. Sample frequency was decreased for the deep wells
during the second year and increased in selected alluvial wells. Alluvial wells were
sampled by pumping water directly with a submersible electric pump. Pumping
continued for 1 hr, with water temperature and conductivity being periodically
recorded. Samples were filtered in the field under nitrogen pressure and placed in
bottles for analysis. Water was pumped from the deep wells by means of a swabbing
rig. The water quality parameters analyzed are presented in Table C-21.
Interim Monitoring Program—
The interim surface water and groundwater monitoring program took place
from November 1976 to November 1978 and was covered by correspondence between
the lessee and the Area Oil Shale Office.
Surface water—Water quality measurements were taken at the surface water
quality stations shown in Table C-21. Figure C-19 presents the locations of the
surface water stations involved.
Precipitation—Precipitation data collection, managed by the USGS, ended in
October 1976. Data were collected at 5 of the 13 water-gaging stations presented
in Figure C-19. Precipitation data are also collected at two air quality stations, 020
and 023, by weighing buckets.
Springs and seeps—Water quality data were collected at six springs around the
tract. These springs were S-l, 5-3, S-6, 5-7, S-9, and S-10. The locations of these
springs are presented in Figure C-19. A description of the sampling and analyses
procedures is not available.
Groundwater—Water quality samples were taken from 11 alluvial wells and
from upper and lower aquifer wells. A description of the schedule and methods of
sampling and analysis are not available. The locations of these well sites are
presented in Figure C-21. Water level data and water quality data are reported in
Tables II-A-3 through II-A-8 of the Interim Monitoring Report No. 2 (26).
Development Phase Monitoring Program-
Surface water, springs and seeps, and groundwater are all being monitored for
quantity and quality during the development monitoring program phase. The time
periods covered during this program and the source of iitformation on the subject are
C-77
-------
A A-l
MMmrwsm
-•y^f^-Tract Boundary
rw^^OM
Figure 21. Alluvial and deep wells established in the Tract C-b area
and used during baseline monitoring.
C-78
-------
identical to those discussed in the development air quality and meteorology
monitoring discussion.
Surface water—Through a contract arrangement with the USGS, and the
Colorado River Water Conservation District, 13 water gaging stations were
constructed on and around Tract C-b. Nine of the stations are on ephemeral
streams and four are on perennial drainages. The stations contributing to the
developmental phase surface water monitoring program are listed in Table C-22.
The locations of these stations are presented in Figure C-19. Continuous
measurements of temperature and specific conductance will be made at all stations.
Dissolved oxygen and pH will be measured continuously at the four major stations,
and turbidity will be measured continuously at the two Piceance Creek stations.
The remaining water quality parameters to be measured at water quality sampling
stations are presented in Table C-18. Monthly, quarterly, and semiannual
monitoring will be carried out at: Stations 007, 022, 058, and 061; major stations
and stations on ephemeral streams; and major stations, respectively. Methods of
analysis will be identical to those utilized in the baseline program.
Springs and seeps--Water quality and quantity will be measured at nine springs
and seeps around Tract C-b. The locations of these sampling sites are illustrated in
Figure C-19. Water quality will be measured quarterly and quantity will be
measured weekly at all stations. The schedule of sampling and the parameters to be
measured is outlined below. Methods of analyses are identical to those used in the
baseline program.
Weekly. Discharge of the following springs and seeps will be measured on a
weekly basis: S-l, S-2, S-3, S-4, S-6, S-7, 5-8, S-9, S-10
Monthly. Each month the springs and seeps will be checked for pH,*
conductivity,* DO,* and temperature*. If the values are more than 20 percent
below minimum baseline values or more than 20 percent above maximum baseline
values, additional water quality samples will be obtained.
Quarterly. All springs and seeps will be sampled quarterly and analyzed for
the following parameters (starred items are indicator variables):
Ag
Mo
Ca
*TDS
*As
CI
Mg
SO-
Ba
Li
~Fluoride
CO,
Cd
A1
*B
HCOj
Cr
Sr
Ni
NOs
Cu
Se
Oil & Grease
Alkalinity
Fe
Zn
Temperature
Hardness
Hg
*pH
Kjeldahl-N
* Phenols
Mn
Na
COD
*Ammonia
Pb
K
BOD
Semiannually. All springs and seeps will be examined semiannually for
bacterial contamination (fecal and total bacteria) and radioactivity. DOC
fractionation will be examined for two springs to be selected in coordination with
the Area Oil Shade Supervisor.
c-79
-------
TABLE C-22. SURFACE HATER MONITORING STATIONS FOR THE DEVELOPMENT PHASE AT TRACT C-b
USGS
Station location
Comments
09306007 -
MAJOR
Piceance Creek below Rio Blanco
Operate during life of project
09306061 -
MAJOR
Piceance Creek at Hunter Creek
Operate during life of project
09306042
Unnamed Gulch west of Cottonwood
Gulch
Used to monitor road con-
struction activities, and
mine area developmenti
reevaluate at a later date
09306036
Gorghum Gulch at mouth
Operate during life of project
09306033
Sorghum Gulch upstream
Operate during ancillary, re-
evaluate at a later date
09306039
Cottonwood Gulch at mouth
Operate during life of project
09306022 -
MAJOR
Stewart Gulch
Consider reduction if data are
stable after period of com-
mercial operations
093060S2
Scandard Gulch at mouth
Operate during life of operatioi
09306058 -
MAJOR
Willow Creek
Consider reduction if data are
stable after period of com-
mercial operations
09306050
Scandard Gulch upstream
Operate during ancillary de-
velopment , reevaluate at
later date
09306028
West Fork Stewart mouth
Operate during ancillary de-
velopemnt, reevaluate at
later date
09306025
West Fork Stewart upstream
Operate during ancillary de-
velopment, reevaluate at
later date
09306015
Middle Fork Stewart Gulch
Operate during ancillary de-
velopment, reevaluate at
later date
09306033
Sorghun Gulch upstream
Operate during ancillary de-
velopment, reevaluate at
later date
-------
Annually. All springs and seeps will be examined annually for bromine. All
analyses except those for bacteria, radioactivity, and DOC will be performed at the
Occidental Oil Co.'s Grand Junction Lab.
Alluvial wells—Water quality and quantity of alluvial wells will be measured at
five new and 13 old alluvial test wells. The five new wells (A-2A, A-3A, A-5A,
A-6A, and A-7A) will be developed to detect any seepage in the main dumps at
Cottonwood and Sorghum Gulches, leakage from proposed storage dams, accidental
spills from plant operations, and runoff from construction activities. At this -date
only one well is completed. The locations of these wells are presented in Figure
C-22. Water quality will be measured quarterly at wells A-2A through A-7A and
semiannually at wells A-l, A-8, A-9, A-10, A-ll, and A-12. Monthly measurements
will be made for conductance, pH, temperature, and dissolved oxygen. Water levels
will be measured continuously at all stations. The schedule of sampling and
parameters to be measured are presented in Table C-21.
Deep Aquifers-
Samples will be taken from 17 upper-aquifer and 14 lower-aquifer wells around
Tract C-b. A list of the upper aquifer wells is presented as follows:
Upper aquifer monitoring network:
Before recompletions:
AT-1C #3
SG-1 #2
SG-6 // 3
SG-8 in
SG-9 in
Cb-2
Cb-4
SG-10A
SG-11 y/3
SG-17 in
SG-18A
SG-19
SG-20
SG-21
After recompletions:
UPCi
UPC2
Close in during ancillary development:
SG-1 in
SG-1 A
Cb-2
(UPC )
(UPCi)
(UPC2)
SG-6 #3
SG-10A it).
SG-20 in
AT-1B if 3
(UPCi),//l (UPC2)
(UPC*),#2 (UPCi)
(UPC2),//3 (UPCi)
(UPCi)
Remote during ancillary development:
Cb-2
Cb-4
(UPC2)
(UPC2)
C-81
-------
A Alluvial test wells
Figure C-22. Alluvial test wells in Tract C-b area during development
phase monitoring.
C-82
-------
SG-9 It 2
SG-11 #2
SG-17 #2
SG-18A #2
SG-19
(UPC2)
(UPC2),//3 (UPCi)
(UPC2),//3 (UPCi)
(UPC2),//3 (UPCi)
(UPCi)
SG-21 #3
(UPC2),#<* (UPCi)
Additional upper aquifer monitoring wells:
Federally owned:
TH 75 - 5A
TH 75 - 13A
TH 75 - 18A
TH 75 - 9A
TH 75 - 15A
CER RB - D - 02
Owned by Union Oil Co.:
Union 8 - 1
Owned by Atlantic Richfield:
Colony 12-596
The locations of these wells are illustrated in Figure C-23. Water quality samples
will be taken semiannually and water levels will be taken monthly. A sample will be
taken by swabbing. A summary of the sampling schedule and parameters to be
measured is presented in Table C-21.
In addition to the monitoring of the conventional water bodies in Tract C-b,
water quality measurement will be taken of water in Impoundment areas, shale
dump sites, and mine drift sumps. Many of the details of these programs are yet to
be determined, and hence program specifics are not outlined here.
Biological Resources
Baseline Data Gathering Program —
The biological resource baseline data gathering program was conducted from
November 1974 to November 1976. Work on the program was conducted by the
Ashland and Occidental Oil Companies. The published reports that have been used
as reference material for this report are the First Year Environmental Baseline
Program: Annual Summary (23) and the Final Environmental Baseline Program:
Final Report (24).
Vegetation—Five areas of interest have been studied in the vegetation data
gathering project. These areas are: Phytosociology, productivity, decomposition
and litter, herb phenology, and shrub stem growth. The sampling locations for these
studies are presented in Figure C-24.
C-83
-------
LEGEND
# Deep Wells
Figure C-23.. Deep aquifer monitoring well sites in Tract C-b area
during development phase monitoring.
C-84
-------
LEGEND
o
Intensive Study Plots
•
Vegetation Sampling Locations
A
Sampling Sites for Shrub
*•
Current Year's Growth Study
0 \2j i f
Miles
Vegetation sampling site locations used during baseline
data gathering at Tract C-b.
C-85
-------
As part of the phytosociology studies, a list of species was developed by
recording all species encountered during normal field sampling and specific species
sampling activities. A vegetation map was prepared by using air photo and field
checking methods. After the vegetation had been sampled and mapped, tree
densities, frequencies, and basal areas were estimated using the point quarter
method. Shrub cover, density, and frequency were estimated using the line strip
method; and herb frequency and ground layer parameters were estimated using the
quadrant method.
Production was determined using the harvest method for herbs and shrubs, and
new shoots were determined by clipping and weighing.
Decomposition was studied by enclosing leaves of a known weight in nylon
mesh bags and placing them in the field on the surface and at 10 cm (4 in.) depth.
After a period of time, the bags were retrieved and weighed. Litter fall in the
woodlands was studied using litter traps.
Herb phenology was studied by sampling of permanently marked quadrants and
the measurement of eight growth stages in the separated samples.
Shrub stem growth was determined by repeated measurement of marked twigs.
A summary of the vegetation sampling and phytosociological studies is presented in
Table C-23.
Big game—Big game data gathering programs were oriented around mule deer
and elk. Mule deer movement patterns were determined by track counts on major
north-south ridges, on and around Tract C-b. This program was conducted during
fall and spring. In addition, road counts and fixed-wing aerial reconnaissance was
used. Mule deer habitat utilization was measured with pellet group counts. The
counts were carried out in pinyon-juniper woodland, chained rangeland, upland
sagebrush, and pinyon-juniper bottomland brush (springs of 1975 and 1976). Browse
production and utilization were determined by shoot measurements in pinyon-juniper
and chained rangeland (spring of 1976). Browse conditions in mountain mahogany,
bitterbrush, serviceberry and big sagebrush were determined by visual estimates
(1975 and 1976). Carcasses of mule deer were examined and recorded to analyze
circumstances.
Medium-sized mammals—Scent station lines and track count methods were
used to quantify the presence of such mammals as coyotes, foxes, mountain lions,
etc. Identification of medium-sized mammals was based on direct observation for
all except bobcat and badger. Habitat affinity was determined by sampling within
four habitat types: pinyon-juniper, chained rangeland, bottomland sagebrush, and
agricultural meadow. Sampling periods occurred in September of 197<* and 1975.
Small Mammals—Small mammal populations were sampled quantitatively at
two grid locations (chained pinyon-juniper rangeland and pinyon-juniper woodland)
and completely inventoried on nine satellite grids (-all other vegetation areas).
Sampling was conducted during the months of May, June, July, August, and
September and, in addition, once during December and January on the satellite
grids. Analysis of food habitats were conducted on animals trapped on grids one and
two.
C-86
-------
TABLE C-23. SUMMARY OF PHYTOSOCIOLOGICAL STUDIES AND VEGETATIVE SAMPLING IN BASELINE
VEGETATIVE DATA GATHERING PROGRAMS AT TRACT C-ba
Type of
No. of
No. of quarter
No. of shrub
No. of herb
vegetation
sampled
method tree
transects
quadrants 1. i
stands
points/stand
per stand
per stand
Pinyon-juniper woodland
3
40
20
20
Douglas-fir forest
1
—
10
10
Mixed mountain shrub
1
—
20
20
Chained rangeland
3
—
20
20
Upland sagebrush
3
—
20
20
Bottomland sagebrush
2
—
20
20
Greasewood
1
—
20
20
Rabbitbrush
1
—
20
20
Bunchgrass
1
—
20
20
Disturbed Sites
7
—
—
10
(annuajL weed)
Marshes ^
Great Basin wild rge
Riparian community^
Agricultural areas
Ponds
No sampling data
No sampling data
No sampling data
No sampling data
No sampling data
aSource: Reference 23.
These vegetation types are very limited in extent
munities are based on observations only.
within the study area. Descriptions of these com-
-------
Birds—A strip census procedure was implemented to provide data from which
bird densities could be extracted. The width of strip transects and methods of
density determinations were adjusted for each particular bird group being measured.
The species being studied were songbirds, upland gamebirds, waterfowl and
shorebirds, and raptors. The sampling schedule is presented in Table C-24.
Amphibians and Reptiles—Sampling of amphibians and reptiles was conducted
on small mammal grids 1 and 2 during the months of May through September in 1975
and 1976. Ten transects, 150 m (492 ft) in length, were surveyed on each grid.
Identification not founded on grids one and two were made on an opportunistic basis.
Arthropods—Ground and shrub-dwelling arthropods were sampled on grids 1
and 2 using pitfalls spaced 15 m (49 ft) apart. Shrubs were sampled by beating
branches to dislodge arboreal insects. Total number of individuals, species diversity,
and number of individuals were compared in each shrub species, season, and
location. Sampling was carried out between May and September.
Fish—Studies were conducted on local fish to determine species abundance,
data on age and size ratios, migration, spanning, distribution, and aquatic habitat.
Other Aquatic Organisms—Data on aquatic organisms in the springs and seeps
of Tract C-b were accumulated at 20 sampling stations on the Piceance, Stewart,
Willow, and White Rivers. Plankton, periphyton, benthos, and fish samples were
taken for analysis.
In addition to the baseline data gathering programs described here, a study was
conducted to determine the interrelationships of the Tract C-b ecology and to
discuss possible mitigation programs for adverse impacts resulting from Tract C-b
development.
Interim Monitoring Program—
The interim biological resources monitoring program took place from
November 1976 to November 1978 and was controlled by correspondence between
the lessee and the Area Oil Shale Office.
Terrestrial Wildlife Studies—Data were gathered from September 1, 1977,
through April 1, 1978. Discussion of the tabular data contained in this section will
be restricted to a brief description of the methods used. Figure C-25 depicts the
biological program station locations.
Mule Deer Road Counts. Mule deer road counts were conducted in the same
manner as during baseline studies. A 56-km (35-mile) length of road was driven
(from Rio Blanco to Little Hills), and all deer observed were recorded within 1.6-km
(1-mi) intervals. All counts were made during late evenings. Beginning on January
25, 1978, the road count was extended seven miles to include the entire 66-km
(41-mi) length of the Piceance Creek road.
Deer Pellet-Group Studies. Deer pellet groups were cleared along 27 transects
located in two habitat types, pinyon-juniper and chained rangeland. Pellet groups
were cleared from the plots in September 1977.
C-88
-------
TABLE C-24. SCHEDULE OP BASELINE DATA COLLECTION ON BIROS AT TRACT C-b*
Strip transect number Night owl Waterfowl Raptor nest Pellet cast
Census period
1
2
3
4
5 h SB
6
7A
7B
8
transects
counts
survey
collections
October 1974
lb
X
1
X
1
X
1
X
1
X
1
X
1
X
1
X
X
X
Noveaber 1974
1
X
1
X
1
X
1
X
X
X
January 1975
1
X
1
X
1
X
1
X
1
X
1
X
1
X
1
X
X
March 1975
1
X
1
X
1
X
1
X
X
X
Hay 1975
1
X
1
X
1
X
1
X
1
X
1
X
• 1
X
1
X
X
X
X
X
July 1975
1
X
1
X
1
X
1
X
X
September 1975
1
X
1
X
1
X
1
X
1
X
1
X
1
X
1
X
X
October 1975
X
Deceaber 1975
X
X
X
February 1976
3
X
3
X
3
X
3
X
3
X
1
X
1
X
1
X
X
X
April 1976
3
X
3
X
3
X
3
X
3
X
1
X
x*
1
X
X
X
May 1976
X
X
X
June 1976
3
X
3
X
3
X
3
X
3
X
1
X
x1
1
X
July 1976
1
X
1
X
I
X
1
X
X
X
aSourcet Reference 23.
¦ Transect saapled once during census period,
x « Transect saapled in triplicate during census period.
-------
vo
VF
LEGEND
Ornithological Gamebird Study Transects
Deer Pellet and Browse Utilization Transects
Water Gaging Station - Benthos
~ VO „ t VOOpen (50x70m)
~ VF Ve9etata.on Site: (50x70m)
Microenvironmental Station
O Fish Sampling —— Predator Survey Lines
• Periphyton ^ Other Sensitive Areas
Figure C-25. Interim phase biological resource monitoring
program at Tract C-b.
C-90
-------
Deer Road Kill. The deer road kill count was started in October and concluded
in May 1978. Counts were made from a vehicle driving approximately 50 kmph (30
mph). When a carcass was found it was tagged, so as not to be recounted.
Carcasses were aged using tooth wear criteria. Mileage from starting point was
noted. Other road kills (domestic and wild) were also noted; only large animals were
tagged.
Deer Mortality. No studies were conducted during this period. The study will
be conducted in June, as described in the Development Monitoring Program for Oil
Shale Tract C-b (27).
Age Class Composition of Deer. Age class estimates of deer were obtained by
observations of deer in the agricultural meadows near Piceance Creek during
November 1977.
Coyote Abundance. The coyote scent station transects were conducted in
October in the same manner as baseline studies. The only change was the addition
of two 24-km (15-mi) transects on and around Tract C-b.
Lagomorphs. Lagomorph pellet counts were conducted in the same plots that
were used for deer pellet counts. Plots were cleared of pellets in September 1977.
Small Mammals. No studies were conducted during this period; however, some
changes were made in the program. The grids were changed to live transects.
There were four study sites: Two in agricultural meadows, one in pinyon-juniper
woodland, and one in chained pinyon-juniper. The meadow transects are north of
Tract C-b, while the other two transects are on the tract. The two study sites in
the meadows have four transects apiece, while the remaining sites have two
transects apiece. Each transect consists of 25 live traps at 15 m (49 ft) intervals.
Traps were checked for three consecutive nights. Studies were conducted in June
and in September.
Avifauna. No study was conducted during this period; however, some changes
were made when the study was conducted in May 1978. Sampling frequency was
increased from three to four. Also, one international census plot was conducted this
year to compare results with the Emlen strip transect method.
Shrub Productivity and Utilization. Browse shrub species were tagged in
September along the 27 deer pellet group transects. Methods of tagging were the
same as those in baseline studies; however, some changes have been made. Only
bitterbrush were clipped and measured as in baseline studies. Mountain mahogany
was discontinued. Visual estimates of sagebrush were conducted along the same
deer transects. Periods of sampling remained the same: June and September.
Aquatic studies—Aquatic sampling was reduced from baseline studies, both in
sampling frequency and locations (see Figure C-25). Periphyton was not done from
September to March. The sampling period began in April 1978 and ran through
September 1978. Benthos was sampled when possible. Fish studies were
systems-dependent (they were done if a significant difference was noted in
periphyton or benthos).
C-91
-------
Benthic invertebrates were collected monthly by the USGS at three locations:
Piceance Creek near Rio Blanco, Willow Creek, and Piceance Creek upstream from
Hunter Creek. Some winter months were not sampled because of ice on the creek.
Benthos studies were done by the USGS at monthly intervals. Benthic invertebrates
were identified to order, family, and species.
Periphyton data were not collected for this period. Periphyton sampling was
an important indicator of water quality. Beginning in April 1978, and running
through September 1978, periphyton was sampled every 30 days, with collectors used
continuously.
Terrestrial vegetation studies--
Vegetation Community Structure and Composition. Data were not collected
for the winter period. Starting in 1978, sampling was carried out on a 3-year
rotational basis. Each plot will be sampled every 3 years, two plots each year.
Herbaceous Productivity and Utilization. Data were not collected for the
winter period. In 1978, sampling continued on the exclosure and unfenced plots. A
new evaluation tool was used this year—range cages in major vegetation types
provided additional vegetation type productivity and utilization data.
General Condition of Vegetation with Colored Infrared Photography.
Vegetation condition was not done on a routine basis previously, but it was planned
for 1978 and thereafter to detect vegetation stresses and changes.
Development Phase Monitoring Program—
The environmental monitoring program that is taking place now during the
development phase of the Tract C-b oil shale project was initiated in February 1978
and will continue through project development. The source of information for the
biological resources section of this report is the Development Monitoring Program
Supplement (27).
Big game - deer—Deer days of use will be estimated by pellet-group counts.
Fifteen permanent transects are located in the chained pinyon-juniper, and 12
transects are located in the pinyon-juniper woodland. Each transect consists of 20
plots that are raked free of pellets in the fall and surveyed in the spring.
Distribution and migration of deer will be determined by use of vehicle counts.
Weekly sampling will be conducted between mid-September and the end of May.
Deer counts will begin 15 min before dusk, and the deer will be counted at 1.6 km
(1-mi) intervals.
Deer mortality will be determined by two methods: road kill and permanent
plot surveys. The deer will be located, plotted, and identified by age using the teeth
wear methods. The location of the deer mortality plots is illustrated in Figure
C-26. Mule deer age class will be determined by observation in meadows within a 8-
km (5-mi) radius of Tract C-b. Points on buck antlers will be counted once in fall
and once in spring.
Other animals—Medium-sized animals, including coyotes and lagomorphs
(cottontails and jackrabbits), will be surveyed on and around Tract C-b. Coyote
C-92
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' vo
yO
vo
LEGEND
— - - Deer Pellet and Browse Utilization Transects
Ornithological Gamebird Study Transects
Predator Scent-Post Survey Lines
Deer Distribution and Migration
VO=Open (50x70m)
VF»Fenced (50x70m)
Microenvironmental Station
Small Mammal Trap Site
Deer Mortality Sites ™
X
~ vo
~ VF
¦
UMIIHI
0
Vegetation Sites:
C-b Power Line
Public Power Line
Water Gaging Station
Aquatic Sampling Site
'Study Area Boundary
Figure C-26. Developmental phase biological resource monitoring
program sites at Tract C-b.
C-93
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abundance will be determined using the scent post survey. Lagomorphs will be
counted for density using pellet counts on established plots. Small mammal
population estimates will be obtained by live trapping and mark and release methods
on line transects.
Birds—The species and abundance of songbirds will be determined by the
Emlen strip method, within 3.5 hr of sunrise and sunset. The specified procedures
used in the baseline program will be employed three times during segments of the
breeding season. Upland gamebirds and mourning doves will be studied for relative
abundance using the same methods employed in the songbird program. Utilization
and habitat data for raptors will be established by nest inspections during various
breeding seasons throughout the year.
A monitoring program will be established to keep track of any threatened and
endangered species in the area. Peregrine falcons, greater sandhill cranes, and bald
eagles have been noticed in the area during the baseline and interim programs.
Aquatic ecology—The variables of the aquatic program to be sampled through
the environmental monitoring program are benthos, periphyton, and water quality.
Because aquatic ecosystems could be secondarily affected by on-tract mining and
development, aquatic monitoring is essential. Benthos and periphyton are
"indicators" of a significant change in stream characteristics downstream from oil
shale development. The specific changes should be apparent in water quality
parameters. In addition to the quarterly water analysis, daily water samples will be
collected and stored for a month after periphyton are sampled and analyzed. (Water
quality sampling will be coordinated with that for hydrology.) If significant
differences are noted in the primary indicators (periphyton and benthos), these daily
samples can be analyzed to determine if changes in aquatic biota are due to a
change in water quality. Also, if a significant difference is noted, a systems-
dependent study (fish shocking) may be initiated. The daily water sampling will
reflect rapid changes in water quality that may be short-lived but may still have an
effect on the aquatic biota. Statistical comparisons to baseline data would show
alterations of baseline conditions and indicate, through correlation coefficients, the
severity of the impact so that timely corrections of detrimental conditions could be
made.
Benthic organisms will be sampled at three locations by the USGS. The
sampling itself will be accomplished by a Surber sampler, and the methods will be
identical to those employed during the baseline and interim programs. The aquatic
ecology sampling schedule is included in Table C-25. The collection of periphyton
will take place at two sampling sites, on a monthly basis from May to November.
Artificial substrates will be incubated for 21 days, weighed, dried, biomass
extracted, and taxonomically identified. Water quality in the designated study
streams will be analyzed according to the schedule laid out in the Hydrology section.
In addition to this monthly and quarterly sampling, daily sampling will be conducted.
If a change in benthos is noticed, the daily samples will be analyzed. The locations
of the sampling sites in the aquatic ecology monitoring program are presented in
Figure C-26.
Terrestrial vegetation studies—Two control and two development plots have
been established representing the two major habitat types in the Tract C-b area,
namely, chained pinyon-juniper rangeland, and pinyon-juniper woodland. These plots
oa4
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TABLE C-25. SUMMARY OF DEVELOPMENT PHASE BIOLOGICAL
RESOURCE MONITORING PROGRAM
Approximate
Variable
Sampling period and/or intensity
starting date
Deer days of use
Once per year in chained pinyon-
June 1
juniper rangelands and pinyon-
juniper woodlands.
Distribution
Mid-September through May -
September 15
and migration
Highway 64 to Rio Blanco.
Road kills
Mid-September through May -
September
Highway 64 to Rio Blanco.
Mortality
Once each year in spring in
June 1
lateral draws and bottomland sage-
brush north of Tract.
Age-class
Twice each year in fall and
November and
spring in meadows adjacent to
April
Piceance Creek.
Medium-sized mammals:
Coyote abundance
Once each year along 24 km of
September
road segments on Tract C-b and
24-km segments west of Tract C-b.
Lagomorph
Once each year in the chained
June 1
abundance
pinyon-juniper rangelands and
pinyon-juniper woodlands.
Small mammals:
Twice per year in spring and early
June 1 and
fall in chained pinyon-juniper
September 15
rangelands, pinyon-juniper wood-
lands, and bottomland hay meadows.
Avifauna:
Songbird relative
abundance and
Three times each year in pinyon-
May 15
species
juniper rangelands and pinyon-
composition
juniper woodlands.
Upland gamebirds:
Mourning dove
Three times each year in pinyon-
May 15
relative abundance
juniper rangelands and pinyon-
juniper woodlands.
(continued)
C-95
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TABLE C-25. (continued)
Variable
Sampling period and/or intensity
Approximate
starting date
Raptor activity
Aquatic ecology:
Benthos
Periphyton
Water quality
Terrestrial vegetation:
Community
structure and
composition
Herbaceous
productivity and
utilization
Shrub productivity
and utilization
Shrub productivity
and utilization
General condition
of vegetation
Micro-climactic
studies
Twice each year during the appro-
priate breeding season, nest
occupancy will be checked. Also,
throughout the year, all raptor
sightings within the study boundary
will be recorded.
March and
June
Monthly - except winter, when
inaccessible.
Monthly through growing season.
Daily with analysis only if
significant difference is noted
in Benthos or Periphyton.
Three-year rotational sampling in
each of the six extensive study
plots established in the four
major vegetation types.
Once each year in four exclosure
locations and 65 range cages
established in the four major
vegetation types. In addition,
five line transects for sampling
the fertilization plots.
Once each year in six exclosure
locations and 60 range cages
established in the four major
vegetation types.
Twice each year along 31 transects
used for deer days of use.
Yearly over all the tract.
Twice monthly at ten baseline sites.
April and
September
June 10
July 1 -
Exclosures,
August 1 Cages,
transects
July 1
June and
September
June 10
(starting in 1979)
C-96
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will be surveyed on a 3-year rotational basis; each plot will be sampled every 2 years
(two plots each year). Shrub frequency, density, cover, cover by litter, soil, rock,
lichens, mosses, and woody seedlings will be measured. Six sites (two development
sites and two control sites for pinyon-juniper and chained pinyon-juniper, and two
control sites for bottomland sagebrush) will be utilized to estimate herb production
and utilization. The vegetation will be clipped, using the double sampling approach,
weighed, and compared to vegetation samples from nonfenced areas. Additional
determinations are made using 40 range cages and by visual investigation. Shrub
utilization and production is determined by taking measured samples along the same
development and control transects used for deer days of use. Visual estimation is
also used. The condition of the general vegetation is determined through the use of
aerial photogrammetry, including color-infrared and color film taken by fixed-wing
aircraft. There are 10 established microclimatic stations in Tract C-b—five on
control sites and five on development sites (Figure C-26). Each station is monitored
twice monthly for air temperature, soil temperature, precipitation, snow depth, and
moisture content.
Revegetation of the disturbed sites in the Tract C-b project area will be
monitored for vegetative structure, composition, and productivity.
In addition to the established biological resource monitoring projects,
additional projects will be initiated if a change in a local ecosystem is detected by
measurement of an indicator variable moving above a threshold level. Such
additional programs are referred to as systems dependent monitoring programs. For
example, these programs might include the sampling of fish as a reflection of
change in benthos or periphyton, the measurement of pollutants in plant tissue if
significant differences in herb production are noticed, and the measurement of
toxicity in plants, soils, and air.
Solid Wastes Disposal, Revegetation
Baseline Data Gathering Program—
During the time period covered by baseline data gathering operations no
experimented revegetation studies were conducted at Tract C-b. However, a close
watch was kept on the revegetation studies being done by the Occidental Oil Co. and
the Colony Development Operation to stay informed of any problems and potential
solutions.
Interim Monitoring Program—
The interim solid waste, revegetation monitoring program took place from
November 1976 to November 1978 and was controlled by correspondence between
the lessee and the Area Oil Shale Office.
Development Phase Monitoring Program-
In 1979, an experimental plot was constructed to test the reclamation
methodology planned for spent shale disposal embankments. Plant species,
fertilization, mulches, and irrigation are tested. Half the plot is irrigated with 1233
cubic meters (1 acre-ft) of water over a 2-year period and the other half is not
irrigated. Both sides have independent drains to collect any leachate. The leachate
quality is compared with rainfall to determine effects on water quality from an
embankment of 45.7 cm (18 in.) of soil-like material over raw shale. Parameters to
C-97
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be measured are the same ones that are important for the hydrology program with
regard to impoundments (see Table C-22).
A program of revegetation will be submitted to the Area Oil Shale Supervisor
before any solid waste disposal from oil shale mining and/or retorting.
Noise
Baseline Data Gathering Program—
The baseline noise monitoring program was conducted between November 1974
and October 1976. The two published documents that have been used most for
reference in this report are the First Year Environmental Baseline Report (23) and
the Final Environmental Baseline Report (24).
Two sets of noise measurements were made on Tract C-b during baseline
monitoring. One set of measurements was geared toward traffic noise, and the
other toward ambient background noise. The traffic noise was measured by the
State of Colorado Highway Department at 13 locations in the general area of the
Piceance Basin. The State Highway Department provided a correlation curve to
estimate noise from traffic level at locations 152 m (500 ft) from the highway.
Additional noise level measurements were made at 14 locations around Tract C-b to
determine background noise levels. The locations of these sites are presented in
Figure C-27. The measurements were made !rom September 1975 to October 1976
with a General Radio Type 1565-B sound level meter. A windscreen was used for all
outdoor measurements and no measurements were made with winds greater than 48
kmph (30 mph). The microphone was pointed at right angles to the direction of the
estimated noise path.
Interim Monitoring Prograim—
The interim noise monitoring program took place from November 1976 to
November 1978 and was controlled by correspondence between the lessee and the
Area Oil Shale Office.
Traffic noise measurements were made 1 day/month approximately at morning
shift change at Stations II and XV (Figure C-27) along Piceance Creek Road and on
the access road at the tract boundary, respectively. The General Radio 1565 sound
level meter was used to measure peak noise levels at A weighting. Background
levels (i.e., no traffic) were obtained the same day at A, B, and C weightings.
Tract noise surveillance has been determined since February 1978 at Station
XV, located in the vicinity of proposed ancillary development activity. The B & K
precision sound level meter (model 2203) was located on the tract northern
boundary. Continuous noise measurements at A weighting were made for 24 hr
every sixth day. The single station acted as a control during off-shift or quiet
intervals, and as a development site during operational periods of the day.
Development Phase Monitoring Program—
During the development phase monitoring program, a continuation of the
baseline and interim noise measurement program is being accomplished. The
program is described in the Development Monitoring Program for Tract C-b (20).
C-98
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II
XV
LEGEND
Traffic Noise Station
Shift Change - 1 day/wk
Tract Noise Surveillance
Continuous - every 6th day
Figure C-27. Environmental noise monitoring network at Tract C-b.
C-99
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Measurements are made of traffic and ambient tract noise as a continuation of
the baseline and interim programs. Traffic noises are measured at Stations II and
XV of Figure C-27. Peak and background noise levels are measured weekly with a
General Radio 1565 sound level meter and recorded monthly.
Continuous background tract noises are measured at Station XV on the
northern boundary of Tract C-b continuously for 24 hr every sixth day. During the
peak of deer migration, the recorded numbers are correlated with noise
measurements. The recording system consists of the following B <5c K instruments:
Radioactivity
Baseline Data Gathering Program—
During the baseline monitoring program, radioactivity was measured in the air
(residue from high-volume filter) and in the water as described in the hydrology and 1
air quality sections of this report. No background radioactivity measurements were
conducted.
Interim Monitoring Program—
The interim radioactivity monitoring program took place from November 1976
to November 1978 and was reported by correspondence between the lessee and the
Area Oil Shale Office. No specifics on the project are available for publication.
Development Phase Monitoring Program—
During the period of development, the monitoring of radioactivity is limited to
the conventional water and air quality radioactivity measurements as described in
the baseline program report. If the Area Oil Shale Supervisor feels at any time that
further measurements of radioactivity in the air or water are merited, the lessee
will comply.
Surface Subsidence
Baseline Data Gathering Program—
During the baseline data gathering program of November 1974 to October
1976, no studies were done to determine the degree of existence or nonexistence of
surface subsidence, if any, on Tract C-b.
Interim Monitoring Program—
The interim surface subsidence monitoring program took place from November
1976 to November 1978 and was reported by correspondence between the lessee and
the Area Oil Shale Office. No specifics on the project are available for publication.
Model UA 0393
Model UA 0381
Model UA 0308
Model 2306
Model 4230
Model 2203
Precision sound level meter with
1.27 cm (0.5-in.) microphone
Portable acoustic calibrator
Microphone rain cover
Wind screen with spikes
1.27 cm (0.5-in.) Dehumidifier
Portable graphic level recorder
C-100
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Development Phase Monitoring Program—
A surface and underground subsidence monitoring network will be designed and
will be in place and operational before the initial rubblization blast.
The surface monitoring network will consist of the following:
For the two- and four-retort auxiliary phase developments:
1. Two mutually perpendicular level lines meeting at the center of the
module.
2. Level stations spaced at approximately 30.5 m (100 ft) apart.
3. Base control run to stable ground at each of the level lines.
4. Control lines extending approximately 73.2 m (240 ft) beyond the
mining development.
For the commercial development:
1. Parallel level lines are to be established along the barrier pillars and
along the middle of the panel.
2. Level stations are to be installed at approximately 30.5-m (100-ft)
intervals along the level lines.
3. Cross links between lines will be established at 91.5-m (300-ft)
intervals with individual stations at approximately 30.5-m (100-ft)
intervals
The equipment and procedures for use in the level surveys are:
1. A self-leveling engineer level, optical micrometer, and invar staves
will be used for measurements.
2. Normal differential-leveling surveying techniques will be used to
alleviate surface effect as a result of moisture and temperature
3. Permanent, standard level monuments will be used to alleviate
surface effect as a result of moisture and temperature.
4. The expected accuracy of single measurements are on the order of
0.015 cm (0.0005 ft).
The underground monitoring effect includes:
1. The mine surveying network will be utilized to determine vertical
and horizontal displacements on all mining levels.
2. A resurvey of the underground survey network will be undertaken at
yearly intervals, and changes in vertical and horizontal distances
will be tabulated.
C-101
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For the distance and angle measurements for horizontal and vertical
displacements:
1. Distances are to be measured with an electronic distance-measuring
device from selected base stations.
2. Angles are to be measured with a theodolite (1-s accuracy) from
selected base stations
3. Adequate primary, secondary, and tertiary base controls will be
established to determine horizontal changes between level stations.
The equipment and procedures for use in distance and angular surveys are:
1. An electric distance-measuring device and accessories will be used
to measure distances.
2. A theodolite (1-s accuracy) will be used for angular measurements.
3. A primary triangulation network will be established on stable ground
and maintained for the project life.
For the aerial photography to inventory the physical features of the site, the
work includes:
1. A 1/6000 scale photography to inventory site physical condition.
This photography occurs at yearly intervals in black and white. It is
the same photography as in:
2. A 1/1000-scale photography over active mining areas to provide the
details of subsidence-caused effects on the surface and to
photograph at yearly intervals areas mined in the previous 2 years,
and areas in which mining is to be undertaken in the next year.
3. Equipment and procedures for aerial photography include standard
air photo techniques to produce stereo pairs and controlled mosaics,
field premarking to be established for the project life and renewed
annually before photographing, and taking of the photographs at the
same time each year in the spring.
For the specific monitoring in the shaft pillar areas the work includes:
1. Two lines at right angles across each shaft pillar that will extend
into the rubblized areas.
2. Level stations established at approximately 30.5 m (100 ft)
intervals.
3. Five tiltmeters established in each shaft pillar (one tiltmeter is
located in each quadrant of the pillar near the boundary with
rubblized rock, and the fifth tiltmeter is located near the shaft
pillar center.
C-102
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For the surface vibration measurements the work includes:
1. Establishment of three continuous-reading accelerometer stations at
widely-spaced intervals at surface.
2. Mounting of accelerometers on concrete pads coupled to bedrock
(location on stable ground is not influenced by rubblized retorts).
3. Provision of a quantified assessment, by means of accelerometer
data, of the magnitude and duration of the rubblization blast-
induced vibrations and, in addition, any pinpointing of any
earthquakes that might be induced onsite.
TRACTS U-a and U-b
Air Resources
Baseline Data Gathering Program-
Baseline Data Gathering Programs were conducted in accordance with the
terms of Oil Shale Leases U-25918 (U-a), and U-26194 (U-b) as issued on 3une 1,
1974, by the U.S. Department of the Interior. Both tracts are in Uinta County,
Utah, approximately 80 km (50 mi) southeast of Vernal, Utah. The tracts are each
2073 ha (5,120 acres) and are contiguous with one another (see Figure C-28).
The information contained in this report was taken from First Year
Environmental Baseline Report, White River Shale Project, Tracts U-a, U-b,
Volumes 1 and 2 (30), and Final Environmental Baseline Report; White River Shale
Project, Tracts U-a, U-b (3lX
White River Shale Project (WRSP) (Sunco Energy Development Co., Sohio, and
Phillips Petroleum Co.) baseline studies were conducted between the years 1974 and
1977 by VTN Colorado, Inc. and the following subcontractors:
1. AeroVironment, Inc. (Air Resources)
2. Utah State University
Dr. Cyrus McKeil, Vegetation
Dr. Ned Bohart, Terrestrial Invertebrates
Dr. 3ohn Skujins, Microbiology
Dr. Don Dwyer, Range Science
Dr. David Bolph, Ecological Interrelationships
Dr. Martha Bolph, Ecological Interrelationships
Mr. Alvin Southard, Soils
3. Utah Division of Wildlife Resources
4. U.S. Geological Survey
5. Utah Historical Society, Archaeology
Dr. David Madsen
C-103
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Flaming Gorge Reservoir
Wyoming
Utah
Ducnesne County
Vernal
Roosevelt
Dinosai
Uintah
County
40
Ducnesne
White
lonanza
Tract U-a-^
Colorado
Tract U-b
30
Carson
County
l> Green
Price
sook
VCliffs
43
Book
Cliffs,
Grand
County
32 KM
Green
River
7o,
20 M
10
SCALE
Figure C-28. Location map for Tract U-a and U-b projects.
C-104
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6. Brigham Young University, Paleontology
Dr. Wade Miller
7. Fugro Inc., Geology
8. Richter and Associates, Seismicity
In the first year of baseline data gathering, eight monitoring stations were
developed to sample air quality parameters in the area. The stations were situated
so that every 13 km2 (5 sq mi) was occupied by one monitor (Figure C-29.) The air
quality and meteorological parameters measured are presented in Table C-26, the
parameters measured at each air quality station are shown in Figure C-29.
Sulfur dioxide (SO2) and hydrogen sulfide (H2S) were measured by gas
chromatography using a flame photometric detector. Carbon monoxide (CO) was
also measured by gas chromatography utilizing a flame ionization detector after the
catalytic conversion to carbon dioxide (C02). Total and nonmethane hydrocarbon
(NMHC) were separated by gas chromatography and measured by flame ionization
techniques. Ozone was monitored by chemiluminescence of NO with ozone,
catalytic conversion of NOx to NO for similar chemiluminescent measurement, and
subtraction of NO from NOx to give nitrogen dioxide (NO2) (see Table C-26).
All major air quality instruments were calibrated quarterly and by secondary
calibration standards (permeation tubes and compressed gas mixtures) after each
malfunction. The secondary standards were in turn calibrated quarterly by
EPA-prescribed wet chemical analysis procedures (32). The estimated accuracy of
the methods and instruments used is presented in Table C-26.
From data gathered in the first year of baseline work, it was determined that
certain monitoring programs were unnecessary and that certain corrections to the
second year program were in order. The following items were terminated for the
second year baseline program, with approval from the Area Oil Shale Supervisor:
1. Measurements on coefficient of haze,
2. Air quality monitoring (H2S, SO2, and suspended particulates) at
Station Al,
3. S02, H2S, suspended particulate, N02, HC, CO, and O3
measurements at Station A2,
k. NO2, HC, CO, and O3 measurements at Station A3,
5. All air quality monitoring (hhS, SO2, and suspended particulates) at
Station A5,
6. All air quality monitoring (H2S, SO2, and suspended particulates) at
Station A8.
After the first year of baseline meteorological data gathering, certain
adjustments were made to the monitoring program. Five of the 12 monitoring
stations were shut down, and one new one was developed.
C-105
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Kilometers
Sulfur Dioxide
Hydrogen Sulfide
Suspended
Particulates
Carbon Monoxide
Hydrocarbons
Ozone
Nitrogen Dioxide
Coefficient of Haze
Local Visual Range
Trace Metals
Visibility
SO2 h2S
White
River
so2 co no2
h2s hc
SP 03
ation
Evacu
( Cree
<8>
H-,S
Figure C-29. Location map for Tracts U-a and U-b air quality monitoring stations for the baseline
data gathering programs.
-------
TABLE C-26. AIR QUALITY PARAMETERS, MONITORING INSTRUMENTS, AND TOTAL
ACCURACY OF THE BASELINE AIR QUALITY PROGRAM FOR TRACTS U-
ROOT-MEAN-SQUARED
-a AND U-b
Parameters
Honitorlnq instruments
Total RMS accuracy
Sulfur dioxide
Tracor 270 HA sulfur analyzer—
gas chromatography
+ 71 or 4 ppb
Hydrogen sulfide
Tracor 270 HA sulfur analyzer-
gas chromatography
12% or 8 ppb
Total sulfur
Tracor 270 HA sulfur analyzer—
gas chroetatography
Nitrogen oxides
(NO, NOg, N02>
Monitor Labs Model 8440 N0X
analyzer— chemiluminescence
~ 6% or 0.01 ppm
NHHC
± 4% or 0.2 ppm
Hydrocarbons
(Total Hydrocarbon, CA^)
Beckman 6800 gas chromatograph
flame ionization
~ 3% or 0.1 ppm
Carbon Monoxide
Beckman (800 gas chromatograph--
flame Ionization
Oxidants (0j>
Monitor Labs 8410 ozone analyzer—
chemi luminescence
+_ 5% or 0.01 ppm
Suspended
particulates
General Metals Model 5000
HiVol v/constant flow control
+_ 1 ug/m^
Wind speed
MRI Model 1022 anemometer
MRI Model 1071
Mechanical weather station
± 2% or .25 m/s
Hind direction
MRI Model 1022 anea»ometer
MRI Model 1071
Mechanical weather station
4 3°
Temperature
MRI Model 1071
Mechanical weather station
+ 0.2° C
Hind variance
MRI Model 1022 and R.M. Young anemometer,
and AeroVironment Sigma meter
Change in temperature
MRI Thermistors w/ R.M. Young shield
~ 0.15° C
Dew point
Heather Measures Model 1132IS
hydrograph
+ 2° C
-------
Surface meteorology was measured continuously at 12 air resources monitoring
stations. The locations of these stations are illustrated in Figure C-29, together
with the parameters measured at each site. The method used for each parameter
measurement is presented in Table C-26.
Calibration of the equipment was made at the outset of the project and at
least quarterly after that. Estimates of the accuracy obtained from the most
common sensors are tabulated in Table C-26. It should be noted that site-specific
factors such as the sensor location in relation to topographic features and sensor
height contribute more to the data variability than do instrument variability.
Measurements of upper air meteorology were made by means of rawinsonde
balloons launched from one of the established air quality monitoring stations at
various times. The balloons recorded temperature, relative humidity, windspeed and
direction. The balloons were launched twice every sixth day, within 1 hour after
sunrise and at approximately 1400 MST. This schedule was altered when weather did
not permit scheduled launching. Acoustic soundings were made continuously by a
monostatic acoustic sounder, supplemented by a bistatic sounder at certain times of
the year. Monostatic records reveal atmospheric structure, stability, temperature
inversions, and thermal plumes up to a height of 1 km (.6 mi) above surface.
Measurements were made from the lowest atmospheric level 0.6 m (.36 mi) to the
500 millibar (mb) pressure level (about 5,500 m or 18,000 ft above sea level).
After the first year of baseline data gathering, the upper air meteorology tests
were terminated. All available data can be found in the text of References 30 and
31.
Precipitation-
Twelve precipitation monitoring gages were implemented on and around Tracts
U-a and U-b in January of 1976, as directed by the Area Oil Shale Office. The
location of these monitoring stations is presented in Figure C-30.
Standard-recording and continuous-recording weighing gages cammed to punch
at 5-min intervals were used to monitor precipitation. Rain water samples were
collected upwind, near the center, and downwind of the tracts by reconnaissance at
the three locations using a plastic sheet and prepared bottles. Snow samples were
collected in winter, and rain samples were taken in late spring, early fall, and during
summer thunderstorms.
Two evaporation tanks with screened covers were also located in Tracts U-a
and U-b. Water losses were recorded, and tanks were refilled twice a week.
Interim Monitoring Activities—
The interim monitoring program is that which has existed since the completion
of the Tract U-a and U-b baseline data gathering program and which is still being
implemented during the present lease suspension period. Information for this report
has been taken from References 33, 34, and 35.
These reports have been prepared by the WRSP, Sunoco Energy Development
Co., Sohio Natural Resources Co., and Phillips Petroleum Co.
C-108
-------
LEGEND
1 .5 0 1
Kilometers
AR
Automatic
RS
Storage
Precipitation
Precipitation
W10
Wind at 10 m level
SO2
Sulfur Dioxide
TIO
Temperature at
H2S
Hydrogen Sulfide
10 m level
SP
Suspended
H
Humidity
Particulates
O0
Lateral Turbulence
CO
Carbon Monoxide
°w
Vertical Turbulence
HC
Hydrocarbons
P
Barometric Pressure
03
Ozone
NR
Net Radiation
N02
Nitrogen Dioxide
\
W10 TIOO 30
W20 T30 0
h2s HC 03
At Wats
Town Si
Figure C-30.
Location map for Tracts U-a and U-b interim .air quality and meteorology monitoring
stations.
-------
The monitoring of ambient air quality parameters within Tracts U-a and U-b
began at the conclusion of the baseline data gathering program in January 1977. At
that time, operations were continued at four air monitoring stations. Their
approximate locations are shown in Figure C-30.
On one site (6), monitoring of air quality parameters is continued in the same
fashion as during the baseline program. Particulates are measured over a 24-hr
period every sixth day. All other parameters are measured continuously. A list of
the parameters and the equipment involved in their sampling can be found in
Table C-26. The specific measurement techniques used are the same as those used
in the baseline program. To assure accurate measurement, the instruments are
recalibrated (dynamic multiple point) every month. The equipment also receives
span and zero checks every 2 days. In addition, the White River Shale Project is
participating voluntarily in an air pollution measurement quality assurance program
implemented by the EPA. The measurement of all pollutants, except for ozone and
NMHC, seems to indicate a pristine air environment. Periodically high levels of
ozone and NMHC have been measured.
Meteorological monitoring equipment was set up at four locations. The
settings of these stations are presented in Figure C-30. Meteorological data are
collected continuously and recorded on digital punch tapes every 6 min. Strip charts
are also used on two of the sites for a backup record. The type of meteorological
data recorded at the individual stations are presented in Table C-27. In 1977, storm
tracks were farther north than usual, causing the year's weather to be exceptionally
dry and warm.
Proposed Commercial Development Phase Monitoring Program—
A monitoring program has been proposed to be implemented during future
WRSP developments. It should be kept in mind that this monitoring program is
preliminary and that, as the WRSP project is implemented, changes may be made as
determined by WRSP and the Area Oil Shale Supervisor. The information necessary
to complete this report was taken from the following document: WRSP Detailed
Development Plan: Federal Lease Tracts U-a and U-b, Volumes 1 and 2 (36).
The primary contractors on the DDP were:
1.
Bechtel Inc.
2.
VTN Colorado, Inc.
3.
AeroVironment, Inc.
4.
Bingham Engineering
5.
Western Environmental Associates
6.
Utah State University
The proposed monitoring of ambient air quality will be accomplished by the
activation of six air sampling stations at various stages of project development.
Four of the six stations will be reactivated from the interim monitoring program 3
months before the beginning of major construction activities. Two additional
C-110
-------
TABLE C-27. METEOROLOGICAL PARAMETERS MONITORED DURING THE
LEASE SUSPENSION PERIOD
Station
Parameter
M
A6
All A13
Meteorology:
WS/WD - 10 m
X
X
X X
WS/WD - 20 m
X
WS/WD - 30 m
X
T - 10 m
X
X
X X
A T - 10-30 m
X
°6 - 10 m
X
a6 - 30 m
X
E
o
1
O*
X
aw - 30 m
Net solar radiation
X
X
Dew point
X
Relative humidity
X
Barometric pressure
X
Precipitation
X
stations will be reactivated before commercial operation. It has been proposed that
once all six stations have been reactivated, they remain in operation until
discontinuation is agreed on by the WRSP and the Area Oil Shale Supervisor. The
type of equipment to be used at each station is presented in Table C-28, together
with the parameters to be measured by each monitoring station, the scheduling, and
the monitoring frequency.
In addition to air quality and meteorology sampling stations, source sampling
access points will be located at all points of possible significant pollutant emissions
to the atmosphere. These sampling ports will allow for compliance testing and
validation of atmospheric model results with regard to future project phases.
All instruments will be calibrated at least once every 3 months to ensure their
continuing accuracy. In addition, as data are being extracted from the analog
records, they will be scanned for anomalous readings. In the monitoring program,
all instruments will be inspected in situ at least twice a week, and a record will be
kept of maintenance and of any malfunctions. Corrective actions will be logged.
Olll
-------
TABLE C-28. KIR QUALITY AND METEOROLOGICAL PARAMETERS, INSTRUMENTATION, SAMPLING FREQUENCY, AND SCHEDULES
OF PROPOSED COMMERCIAL PHASE RESOURCE MONITORING PROGRAM FOR TRACTS U-a AND U-b
Air resource parameters
Monitoring instrumentation
Honitorinq stations
Monitoring
schedule*
Monitoring frequency*
Hind speed and direction
MRI Model 1022
A-6 (10 and 30 ¦)
A-3 (10 ¦)
A-7 (10 B)
A-ll (10 a)
1
2
2
1
C
Hind speed, direction, and temperature
MRI Model 1071
nechanlcal weather station
A-2, A-4
A-I3
1.
1
1
C
Wind variance
MRI Model 1022/R.M. Young and
AeroVironment sigma meter
A-6 (30 a)
1
C
Temperature and lapse rate
MRI Thermistors v/R.M. Young
shield
A-6 (10 and 30 b)
1
C
Dew point
EGCG Model 880 hygrometer
A-6
1
c
Suspended particulates
General Metals Model 5000
HiVol Constant Flow Control
A-2, A-3,
A-6, A-ll
1,
1,
2
1
A
Sulfur dioxide
Tracor 270 11A sulfur analyzer—
gas chromatography
A-3, A-6
A-7, A-ll
2,
2.
1
1
C
Nitrogen oxides
Monitor Labs Model 8440
M0 analyzer
chemiluminescence
A-3, A-6
2,
1
c
Hydrocarbons
Beckman 6800 gas chrosMtograph--
flame ionization
A-3, A-6
2,
1
c.
Carbon monoxide
Beckman 6800 gas chromatograph--
flame ionization
A-3, A-6
2,
1
c
Oxidants
Monitor Labs 8410, ozone analyzer—
photolumi nescence
A-3, A-6
2,
1
c
Precipitation
Fisher-Porter Automatic Rain Gauge
Series 35 B 1558
PI, A-8, Plant Site
S-9, A-2, S-12
1,
1.
1, 1,
1. 1
c
Bli Initiated three Booths before construction and continuing through coanercial operation.
21 During comercial operation.
Ci Continuous.
Ai One 24-hr saaple each 6 calendar day*.
-------
Water Resources
Baseline Data Gathering Program—
The programs for the development of baseline hydrological data were
conducted during the same time period and by the same contractors who performed
the baseline air quality and meteorology data gathering programs. The information
for this baseline surface and groundwater report has been drawn from the U-a, U-b
First Year Environmental Baseline Report (30) and the Final Environmental Baseline
Report (31).
Surface water—Surface water in the Tract U-a and U-b area was sampled from
seven monitoring stations set up along various perennial and annual watercourses.
The approximate locations of these stations are illustrated in Figure C-31.
Each surface water monitoring station was equipped with a stilling well and
equipment to record specific conductance, temperature, and flow. Bottom sediment
samples and water quality samples were taken by VTN and the USGS quarterly and
semiannually. The USGS-Salt Lake City analyzed all water quality samples,
processed the continuous punched-tape records of specific conductance,
temperature, and flow, and developed the flow-rating curves. A list of the water
quality parameters measured is presented in Table C-29. Surface water flow was
measured throughout the year, or as directed by the Area Oil Shale Office, and the
water monitoring stations were checked at least twice a month by Voorheis-Trindle-
Nelson and USGS.
Groundwater—Four test wells were sunk at the outset of the program to locate
aquifers and study stratigraphy and oil shale properties. As a result of the test
wells, 20 wells were sunk at various locations for observation and pumping. At each
test well rotary air drilling was used to collect 8.9 cm (3.5 in.) cores from the
ground to a depth of 122 m (400 ft) below the Mahogany Zone. At maximum
intervals of 9.2 m (30 ft), the discharge fluids were measured for temperature,
specific conductance, and flow quantities. Additional tests were run consisting of:
(a) gamma ray, (b) gamma-gamma density, (c) neutron, (d) neutron epithermal
neutron, (e) flow, (f) temperature, (g) caliper, (h) SP, and (i) resistivity. Each test
well was developed as an aquifer test site and suited with a pumping well and two
up-dip observation wells 15 m (50 ft) and 40 m (131 ft) from the test hole. Also,
water level sensing devices and punch tape recorders, set to punch at 15-min
intervals, were used for continuous monitoring. At the 20 observation wells, water
levels were measured with steel tapes and electric probes. Groundwater chemistry
was determined from water samples drawn once every 6 months. Thirteen alluvii
wells were developed to measure water levels, subsurface water migration, and
groundwater quality. Where the alluvium contained water, samples were taken and
analyzed monthly. Seven deep aquifer wells were monitored for the same purposes.
These and other wells have been logged quarterly, using a combination of gamma ray
and neutron tools. The locations of these wells can be found in Figure C-31.
In January 1975, 12 additional alluvial wells were developed as directed by the
Area Oil Shale Office to assist in the vertical gradient moisture monitoring at
proposed processed shale disposal sites.
Oil 3
-------
0
1
LEGEND
XEVP
Evaporation Pan
~ RS
Precipitation, Storage
(Hater)
(Hater)
OS
Surface Water
O US
Existing Geologic Core
Monitoring Station
Hole, Southam
OP
Pilot Test Hole
OX
Exploration Geologic
(Hater)
Core Hole
OG
Ground Hater
O AG
Alluvial Hell (Hater)
Monitoring Station
A AR
Precipitation, Auto
O HE
Existing Geologic Cora
Hater
Hole> Evacuation
S-5
RS-3
RS-1
AG-1A
AAR-1
°P-1
° X-2
OAG-B
RS-2 i°G-a,
S-2
A AR-4
o .
HE-X
HE-2
11S-4
G-10
G-22
OHS-1
AR-12
G-3
HS-JO % G-21 ox-ll
x
EVP-2
1BA
AG-9
AR-8
HE-3
G-14
ox-9
RS-10
ox-10 oHS_2
„ AAR-9
G-12
Miles
RS-6 £ S-6
At Hatson
Town Site
Figure C-31. Water and geologic resources baseline monitoring stations.
-------
TABLE C-29. HATER QUALITY PARAMETERS MEASURED IN BASELINE, SURFACE AND
GROUNDWATER DATA GATHERING PROGRAM FOR TRACTS U-4 AND U-b
Schedule
Parameter
Baseline program
Surface Groundwater
Interim program
Surface Groundwater
Proposed program
Surface Groundwater
Calcium
a4
SD.XA
Q
SD.XA
M
SD.XA
Magnesium
Q
SD.XA
9
SD.XA
M
SD.XA
Sodium
Q
SD.SA
9
SD.SA
M
SD.SA
Potassium
Q
SD.XA
Q
SD.XA
M
SD.XA
Chloride
Q
SD.XA
g
SD.XA
M
SD.XA
Sulfate
<3
SD.XA
9
SD.XA
M
SD.XA
Bicarbonate
Q
SD.XA
9
SD.XA
M
SD.XA
Carbonate
Q
SD.XA
9
SD.XA
M
SD.XA
Alkalinity
S
SD.XA
Q
SD.XA
M
SD.XA
Hardness
9
SD.XA
<3
SD.XA
M
SD.XA
Fluoride
Q
SD,XA
Q
SD.XA
H
SD.XA
Silica
a
SD.XA
Q
SD.XA
M
SD.XA
Iron
9
SD.XA
Q
SD.XA
M
SD.XA
Aluminum
S
SD.XA
9
SD.XA
H
SD.XA
Boron
Q
SD.XA
8
SD.XA
M
SD.XA
Lithium
Q
SD.XA
Q
SD.XA
H
SD.XA
Strontium
Q
SD.XA
Q
SD.XA
M
SD.XA
Magnesium
Q
SD.XA
Q
SD.XA
M
SD.XA
Phosphate
Q
SD.XA
a
SD.XA
H
SD.XA
Total phosphorus
Q
SD.XA
g
SD.XA
M
SD.XA
Nitrate
<3
SD.XA
<3
SD.XA
H
SD.XA
Nitrite
9
SD.XA
g
SD.XA
M
SD.XA
Amnonia
9
SD.XA
g
SD.XA
M
SD.XA
Total Kjedahl nitrogen
a
SD.XA
g
SD.SA
M
SD.SA
Chemical oxygen demand
Q
SD.SA
g
SD.SA
M
SD.SA
Chlorophyll A
Q
SD.SA
g
SD.SA
M
SD.SA
Chlorophyll B
9
SD.SA
g
SD.SA
M
SD.SA
Color
Q
SD.SA
g
SD.SA
M
SD.SA
Turbidity
Q
SD.SA
g
SD.SA
N
SD.SA
Dissolved solids
Q
SD.XA
g
SD.XA
M
SD.XA
Arsenic
s
SD.XA
g
SD.XA
N
SD.XA
Cadmium
s
SD.XA
g
SD.XA
N
SD.XA
Chromium
3
SD.XA
g
SD.XA
H
SD.XA
Copper
S
SD.XA
g
SD.XA
N
SD.XA
Mercury
s
SD.XA
g
SD.XA
H
SD.XA
Molybdenum
s
SD.XA
g
SD.XA
M
SD.XA
Selenium
s
SD.XA
g
SD.XA
M
SD.XA
Vanadium
s
SD.XA
g
SD.XA
M
SD.XA
Zinc
s
SD.XA
g
SD.XA
H
SD.XA
Barium
s
SD.XA
g
SD.XA
M
SD.XA
Sulfide
s
3D.XA
g
SD.XA
M
SD.XA
Bromide
s
SD.XA
g
SD.XA
N
SD.XA
Lead b
s
SD.XA
g
SD.XA
M
SD.XA
Datergt.nts
s
g
M
SD.XA
Organic carbon
s
SD.XA
g
SD.XA
M
Pesticides
s
Q
H
Phenols
s
g
M
Gross alpha, gross betac
s
SD.XA
g
SD.XA
M
SD.XA
M - Monthly X - Seasonally
Q - guartarly A - Alluvial aquifer
3 a Semiannually D ¦ Deep oil shala aquifer
bNoe included in WKSP Program.
cIf gross alpha aeeivity la measured at greater than 4 pel/1, than analysis for
radium 226 and for natural uranium will b« doga. If b«ta activity is
greater than 100 pci/1, than analysis for Sr and Ca will ba dona.
C-115
-------
Interim Monitoring Activities--
The interim surface and groundwater monitoring program was begun in 1977
and is continuing with termination of the lease suspension and commencement of the
commercial development phase. The primary contractors on this program are the
same as those identified in the discussion of the baseline air quality and
meterorology data gathering program. The sources of information are the Progress
Report: Environmental Programs, Work Plan Lease Suspension Period, and WRSP
Detailed Development Plan (33-36).
The Interim program has been designed to be used in conjunction with USGS
studies presently being conducted in the areas of Tracts U-a and U-b.
Surface water—The USGS and WRSP water monitoring teams set up a
combined total of 16 samplers throughout Tracts U-a and U-b along the paths of
pertinent drainage courses. Stream flow is measured by WRSP continuously at two
sites, and at peak and low flow at one other site. The digital recorder tapes are
removed and processed monthly. Stream flow is monitored by USGS continuously at
five locations through the area.
Suspended sediments were intended to be sampled continuously at two WRSP
sites; however, severe icing caused one sampler to be shut down from December 18,
1976 to March 31, 1977. It was restarted to draw four samples a day. Manual
suspended sediment measurements were taken at least monthly to ensure proper
calibration of the instruments. Because of lack of major snowmelt, no sampling
beyond the original schedule was performed. Sediment is monitored by the USGS at
four locations. Automatic samplers and two-bottle, single-stage samplers are in
use.
Water quality samples are drawn at one site by WRSP on a quarterly basis.
Dissolved oxygen, temperature, pH, and conductivity are measured in the field at
the time samples are collected. The constituents are analyzed according to the
schedule presented in Table C-29. Water quality samples are collected by the USGS
at three sites, also on a quarterly basis. The samples are analyzed according to the
schedule presented in Table C-29. Temperature and conductivity are measured
continuously by WRSP at one site. Both probes are checked and calibrated
regularly, and the digital recorder tapes are pulled and processed monthly.
Groundwater—The WRSP and USGS have placed wells at 12 locations around
the areas of Tracts U-a and U-b for the purpose of monitoring water levels in the
local deep aquifers. The locations of these wells are shown in Figure C-31.
Water levels are continuously monitored by the USGS at three wells, and
time-activated digital punch recorders record the level hourly at all four wells and,
to assure accuracy, one well is checked manually by WRSP monthly. In addition,
manual-level readings are taken by WRSP at eight additional wells. These
measurements are taken twice a year, in January and July—times of the year that
correspond to highest and lowest levels.
The water levels seem to be consistent with observations during baseline
studies for all wells except one. The condition at this well seems anomalous, and no
explanation is presently available.
C-116
-------
Eight wells are developed in five different alluvial drainage areas by the WRSP
and USGS. Five additional wells are available for water quality monitoring if the
conductivity of water has been found to be 20 percent to the extreme side of
maximum or minimum value found in prior, comparable time periods. The locations
of these wells are shown in Figure C-31.
Water samples were drawn from the eight original wells on a quarterly basis
through December 1976 and analyzed according to the program presented in Table
C-29. As of January 1977, these quarterly-drawn samples are measured for water
level, temperature, and conductivity. Water quality samples were taken only during
high flow of 1977 at five sites. These samples were analyzed according to the
schedule in Table C-29. Water level, temperature, and conductivity analyses have
been resumed on a monthly basis during snowmelt and thunderstorm seasons.
A slight decline in static water level was noticed in 1977, probably because of
low annual precipitation and consequent low recharge capabilities.
Proposed Commercial Development Phase Monitoring Program—
The proposed surface and groundwater monitoring program to be conducted
during Tract U-a and Tract U-b commercial development has been outlined in the
WRSP Detailed Development Plan (36).
The water monitoring program described here will continue until Phase II
construction has been underway for approximately IS months. The program will be
reassessed at that time on the basis of future development activities and analyses of
Utah processed shale and processed shale leachate.
Surface water—Surface water monitoring will begin immediately after the end
of the interim monitoring program. The exact schedules have not yet been
determined. Seven recording stations are proposed to be situated along main
drainage courses throughout the tracts. The equipment will be the same as was used
during baseline data gathering. Continuous streamflow records will be taken at all
seven stations. Three of the seven stations are expected to experience zero flow
rates for most of the year, and these points will be sampled for water quality
manually, as necessary. Temperature and specific conductance will be monitored
continuously and automatically at the four perennial streams and at the three annual
streams when flow exists. Four of the seven stations will be sampled monthly, and
an analysis of the water quality parameters in Table C-29 will be carried out.
Monitoring of water in the retention dam located downstream of the processed
shale disposal site will be carried out when there is standing water. Water depth
will be measured quarterly, and an automatic level recorder may be installed.
Water quality will be measured quarterly, using the same parameter list as for
stream water analyses (Table C-29). The same monitoring will also be used for any
new ponds that may form during the life of the processed shale disposal system.
All surface water samples will be collected using standard field equipment and
techniques. All parameters will be determined according to procedures detailed in
Standard Methods for the Examination of Water and Wastewater (37), or according
to methods approved by the Area Oil Shale Supervisor, where appropriate.
C-117
-------
Groundwater—Groundwater quality will be monitored quarterly (if water is
present) at 11 alluvial wells and semiannually at five deep aquifer wells. These
wells are the same ones used in the baseline monitoring program. Depth to water
will also be measured at nine of the 16 wells. Water samples will be drawn from
each well using a pump or, in the case of small diameter wells, a boiler or thief
sampler. Water depth measurements will be made using a steel-type electric probe
or continuous water level recorder.
Semiannual samples will be collected in May-June and November-December.
Quarterly samples will be collected during February-March and August-September.
The water quality parameters to be tested are listed in Table C-29. Water sample
collection and treatment will follow methods described in Techniques of Water-
Resources Investigations of the U.S. Geological Survey (38).
In addition to analyses of water drawn from deep aquifer and alluvial wells,
analyses will be performed on water drawn from shallow wells to be drilled adjacent
to processed shale stockpiles. This test should provide information on any shallow
aquifer contamination as rapidly as possible.
Biological Resources
Baseline Data Gathering Program—
The baseline biological resource data gathering program was conducted from
197^ to 1976. The major contractors on the project have been outlined in the
baseline air quality program. All information generated by the baseline biological
resource program was published in the First Year Environmental Baseline Report
(30), and the Final Environmental Baseline Report (31). All program procedures and
analytical methods have been taken from these publications.
Vegetation—Vegetation in the Tract U-a and U-b area was sampled in 400
plots. Within each of the four vegetation types existing in the local environment,
five sites were picked, making a total of 20 sites. Within each of the 20 sites, 20
plots were developed, thus giving a total of 400 plots. A map showing the location
of the vegetation study areas within each vegetation type is shown in Figure C-32.
Within each plot, four plant attributes were established by two-man teams. These
attributes were species, height, cover, and density. The sampling program was
carried out in the spring to estimate the characteristics of species maturing in June,
and in the fall to estimate the characteristics of late-summer maturing species
(perennials).
Field plot data were analyzed statistically to determine a 90-percent
confidence interval about the means and the necessary sample size (number of plots)
required to estimate within 25 percent of the true mean with a 90-percent
statistical probability for each attribute measured for each species. The sampling
procedures were basically the same in the second year of sampling, except for the
following changes:
1. The number of plots analyzed in June 1976 were doubled from 1975.
2. Seedlings of the major shrub and tree species were observed and
recorded separately to measure reproduction.
C-118
-------
WG3
J
VG3
VG4
PP1*
VG5
r"i
WR2
i i
PP5
PP
../WG?
#3 PP7 fj
VG2
/# 6
WRl •
^PP13
)R
iha.
W >
PP6
VG3
WJ3
PP8j
r
mj F2
F4
o
581
58C y^5
»
PP20 VS4
PP19
#2
\
VJ5
A/PP10
1>S
*
50J
f
J WG1
A
\7 ""
PP9
/*4
PP
A
VR5
i**i
i.J
•39
U-b
VS2
PP17
#5,
PP16
WS
WS3
• VS3 f*.
W
ppie
l
l_
1
-I
Miles
~
LEGEND
Sagebrush Stem Growth
Sampling Site
Microorganism Sampling
Station
Invertebrate Sampling
Station
W Wildlife Sampling Area
C.TJV Vegetation Study Area
G Sage Greasewood
J Juniper
R Riparian
S Shadscale
Aquatic Biology Sampling
Station
Permanent Plot
CU F
« PP
Figure C-32. Location map for Tract U-a and U-b biological resource sampling sites.
-------
Animals—Sampling of terrestrial vertebrates on and around Tracts U-a and
U-b took place at 12 sampling sites—four in primary onsite vegetation areas, three
in secondary onsite vegetation areas, and five in secondary offsite vegetation areas.
The locations of these sites are presented in Figure C-32. Flushing transects were
used to determine the number and kinds of diurnal terrestrial vertebrates in the
area. Biologists walked the transects and recorded the animal species seen and the
distance of each animal from the transect time at first sighting. A rodent live-
trapping system was set up to sample nocturnal terrestrial vertebrates. A total of
240 traps was set on both primary and secondary sampling sites. The following
information was recorded for each capture: date, sampling, sampling day, species,
sex, age, animal condition, animal identification, trap number, capture number.
Mist netting was used for bats. The Jennrich and Turner (39) method of determining
home range was used to analyze the trapping data. Density estimates were made
with the Schnabel (40) technique, as presented by Overton (41).
The second year of baseline terrestrial vertebrate sampling was carried out in
a similar manner. The Schnabel estimator (40) as modified by Overton (41) and the
Jennrich and Turner method of calculating home range (39) were not used as a result
of the large number of assumptions involved. Also, a literature review was
employed to determine the presence or absence and distribution of species.
Special studies were performed on mule deer, elk, antelope, predators,
amphibians and reptiles, waterfowl, raptors, cottontail rabbits, mourning doves,
livestock (cows and domestic horses) and feral horses, and beaver.
Arthropods were collected on the tract and along a 1.6 km (1 mi) perimeter
from May to September of 1974 and 1975. During 1975 and 1976, species were
identified and classified. Quantitative collection and analyses were performed in
1976. Basically, the collection techniques included: (a) net collecting from flowers,
leaves, soil surface, etc.; (b) routine net sweeping of vegetation; (c) malaise
trapping; (d) searching in hiding or dwelling places under rocks, in logs, under bark,
etc.; (el using Berlese funnels to drive arthropods out of "duff" taken under trees and
shrubs; and (f) using a black light trap and collecting from a sheet illuminated by a
black light. Species identification was performed by entomologists of Utah State
University, and by various specialists in the United States and Canada.
Aquatic biology—Aquatic biology on the tracts was surveyed at various
sampling stations along local watercourses. Station locations were selected on the
basis of their relationship to tributaries, lease boundaries, and accessibility (refer to
Figure C-32). Each station included a section of stream approximately 300 m (985
ft) long and a variety of habitat or stream conditions such as pools, riffles or rapids,
backwaters, etc. Samples of the same type were taken from identical locations at
each sampling station wherever possible. The methods of sampling and analyses are
those of the EPA, USGS, public health agencies, and other groups involved in applied
aquatic biology. The methods are discussed by Usinger (42) and outlined in detail in
Quarterly Report No. 4 (43) and other documents. The program is summarized as
follows:
1. Aquatic macrophytes were virtually absent from the study area and
therefore were not sampled.
C-120
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2. Floating artificial substrates were used for collecting periphyton.
One sample strip from each periphyton collection was preserved in
formalin. The accumulated growth was scraped into the
preservative from the sample strip with a rubber policeman. The
sample jar was closed and agitated violently to disperse algal cells
into the preservative. Aliquots were placed in a Sedgwick Rafter
cell, and algal cells were counted in accordance with Standard
Methods (37).
3. Plankton were not sampled for chlorophyll. Chlorophyll determinations
were conducted in the surface water study.
4. Captured fish were identified, fin clipped, and released in 1976, as
permitted by the Utah Division of Wildlife Resources. Some of the
standard identification guides employed were Smith (44), Patrick
and Reimer (45), and Weber (46). A Zeiss 32-x 1000 x phase contrast
microscope was used.
M icrobioloRy—The microbiological activity of the soil in the Tract U-a and
U-b area was determined by analyzing soil samples taken from four sample holes,
one in each vegetation area. Generally, the cores were taken in three stages down
to 50 cm (20 in.). The locations of these sampling sites are to be found in Figure C-
32. Each sample was ground in the laboratory and particles larger than 3 mm (0.12
in.) in diameter were removed. The sample was then stored at 4°C (40°F) until
examined. The numbers of bacteria, streptomycetes, and fungi in the soils were
determined by standard microbiological plating methods. Proteolytic activity was
based on a protein (gelatin) hydrolysis by the soil enzyme. The total dehydrogenase
activity was measured and defined as the ability of the soil biota to reduce
triphenyltetrazolium chloride to the respective formazan. Soil respiration was
measured by its CO2 release, a process dependent on soil moisture conditions and
the soil water potential measurements (i.e., measurement of available water, not
total water content). ATP measurement (adenosine triphosphate) was based on the
luciferin-luciferase reaction. Nitrogen fixation was determined with a gas
chromatograph by the acetylene reduction method. The organic carbon content was
determined by digestion of a soil sample with potassium dichromate. Ammonium,
nitrate, and total nitrogen contents were determined by using appropriate Kjeldahl
digestion systems and spectrophotometry.
Interim Monitoring Program—
The interim biological resource program for Tract U-a and U-b has been
conducted since the conclusion of baseline studies in 1976. The interim program
involves work on vegetation and terrestrial vertebrates. Data from USGS Water
Resources Division aquatic biology monitoring program, the Utah Division of
Wildlife Resources, and the Bureau of Land Management programs were
incorporated when applicable. The main source of information on the interim
program was the Progress Report: Environmental Programs 1977, WRSP (34) and
the Work Plan: Lease Suspension Period (3IT
Vegetation—Dr. Cyrus McKell is under contract with WRSP to conduct the
vegetation monitoring program. During the monitoring program, plant samples are
taken, and visual observation is pursued to accomplish the following: (a) measure
productivity of annual plant species, (b) measure growth of dominant shrub, (c)
c-121
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measure percent of stems browsed on shrubs measured in (b); (d) observe seed
production, seedling establishment, animal utilization, unusual buildup of insects or
plant disease, or early seasoned dormancy.
At the peak of annual growth in the spring (June).annual species are clipped
from approximately 200 0.5-m2 (5M sq ft) plots and analyzed. In the fail (September
-October) the current year's stem growth of the dominant shrub is measured in a
paired plot arrangement along three transects along the zone of influence of the
industrial site and in three transects in areas surrounding that site. During both
these times (spring and fall) visual reconnaissance is conducted to observe
reproduction, plant growth, vigor, and any excess animal utilization.
Animals—Bio Resources, Inc. was contracted to perform terrestrial vertebrate
studies on Tract U-a and U-b beginning in December 1976 and ending December
1977. During that time, an attempt was made to establish five criteria. Those
criteria were: (a) species inventory, (b) species distribution within habitat types, (c)
species distribution within seasons of the year, (d) species abundance and density, (e)
ecological relationships of vertebrates to their biotic and abiotic environment.
Two vertebrate sampling sites were placed on each of the prominent
vegetation areas to study spatial distribution. To study temporal distribution,
vertebrates were sampled in February, April, June, and August. To determine
abundance and density, techniques particular to the different vertebrates were
carried out at each sampling site. To establish an inventory, vertebrate
identifications were carried out during each sampling period. The various
techniques of sampling for each vertebrate type are listed below.
Mammals: flushing transects, trapping, mist netting and large
mammal aerial survey
Birds: flushing transects
Reptiles: flushing transects
During this interim monitoring program three hypotheses were tested: (a)
mammal populations have reached a peak and will decline, (b) bird populations are in
a downward trend and will continue to decline, and (c) reptile populations will
remain stable. It was found that temporal and spatial distribution is affected by
climate and that these changes are hence not long-term.
Aquatic biology—WRSP is not conducting any studies on aquatic biology during
the interim period, but it is following the progress of an ongoing USGS study in the
area.
Proposed Commercial Development Phase Monitoring Program—
The monitoring program prepared for future Tracts U-a and U-b commercial
development is outlined in the WRSP Detailed Development Plan (36). All
information necessary to complete this summary has been extracted from the DDP.
During the 2-year baseline program, relevant data were gathered to confirm
which biological parameters were the most reliable indicators of the baseline
biological conditions in the Tract U-a and U-b area. Those indicators that illustrate
low variability or high correlation with other ecological factors will be standards
against which to measure change.
C-122
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The field program as proposed will have a series of vegetation plots, wildlife
transects, and trapping grids against which to measure these indicator species. The
field monitoring program itself will follow much the spme line of the baseline
program. An estimate of the appropriate parameters to be measured and the
methods of sampling to be utilized is presented in Table C-30.
The WRSP will propose a system of data management and report format
acceptable to the AOSS. Threshold values will be developed to indicate points of
biological stress, beyond which significant deterioration of the local environment
will exist. This will be done in recognition of the natural variability in even the
most representative parameters.
Any changes brought about in the local ecology during plant operation will be
evaluated in the following manner:
o Data from each station will be compared to the corresponding baseline
data collected for that station in 1974-1976 to permit a statistical
comparison of season-to-season or year-to-year changes.
o Data from each station will be compared to provide a "between sample"
control and assessment of any differential change.
o Data on the growth rates and any evidence of leaf necrosis in sensitive
species will be correlated to pollutant or emission concentrations
predicted by the air dispersion model. Results will be compared between
plots to detect changes at difference directions and distances from the
emission source center.
o Browse utilization transects will be established in various locations to
determine changes in grazing pressure as a result of displacement and
enhancement procedures.
o Samples of plant tissue will be analyzed to demonstrate possible
accumulation of toxic materials.
o Soil samples from representative localities will be analyzed and
correlated with known meteorological conditions to demonstrate any
project-related reduction in microbiological activity.
Solid Waste Disposal, Revegetation
Baseline Data Gathering Programs—
The gathering of baseline data on various aspects of revegetation has been
accomplished at the Utah State University Agricultural Experiment Station. The
head of the various projects was C. M. McKell, Professor of Range Management.
Various aspects of the revegetation concept have been evaluated. Some of
those concepts are: (a) use of native adapted plant species, (b) transplanting of bare
root and container-grown plants, (c) soil surface shaping, (d) soil surface
stabilization, (e) limited use of topsoil, (f) minimal fertilization; and (g) temporary
supplemental irrigation for salinity control and plant survival. In addition, studies
have been performed to determine the most effective methods of naturally
C-123
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TABLE C-30. SUMMARY OF PARAMETERS TO BE MEASURED FOR THE PROPOSED
COMMERCIAL DEVELOPMENT OF TRACTS U-a AND U-b
Item to be
measured
Parameter
Sampling plan
Vegetation
Birds
Rodents
Small Game Species
Big Game Species
Microorganisms
Species, density,
height, cover, litter,
productivity
Species, number of in-
dividuals , age and
sex, habitat
Species, numbers, sex,
age, body condition,
habitat type, time of
year, trap location
Species, numbers, sex,
-------
revegetating processed oil shale in the wild environment. All of the baseline
revegetation programs have been summarized in the following documents:
Achieving Effective Revegetation of Disposed Processed Oil Shale (47) and Final
Report: Revegetation Studies for Disturbed Areas and Processed Shale Disposal
Sites (48)~
In addition, a preliminary revegetation program has been developed to function
in a logical and coordinated fashion. Plant species have been selected that illustrate
a high salinity tolerance, compatibility with domestic and wildlife use, " and
aesthetically desirable features. Plants will not be transplanted from growing media
until a hearty root system is developed. After compaction, the disposal pile will be
shaped into terraces and slopes so as to minimize erosion and capture precipitation.
Surface particle-binding mulches will be applied to the slopes. Trenches 45 cm wide
by 75 cm deep (17.7 by 29.5 in.) will be filled with topsoil. The plants will be
fertilized to a minimum degree and watered with drip irrigation.
Interim Monitoring Program-
Presently there is no program ensuing for the monitoring of solid wastes
because of the fact that no solid wastes are being generated. Since the end of
baseline monitoring, two reports have been presented, each dedicated to reporting
the progress of continuing research. From January 1, 1977 to June 30, 1977, the
main study concerns were: propagation of native plants and container problems,
physiological studies of plants grown in saline soils, rehabilitation plantings on
disturbed sites, salt movement and chemical weathering in process shale and pilot
model, and water harvesting studies. Study concerns from the period 3uly 1, 1977 to
December 31, 1977, were : physiological studies, rehabilitation planting on
disturbed sites, water harvesting from a siine medium, weathering of processed oil
shale, pilot model and associated studies, and research plans.
Commercial Development Phase Monitoring Program—
The solid waste monitoring plan is based on requirements of the Oil Shale
Lease and of the Utah State Code of Solid Waste Disposal Regulation, which are
summarized in Section 7 of that Regulation. The solid waste disposal plan, including
waste sources, and types and quantities expected during the single retort operation
and the commercial operation phases, is described in Section 5.3 of the Detailed
Development Plan (36). All solid wastes will be deposited in the processed shale
disposal area, some uniformly mixed in processed shale, and some layered in
processed shale.
The solid waste monitoring program will consist largely of recordkeeping and
physical inspection practices. Surface water, groundwater, and ambient air
monitoring around the areas of disposed will also supply useful data. Records of
disposed wastes will be kept. The record will incdude types and approximate
quantities of solid wastes, the disposal area being employed, and special provisions
used for chemical waste disposal. During commercial operation, wastes from Phases
II and IV will be inventoried as to types and quantities and will then be mixed with
the processed shale for disposal. In addition, a regular program of inspection will be
established to ensure that collection, storage, transport, and disposal practices are
being carried out in a safe and environmentally acceptable manner.
In the implementation of the water monitoring program, surface water and
groundwater quality data will be collected and used to assess the changes, if any, in
C -125
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surface water or groundwater quality attributable to solid waste disposal practices.
Samples collected at two streamflow gaging stations will provide data to evaluate
surface water quality upgradient and downgradient from the solid waste disposal
sites in the processed shale disposal area. In addition, any runoff or leachate
collected from the initial solid waste landfilling operations (during construction and
before deposition of processed shale) will be sampled semiannually and analyzed.
This activity will be supplemented by monitoring the water quality in the Southam
Canyon runoff retention pond when processed shale and other solid wastes are being
deposited. Groundwater sampling stations will be located in the water-bearing
zones, both upgradient and downgradient from the processed shale disposal area,
which includes the solid waste disposal area. The groundwater sampling and analysis
program will provide information to assess water quality changes that might result
from processed shale and solid waste disposal operations.
Air quality monitoring plans associated with processed shale disposal will
include monitoring in the solid waste disposal area. The initial solid waste landfill
will contain a small amount of decomposable wastes. Although gas evolution is not
expected to be detectable over the life of the lease, the site will be checked
regularly for gas emissions through the use of a hand-held hydrocarbon sensor. If
detected, the gases will be sampled and analyzed to determine whether control
measures such as vents or barriers are warranted.
At the conclusion of studies done by Utah State University during the interim
and baseline periods, a suitable system of revegetating raw and processed shale will
be determined. This system will be utilized to control erosion and nonfavorable
aesthetic impacts of shale disposal piles.
Noise
Baseline Data Gathering Program-
Noise data were collected during the first year of baseline data gathering.
The data had indicated that sound levels for all seasons were in the range of 2
-------
digital or analog recorder with a sound measuring system that meets ANSI standards
for Type I sound level meters. Recordings will be taken for 2 days (two 24-hr
periods) at each location during the following stages of program development:
o Before construction
o Construction of the single retort - earth-moving stage
o Operation of the single retort-field capacity
o First train construction - earth-moving stage
o First train construction - full capacity
o Second train construction - earth-moving stage and
simultaneous full capacity operation of first train
' o Two-train operation - full capacity
None of the above noise measurements would be made during extraordinary
events. The instrumentation and measurement techniques will follow the
considerations for outdoor environments presented in American National Standards
Institute Methods for the Measurement of Sound Pressure Levels (49). In addition,
provisions will be made for measuring wind speed at the monitoring location during
the monitoring period. The parameters to be used for assessing ambient noise will
include:
o Sound pressure level—used to express the loudness of a sound, measured in
dBA.
o A-weighted sound pressure level—used for describing the magnitude of
sounds in terms of human aural response, measured in dBA.
o Cumulative distribution level - the A-weighted sound pressure level in
dBA exceeded for a given percentage of the time, denoted by the
subscription.
o Equivalent sound level - the A-weighted steady noise level that, in a
stated period of time, contains the equivalent amount of noise energy as
the time-varying noise during the same period.
o Day-night sound level - the equivalent A-weighted sound level during a
24-hr time period with a 10-dB weighting applied to the equivalent sound
level during the nighttime hours of 10 p.m. to 7 a.m.
Radioactivity
Baseline Data Gathering Program—
During the baseline data gathering program at Tracts U-a and U-b,
radioactivity was measured in the ambient air, surface water, groundwater, and the
local soil horizons. The main document providing assistance was the First Year
Environmental Baseline Report (30).
0127
-------
Ambient radiation was measured continuously at various locations throughout
the Tracts during the baseline data gathering programs at Tracts U-a and U-b (31).
Three thermoluminescent dosimeters were installed at each of the 12 monitoring
stations after June 1975 and were read monthly to determine overall average
radiation dosage levels. Before June 1975, a pressurized ion chamber was rotated
from site to site at intervals of 6 days. Before the ion chamber was installed at any
one of the sites, a portable ionization chamber and scintillation counter were used
to survey the area to determine that the continuous measurements would be
representative of the area. Gross alpha and gross beta measurements were made
monthly. One gamma radiation scan was made of a high-volume filter sample. In
addition, one sample of air was analyzed for radon-222 activity. Ambient
radioactivity measurements by pressurized ion chamber and hand-held radiation
monitor were terminated in January 1976 with the approval of the Area Oil Shale
Supervisor. Monitoring by thermoluminescent dosimeters at Stations A1 through
A12, analysis of particulates for gross alpha and beta activity, and isotopic gamma
analyses continued through the second year of monitoring.
In addition to the monitoring of radiation in the ambient air, radiation levels
were determined in local soil horizons, surface water, and groundwater. A number
of soil samples were collected from representative locations on the two lease tracts
and analyzed for radioactivity. No sources above a normal background level were
identified, with Ra226 activity below 0.87 pCi/g, Sr90 (395 pCi/lg) below 0.52 pCi/g
(236 pCi/Ib), K*10 below 20.0 pCi/g (907k pCi/lb), Pb212 below 1.5 pCi/g (681 pCi/lb),
and Cs137 below 1.6 pCi/g (726 pCi/lb) recorded for all samples. Detailed results of
the soil radioactivity tests are appendicized in the First Year Environmental
Baseline Report (30). Surface water quality samples were also analyzed for gross
alpha (mg/lU), gross beta (mg/lU), gross beta (pCi/1 Cs-137) and gross beta (mg/1
Sr90/Y90).
Interim Monitoring Program--
Radioactivity was measured in the ambient air and in the water and
groundwater during the interim monitoring program. Documents that supplied
information for this report were the Tract U-a and U-b Progress Reports (33,34) and
Suspension Period Work Plan (35).
Ambient radioactivity measurements by pressurized ion chamber and
hand-held radiation monitor were terminated in January 1976 with the approval of
the Area Oil Shale Supervisor. Monitoring by thermoluminescent dosimeters,
analysis of particulates for gross alpha and gross beta activity, and isotopic gamma
analyses continued through the second year of baseline data gathering, but has been
discontinued until the commencement of commercial construction. It has been
determined that no significant radiation exists in the ambient air (33).
Surface water quality samples were also analyzed for gross alpha (mg/1 U),
gross beta (mg/1 U), gross beta (pCi/1 Cs137) and gross beta (mg/1 Sr90/Y90).
Commercial Development Phase Monitoring Program—
A radiation monitoring program during commercial development at Tracts U-a
and U-b has not been proposed. This determination was made after reviewing
results of the baseline program and was based on the supposition that oil shale
production will not contribute to the ambient radioactivity. If a program is thought
C-I28
-------
necessary in the future, one will be instituted by the Area Oil Shale Office and the
WRSP.
Surface Subsidence
Baseline Data Gathering Program —
Surface subsidence was monitored during the baseline data gathering program.
The description of the program is presented in the First Year Environmental
Baseline Report (30) and the Final Environmental Baseline Report (31). A precise
releveling survey was completed for the WRSP to determine whether or not
subsidence is occurring within the area.
The survey route was 18.0 km (28.9 mi) long and includes 16 bench marks. The
bench marks used were established in 1933 and 1934 by the U.S. Coast and Geodetic
Survey. The survey showed little or no subsidence.
Interim Monitoring Program and Proposed Commercial Development Phase
Monitoring Program-
Subsidence measurements have been made during the interim monitoring
program, and one is proposed for the commercial development phase. The sources
of information on this subject are the Progress Reports (33,34) and the Work Plan;
Lease Suspension Period (35). Based on rock samples taken from the core of drill
holes on Traits U-a and U-b, the mine is expected to have a safety factor of 2.5,
thus making surface subsidence unlikely. However, a monitoring program has been
proposed to indicate subsidence if it occurs. Two lines of surveyed stations will be
established on the surface overlying the initial mine area. These lines will be
perpendicular to each other and oriented in the same direction as the mine entries.
They will be set and measured before Phase II mining begins and will be measured
periodically for elevation to determine if subsidence is taking place. Initial
measurements will be done at least semiannually.
U.S. DEPARTMENT OF ENERGY ROCK SPRINGS RESEARCH SITES
Environmental data gathering programs have been conducted and reported at
the DOE Rock Springs research sites since the early 1970's. The Rock Springs sites
are located approximately S km (5 mi) west of Rock Springs in Section 15, T 18 N, R
106 W of Sweetwater County, Wyoming (Figure C-33). Most of the environmental
programs that have been conducted to date have not been outlined and documented
in great detail because of the fact that these projects are research-oriented and
hence, until recently, have been exempt from stringent environmental control.
All information necessary for completion of this report on environmental
programs at the Rock Springs sites was derived from References 50-57.
Air Resources
Air Quality and Meteorology-
Measurements of ambient air quality and meteorology have been made by the
DOE on a very limited basis. Air quality monitoring activities, with the exception
of particulates, were suspended with the completion of baseline monitoring in
October 1977. These baseline measurements, which began in February 1975,
consisted of discrete samples taken on 6-day intervals. The data gathered during
C-129
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Greens
Canyon
Greens Canyon
Killpecker
Creek
Mountain
White
Bitter Creek
Mountain
White
Sweetwater
Creek
Rock Springs
Sites 1-12
Little
Bitter
Creek
Bitter
Creek
^®<0 N^
Upper Green River
Site 2
LEGEND
• Proposed Sites
O Stream Sampling
Stations
© DOE Core Holes
~ Water Quality
Sampling Stations
Figure C-33. Area location map for DOE oil shale in situ research sites.
-------
this period, considering the intermittent sampling scheme and the techniques
employed, are not suitable to truly represent mean ambient concentrations, and
therefore they have not been subject to analysis.
Preparations are being made at this time to establish a continuous monitoring
station near the 30.5 m (100-ft) meteorological tower. This station is operating and
will employ Federal reference or equivalent methods for particulates, sulfur dioxide,
hydrogen sulfide, carbon monoxide, and ozone.
Meteorology—Wind speed, wind direction, temperature, and delta temperature
are measured at the 30.5 m (100-ft) level on the meteorological tower. The
instruments were repaired and reactivated in late August 1978 after 5 months of
down-time for repair.
Stack gas monitoring—Some monitoring of stack gas effluents has been
conducted at Site 9, but details of the program are not available. A list of the stack
gas monitoring equipment available to the Laramie Energy Technology Center for
future use is presented in Table C-31.
None of the proposed ambient air or stack gas monitoring programs have been
published, but a meteorological monitoring program to determine evaporation rates
of produced water at Site 12 has been proposed (54).
Water Resources
Baseline Data Gathering Program—
Surface water—Baseline surface water quality and hydrology in the Rock
Springs area has been established mainly by the Energy Research and Development
Administration (ERDA, now a part of the DOE) and the USGS with data that has
been gathered in the past. Surface water quality samples have been collected by the
Water Resources Division of the USGS at two locations in the Rock Springs vicinity:
1. Bitter Creek near Green River, Wyoming
2. Green River near Green River, Wyoming
Regional hydrology has been determined by a USGS stream-gaging station on
the Green River below the Bitter Creek confluence.
In response to a lack of pertinent water quality and hydrology data, the LETC
has established a system of monitoring water resources in the areas more immediate
to the Rock Springs research sites.
A small-scale program was first established on a weekly basis from April 28 to
July 15, 1976. Flows were measured, and water quality samples were taken at sites
below four springs and seeps in the Green Canyon alternate site area and one spring
near the primary site above ERDA/LETC Well Number
Groundwater—Before LETC monitoring of static water levels and water
quality in Rock Springs groundwater, this information was received through
inspection of local, privately owned water wells. Twelve wells were drilled in the
C-131
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TABLE C-31. LARAMIE ENVIRONMENTAL TECHNOLOGY CENTER PRIORITY KIR POLLUTANT
MONITORING EQUIPMENT USED AT DOE ROCK SPRINGS SITES
Units
Mfq.
Model
Effluent
Range
Sensitivity Remarks
Sulfur oxidesi
3
Meloy Laboratories, Inc.
SA-160-2
s°
0-10 ppm
0.005 ppm
3
Meloy Laboratories, Inc.
Sll-202-2
TS/HC
0-10/0-1000
0.005/0.1 CH.
2
Energetics Science, Inc.
Ecolyzer eeries 7000
h s
Dual
4
0-100/0-500
1
Baseline Industries
TCD1010
SO,, H S
Gas chraaatograph
< *
1
Baseline Industries
TC01030
SO,. H_S
Gas chrcsuitograph
Nitrogen oxidest
1
Meloy Laboratories, Inc.
HA-510-2
HO, NO , NO
0-10
0.1 ppa —-
0-100
0-1000
0-2000
3
Energetics Science, Inc.
Ecolyzer Series 7000
no2
Dual
0-50
0-250
1
Monitor Laboratories, Inc.
8440
MO, NO , NO
0-0.2 ppm
2 ppb
0-0.5 ppm
0-2.0 ppm
0-5.0 ppm
Hydrocarbon (
other gasesi
Meloy Laboratories, Inc.
SH-202-2
As described
As described
under sulfur
under sulfur
oxides
oxides
Baseline Industries
FID1020
CH., THC, CO
1
Mine Safety Appliances Co.
Lira 303
co*
0-50%
Fisher Scientific Co.
Orsat gas apparatus
0 . CO .
B2> CO, HC
'other equipment Is available for measuring barometric pleasure, tumidity, flow, and temperature of gas streams and a special balance for weighing
large filters. Duel-pen recorders are used to reduce space requirements. Standard gas mixtures for calibration are housed in the unit while gas
cylinders for instrument operation are secured outside the unit. Calibration gas mixtures for Meloy Sulfur analyzers should, where possible, be
made up In air rather than nitrogen.
(continued)
-------
TABLE C-31. (continued)*
Units
Hfq.
Model
Effluent
Range
Sensitivity
Remarks
Auxiliary equipmenti
3
Meloy Laboratories, Inc.
Pneuaotron
—
Self-contained pneumatic dilution
device - Dilution factor 4 to 40
1
Monitor Labe, Inc.
Attenutron
Model 3710
Dilution device employing a semi-
permeable diffusion barrier
2
Meloy Laboratories, Inc.
Saapletron
Model 5530-2
Sample conditioner permits mea-
surement of total sulfur, hydro-
gen sulfide and sulfur oxides
aa SOX
3
Meloy Laboratories, Inc.
CS10-2
SO calibration source, 0.1 to
0.8 ppa from permeation tube,
+ 2% accuracy
X
Meteorological Station
—
Stack Monitoring
equipment - speciali
1
Research Appliance Co.
Stack gas
train
36"-Probe, inpinger train, mod-
ular electrical unit with mano-
meters, pltot (S-type) tube and
pump. Equipped with an Alundum
thimble filter and Andersen ln-
stack fractionating sampler
assembly.
3
Research Appliance Co.
High-volume
air soapier,
deluxe model
Continuous-duty, 24-hr cycles
(or longer), 7-day skiptlmer
also equipped with an Andersen
particle sixlng sampling head
and variable 90-volt transformer.
*Other equipment la available for measuring barooetric pressure, humidity, flow, and tenperature of gaB streams and a special balance for weighing
large filters. Dual-pen recorders are used to reudce space requirements* Standard gas mixtures for calibration are housed in the unit while gas
cylinders for instrusient operation are secured outside the unit. Calibration gas mixtures for Meloy Sulfur analyzers should, where possible,.be
made up in air rather than nitrogen.
-------
area from 1970 to 1975. These wells were sampled for water quality and have been
sampled periodically since 1976.
Existing Monitoring Program—
Surface water—since 1976 there has been very little surface water monitoring
in the Rock Springs area. The data that have been gathered are not well
documented, and a summary of the sampling procedures is presently unavailable for
publication.
Groundwater—There are numerous wells in the Rock Springs area. Maps
showing regional location and well patterns at individual research sites are
presented in Figures C-33 and C-34. The following parameters are measured
monthly at Sites 6, 9, and 10 and quarterly at Green River Site 2 and the Upper
Green River Basin: Na, K, Ca, Mg, Cd, CI, F, NOs, SOi,, CO3, HCO3, POi, -Ortho,
NH3-N, TDS, hardness, total alkalinity, pH, conductivity, COD, TKN, DOC, TIC,
TC.
This monitoring program is expected to continue indefinitely, with the
possibility that monitoring frequency at Green River Site 2 and Upper Green River
Basin will be extended to annual sampling.
Proposed Monitoring Programs—
At Rock Springs Site 12, the water resources monitoring program is more
sophisticated, since it has been developed more recently. Observation wells have
been drilled in a semicircle around the central areas (Wells E5, E6, 5 and 7), as
shown in Figure C-34. These wells will be monitored in the preoperational,
operational, and post-operational phases of Site 12 development. The schedule of
proposed monitoring is presented in Table C-32. The parameters to be analyzed
under schedules A, B, and C are listed as follows:
Analysis Schedule A Parameters: Analysis Schedule B Parameters:
Alkalinity
Ammonium ion/ammonia
Bicarbonate/carbonate
Boron
Calcium
Chemical oxygen demand (COD)
Chloride
Conductivity
Magnesium
Oil and grease
(separation tank and
evaporation pond only)
pH
Potassium
Residue on evaporation (ROE)
Sodium
Sulfate
Thiosulfate
Total Kjeldahl nitrogen (TKN)
Arsenic
Cyanide
Mercury
Selenium
Tetrathionate
Thiocyanate
Analysis Schedule C Parameters:
Aluminum
Barium
Cadmium
Chromium
Copper
Fluoride
Iron
Lead
Manganese
Nickel
C-134
-------
J ~
<8)
0
1500-
• 12
Y 11*.
B>
>~
200'
s» %y
9« ly^S' *7
?'r
300
.•13
8
125'
LEGEND
^Injection Well #9
£3 Injection and
Monitoring Well <110
^ Honitor Hells
100'
B12
* L7
100'
.100' _
. . 100' .
2
L12
100'
<
~ t
~C
^ D ^ 01
Rock Springs Sites 9 and 10
~ L17
50'
+ L19
Upper Green River Site 2
LEGEND
^Monitoring Hells
Oi
<>B2 <>2 O8
^ o*
V« +7
I
(Q)
~ " <>E4 O6
~ ES ~S
LEGEND
0 Production Hells
~ Monitoring Wells
A EPA Wells
(approximate)
~l
~ ~£~<
~ 2
LEGEND
^ Moriltoririg
Well
A ~
Rock Springs Site 12 (Proposed)
Bock Springs Site 6
Figure C-34. Monitoring well patterns at Rock Springs research sites and Upper Green River.
-------
TABLE C-32. PROPOSED WATER SAMPLING SCHEDULES
AT ROCK SPRINGS SITE 12
Phase and sampling
location
Analysis schedule
A
B
C
Pre-operational phase:
Production wells
wa
B
T
Observation wells
W
B
T
(Collector
(Oil-water separator
(Oil tank
Evaporation pond
——
Operational phase:
Production wells
W
B
T
Observation wells
w
B
T
(Collector
v.
H
(Oil-water separator
vr
tr
(Oil tank
Evaporation pond
B
M
M
c
Post-operational phase:
Production wells
W,M
B,Q
T,S
Observation wells
W,M
B,Q
T,S
(Collector
(Oil-water separator
(Oil tank
Evaporation pond
B,M
M,Q
M,Q
a
B - Biweekly (every 14 days +_ 2 days)
M - Monthly (every 30 days 3 days)
Q - Quarterly (every 90 days + 10 days)
S - Semiannually (every 6 months + 20 days)
T - Twice during the period (minimum time separation, 3 weeks)
W - Weekly (every 7 days +_ 1 day)
A sample should be taken from the oil-water separator whenever discharge is
made to the evaporation pond, and the quantity of the discharge should be
recorded.
Q
Two frequencies are recommended: The first relates to near-term monitoring
requirements (for 3 months after the experimental burn) , and the second to
long-term monitoring.
C-136
-------
Total inorganic carbon (TIC) Nitrate
Total organic carbon (TOC) Sulfide
Zinc
The wells will be pumped before sampling to achieve a water volume
representative of the surrounding aquifer. Some measurements will be made in the
field, and others will be made in a water quality laboratory. Appropriate
preservation and transporting practices will be employed.
Biological Resources
Vegetation—Plant collections were made in spring 1976 by walking the Rock
Springs research area. Collections were identified and confirmed using the Rocky
Mountain Herbarium located at the University of Wyoming. Concurrently,
vegetation maps were compiled by using photographs.
Two sites were surveyed (the alternate and primary site) by the line intercept
method. The quandrants and line transects were taken in what was considered to be
the center of each homogenous plant community. 30.5 cm (1 ft) quadrants were
positioned every 3 m (10 ft) along a 30.5 m (100 ft) tape stretched above the shrub
layer.
Shrub cover was determined by the line intercept technique. The 30.5 m (100-
ft) tape was positioned in a random manner. The 30.5 cm (1 ft) square quandrant
was divided by two crossbars perpendicular to each other and centered within the
30.5 cm (1 ft) square. One crossbar had an arrow painted on it. The 30.5 m (100 ft)
tape was placed at the edge of the quadrant and stretched in the direction of the
arrow. In areas where narrow homogenous plant communities existed, the tape was
centered within the community and stretched parallel to the edges.
Birds—
A literature search was first conducted, and then observations were carried
out by walking through the area in the morning and evening. Birds were identified
according to species. No estimation of density was attempted.
Mammals-
Large mammals were surveyed using visual observation in the early morning
and evening. Pellet transects were taken to verify area use.
Small mammal species were identified through literature search.
Aquatic Biota-
Four reaches of Bitter Creek and Killpecker Creek were selected for aquatic
biota sampling considering: Relationship to future DOE sites, representation to
future DOE sites, representation of other reaches, and accessibility. Field
measurements were conducted on May 15, 1975, at each study site.
Fish collections were made using 25-ft nylon seines having a depth of 1.2 m (4
ft) and a 0.4763 cm (0.1875 in.) mesh size. For each fish collected, total length was
measured to the nearest 1.0 mm (0.04 in.), and weight was recorded to the nearest
1.0 g (0.28 oz). To avoid misidentification of the species collected, representative
C-137
-------
individuals were preserved in 95 percent alcohol and transported to Laramie for
verification. Fish population estimates were made.
To survey the benthic invertebrate populations, five bottom fauna samples
were taken at each study site, with each sample encompassing an area of 0.023 m2
(0.25 ft2). Random number tables were employed to select sampling locations. All
collections were made using an Eckman dredge (a spring-operated, jaw-type sampler
because of the soft mud and sand substrate present. The benthic invertebrates
collected were then identified using available keys, enumerated, and placed on a
number/.09 m2 (1.0 ft2) basis. Shannon Diversity Index values were calculated for
each site to facilitate comparisons of benthic community structure.
Physical and Chemical-
Discharge was measured at the Bitter Creek study sites using a Price current
meter and top-setting rod, following standard USGS procedures. Flow could not be
measured at the Killpecker Creek sites because of extremely shallow water.
Field measurements were taken for pH, specific conductance, dissolved
oxygen, and temperature using the following equipment:
1. Sargent-Welch Model PBL pH meter
2. Yellow Springs water temperature and specific conductance meter
3. Yellow Springs dissolved oxygen meter
Turbidity samples were collected and analyzed in Laramie using a Hach
turbidimeter.
Solid Wastes Disposal, Revegetation
Where applicable, revegetation of the mine site will be implemented. The
plans covering this aspect of the project include the following:
a. LETC will accomplish revegetation of all affected lands in a manner
consistent with the approved reclamation plan and the proposed
future use of the land.
b. Land that did not support vegetation before becoming affected land
because of natural soil conditions will not be revegetated unless
subsoil from such affected land will support vegetation.
c. After backfilling, grading, contouring, and replacing topsoil and/or
an approved substitute in such a manner as to accommodate most
efficiently the retention of moisture and control erosion on all
affected lands to be revegetated, LETC will fulfill any fertilizer
requirements as determined on the basis of previous analyses.
Seeding that is accomplished by mechanical drilling will be on the
contour unless specific situations dictate that other methods of
seeding be used.
C—138
-------
d. The species of plants (grasses, legumes, forbs, shrubs, and trees)
seeding rates, seeding techniques, mulching requirements, and
seeding times to be used in a given area for reclamation purposes
shall be in accordance with rules, regulations, specifications, and
standards adopted by the State Conservation Commission and
approved by the Land Quality Division. Whenever practicable, the
Wyoming Game and Fish Department and the Wyoming Department
of Agriculture may be consulted regarding revegetation procedures.
Seed types will depend on the climatic and soil conditions prevailing
in the permit area and the proposed use of the land after
reclamation. Species to be planted as permanent cover shall be
self-renewing. Seeding rates will depend on seed types, climatic and
soil conditions, and the techniques to be used in seeding.
e. More suitable species of vegetation may be substituted if
revegetation test plot results show such species to be of superior
value for reclamation purposes.
f. LETC will protect young vegetative growth from being destroyed by
livestock by fencing or other approved techniques for a period of at
least 2 years, or until the vegetation is capable of renewing itself
without supplemental irrigation or fertilization.
g. In those areas where there were very few or no noxious weeds
before being affected by mining, LETC will control and prevent the
introduction of noxious weeds into the revegetated areas for a
period of at least 5 years after the initial seeding.
Noise
No programs for the monitoring of noise have yet been designed.
Radioactivity
No programs for the monitoring of radioactivity have yet been designed.
Surface Subsidence
No programs for the monitoring of surface subsidence have yet been designed.
PARAHO
Air Resources
Stack effluent data at Anvil Points have been accumulated by the Gulf Energy
and Minerals Co. (May 5-16,1975), Rocky Mountain Technology (November 25-26,
1975), and TRW, Inc. (March 6-15, 1976). The data were obtained during retorting
operations from all stationary sources, including boiler stacks, thermal oxidizers,
and the retort external heaters. In addition, the heater stacks were monitored
frequently during the direct and combination runs. Monitoring was performed on the
thermal oxidizer stack during 1976. The air quality parameters that were measured
are listed in Table C-33.
C-139
-------
TABLE C-33. AIR QUALITY PARAMETERS MEASURED DURING THERMAL
OXIDIZER STACK MONITORING
Parameter
Source
02
CO
co2
HC H2S
so2
NO
X
NH
Recyle gas
X
X
X
X
X
X
Boiler stacks
X
X
X
X
X
X
Thermal oxidizer stacks
X
X
X
X
X
X
X
Pilot plant heater stacks
X
X
X
X
Semi-works heater stacks
X
X
X
X
X
During this period of time, Development Engineering, Inc. monitored air
(process gaseous emissions, ambient air quality, and meteorology) to satisfy DOE
contracts.
Process Gaseous Emissions—
During various periods of time in 1977 and 1978, the thermal oxidizer at
Paraho was sampled weekly, and the rotary seal leakage was monitored weekly
(October 1977 - June 1978). During the same period, recycle gas and headspace
from the raw shale bins were also analyzed periodically. Gaseous and particulate
sampling of the thermal oxidizer discharge was done through an available port in
the stack. Recycle gases were sampled between the electrostatic precipitator and
the recycle gas blower. Gas samples were taken using an integrated gas sampling
train. The gas was pulled through a stainless steel probe and an ice bath condenser.
A flow meter measured flow into a Tedlar bag. A high-volume source assessment
sampling system was used to monitor particulates. About 1,200 standard liters (42
cu. ft) of sample gas were processed in each test for high accuracy. A diagram
illustrating the locations of these sampling sites is presented in Figure C-35. The
air quality parameters addressed, and the methods of analysis for process emission
monitoring are shown in Table C-34.
Ambient Air—
The ambient air around the mine (Adits No. 1 and 2), haul road, crusher, retort
and shale disposal areas was monitored for 2-week periods to determine particulate
and priority air pollutant concentrations. All four areas were monitored in
December 1972 and January 1978.
O2, CO2, CO, and CHi» were measured using GC. Metals were measured using
AAS, and S02 and NOx were measured using colorimetry. Particulates were
sampled with a high-volume sampler, tape sampler, and Cascade Impactor.
C-140
-------
0
1
Raw Shale
Fines
Shale
Feed
Raw
Effluent
t Mists
Gas
Oil
Wet
Retorted Shale
DRY OIL
WATER
BINS
Product
OIL/GAS
SEP 'N
MINE
OIL/WATER
SEP1N
CRUSHER
• Sampling Points
LEGEND
PILOT
PLANT
SEMI-WORKS
THERMAL
OXIDIZER
Figure C-35. Sampling points of gaseous process emissions at Anvil Points
operations, Colorado.
-------
TABLE C-34. AIR QUALITY PARAMETERS AND METHODS OF ANALYSIS FOR
PROCESS EMISSION MONITORING AT ANVIL POINTS
Parameter
Source O2 CO CO2 NOx H2S SO2 HC H2 M2 Ar Pb Hg Se Methane
Thermal
oxidizer
Xa X
XX X
X
Recycle gas
Ab A A A
Rotary seal
leak
Gc
G G G
Storage
headspace
G G
G G G G GGGAAAA
G
a
.Unknown method of analysis
Atomic absorption spectrophotometry
cGas chromatograph
Five specific sites were chosen in the Anvil Points mine area for sampling.
The locations and sampling dates for each are shown in Figure C-36. Seven specific
sampling sites were used around the crushing area. The locations of these sites and
the dates of sampling are presented in Figure C-37. The six sampling sites chosen
around the retorting operations and shale disposal areas are located in Figure C-38.
The three sites selected at the retorted shale disposed area are also shown in Figure
C-38, along with a sampling schedule.
Meteorology—
A weather station was established to monitor local meteorology from
December 1972 to June 1978. The meteorological parameters measured for certain
time periods are listed below.
High and low temperatures
High and low mean temperature
Precipitation
Relative humidity
Evaporation
Wind direction
Aerovironment, Inc. performed a detailed study of surface wind direction and
speedy temperature variations and drainage flow. Tethersonde experiments were
also performed.
C-142
-------
#13XCut
George
Drift
#HXCut
#9XCut
Able
Drift
Charlie
Drift
#7XCut
Easy
Drift
#5XCut
Rvent
#3XCut
#lXCut
Adit
#1
LEGEND
Sampling
Date of
Site
Sample
1
12/ 7/77
2
12/ 8/77
3
12/ 9/77
4
12/12/77
5
12/13/77
Figure C-36.
Sampling sites for ambient air quality monitoring
around the mine at Anvil points.
C-143
-------
LEGEND
Sampling
Date of
Site
Sample
1
1/18/78
2
1/19/78
3
1/23/78
4
1/24/78
5
1/25/78
6
1/28/78
7
1/29/78
©
Fines Belt
Fines Belt
©
Figure C-37.
Sampling sites for ambient air quality
monitoring in the crushing area at
Anvil Points.
Bins
Polishing
Screen
Room
Convevor #7
C-144
-------
Conveyor #7
Cliff
Edge
.Pilot
Plant
Screw Conveyor
Paraho Retort
Operations Area
Paraho
Shale
Disposal
Area
Semi-^2 4
Works
.Conveyor #
Gas
Blowers
Embankment •
LEGEND
Retort Sampling
No. Location Date
1 Bottom Rotary Seal 12/22/77
2 Middle Distributor 12/23/77
3 Top Rotary Seal 12/24/77
4 Top Rotary Seal 12/26/77
5 Bottom Rotary Seal 12/27/77
6 Gas Blower 12/30/77
Retorted Shale Sampling
NO. Location Date
m N. of Screw 1/ 8/78
Conveyor
IT] Retorted Shale 1/12/78
Belt
[T| Between Belt and 1/22/78
Conveyor
Figure C-38. Sampling sites for ambient air quality measurements around the
retorting operations and shale disposal areas at Anvil Points.
C-145
-------
Water Resources
Sampling of process water and ambient surface water and groundwater was
conducted from 1973 to 1978. The monitoring programs have been reported for two
periods: 1973-76 and 1977-78.
Process Water—
Because water remains as vapor in the Paraho recycle and product gas,
samples were taken from oil storage tanks and condensate samples from recycle gas
lines. Most of the water samples were taken in 1975 and 1976 and were analyzed
according to the parameter schedule shown in Table C-35.
Process waters were analyzed weekly between 1977 and 1978 for carbon,
hydrogen, nitrogen, sulfur, mineral carbon dioxide, sulfate, sulfide, ammonia, and
total organic carbon. Periodically, a separate analysis of 43 parameters was also
conducted on process water. These 43 parameters and some of the analytical
methods utilized are listed in Table C-35.
From October 1977 through April 1978, the evaporation pond was sampled
monthly, and the samples were sent to Natural Resources Laboratory and
Commercial Testing and Engineering for analysis. A list of the parameters analyzed
and some methods are shown in Table C-35.
Surface and Groundwater--
A surface water and groundwater monitoring program was initiated in 1974 to
assess the salinity effects, hydrocarbon spills, and potential release of toxins to
animals and plants caused by oil shale development. Samples were collected
quarterly from six stream sites (Figure C-39) and tested for 43 water quality
parameters (Table C-35).
A special study was made to sample several streams from Balzac Gulch that
flow adjacent to mine traffic and retorting operations, and also to sample one
stream that is not at all affected. The study was a one-time sampling in October
1975.
Six surface streams continued to be monitored between 1977 and 1978. The
water was analyzed for the parameters noted in Table C-35. Identical samples were
sent to Natural Resources Lab and Commercial Testing and Engineering for analysis.
Other Environmental Studies
Several additional studies have been conducted at the Paraho project to
determine the impacts of oil shale development on air quality, water quality, and
public health. Although these studies are not available for public review, they are
mentioned briefly here for future reference.
The Los Alamos Scientific Laboratory was contracted by the DOE to monitor
fugitive dust and all priority gaseous pollutants in the mine, crushing, retorting and
shale disposal areas of the Paraho project. Some materials related to the process
were analyzed for toxicology purposes. A small amount of work was also done on
noise monitoring.
C-146
-------
TABLE C-35.. WATER QUALITY PARAMETERS AND METHODS OF ANALYSIS
EMPLOYED DURING PROCESS WATER, SURFACE HATER, AND
GROUNDWATER MONITORING AT ANVIL POINTS
Puaattut, ppn Method of Analysii®
Aluminum
A
Arsenic
A
Barium
A
Boron
A
Cadmium
A
Calcium
A
Chromium
A
Copper
A
Iron
A
Lead
A
Magnesium
A
Mercury
A
Molybdenum
A
Potassium
A
Selenium
A
Silver
A
Sodium
A
Silicon
A
Zinc
A
Alkalinity
' as CaC03
T
Carbonates
i as CO,
C
Carbon, total <«
P
Carbon, organic
P
Chemical oxygen demand
T
Chloride
Cyanide
I
Fluoride
I
Hydrogen,
total
P
Nitrogen,
total
C
Nitrogen,
aamonia
c
Nitrogen,
nitrate
c
PH
Phenol
|
G
Phosphate,
total
c
Suspended
G
Dissolved
solid®, total
G
Sulfate
Sulfide
G
Sulfur, total
T
Salinity
Oil and grease
Silica
Kjaldahl nitrogen
S - Parkin Elmer elemental analyzer
L " LECO sulfur analyser
T ¦ Titrametric techniques
C " Colorimetric techniques
A • Atonic absorption
I - Ion sensing electrodes
G " Gravimetric techniques
C-147
-------
% Paraho
f Mine $
ft Oo
Paraho
Plant
Miles
Figure C-39.
Locations of stream sampling sites at Anvil Points.
-------
The EPA commissioned the Oak Ridge National Laboratory (ORNL) to conduct
health effects and toxicology assessments on process solid and liquid wastes.
Gulf South Research Institute has conducted process, groundwater, and surface
water quality monitoring under the direction of EPA.
Battelle Northwest, under the direction of DOE, has performed analyses of
process water and gaseous emissions. In addition, analyses of raw and retorted shale
have been conducted.
Under a joint program with the University of Colorado, Colorado School of
Mines, and Colorado State University, the DOE has conducted research on retorted
shale as it relates to land disturbance, revegetation, and leaching of undesirable
compounds.
Solid Wastes Disposal, Revegetation
A study was conducted by Colorado State University for the EPA to determine
the effects of leaching spent shale disposal piles and to test various methods of
spent shale revegetation.
Two lysimeters (waterproof containment areas designed to help determine
percolation and leachate characteristics), each 13.4 m (44 ft) wide by 40 m (131.2 ft)
long and 2.4 m (7.9 ft) deep, were constructed to simulate the disposal system
described above. The lysimeters were constructed of reinforced concrete with
water stops between the cold seams. Each lysimeter has a 25-percent slope
representing the fill face and a 2-percent slope representing the fill area. In the
lysimeters, a 90-cm (35.4 in.) deep layer of compacted retorted shale (1.5 to 1.6
g/cm3 or .027 to .028 oz/in.3) was covered with a 150-cm (59.0 in.) uncompacted
zone (1.2 to 1.4 g/cm3 or .042 to .049 oz/in.3) (Figure C-40). The study was
designed with two lysimeters to provide replication for mathematical hydrological
modeling work during the leaching phase, and then to serve as separate units in
which to simulate both a high-elevation (moist) and a low-elevation (dry) disposal
site.
The study site is 0.3 km (0.19 mi) south-southwest of the housing area at the
U.S. Department of Energy, Anvil Points Oil Shale Research Facility. The study
site, which is on public land managed by the Bureau of Land Management, is
characteristic of a low-elevation disposal site with an elevation of 1,737 m (1.08 mi)
and a mean annual precipitation of approximately 28 cm (11.0 in.). Both lysimeters
were built at this site because of its proximity to water, electricity, retorted shale,
and concrete construction supplies. Greater precipitation and less evaporation at a
high-elevation disposal site was simulated in one of the lysimeters by applying
additional irrigation water.
The following six treatments were tested in each lysimeter on both a
2-percent and a 25-percent slope:
1. Retorted shale to the surface (shale treatment), leached
2. 20-cm (7.9 in.) soil cover over retorted shale, leached
C-149
-------
0
1
t-*
ui
o
tonUomrtm
won «©N»aer*
«ootf Semi Kan
£5>r<*» MCiii \wb»
' 7 ; « «rc">/*T.V^
Q fo.^V) vJ -• traj i ;.rq»»-frfc
L^»Jj~Vrrt',' ~ 4- Jm (17; t'Vi.. ^ l, ,, „ , r , !; LJ (
_ _ -,..-...-.,.?™'*Jji''y<[!\M.J-?*Kata «0"6 '>• ;.t::^'-q-.''^:-o';->3ArrrTT
ffifsTH-O" iuJIw J lli HUj SillYliI 5(11 jilt; III JIIII £"n J HI Jul i III Jill ="11/ -11/:llWr^4jir H'tJU/ l» t hi t"'i £ i" *mi? i'is i" * l"JcS..* mi c»i£ u>a>">f '"-
IScm ralnfcrsx cencrM* pod
-( Jm I tl')~
M:jlis|ll5«iaNI£«r
Figure C-40. Cross section showing the design of the lysimeters at the Paraho Development.
-------
3. 40-cm (15.7 in.) soil cover over retorted shale, unleached
k. 60-cm (23.6 in.) soil cover over retorted shale, unleached
5. 80-cm (31.5 in.) soil cover over retorted shale, unleached
6. soil control, unleached
Thus within each lysimeter there are 12 treatment areas 6.7 by 6.7 m (7.3 by 7,3 yd),
six with a 2-percent north-facing slope, and six with a 25-percent south-facing
slope. Each of the 12 treatment areas has an upper drain at the interface of the
compacted and uncompacted zones and a lower drain beneath the compacted zone.
Each of the 12 treatment areas are separated into two side by side vegetation
and surface runoff replications (3A by 6.7 m or 3.7 by 7.3 yd) divided at the surface
with a redwood board. Each 3A by 6.7 m (3.7 by 7.3 yd) replication has a set of
instruments to monitor water and salt movement and a surface runoff collector.
The location and plot plan for each of the treatments and replications are shown in
Figure C-^l.
COLONY DEVELOPMENT OPERATION
Air Resources
Baseline Data Gathering Program-
Since the Colony Development Operation (CDO) is not on Federally-leased
land, it was not necessary to satisfy a 2-year baseline study lease stipulation.
However, many studies have been conducted for CDO since the 1960's to determine
if the plant could be located at several different sites on the Dow property without
creating air pollution in excess of State and Federal standards. The baseline air
quality data gathering program consisted of the following studies published in
References 58-61:
1. Parachute Creek Valley Diffusion Experiments - September 1972
2. Climate and Air Quality Analysis of the Parachute Creek Airshed,
Garfield County, Colorado, January 1973
3. Climatology at Parachute Creek, April 1973
4. An Evaluation of Existing Air Quality Data Obtained at the
Parachute Creek Site of the Semi Works Plant, July 1973
5. Atmospheric Dispersion of Airborne Effluents from the Roan
Plateau, October 1973
6. Colony Development Operation (various internal studies)
The contractors on these programs were Thorne Ecological Institute, Battelle
Pacific Northwest Laboratories, Dames 6c Moore, and CDM Environmental
Consultants.
C-151
-------
Lab/Office
"frailer
o Weather Station
Evaporation Pan
9% 9?9 ?Qg- gQ? -gSk.S&L
hQ4 | H22|H?0 H18|H« WM| H10| HS | H6 | H4 | H2
H23
HI 7
HI 3
Mil
H7
HI
KJ
Gravel
Road
Sign
HIGH ELEVATION LYSIMETER
Sign
(100) 30m
Irrigation Water Line
and Controller
LOW ELEVATION LYSIMETER
L2
L8
L4
LO
L16
U4
L3
U
Lit
LO
LIS
U3
137
LIS
L21
L23
40m
Figure C-41. Plot plan of lysimeter study site.
C-152
-------
The climate and air quality analysis of the area—In mid-1969, CDO initiated a
program of ambient air quality sampling in the Parachute Creek Laboratory site.
This study lasted until the end of 1972. An analysis of the meteorology and air
quality collected was described in a report prepared by Dames 6c. Moore (59).
Similar programs were conducted afterwards, and they are being augmented in
two more primary locations in the area. In October 1970, Dames <5c Moore operated
a network of six mechanical weather stations (Stations 1-6 on Figure C-42) for
approximately 14 months. The rest of the stations in Figure C-42 along the
Parachute Creek Valley were operated for several months in the spring of 1972 by
Thorne Ecological Institute. Analysis of selected features of the area based on the
data collected in these stations was prepared for CDO by Dames & Moore and
Thorne Ecological Institute (58,59).
The air quality program conducted in the above studies included continuous
analyses for sulfur dioxide, oxides of nitrogen, total hydrocarbons, particulates, and
the total sulfur content of the air. The program also included the recording of
temperature, relative humidity, barometric pressure, wind, wind direction,
precipitation, and solar radiation.
The continuous measurement of sulfur dioxide was performed by means of the
Scientific Industries Model 67 Analyzer/Recorder. This instrument detects the
presence of SO2 by measuring the conductivity change in a known volume of
electrolyte produced by impingement of a known volume of ambient air. The
method of impingement of this particular instrument is such that interferences are
minimized. Continuous measurement of total hydrocarbons was performed at
Parachute Creek by means of the Beckman Instruments Model 400 hydrocarbon
analyzer. This instrument detects the presence of hydrocarbons in four decade
ranges from 0 to 10,000 ppm in the ambient air by the method of flame ionization.
The continuous measurement of oxides of nitrogen at Parachute Creek was
performed by means of the Beckman Model 909 NO analyzer. The instrument has
three indicating ranges--0 to 0.2 ppm, 0 to 0.5 ppm and 0 to 1.0 ppm. Integrated 24-
hr measurements of particulates were performed by means of the standard high-
volume sampler. The high-volume samplers within Parachute Creek were regulated
by timers to sample 15 min out of each hour. Periodic calibrations of the sampler
flow rate indicators were performed before weighing both the exposed and
unexposed filter paper. The total sulfur content of the air was determined at
several locations by means of sulfation discs, whose active agent is Pb02. This
powerful oxidizing agent reacts readily with several sulfur-bearing compounds,
including SO2, SO3, H2S, sulfuric acid mist, mercaptans, and organic sulfides. The
discs were exposed to the ambient air for a 30-day period and then sent to a
commercial laboratory for analysis in accordance with well-defined procedures.
Field tracer studies—During the week of May 31 to June 6, 1972, an extensive
field study was undertaken to determine the ventilation rate through the Parachute
Creek Valley. This study (60) involving the measurement of diffusion of tracer
particulates was conducted jointly with the CDO and Battelle Northwest
Laboratories. Seventeen tracers were released during the 7-day experimental
period. Fluorescent dye, sulfur dioxide, and silver iodide particles were released
from various heights of the two towers. One of the towers was located on the Roan
Plateau, and the other is at the confluence of the East Middle Fork and Middle Fork
Valleys of Parachute Creek. Sampling of the fluorescent dye and the silver iodide
C-153
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(6620) (8200)
(6270)
Colony
Mines
4 (7000)
»6 (6310)
1 (6025)
(5990)
(5610)
Relay Tower
Stations
11 (5340)
Parachute Creek
•8 (5160)
Grand Valley
US
J (5195)
Xl7 (5415)
X 16 (5765)
(5025)
i De Beque Ridge
(5255) ' Stations
13
Morrisania Mesa
Stations
Colorado River
15 (5970)
14 (4978)
Figure C-42. Location map for CDO primary weather station.
-------
was performed with engine-driven vacuum pumps that drew air at a controlled flow
rate through filters on which the particulates were collected. Sulfur dioxide
sampling was accomplished with battery-driven, miniature pumps that bubbled air at
a constant rate through a solution that retained the sulfur oxide. Thirteen other
sampler systems were operated at the 18 sampling sites in the Valley. Only
particulate samplers were operated at an additional 12 sites east and west of Grand
Valley on U.S. Highway 24. Aircraft sampling of silver iodide was performed with
an electro-optical ice-nuclei counter. The counts that are recorded on a strip chart
as a function of time are converted to concentrations and correlated with aircraft
positions for those times during analysis. Meteorological measurements such as
temperature, wind velocity, and humidity were recorded at the two previously
mentioned release towers and at a third. A rawinsonde unit was operated to obtain
vertical profiles in and above the Valley on run nights.
For analysis, the fluorescent tracers were washed from the sample filters by a
fixed volume of distilled water, and the fluorescence was measured with a G. K.
Turner Associates fluorometer. The measured fluorescence was then converted to
concentrations in air using the sampler flowrate. The sulfur dioxide samples were
analyzed with a Technicon Autoanalyzer using the sulfamic acid variation of the
West-Gaeke method.
Unfavorable conclusions from the above investigation resulted in another
study, performed on the Roan Plateau. The location of the new site is indicated in
Figure C-43, along with the release tower, whose location is shown by an asterisk.
An onsite field experiment was conducted on seven consecutive days in the period of
June 29 - July 6, 1973. It included the release and sampling of tracer material, the
tracking of pibal balloons, the tracking of no-lift (constant density) balloons, and the
operation of an aircraft to obtain definition of the temperature field over the region
of interest. Meteorological data were recorded from three tower levels during this
period.
The tracer used in the tracer experiments was Tracerite FP3206, which
fluoresces green under ultraviolet light. The material was fluidized to assure free
flow from the tower-mounted dispenser and separated into individual particles. The
metering system was remotely controlled so that a constant emission rate could be
maintained. The rotorod sampler was the device used to sample the air
concentrations of tracer, and the samplers were mounted on wooden stakes at a
height of about 150 cm (59.0 in.). Locations of the sampling positions used are
shown in Figure C-43. Assay of the sample collector rods was performed by a visual
count of the particles. The rod was mounted in a suitable holder on the mechanical
stage of a microscope and was illuminated by ultraviolet lamps in an otherwise fully
darkened room.
Pibal tracking—Pibals are small balloons that are ballasted to rise on the order
of 150 m/min (492 ft/min) and to respond to the wind velocities that they encounter
during the rise. Results of this operation were generally disappointing because of
the difficulty in accurately locating the pibal at its first observation 30 sec after
release.
Aircraft soundings—The aircraft soundings were invaluable in determining
vertical temperature profiles at the site for comparison with Grand Junction
rawinsonde temperature profiles.
C-155
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©
4
•D18
¦oo. » «
0 1 2 3 4 5
1 1 I 1 ..I l
Kilometers
\L/ Source
(60 m Tower)
% Sampling
Locations
Elevation in
Feet
Figure C-43. Location map for CDO atmospheric dispersion
sampling stations.
C-156
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Interim Monitoring Program-
While awaiting a favorable economic climate for commercial development, the
CDO has ceased its semi-works mining and retorting operations. Since the last
operation of the semi-works plant in 1972, the Parachute Creek environmental
studies program has been maintained at a low level.
No publications are available that describe the monitoring program that has
been implemented at the CDO since 1973. All information on this subject was
supplied by Mr. Max Legatski, Coordinator for Permits and Water Contracts, and
Mr. Larry Kline, Environmental Coordinator for the Atlantic Richfield Co. (ARCO).
Presently there are three meteorological stations operating on CDO property.
Wind speed, wind direction, and temperature are recorded continuously. At two
monitoring sites, particulate concentrations are monitored every 4 days. In
addition, precipitation is being measured at Davis Gulch.
In addition to the field monitoring program, a number of studies have been
recently prepared regarding environmental consequences of CDO commercial
development. These studies include References 62-65.
Commercial Development Phase Monitoring Program-
Presently there are no detailed plans for a commercial operation monitoring
program. The Colony Development Operation has agreed to conduct stack
monitoring as part of permit requirements, but ambient monitoring is still not well
defined. An official ambient monitoring schedule will be developed subsequent to
agreement with EPA and the Local Air Pollution Control District.
Water Resources
Baseline Data Gathering Programs—
The baseline surface and groundwater data gathering programs were mainly
conducted between 1972 and 1974. The project contractors were the Thome
Ecological Institute and Wright Water Engineers. The documents published on the
subject include the Colony Environmental Study (58) and Water Studies, Parachute
Creek, Colorado (66]l The reports that have been discussed in these published
documents and that have been utilized in the completion of this study include the
following:
1. Water Quality of the Parachute Creek Ecosystem and the Impact of
Possible Oil Shale Operations
2. Chemical Water Quality Characteristics of Parachute Creek
3. Preliminary Water Supply Strategy for One Oil Shale Plant in
Parachute Creek Basin
k. Colorado River Salinity: Impact of Parachute Creek Oil Shale Plant
and Alternatives for Mitigation
5. Moisture Level Investigation of the Colony Spent Shale Disposal
Embankment, Parachute Creek, Garfield County, Colorado, July
1976
C-157
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Surface water quality studies—One water quality study was conducted by
Thorne Ecological Institute for CDO in 1973 (67). The purpose of this report was to
define the water quality of Parachute Creek and its tributaries with regard to
inorganic constituents. Data for the study were extracted from extensive water
records in Colony files. For this reason, there were no data presented on frequency
of sampling and analysis. The collecting stations from which data were gathered to
be used in analyzing impacts were chosen to give a reasonably valid representation
of the Parachute Creek Watershed. A map of these stations is presented in Figure
C-44. The water quality parameters measured during the study are listed as follows:
Total dissolved inorganic solids
Total dissolved solids
Total anion or cation
SO*
Na + K
HCO3 + CO3
Mg
Ca
CI
Flow
DO
BOD
PH
EC
TDS
Ion balance
Suspended solids
Turbidity
F
Ni
Hg
Pb
Cd
Fe
Mg
Ca
Na
SAR
HCO3
CO$
A1 Pyrite
Cu Feldspar
Zn Analcite
Ca Clays
Co Quartz
CO2 Carbonates
Temperature
PH
Organic
Toxicants
Inorganic
Toxicants
CI
SO-
N03
PO-
Si02
F
Conductivity, pH, and dissolved oxygen were all measured in the field using
commercially available meters and sensing probes (laboratory calibrated). Water for
laboratory analysis was collected in acid-washed new polyethylene bottles. All
samples were taken in duplicate, and analyses were run separately. Metals were
measured using an AAS. Mercury was measured using a cold vapor atomic absorption
spectrophotometer. All water analyses were performed in accordance with Standard
Methods (37).
From September 1969 to August 1972, water samples were taken by CDO to
determine the baseline chemical water quality characteristics of Parachute Creek
(67).
Water quality analyses were run on samples taken from 12 stations in the
Parachute Creek drainage basin and two stations on the Colorado River near the
mouth of Parachute Creek. Streamflow measurements were made at three gaging
stations operated by CDO. In addition, data were taken from records of three
streamflow gaging stations operated by USGS. A map showing the locations of the
CDO and USGS streamflow gaging stations is presented in Figure C-M.
Stream-flow data for USGS Stations 9-935, 9-930, and 9-928 are available for
the years 1922-27, 1949-54, and 1958-62, respectively. Streamflow data for CDO
Stations 551, 552, and 557 are available for June to September 1970 and August 1971
to 3une 1972.
C-158
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Gi
East Middle Fork,
West Fork
East
Fork
Parachute
Creek
Grand Valley
Colorado River
U. S.
Highway 6
LEGEND
2
Miles
Sampling
Location
Streamflow
Station
Figure C-44. Location map for CDO and USGS
water quality sampling stations.
C-159
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Water quality samples were taken for the period September 1969 to August
1972. During this time, 37 samples were taken from Stations 551, 552, 554, 555, and
556; 26 samples were taken from Station 553; 10 samples were taken from Stations
557 and 591; and two samples were taken from Stations 558, 562, 565, 566, and 567.
The water quality parameters that were measured are listed above.
Water supply—A study was conducted by Wright Water Engineers in 1973 to
determine the best method to secure an adequate water supply for a commercial oil
shale plant (67).
The study was very thorough and included a survey of the existing possible
sources of water supply (both surface water and groundwater). It also included an
analysis of the future availability of water rights in the area and of areas most
suitable for future water storage (reservoirs) development. Subsequent to the study,
recommendations were made as to the most appropriate form of action for CDO to
take.
Another study was performed by Gaylard V. Skogerboa, a consulting engineer,
for Colony Development Operation in 197k (67). The purpose of the study was to
determine the effects of water usage at the proposed Colony oil shale plant on the
salinity levels in the Colorado River System. First, the salinity effect of removing
283 1/s (10 cfs) of water (the amount anticipated to be necessary for the proposed oil
shale development) from the Parachute Creek drainage, and consequently the
Colorado River, was assessed. Second, alternative forms of water use in the
Parachute Creek watershed were recommended as mitigation to the projected
increase in Colorado River salinity.
Interim Monitoring Programs—
Since the last operation of the semi-works plant in 1972, the Parachute Creek
environmental studies program has been maintained at a low level. No publications
are available that describe the environmental monitoring programs that have taken
place since 1972. Representatives at the Atlantic Richfield Co. have provided a
description of the hydrologic monitoring practices presently being performed.
Water quality samples are being collected and analyzed along the major
drainages of Parachute Creek during high and low flow periods. Stream flows are
also regularly monitored. Groundwater levels are recorded on a monthly basis. Four
wells are soon to be equipped with continuous water level recorders.
In addition to the water quality monitoring program, some water resource and
water impact studies have been conducted recently. There are two major
unpublished reports that are most applicable to this study, and their titles are as
follows:
1. Water Pollution Potential From Surface Disposal of Processed Oil
Shale From the Tosco II Process; A Report to CDO. The Atlantic
Richfield Co., Denver, Colorado, October 1975.
2. Reconnaissance Study, Middle Fork and Davis Gulch Dams, Colony
Oil Project, Denver, Coi
-------
Commercial Development Phase Monitoring Program-
Presently there are no detailed commercial development phase monitoring
program plans available for public inspection. The Atlantic Richfield Co. has stated
that when commercial development proceeds, all State, local, and Federal legal
stipulations will be met.
Biological Resources
Baseline Data Gathering Program-
In the period 1970-73, the Thome Ecological Institute performed baseline
resource studies for CDO. The studies included air, water, and biological resource
monitoring programs, along with impact assessments of Colony's future
development. To assure thoroughness, a summary baseline data gathering program
has been provided for each project individually. CDO has, by far, provided the most
information on local ecology and the environmental impact of development than any
of the other private oil shale developers.
The reports that have been used in completing this report are published in two
documents—the Colony Environmental Study (58) and Ecological Studies (68). The
titles are as follows:
1. Vegetation Inventory and Impact Study of the Parachute Creek
Area, Garfield County, Colorado;
2. Warm Blooded Vertebrates Inventory Analysis and Impact Study of
the Parachute Creek Area, Garfield County, Colorado;
3. Lower Trophic Levels and Disease Vectors Inventory Analysis and
Impact Study of the Parachute Creek Area, Garfield County,
Colorado;
k. Annotated Checklist of Birds and Mammals Known to Occur in
Northwestern Colorado;
5. Big Game Fencing and Underpasses;
6. Cold Blooded Vertebrates of Parachute Canyon, Garfield County,
Colorado;
7. Competition Between Deer and Livestock;
8. Survey of 1972 Deer Season, Game Management Unit //32,
Parachute Creek, Garfield County, Colorado;
9. Literature on Beaver and Their Relation to Stream Flow - Inventory
of Beaver Ponds, East Middle Fork, Parachute Creek;
10. Movement of Mule Deer in Parachute Basin, Garfield County,
Colorado, 1971 - 1972;
11. Preliminary Review of Literature and Effects of Air Pollution on
Wildlife Habitat.
C-161
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Each of these reports is discussed briefly in the following subsections.
Vegetation inventory and impact study—Iri 1971, a study was performed to
determine in detail the vegetative resources existing in the Parachute Creek area of
Garfield County, Colorado (58). Before any field investigation, a significant
amount of time was spent in reviewing aerial photographs and topographical maps to
become familiar with the area and to design an efficient sampling technique.
Field work was initiated in June 1971. Plants were first collected from a
variety of habitats, identified, pressed for future reference, and listed. Transects
were established using the nested quadrant technique (69). This technique utilizes
10 m (32.8 ft) on a side for the tree stratum, 4 m (13.1 ft) for the shrub stratum, and
1 m (3.3 ft) for the herbaceous stratum. The quadrants were established along set
compass lines at 150 m (492 ft) paced intervals. These plots were established as
permanent after the 1971 reconnaissance sampling program. The procedure
followed during vegetation monitoring was as follows: All plant specimens were
verified by William A. Weber of the University of Colorado Museum. In the
laboratory, frequency for each species, density, cover, and height of each vegetation
type was computed.
Warm-blooded vertebrate inventory analysis and impact study—Before any
field work was done in the Parachute Creek Basin, a literature search was
performed (68). Very little published information was available dealing with wildlife
of the Parachute Creek Basin. The field work consisted of aerial and ground survey
techniques and small mammal trapping. A standard management area statistical
history analysis and some literature searches were also conducted.
General field observation techniques were used to identify the presence of bird
species in the area. An impact evaluation of the project development on wildlife
was conducted along with a study of recommended impact mitigation methods.
Lower trophic levels and disease vectors inventory analysis and impact study—
Aquatic invertebrates and blood-sucking arthropods were inventoried along the
Parachute Creek drainage areas at 14 locations in the summer of 1972 (58). The
locations of the sampling sites for aquatic ecosystems is presented in Figure C-45.
A Surber sampler was used to Inventory aquatic invertebrates. A .09 m2 (1 ft2) area
was disrupted, and all living residue was allowed to flow into the Surber net.
Examination of the net contents, either alive or preserved in alcohol or formalin,
permitted a determination of the number of animals in .09 m2 (1 ft2) of streambed.
Since conditions change almost continuously along the course of a streamflow, the
determinations made at each sampling site could only be considered valid at that
site. Samples were obtained by hand at places that did not permit the use of the
Surber sampler. A fine plankton net was used to sample true planktonic free-
flowing forms and forms dislodged from the streambed. Approximately 40 1 (10 gal)
was allowed to run through the net during each sampling experiment.
Special collections were made for protozoa by collecting submerged plant
materials or bottom samples. Collections were examined within a few hours.
Cultivation of protozoa in culture dishes was also attempted.
Five fish were killed and examined for feeding habits. Random collections
were made of biting arthropods such as mosquitos and deer flies. Information was
c-162
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East Middle Fork
'est
fork
East
VFork
Parachute
Creek /
Lindauer Ranch
10
Grand
_ey
Colorado
River
11
U.S. Highway 6
(13 miles from Grand Valley)
De Beque
13
LEGEND
14
Miles
Figure C-45. Location map for CDO aquatic ecosystem sampling sites for
the baseline biological resource monitoring program.
C-163
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gathered from nearby ranchers and the Colorado State Department of Health.
Water temperatures were measured, and samples were secured for dissolved mineral
measurements at alternate sites along the stream course (see Figure C-45).
Included in the environmental survey was an analysis of the impacts the CDO might
have on the inventoried animal species.
Annotated checklists of birds and mammals known to occur in Northwestern
Col or ado--A survey of ecological studies done in the area of Northwestern Colorado
was conducted in May 1972 (58). Paul Neil of the Thorne Ecological Institute
derived a list of various birds and mammals known to be in the area.
Big game fencing and underpasses—A review of ail the studies done in the area
of deer highway fatalities was conducted by Paul Neil of the Thorne Ecological
Institute. The October 1972 review (58) lists all known abstracts and references on
the subject.
Cold-blooded vertebrates—A description of all the cold-blooded vertebrates
known to exist in the Parachute Canyon area was compiled by Dr. David Dettus of
the Thorne Ecological Institute in September 1972 (58). The methods of sampling
and analysis are not presented in published documents.
Competition between deer and livestock—A review of all the studies done to
interpret the competition between deer and livestock in the Parachute Canyon area
was presented by Paul Neil of the Thorne Ecological Institute in May 1972 (58).
Survey of 1972 deer season—A survey of the hunter's actions in Game
Management Unit //32 was conducted in October 1972 (58). The methods used for
surveying included aerial survey and ground-based interview?. The information
gathered included the camp location, number of hunters and vehicles, the State and
County of hunters, total man days hunted, frequency of return to Unit #32, and
harvest and location of kill.
Beaver and beaver ponds—A list of references on information pertaining to
beaver and their relationship to stream flow was compiled, along with results of a
beaver pond inventory, by Paul Neil of Thorne Ecological Institute in June 1972 (58).
The methods of beaver pond surveillance are not described in detail.
Movement of mule deer—An analysis of mule deer migrations and local
movements in the Parachute Basin was conducted by the Thorne Ecological Institute
in 1972 (58). Winter mortality was first determined by walking linear transects 1.67
km (1 mile) long by one chain wide. Two men inventoried 39.12 km (2mi) or
121.3 ha (299.7 acres) of prime winter grazing land above Garden Gulch. For each
dead deer contacted, the following information was recorded: (1) age (2) sex (3)
years since death (4) distance from transect line and (5) condition of bone marrow.
A lower jaw was taken, if possible. Aerial and ground surveys were conducted from
January to April 1972. Special emphasis was placed on aerial views of trail patterns
and ground views of tracks, scat and actual presence of deer.
Effects of air pollution on wildlife habitat—A review of all available literature
dealing with the effects of air pollution on plants and animals has been conducted by
Thorne Ecological Institute (58). The review included a summary of the literature
C-164
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and some concluding comments as to the possible air pollution effects of the CDO
on existing air quality.
Interim Monitoring Program—
The monitoring program that has been instituted by the CDO in the interim
period between baseline data gathering and commercial development phase
monitoring includes limited monitoring of biological resources. CDO has conducted
big game counts during the interim monitoring phase and compiled a list of
endangered plant species (68).
Commercial Development Phase Monitoring Program-
No outline has been published for a commercial development phase biological
resource monitoring program at the Colony Development. CDO has stated,
however, that they will comply with all Federal, State, and local monitoring
requirements when commercial development operations are conducted.
Solid Wastes Disposed, Revegetation
Baseline Data Gathering Program-
Since 1965, many studies have been published on the disposal of solid wastes
generated in the production of oil shale at the CDO. Because the main source of
solid waste from this production would be in the form of spent shale, all of the
published studies either address the revegetation capabilities of processed shale or
possible alternative methods of large-scale solid waste disposal. The reports that
have been published on revegetation of processed shale at CDO have been published
in Environmental Impact Assessment at Colony Development Operation (70). Their
titles are as-follows:
1. 1965 Denver Field Experiment
2. Some Properties of Spent Oil Shale Significant to Plant Growth
3. Greenhouse Experiments of Plant Growth in Processed Shale
<*. 1967 Field Experiments at Parachute Creek
5. 1968-69 Semi-Works Plot Field Experiment
6. Vegetation Establishment Demonstration (1971) on TOSCO II
Processed Shale
7. Performance of Plants with Minimal Treatment of Processed Shale:
An Interim Report
8. 1973 Annual Revegetation Report
9. Growing House Plants in Processed Shale
10. Chemical Analyses of TOSCO II Processed Shale and Their
Interpretation Relative to Plant Growth
11. The Cost of Processed Shale Revegetation
C-165
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12. Estimated Water Balance of Davis Gulch: For Present Conditions
and After Use for Processed Shale Disposal
Reports addressing other aspects of massive solid waste disposal at CDO were
published in Environmental Impact Assessment at Colony Development Operation
(71). Their titles are as follows:
1. Uses of Spent Oil Shale Ash
2. Processed Shale Embankment Study
3. Proposed Shale Backfilling (Phase I)
k. Liquefaction Studies: Proposed Processed Shale Disposal Pile,
Parachute Creek, Colorado
5. Slope Stability Studies: Proposed Process Shale Embankment,
Parachute Creek, Colorado
The locations of all the revegetation sites developed by the CDO on the Dow
property are presented in Figure C-46. The revegetation studies cited above are
discussed briefly in the following subsections.
1965 Denver field experiment—Six test plots were constructed with dimensions
of .9 x .9 x .2 m (3 ft x 3 ft x 8 in.) (70). The six plots were filled to a 15 cm (6-in.)
depth with the following material:
Plot 1: 100 percent pure retorted shale
Plot 2: 100 percent pure retorted shale mixed with Platte River sandy
bottom clay
Plot 3: Sandy clay soil
Plot kt 100 percent processed shale
Plot 5: (Same as Plot 2)
Plot 6: (Same as Plot 3)
The plots were thoroughly wetted and mixed, planted, watered, and covered
with a moist burlap. Measurements were made of germination rate, root growth,
stem growth, drought resistance, and soil erosion.
Some properties of spent oil shale significant to plant growth—Two spent shale
samples, one from the TOSCO II process and one from the USBM gas combustion
process, were analyzed for properties significant to plant growth. In addition, two
shale/ash byproduct materials were analyzed, both from the TOSCO pilot plant near
Denver.
The analyses performed and the methods are listed below:
0166
-------
mmmmMwm
1972 Plateau
¦>& Sp?,P.ifs .Plots
Serai-Works Plant >(^^jiffifr.!
H..Q Semi-Works Plots . ? •
-ST-t* 1971 Species. Plot
v'^/A v?--r
Figure C-46. Colony revegetation plots, Dow Property,
Garfield County, Colorado.
C-167
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Fertility
Salinity
Available Nutrients
Fe, Zn
K
Analysis
Method
Colorado State University Soils Test Lab
Colorado State University Soils Test Lab
Sodium bicarbonate
Diethylenetriaminepentaacetic acid pressure
Ammonia acetate procedure
Greenhouse experiments of plant growth in processed shale—Extensive plant
growth experiments were conducted in a greenhouse in Grand Junction, Colorado,
during the winters of 1968, 1969, and 1970. The purpose of these experiments was
to observe and compare the growth of various grass, shrub, and forb species in both
untreated and treated processed shale. The treatments included various mixtures of
processed shale and peat moss, sawdust, perlite, and fertilizers. Severed plant
species, including those shown to be successful in earlier Colony processed shale
experiments, were grown in the various growth media in order to compare plant
growth rates and survival rates of the different treatments.
1967 field experiments at parachute creek—The Denver field experiment in
1965 established that four species of grass would grow in processed shale. The later
1966 study on properties of spent oil shale significant to plant growth obtained good
growth with tall wheatgrass when excess salts were leached from the processed
shale and nitrogen and phosphorus fertilizer were applied before planting.
The 1967 field tests at Parachute Creek were carried out near Grand Valley,
Colorado. They were designed to determine more precisely the effects of various
treatments on the growth rates of grasses in pure processed shale. Tall wheatgrass
(Agropyron elongatum, the most successful species grown in the Denver field
experiment) was used, and evaluations of the effect of each treatment on its growth
rate were made. Effects of variations in depth for seed planting, types of artificial
cover, fertilizer and chemical treatments, and degrees of watering were observed.
1968-69 semi-works field experiment—Experiments during the summer of 1968
were designed to determine the optimal land treatments to achieve germination and
growth in processed shale. Previous experiments indicated that plants grow readily
in processed shale, provided that the shale is treated in ways that improve
germination and subsequent plant growth. It has been learned that leaching is a
highly desirable preplanting treatment, and that some form of organic matter should
be mixed with the processed shale to prevent compaction. This improves aeration
and prevents erosion. Some form of soil cover is highly desirable to reduce the
surface heat. Four species of grass with a high tolerance for alkalinity and 10
species of native shrubs were used in the study.
Vegetation establishment demonstration (1971) on TOSCO II processed shale—
Environmentally acceptable disposal of processed shale is a requirement if an oil
shade industry is to be developed. A possible solution may be stabilization of
processed shale with vegetation. Colony has been working since 1965 on TOSCO II
processed shale as a plant growth medium in applied field and greenhouse studies
(72,73) and in laboratory and greenhouse research (70). These studies have shown
that processed shale can be used successfully as a plant growth medium if the excess
salts are leached out and nitrogen and phosphorus fertilizer are added.
C-168
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In light of the fact that existing plots have been self-sustaining for 5 years
(through the 1977 drought) it seems obvious that revegetated shale areas can be
maintained under natural precipitation. The potential cover will depend, among
other factors, on the aspect, slope, and elevation of the disposal site and on the
chemical and physical properties of the processed shale. This demonstration
attempted to answer these questions.
Performance of plants with minimal treatment of processed oil shale: an
interim report—This study describes and discusses observations after a 2-year period
of a test planting on various TOSCO II processed shale mixtures. Evaluations were
made of 15 species of grasses and shrubs and two transplant operations of 12 species
of woody plants. All materials were planted in adjacent plots with fertilizer and
mulch in three treatments: pure processed shale, half shale/half-soil, and native soil.
No water was applied. Results from seeding indicate very little survival on pure
shale, mixed success on the 50/50 mixture, and excellent survival, vigor, and growth
on native soil. Three species of shrubs (New Mexico locusts, New Mexico foresturia,
and Russian olive) showed better than 50 percent survival on the pure processed
shale. Other species showed lower survival rates. Survival on the other treatments
was about double that on processed shale alone.
1973 annual revegetation report—The information presented in this report is
based on work accomplished during the period January 1 to September 12, 1973. It
is organized chronologically by project, and each project is identified by a name. A
brief history of each project is given along with the summary of results for the year.
The initial box plots, established in 1967 to study the growth response of plant
species in the processed shale, were planted with brome grass, tali wheatgrass,
perennial ryegrass, crested wheatgrass, and Kentucky bluegrass, as well as several
shrub species. A map was made of the plot and the location of each plant was
plotted.
Established in 1968, the semi-works plots were designed to test a variety of
species and various types of mulch. The species surviving from the original planting
responded well to the 1972 application of fertilizer and irrigation.
Embankment slope plots were established in 1972 on the disposal embankment
near the semi-works plant for the evaluation of the effectiveness of various mulches
in the stabilization of processed shale slopes. The species used in this study
consisted of a mixture of Indian ricegrass, annual ryegrass, yellow sweetclover, and
russian wildrye, applied at the rate of M.& kg/ha (40 lb/acre).
The design and evaluation of 1971 species plots is presented in an article that
discusses the various treatments involved. This evaluation notes that the
percentage cover (by visual estimate) of pubescent wheatgrass and tall wheatgrass
increased significantly during the period 1971-73 and that crested wheatgrass,
although increasing, did so to a smaller degree. The rest of the species remained
much the same as observed in 1972, with the exception of the forb mixture plot,
which decreased from 80 to 5 percent cover. This sudden decrease is presumed to
be due to overseeding the plot with biennial sweetclover which did not reseed itself.
The fourwing saltbush showed heights up to 101.6 cm (40 in.), most of which was the
current season's growth. Of the other shrub species in the plot; all were still alive,
C-169
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with the exception of two junipers that seem to have been unable to compete with
the dense grass cover.
The 1971 SCS plots were set up to test the performance of plant species in the
following treatments: 100 percent processed shale, 50 percent processed shale and
50 percent native soil, and 100 percent native soil.
The 1972 species plots, located in the East Middle Fork area, are two
replications of the following treatments: 100 percent processed shale, 50 percent
processed shale and 50 percent native soil, 15.2 cm (6-in.) and 61.0 cm (2-ft) cover
of native soil over processed shale, and 100 percent native soil. All treatments were
mulched with a wood hydro-fiber compound. Of the 1^ species used in this study,
the most successful have been fourwing saltbush, alkali sacaton, desert molly,
crested wheatgrass, and Russian wildrye.
The 1972 plateau species plots were established on the plateau above
Parachute Creek Canyon during the summer of 1972. Half of the plots were planted
in the fall of 1972, and the other half were planted during the spring of 1973. The
three treatments in this study were 100 percent processed shale, 15.2 cm (6-in.)
cover over processed shale, and 100 percent native soil. The plots received uniform
applications of nitrogen 78.6 kg/ha (70 lb/acre) and phosphorus 673.9 kg/ha (600
lb/acre), but only half of each plot was watered.
Growing houseplants in processed shale—Two studies were undertaken to
determine the feasibility of growing house plants in oil shale treated by the TOSCO
II process. In the first study, 18 varieties of house plants were grown in four
different potting mixtures using the processed shale in varying proportions from
one-ninth shale to pure shale. Based on the results of the first study, a second study
was undertaken using the processed shale in higher percentages.
Chemical analysis of TOSCO II processed shale—This report analyzes the
results of soil test data of TOSCO II processed shale between 1968 and 1972. These
data are from samples taken during the various vegetation studies described in this
volume. These studies include the 1968 and 1969 experimental plantings at
Parachute Creek and samples of processed shale used in the greenhouse and
laboratory and studies (some properties of spent oil shale significant to plant
growth, and greenhouse experiments of plant growth in processed shale).
Two sources of soil test information were evaluated. First were samples
submitted to Agricultural Consultants Laboratory (Ag Con Lab), and second were
results of analyses reported in some properties of spent oil shale significant to plant
growth. Results of soil tests with a do-it-yourself test kit were omitted from the
following analysis, as no correlation was available between the results and plant
growth. Use of soil tests on non-soil substrates often has its limitations, but the
results appear to be satisfactory (although, as discussed later, the organic matter
determination is probably of no value). Methods used by both sources of soil test
information are standardized and have been correlated with plant establishment and
growth on neutral or calcareous soils.
Estimated water balance of Davis Gulch—CDO (Atlantic Richfield Co.,
Operator) has intensively studied the problem of developing an environmentally
acceptable commercial oil shale development utilizing the TOSCO II process.
C-170
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Establishment of vegetation offers the most acceptable method of stabilizing the
disposal areas and keeping erosion and leaching to a minimum. Recent
environmental analyses also indicate that Davis Gulch is the most probable site for
processed shale disposal.
The purpose of this .study is to provide an estimate of the water balance
relationships for the Davis Gulch watershed for present conditions, during
revegetation, and during long-term establishment of permanent vegetation on the
processed shale disposal area. An estimate of the irrigation water required for
leaching and rapid vegetation establishment is also provided.
Uses of spent oil shade ash—This report reviews the three alternative methods
of spent shale disposal and evaluates the technical and economic aspects of the third
alternative—using the spent shale ash for some useful purpose such as construction
material.
Processed shale embankment study—The CDO semi-works plant produced
approximately 50,000 tonnes (55,000 tons) of processed shale between startup in the
spring of 1971 through the time of the report, most of which had been placed in an
embankment south of the plant in the Middle Fork Canyon. Construction of the
embankment provided an opportunity to examine the applicability of conventional
hauling, placement, and compaction equipment in handling processed shale.
Material discharged from the pla'nt conveyor was hauled by an elevating scraper and
spread in 30.5 to 45.7 cm (12- to 18-in.) lifts for the compacting. Frontal or down-
canyon slope was set as three horizontal to one vertical; side slope varied to permit
examination of stability limits in the noncritical zones. The toe of the embankment
forms the rear edge of a settling basin intended as catchment for potential runoff
from natural precipitation. The lateral periphery of the embankment consists of a
dike constructed of mine run shale to channelize potentially heavy runoff flows from
the Middle Fork and Davis Gulch drainages away from the pile and to inhibit the
erosion of processed shale. In addition to the original scope of this study, necessity
dictated use of the disposal pile for retort sludge oil, sour water, catchment sump
dredgings, and the extremely varied shale discharges from "processed shale wetter"
development. Likewise, circumstances demanded operation during and following
inundation resulting from line or ditch failure in the plant area above and four
significant rainfalls. Experience gained under these unusual conditions will prove
valuable in defining operational procedure and equipment for a commercial
embankment.
Proposed shale backfilling (Phase I)--This report discusses the results of a
preliminary investigation on the effects of placing high-temperature, processed oil-
shale backfill inside the CDO oil shale mine located near Parachute Creek,
Colorado. The primary purpose of this investigation was to provide a preliminary
evaluation of the effects of the backfill on the fire hazard potential in the mine and
on the temperature of an overlying groundwater aquifer. The preliminary
backfilling plan would involve placing a major portion of the backfill in the
mined-out headings with large trucks. Backfill in the upper portion of these
headings, where overhead clearance would prohibit the use of trucks, would be
placed pneumatically. The shale backfill would be placed soon after processing, and
the temperature of this material is expected to be on the order of 93.3°C (200°F).
For the investigation, backfill temperatures ranging from 93.3 to 20UA°C (200 to
400°F) were considered.
C-171
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Liquefaction studies: Proposed process shale disposal pile, Parachute Creek,
Colorado—This report summarizes the studies done on TOSCO II processed shale.
The studies were conducted to determine the liquefaction potential of the material
when stored in large quantities, as will be the case in the proposed processed shale
pile disposal system.
Slope stability studies: Proposed process shale embankment—This report
summarizes the results of tests that have been conducted to determine the slope
stability of TOSCO II processed shale disposed piles.
Interim Monitoring Program—
During the interim monitoring program, periodic analyses of revegetated shale
pile success are performed on a regular basis to compare with data gathered during
the baseline program. This information is not published, however.
Commercial Development Phase Monitoring Program-
Determination made during the baseline and interim programs will allow for
the design of an efficient commercial phase processed shale revegetation program.
Noise
No noise monitoring projects have been established in the baseline or interim
monitoring programs. However, CDO has stated its intention of conducting noise
monitoring to comply with all Federal, State, and local requirements at the start of
commercial development.
Radioactivity
Radioactivity at the CDO has not been monitored during the baseline or
interim programs, and there is no proposed program for its monitoring during
commercial development. This determination applies to the areas of ambient air,
surface water, groundwater, and soils.
Surface Subsidence
No subsidence tests have been conducted in the baseline or interim monitoring
programs at CDO. However, CDO has stated that upon initiation of commercial
development, any programs required by Federal, State, or local regulations will be
implemented.
BX (EQUITY) OIL SHALE PROJECT
Information on environmental monitoring programs at the BX (Equity) Oil
Shale Project was gathered from the BX Environmental Research Plan and from
review with the project's environmental consultants, VTN in Irvine, California (7k).
Air Resources
Air Quality-
Background air quality at the BX Oil Shale Project locations was determined
by the Tract C-a and C-b baseline air quality programs. Since the three projects are
C-172
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basically in the same air basin, the ambient air quality is expected to be identical.
Stack sampling parameters and methodology will be determined based on process
evaluation and regulatory agency recommendations.
Meteorology-
One mechanical weather station was constructed to take wind speed, wind
direction and temperature readings at 10-m (33 ft) elevation. On a ridge southeast
of the site, a 30.5 m (100 ft) meteorological tower was erected. It is intended to
measure temperature, wind speed and direction, and sigma at the 305 m (100-ft)
level, and difference in temperature with the 30.5 m (100-ft) reading at the 10 m
(33-ft) level. Data will be reduced to hourly averages and monthly frequency
distributions for windflow. Temperature will be reduced to hourly averages.
Estimates of air pollution from the project's development were also made as
part of the air quality studies.
The locations of all air resource monitoring stations are illustrated in Figures
C-47 and C-48.
Water Resources
Water quality and flow measurements will be taken at two sites upstream and
downstream of the Equity site on Black Sulfur Creek (sites ES-2 and ES-3 on
Figure C-48). Monthly measurements will be taken of pH, conductance,
temperature, and flow. Field analysis has been conducted weekly, and laboratory
analysis has been conducted monthly since April 1978. During the operational phase,
upstream water will be sampled monthly; downstream samples will be taken weekly
during the first quarter, bi-monthly the second quarter, and monthly thereafter.
Flow will be determined using the Parshall flumes installed by Equity. A list of the
water quality parameters to be measured in this program is presented in Table C-36.
Regional baseline water quality has been determined by evaluation of Tract C-a and
Tract C-b USGS and State reports.
Depending on the completion date of the operational phase, a quarterly water
quality analysis program will be implemented after the termination of operations.
The deep wells (BX-8 and BX-13 on Figure C-^8) entering the Evacuation
Creek Member and leached zone will be sampled four times during the quarter
preceding the operational phase. Operational sampling and analysis will be done on
a weekly basis for the first quarter, bi-monthly during the second quarter, and
monthly thereafter.
In the alluvial wells (see Figure C-48), conductance^ water levels, and pH will
be determined monthly. If a 25-percent change occurs in any of these parameters,
water quality tests indicated in Table C-36 will be conducted.
Biological Resources
Black Sulfur Creek will be surveyed to determine the condition of aquatic
biota existing on the Equity property. Substrata samples will be collected upstream
and downstream of the project using Surber samplers and Eckman dredges. Sampling
will be performed three times a year during the operation phase (late winter, late
C-173
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0
1
M
LEGEND
Contour Interval 20 Feet
Datum is Mean Sea Level
scale (miles)
Pv7^/-'
-vSf- ¦, <,!;? /
iij
i
rv.' >.v ' . * i '"A- - ,r
" '""-i / / WW
if Qi
s
¦•' {¦' li '¦ BX
Site
tfH)-,/ , ,.„j
/M • V / / • O
phanica
fCO/
'
jf.'-fim v>.-
Xf>)¦/. /.A' .<:• / >o; • /."• i,V'' -'V i ~
m>yJ&sZL
Figure C-47. Location map for BX (Equity) oil shale project and mechanical
weather station.
-------
n
i
e*
Ln
jSWater Quality Station ES-3; Flume
Aquatic Alluvial Well Station #4
—— 8 Alluvial WpI1 Water Quality Sites located
® Alluvial Well
Station #3
^ 1 to 2 Miles Downstream
at Two Springs
Black
Sulfur
Creek
Alluvial
Station ^Pit
BX13 • BX8
rs
Alluvial Well if
n #1-A
Location Map
1" = 400'
Alluvial Well
tation #1
LEGEND
Access Road
X'i
Water Quality \
• Water Wells
O Water Quality Stations
A Meteorological Station
IX xi Groundwater Station
H Process Water Wells
Station ES-2; Flume
Aquatic Site
Figure C-48. Location map for BX (Equity) air resources and water resources monitoring site.
-------
TABLE C-36. WATER QUALITY PARAMETERS TO BE MEASURED DURING
OPERATION OF THE BX (EQUITY) OIL SHALE PROJECT
Constituent
Test method
Major Ions:
Calcium
Magnesium
Sodium
Potassium
Carbonate
Bicarbonate and calculation
Sulfate
Chloride
WQO 103
WQO 114
WQO 147
WQO 143
Glass electrode P & M end point titration
ALPHA 293 (2)
APHA 493B
Electrometric titration - APHA 302 (2)
General characteristics:
Specific conductance
pH
Temperature
Dissolved oxygen
Alkalinity
Hardness
Sodium Absorption Ratio
Dissolved solids
Suspended sediment
(Field Test) APHA (2)
(Field Test) Glass electrode method APHA 460A (2)
(Field Test) WQO 286
(Field Test) Polarographic APHA, 450
(Calculated) - Titrimetric (pH 4.5) WQO 3 (2)
(Calculated) - Sum of Hardness Ions
WQO 103, 114, 110 (2)
(Calculated) USDA Handbook 60
APHA 92 (2)
USGS TWRI Book 5 CPTC 1
Nutrients and organics:
Chemical oxygen demand
Ammonia
Nitrate and nitrite
Orthophosphate
Total phosphate
Total organic carbon
Dissolved organic carbon
Trace Elements (Non-Metals):
Silica
Fluoride
Arsenic
Cyanide
Boron
WQO 20
WQO 159
Specific Ion Electrode (2) APHA, 422
Mo-blue WQO 249
Mo-blue WQO 249
WQO 236
WQO 236
WQO 274
SPADNS - APHA 389
Arsine generation WQO 9
WQO 49
Curcumin - WQO 13
Trace Elements (Metals):
Barium
Cadmium
Chromium
Copper
Iron
Lead
Lithium
Manganese
Mercury
Molybdenum
Nickel
Selenium
Vanadium
Zinc
Aluminum
WQO 97
WQO 101 (1)
WQO 105 (1)
WQO 108 (1)
WQO 110 (1)
WQO 112 U)
APHA 13th Ed.
WQO 116 (1)
WQO 118 (1)
WQO 139
WQO 141 (1)
Fluorimetric (DAN) (Turner Bulletin)
WQO 153 (1)
WQO 155 (1)
WQO 92 (1)
*WQ0 (139) - Refers to the EPA Water Quality Office document. Methods for Chemical Analysis of Water and Wastes (75).
page number is in parentheses.
^APHA (126) - Refers to the APHA document. Standard Methods for the Examination of Water and Wastewater (76). The
number following is the section reference.
Preservation Methods (WQO Tables 1 and 2)
(1) HN0
(2) Refrigeration
C -176
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spring, and late summer). Composition, abundance, species diversity, and spatial
distribution of macrophytes, periphyton, plankton, macroinvertebrates, and fish will
be established. The methods of sampling and statistical analysis are those developed
by the EPA, USGS, and other affiliates of applied aquatic biology. An identical
sampling schedule will be initiated during the post-operational phase.
Solid Waste Disposal, Revegetation
The areas of land expected to be disrupted will be reclaimed in an appropriate
manner (7k). The details of reclamation are not available for publication.
Noise
No noise monitoring programs have been described in the Equity Oil Company's
BX Oil Shale Project Environmental Research Plan (74).
Radioactivity
No program has been developed for the Equity's BX Oil Shale Project (74).
Surface Subsidence
No programs have been developed for the monitoring of surface subsidence at
the Equity's BX Oil Shale Project (74).
OCCIDENTAL OIL SHALE INC., LOGAN WASH PROJECT
Environmental monitoring programs have been conducted at Logan Wash since
the early 1970's. Documentation of these programs is contained in References 77-
90.
Air Resources
Baseline data gathering of air quality and meteorological parameters was
conducted for 34 months, from February 1975 through October 1977. During that
time, there were two retorting operations: A retort for Room 3 was started in
February 1975 and continued to July 1975; Room 4 was retorted from December
1975 to July 1976.
Air Quality—
The air quality measurements consisted of 24-hr concentrations of sulfur
dioxide, suspended particulates, carbon monoxide, nitrogen dioxide, hydrocarbons,
methane, and hydrogen sulfide. The measurements were made every sixth day for
the first year, and every seventh day for the remainder of the program. The
location of the sampling site corresponds to the tower location in Figure C-49. Air
quality samples were packaged and sent to the Coors Spectro-Chemical Laboratory
in Golden, Colorado, for analysis.
Retort Exhaust Gas—
During retorting operations, the retort off-gas was monitored in the stack for
hydrocarbons, carbon monoxide, and hydrogen sulfide/as well as for flow rate. The
person in charge of retort off-gas studies was Dr. H. S. Skogen of Occidental.
C-177
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Parachute Creek
LW-104
Riley
Gulch
LW-131 ol
• Mount
Callahan
D.A. Shale Boundary
Bowdish Wash
O LW-33
O LW-47
LW-32 0
O LW-46 H -
Mine BenchO
LW-1080^0 LW-41
OLW-116
OLW-45
O Tower,
LW-
O LW-103
LW-101
Wash
Logan
Smith
LW-102
Mount
Logan
Gulch
LEGEND
Observation Wells
~ Guard Gate
O Present Location
Stream Gauges
APresent Location
AProposed Location
Meteorological Instruments
~ Present Location
H Proposed Location
Figure C-49. Location of meteorological and hydrological installations at Logan Wash.
-------
Meteorology-
Wind speed and direction has been measured, at 30.5 m (100 ft), since 1975 and
will continue to be measured. Upper air measurements of temperature and wind
speed were made twice a day every six days for a year. The principal investigator
for meteorological and ambient air quality studies was Dr. H. E. Craner of H. E.
Craner Co.
Water Resources
Surface Water—
Surface-water gaging and sampling stations are situated along the main
drainages of the D. A. property at Logan Wash and at Bowdish and Smith Gulches.
Future sites are proposed for Roan Creek and Kelly and Riley Gulches. The water
quality parameters measured during operation of the Logan Wash Project are
presented in Table C-37. A list of the surface-water monitoring stations, the
instrumentation utilized at each station, and the sampling frequencies for each are
presented in Table C-38.
Groundwater—
Baseline hydrologic and water quality characteristics of the Logan Wash
aquifers have been determined by measurement at four deep bedrock wells and at
one alluvial well. Water level and quality were determined according to the
schedule presented in Table C-38. Seven new alluvial wells (LW-101, 112, 115, 22,
121, 103, and 104), and two-deep bedrock wells (LW-106 and 108) are now installed
and in operation.
Current mining activities are located at the head of Logan Wash. Since raw
shale is being deposited at this point, the most noticeable effect of mining activities
on surface waters and groundwater will be evident at the base of Logan Wash.
Smith Gulch and Bowdish Wash flank this drainage, and monitoring there will
represent background data. Water quality data from Kelly and Riley Gulches, as
well as from Parachute Creek, will establish baseline conditions. Roan Creek data
will indicate any change in Logan Wash water quality and its effect in the Colorado
River drainage system.
Biological Resources
Studies of the biological resources existing in the Logan Wash area were
conducted by Claremont Engineering Co. (66, 85-87).
Flora-
Vegetation surveys were conducted at the Logan Wash site once in 1974 by
Wirtz (85) and in 1974, 1975, and 1977 by West et al. (86).
In the 1974 survey by Wirtz (85), major species composition was determined by
use of line intercept transects at 16 different localities. Using this method, species
composition was quantified on the basis of frequency of occurrence and percent
cover. Herbaceous species and grasses were classified subjectively on a four-point
scale of abundance. The survey was conducted by three people traveling on foot.
The survey of vegetation conducted by West and his associates (86) entailed
the positioning of 5- x 100-m (16.4 x 328 ft) macroplots, with their long dimension
C-179
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TABLE C-37. WATER QUALITY PARAMETERS TO BE MEASURED DURING
OPERATION OF THE LOGAN HASH PROJECT
Parameter
Present program
Eliminated
Trace elements:
Boron
X
Lithium
X
X
Beryllium
X
X
Sodium
X
Magnesium
X
Aluminum
X
X
Silica
X
Sulfur
X
X
Chloride
Potassium
Calcium
X
Titanium
X
Vanadium
X
Chromium
X
Manganese
X
Iron
X
Nickel
X
Copper
X
Zinc
X
X
Arsenic
X
Selenium
X
X
Bromine
X
X
Cyanide
X '
X
Lead
X
X
ptrontium
X
X
Zirconium
X
X
Barium
X
X
Platinum
X
X
Gold
X
X
Mercury
X
X
Radioactive alpha
X
Radioactive beta t
X
Radium 226
Major constituents:
Oil and grease
X
TOC
X
COD
X
BOD
X
Nitrites
X
X
Nitrates
X
Ammonia
X
X
Sulfates
X
Carbonate
X
Bicarbonate
X
Fluoride
X
PH
X
Specific conductance
X
Total alkalinity
X
Soluble solids
X
Suspended solids
x
X
Kjeldahl nitrogen
X
Phenols
X
aSourc«i R«f«renc* 89.
C—180
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TABLE C-38. HYDROLOGICAL INSTRUMENTATION AND SAMPLING SCHEDULE
OF BASELINE MONITORING PROGRAM AT LOGAN WASH
PROJECT AND VICINITY
Sampling
Current sites
Instrumentation
frequency
On-Tract:
Meteorological tower
Precipitation gauge
W
Evaporation pan
W
Lower mine bench
Precipitation gauge
W
LW-1
Bedrock observation well
LW-32a
Bedrock observation well
Q
LW-33
Bedrock observation well
Q
LW-41
Bedrock observation well
LW-45
Bedrock observation well
C
LW-46
Bedrock observation well
Q
LW-47a
Bedrock observation well
Q
Off-Tract:
Guard Gate - LW-115
Precipitation gauge
w
Evaporation pan
w
Logan Wash
Stream gauge
M
Smith Gulch - LW-102
Stream gauge
M
Precipitation gauge
W
Kelly Gulch - LW-103
Alluvial observation
well
Q
Riley Gulch - LW-104
Alluvial observation
well
Q
(proposed)
Alluvial observation
well
M
Stream gauge
M
Precipitation gauge
W
Present Sites:
LW-103
Alluvial observation
well
M
LW-104
Alluvial observation
well
M
LW-101
Alluvial observation
well
M
LW-112
Alluvial observation
well
M
LW-115
Alluvial observation
well
M
LW-22
Alluvial observation
well
M
LW-121
Alluvial observation
well
M
LW-106
Bedrock observation well
Q
LW-108
Bedrock observation well
w
aQ = Quarterly
M = Monthly
W = Weekly
C-181
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upslope. All surveys were accomplished in these areas. The first survey took place
in September 1974. Vegetal cover was determined by the line-intercept method,
using 100-m (328 ft) tapes along the sides of the macroplots. Density and frequency
were determined using 1- x 5-m (3.3 x 16.5 ft) microplots. Frequency was defined
simply as the percentage of microplots in which a species occurs within a stand
(macro plot).
In the 1975 summer study (86), the size of the woody plant microplot was
increased to 50 m2 (538 ft2). Ten new microplots were used. Microplots for herbs 1
x 5 m (3.3 x 16.5 ft) were placed randomly within the shrub and tree microplots.
Five to ten stands were sampled within each community.
Ground level photos were taken of each macroplot, and field data were
transferred to digital punch cards for analysis and comparison. Vegetation was
mapped on standard black and white aerial photos.
For the 1977 resurvey, three macroplots were chosen from each community
type. The first macroplot had the fewest species and lowest amount of vegetal
cover; the second had average composition and cover; and the third illustrated the
highest floristic diversity and cover. This resulted in surveys of 23 macroplots. The
methods of sampling and analysis were identical to the previous program.
Fauna-
Surveys of local wildlife were conducted by Wirtz (85) in the summer, fall,
winter, and spring of 1974 and 1975. All surveys were accomplished on foot. During
the summer, three men participated; but only two were responsible for the other
three surveys.
Small mammals were censused in representative sites for each habitat. These
surveys were accomplished in the summer, utilizing Sherman live traps and
Tomahawk wire-mesh traps. Large Tomahawk traps were also set for carnivores
during the summer. For the remainder of the year, the surveying of large carnivores
was limited to observation of tracks, scat, and kills. All live-trapping data were
converted to the number of individuals in each species captured per 100 trap nights
in each habitat.
Deer were counted on each survey (morning and night), and age and sex were
determined whenever possible. Observations were also made of tracks, pellet
groups, beds, trails, brouse, shed antlers, and carcasses or skeletons.
Reptiles were observed irregularly along the survey lines in all seasons except
winter. No quantifiable data were obtained. Terrestrial invertebrates were not
surveyed.
Birds were observed on all four seasonal surveys. Binoculars and 20-45 power
zoom telescopes were used to determine species composition and areas of breeding.
The data were converted to the number of individuals per species per man hour of
observation.
A map showing the locations of all terrestrial wildlife sampling plots is
presented in Figure C-50.
c-182
-------
¦ JLL< WP-
o
oo
U)
-MM
!?vk- ^Mki ^
.. **V. \ -.V • . «.
• v - ~-lV.
Figure C-50. Location map for biological monitoring program at Logan Wash.
(Note location of small mammal study plots, A-F, mine site, and
Occidental property boundary. Birds are studied on trapping plots
and adjacent areas of the canyon, and deer are censused in the
entire canyon where plots are located)
-------
Aquatic Biota-
No data have been generated on the aquatic biological resource of the Logan
Wash area.
Solid Waste Disposal, Revegetation
A plan for the restructuring and revegetation of shale waste piles has been
developed for the Occidental Logan Wash site. Many environmental factors have
been considered in this development, including: Alteration of surface water courses
during storms, erosion of waste piles during storms, wildlife habitat perpetuation,
effect on subsurface hydrology, effect on surface water debris transport rates, and
the perpetuation of vegetation on the piles.
Reclamation of the waste pile from the Logan Wash project will not
commence until the life of the pile is complete. The pile will be recontoured to
slope slightly towards the center, with a 0.9 m (3-ft) drop from edge to center. A
soil addition of very low permeability will be added to the pile's surface, and this
will in turn be covered with rock 1.2 m (4 ft) at edges and 2.1 m (7 ft) at center.
This design will allow for runoff to be spread over a wide area so that erosion will be
minimized. The low permeability of the additive will, in addition, retard seepage of
any kind. The outside slopes will be treated in the same manner. In addition,
surface water analysis programs presently being conducted will continue.
Noise
Two sets of noise level measurements were made in Grand Valley,
approximately 4.1 km (6-1/2 mi) from the Logan Wash mine. The purpose of the
first measurement, made in August 1975, was to assess the noise impacts of mine
blasting on the Grand Valley ambient noise environment. The purpose of the second
group of measurements, made in early 1976, was to determine Grand Valley's
preexisting acoustic environment.
August 1975—
The instruments used in this experiment consisted of a sound level meter
(General Radio Model 1551-C) and a graphic level recorder (General Radio Model
1521-B). The meter was placed at ground level, and the recorder was placed on a
table.
Noise level and seismograph measurements were made for hours before and
after the mine blast. All sources of exceptional noise levels were identified. The
blast could not be heard.
1976 Measurements-
All sound level measurements in this study were made with a General Radio
Company sound level meter (Model 1551-C), using the pass band "B". A wind screen
consisting of cloth netting extending 20.3 to 25A cm (8 to 10 in.) above and below
and 30.5 cm (12 in.) out from the microphone was utilized to cut background noise
readings by 10 to 30 dB.
A map showing the location of noise measurements is presented in Figure
C-51.
C-184
-------
0
1
I-*
03
in
I
-N-
1" - 2000'
DENVER AND
RIO GRANDE
WESTERN
tApproximately 5 miles
to mine
GRAND
VALLEY
COLORADO RIVER
-J
LEGEND
0 Measurement Site
Figure C-51. Sites of noise measurement at Grand Valley and vicinity.
-------
Surface Subsidence
Occidental Oil Shale Inc. does not expect subsidence or uplift as a result of retorting,
at the Logan Wash site. However, changes in surface position were monitored by
precise level recorders before Retort Number k was blasted and from time to time
afterwards. Precise level measurements were made in the summers of 1977 and
1978. Surveys may be established over Retort Number 5 and Number 6.
GEOKINETICS OIL SHALE GROUP
Environmental monitoring programs at the Geokinetics oil shale development
have been documented since 1977 (69, 72, 94-97).
Air Resources
Air Quality—
The Geokinetics Oil Shale Group has instituted programs to evaluate ambient
air quality, process gas streams, and stack gas emissions. The parameters measured
for each source are listed as follows:
1. Process Gas Stream
Temperature
Heat value
Solid particulate aerosols
Common gases
Ammonia (NH3)
Carbon dioxide (CO2)
Carbon monoxide (CO)
Hydrogen sulfide (H2S)
Nitrogen oxides (NOx)
Sulfur dioxide (SO2)
Elemental gases
Hydrogen (H2)
Nitrogen (N2)
Oxygen (02)
Hydrocarbons
Ethane
Methane
Others
Major organic compounds
Organometallics,
Trace elements
2. Stack Gas Emissions
3.
Temperature
Solid particulate aerosols
Common gases (as above)
Ambient Air
Elemental gases (as above)
Hydrocarbons (as above)
Organometallics
Aerosols, gross
Common gases
Ammonia (NH3)
Carbon monoxide (CO)
Hydrogen sulfide (H2S)
Nitrogen oxides (NOx)
Sulfur dioxide (SO2)
Sulfur trioxide (SO3)
Hydrocarbons (as above)
Oxidants
Determinations will include, but not be restricted to, the constituents listed.
Organic and inorganic constituents were analyzed with a dedicated online gas
chromatograph using thermal conductivity detection. Oxides of nitrogen and sulfur,
C-186
-------
carbon dioxide, elemental gases, organic halides, organometallics, conjugated
carbonates, and nitrites were analyzed on an offline gas chromatograph.
In addition, a procedure for photographic monitoring of atmospheric clarity
was improved and implemented in June 1978 and was operated through January
1979.
Sampling and analysis of ambient air and monitoring of aerosols by optical and
mechanical filtration techniques were established in late 1978.
Meteorology—
Localized meteorological data were gathered from four stations located at
various spots around the project site (Figure C-52). A list of the parameters
measured and the equipment used at each site is presented in Table C-39. All
equipment was calibrated quarterly. Visibility studies were also conducted using
seasonal photography.
An additional five meteorological test stations were installed around the test
site in 1978 and operated during the retorting period.
Water Resources
Concern exists that precipitated aerosols from the Geokinetics retort process
will be carried into the local surface water network (7). For this reason, six surface
water sampling stations have been situated to collect samples within 12 hr after a
threshold rainfall, or during the year when thawing of snowpack generates
measurable runoff. A list of the surface water stations is presented in Table C-40.
The water quality parameters measured in the water resources monitoring program
are presented in Table C-41. Geokinetics assumes that retort process water will not
substantially affect the site surface water quality because the water will be
disposed of in evaporation ponds.
As each retort is ignited, wells are drilled proximate to the retort so that
water-quality impact determinations can be made. Table C-42 describes the depths
of individual wells drilled to date. Water levels are measured on a monthly basis by
means of a steel tape or conductivity probe. Water quality samples are taken from
active wells at least quarterly. Ten of the 22 wells associated with retorts 11, 12,
and 16 are sampled no less often than once eachrnonth. All wells associated with a
particular retort are sampled on the 10th and 5th days subsequent to retort
shutdown and every 10th day for an additional 50 days. All wells in the group are
sampled every 2 days during the combustion phase of retort operation. The water
quality parameters analyzed are presented in Table C-41.
An additional 13 wells were established by June 1978, and monitoring has
commenced since that time. The schedules and parameters are basically the same
as for the first round of 32 wells. In 1979, the schedule of water quality parameters
to be analyzed has been changed to make the analysis program more cost effective.
The changes made in the sampling analyses schedule are listed in Table C-41.
C-187
-------
Ul
6733.0
A-04
^A-OI
16723.0.
A-02
687.0
N 4000-
100 200
400 ft
LEGEND
4| Monitoring Station
Figure C-,52.. Locations of meteorological monitoring equipment around
Geokinetics project site. [NE^j NE^ Sec. 2, T14S, R22E, Utah]
(Source: Reference 69.)
C-188
-------
TABLE C-39. PARAMETERS AND INSTRUMENTATION USED IN THE METEOROLOGY
MONITORING PROGRAM AT GEOKINETICS OIL SHALE PROJECT
Station and Instrumentation Used
parameter Source1 Model Dascription
Temperature
Relative humidity
Wind spaed/direction
Precipitation
Barometric pressuxe
A-02:
Precipitation
Evaporation
A-03:
Precipitation
Solar radiation
A-04:
Air temperatures
Soil temperature
Daw point
Barometric pressure
Wind epaed
Wind direction
Precipitation
Precipitation rata
Sunshine duration
MRI 1077
SAI 355BP
MRI 302
SAI 248(1)
BIC 5-349A
MRI 302
SAI 653
SAI 191
SAI 19103
EAIC MS401C-26
SAI 191
SAI 191D1
EAIC MS401C-26.
SAI 222
SAI 222C
EAIC MS401C-26
SAI 363(5)
SAI 364
EAIC MS401C-26
SAI 480-WS-10
SAI 480-WD-10
SAI 480-100019
SAI 480-100086-1
EAIC MS401C-26
EAIC MS401C-26
SAI 552-1
EAIC MS401C-26
BIC 6069A
EAIC MS401C-26
SAI 651B
Mechanical weather station
with #303 rain gage and
#370 heater (haated tipping
(bucket)
Microbarograph
Tipping bucket rain gage
Recording evaporimetar
Totalizing anemometer
Tipping bucket rain gaga
Pyranograph/actinometer
Temperature transmitter
Gaged thermistor probe
Servo chart recorder
Temperature transmitter
Thermistor probe
Servo chart recorder
Devpoint probe & transmitter
Dewpoint probe weatherhood
Servo chart recorder
Barometric transducer
Barometric transmitter
Servo chart recorder
Wind speed transmitter
Direction transmitter
Wired crossarm unit
Translator
Servo chart recorder (spd)
Servo chart recorder (dir)
Transmitting rain gage
Servo chart recorder
Rate transmitter gage
Servo chart recorder
Campbell-Stokes recorder
Manufacturer/supplier abbreviations!
BIC Belfort Instrument Company
EAIC Esterlina Angus Instrument Corporation
MRI Meteorology Research, Inc.
SAI Science Associates, Inc.
c-isa
-------
TABLE C-40. SURFACE WATER MONITORING STATIONS
FOR GEOKINETICS OIL SHALE PROJECT
Station
Subject
Purpose
S-01
(deleted)
S-02
Evaporation Pond #2
Water
level and quality
S-03
Evaporation Pond #3
Water
level and quality
S-04
Evaporation Pond #4
Water
level and quality
S-Ox
(additional stations will
be added if necessary)
S-91
Surface runoff
Water
quality
S-92
Surface runoff
Water
quality
•
S-93
Surface runoff
Water
quality
S-94
Surface runoff
Water
quality
S-95
Surface runoff
Water
quality
S-96
Surface runoff
Water
quality
S-9x
(additional stations will
be added if necessary)
C-190
-------
TABLE C-41. HATER QUALITY PARAMETERS TO BE MEASURED FOR EACH STATION IN HATER
RESOURCES MONITORING PROGRAM AT GEOKINETICS OIL SHALE PROJECT
Parameters measured
Parameters measured
Parameters no
Supplemental parameters
reqularly or routinely
quarterly
longer measured
measured annually
Alkalinity aa CaC03
(In addition to all routine
Germanium
Thiocyanate
Hardness, total
parameters examined)
Uranium
Thiosulfate
PH
Cold
Total sulfur
Specific conductance
Hydroxide as OH
Platinum
Tetrathlonate
Temperature
Barium as Ba
Titanium
Turbidity
Chloride as CI
Copper aa Cu
Dissolved solids, volatile
Suspended solids, volatile
Cheaical oxygen deaand
Iron aa Fe
Broaide
Manganese as Mn
Gross alpha
Carbon, total organic -
Nickel aa Ni
Gross beta
Diaaolved solids, total
BOO, 5-day
Suapended solids, total
Cyanide as Cn
Phosphate, total, aa PO^-p
Trace elementa
Ammonia aa KH -H
Orthophoaphate, aa PO.-p
Total organic carbon
Bicarbonate as HCOj
Total solids
Carbonate as CO,
Coliform, total
Volatile solids
Nitrate aa HO -H
Coliform, fecal
Hydroxide
Nitrate as HO*-*
Sulfate aa SO.
Sulfur •• S
Nitrite
Zinc as Zn
Sulfide
Calciua aa Ca
Potasslua aa K
Oil and Grease
Silica aa SIO,
Phenols
Sodius aa Ha
Surfactants
Carbon, diaaolved organic
Arsenic as Aa
Boron aa B
Fluorine aa F
Magnolia aa Mg
Mercury aa Hg
Molybdenun as Mo
Selenitm aa Ss
Antimony
Beiylli.ua
Bismuth
Tin
Cadaiua
Cobalt
Vanadiw
Lithium
Lead
Silver
Strontium
-------
TABLE C-42. GROUNDWATER MONITORING HELLS Pan
GECKINZrXCS OIL SHALE PROJECT
Well
Depth
Retort
Rational*
W-ll
W-21
W-22
81.5
24.0
24.0
11
Coanunication below retorting zona.
21-'22i Longitudinal and lateral ccomunication
within retorting zona.
W-12
90.0
11. 12
Communication below retorting zone.
W-23
W-24
54.0
53.0
12, 16
Longitudinal and lateral communication within
retorting zone.
W-15
W-16
W-X7
W-X8
100.0
93.5
93.0
95.0
12, 16
Longitudinal and lateral coanunication within
retorting zona.
W-13
100.0
12, 16
Conounication below retorting- zone.
W-27A
W-27B
W-28A
W-2BB
52.5
40.0
52.5
38.0
12
Longitudinal and lateral communication within
retorting zone.
W-25
W-25*
W-25B
35.0
35.5
36.0
12
25i Longitudinal and lateral coenunication.
25A-25B i Lateral comunication and diipcnion
of fracture aystea.
W-26
W-26A
H-26B
34.0
32.0
32.5
12
26i Longitudinal and lateral coenunication.
26A-26B: Lateral caraminication and diaperaion
of fracture ayatea.
W-14*
300.0
16
CoBBunication balow retorting zone.
W-31
W-41
W-42
100.0
50.0
50.0
15
Coanunication balow retorting zone.
41-421 Longitudinal and lateral ccmunication
within retorting zona.
W-32*
W-43
W-44
140.0
57.0
57.0
15
Coenunication below retorting zona.
43-44: Longitudinal and lateral ccaBunicaticn
within retorting zone.
W-51
W- 52
W-53
99.0
105.0
106.0
13
511 Control, balow retorting tone.
52-53> Longitudinal coanunication and
diipersion balow retorting zona.
W-61
W-62
36.0
45.0
14
61¦ Control, within retorting zona.
62i Coanunication within retorting son*.
*Coreholea
C-192
-------
Biological Resources
Flora-
Eight vegetation sites have been established according to the plot design in
Figure C-53. Herbaceous vegetation was sampled in 20 1-m2 (10.8 ft2) quadrants
permanently located in each sampling site. Shrub layer vegetation was sampled
along 20 line-strips permanently situated in each sampling site. Shrub canopy cover,
density, and frequency were estimated along each transect. Trees in forested areas
were sampled using a point-centered quarter method. Tree density, cover (basal
area), and frequency for each species were measured at 48 sampling points. All of
this sampling was accomplished in May 1978.
Herbaceous productivity, was estimated using the double-sampling technique.
In each of the tree stands, 100 0.25-m2 (2.54 ft2) quadrants were located along 10
transects. Ten randomly selected quadrants were sampled, the samples were
weighed, and the site productivity was estimated using a regression analysis. This
study was done between August and September 1978.
Vegetation mapping was produced from aerial photography of the site.
Fauna—
The faunal studies should have been completed by June 1978, however, no
publications on the program are currently available.
DOW CHEMICAL COMPANY
The summary analysis of environmental programs at the Dow development in
Michigan is based on information gathered from References 73 and 98.
Air Resources
Baseline air quality and meteorology has been determined by information
gathered from surrounding county air quality monitoring stations and local weather
stations. A specific plan has been developed to monitor ambient air before, during,
and after combustion tests.
Air monitoring of CO, HC, NOx, SO2, and particulates will be accomplished
both upwind and downwind of the test site stack, before and during combustion
testing. The positions of sampling equipment after combustion testing will be
determined after evaluation of previously gathered data. This air monitoring will be
accomplished during a 7-month period. Gaseous sampling is to be conducted
continuously during this period, and particulates are to be monitored for a 24-hr
period every other day.
Future monitoring of air quality will depend on baseline sampling results.
Water Resources
Surface Water—
Surface water quality is presently measured at 12 stations on the Dow
property (Figure C-54). The water quality parameters being analyzed are listed in
Table C-43.
C-193
-------
61 M.
PHYTOSOCIOLOGICAL SAMPLING
E-00
~ o
20
11
30
21
40
31
50
41
14
60
51
70
61
80
71
90
3
20
19
100
10 M
LEGEND
~o Ecoclimatological
^ Data Station
(S\ One-centare
^ Herb Quadrant
flit
Shrub Belt
Figure C-53. Vegetation plot design for Geokinetics plant monitoring program.
C-194
-------
Sheridan Line Road
Hunt
Drain
|Bricker
Road
Burns Line
^ Bradley |
Brovm
Road
l
i
i
i(
i
i
i
r
J
i
i
Seymour
Creek
| Perry
. Drain
Mortimer Line
Road
I
h
I
- -J_
.Kilgore
¦Road
L-r
I
I
Road ^6
L
/
,z.—- A°
i —
/
t
I
Gardner Line Road
LEGEND
# Surface Sampling Station (sampled monthly)
0 Tentative Additional Stations (sampled occasionally)
W ^ Onsite Water Wells
W 0 Offsite Domestic Water Wells
r1] Dow Property Line
Figure C-54. Surface and groundwater monitoring sites at the
Dow development.
C -195
-------
TABLE C-43. CONSTITUENTS TO BE DETERMINED IN SELECTED WATER SAMPLE
AND ANALYSIS PROGRAMS AT THE DOW DEVELOPMENT
Program
IIa
Program III
Program IV
Program V
Potassium
Total carbon
Aluminum
Aluminum
Molybdegum
Niobium
Sodium
Total organic carbon
Silicon
Silicon
Calcium
Carbonate/Bicarbonate
Iron
Iron
Zirconium
Magnesium
Phenolics
Magnesium
Magnesium
Strontiug
Rubidium
Chloride
NH
Calcium
Calcium
Suspended
Solids
NO
Sodium
Sodium k
Bromine
PH
no3
Lead
Titaniug
Uranium^
Thorium
Seleniug
Arsenic
Germanism
Gallium
Sulfide
Mercury
Barium
Strontium
Lead
Bromide
Thallium
Zinc
Arsenic
Mercury
Copper
Zinc
Tungsten
Nickel
Copper
Tantalum
Cobalt
Nickel
Hafnium
Manganese
Manganese
Lanthanum
Chromium
Chromium
Barium
Vanadium
Vanadium
Tellurium
Scandium
Chloride
Antimony
Chlorine
BorOn
Tin
Phosphorus
Beryllium
Cadmium
Fluorine
Lithium
Silver
Boron
Potassium
Yttruim
Potassium
Beryllium
Lithium
aProgram number represents various stages of project development.
^Subjected to qualitative analysis only; others are analyzed quantitatively to the accuracy of the
method.
-------
Groundwater—
Groundwater quality is also being monitored at five offsite domestic wells
around the Dow property (Figure C-54). This sampling is carried out on a quarterly
basis. Analysis of the parameters listed in Table C-43 is also performed quarterly.
Monitoring of groundwater hydrology will not be performed.
Biological Resources
A survey of vegetation was conducted along east-west and north-south
transects across the study site. In addition to observation of vegetative cover, the
fauna, drainage patterns, and topography were noted. Aerial and ground
photography assisted in calculating ground cover and producing a reliable vegetation
map.
All baseline studies were performed before the first fracturing or combustion
operations. The program will be repeated on a twice-yearly basis.
Noise
The Dow Chemical Co. has taken noise measurements during fracturing and
any other time that excessive noise was created by project activities. The
equipment used during these measurement activities was submitted to the
Environmental Research Institute of Michigan at the time of data submittal. These
measurements will be taken again 2 and 4 years after initiation of the fracturing and
combustion tests.
Surface Subsidence
During the first year of fracturing and combustion experiments, the area
around the subject wells will be intensively monitored. Survey measurements for
subsidence determinations will be made with a laser theodolite furnished by Dow.
Measurements will be made before each fracturing, immediately afterward, 1 month
afterward, and a few times up to a year afterward.
Since frost heave in Michigan can be severe, a set of 43 monuments was
established in a radial array around the wells (Figure C-55). The method of
constructing these permanent monuments follows:
a. Bore a 9 cm (3.5 in.) diameter hole to a depth of 2 m (6.6 ft) into
the soil.
b. Insert a 9 cm (3.5 in.) O.D. PVC pipe into this hole and anchor it at
the bottom by driving it in several centimeters, leaving 0.5 m (1.64
ft) above ground.
c. Drive an iron second pipe 2.5k cm (1 in.) O.D. inside the other to a
depth of 3 m (3.28 ft), leaving 0.5 m (1.64 ft) above ground.
d. Loosely pack the column between the inside and outside with
styrofoam or other temperature-stable medium and seal the cover
to exclude moisture.
C-197
-------
«+¦ 100M
+
+
52M
4- 50M
4- 20M
0
1
M
VO
00
% +
+
+
30M
+
15M
+*+5M
5M +
¦f
+
+
Figure C- 55. Tentative subsidence monument pattern at the Dow development.
-------
TALLEY-FRAC/ROCK SPRINGS PROJECT
The Talley-Frac project has presently been terminated. The sources of
information for this report description are References 99-105.
Air Resources
Air Quality-
Baseline air quality and meteorology were determined by air quality
monitoring networks existing in the area. The State of Wyoming operates and
maintains a network of six air quality sampling stations in the vicinity of the Talley-
Frac/Rock Springs site. All of these stations had high-volume samplers for
particulates and were used for monitoring S02. In addition to the monitoring
stations run by the State, various private developments in the area also participated
in a monitoring program. An identification of the monitoring sites, parameters
measured, and the companies responsible for monitoring in the vicinity of the
Talley-Frac project are summarized in Table C-44. In addition to ambient air
quality, gas streams from retorting operations were to be monitored. The
parameters to be measured were particulates, sulfur dioxide, oxides of nitrogen,
carbon monoxide, total hydrocarbons, nonmethane hydrocarbons, hydrogen sulfide,
ammonia, total sulfur, heavy metals, carbon dioxide, oxygen, water, nitrogen and
hydrogen.
Meteorology—
Baseline meteorology was also determined using the techniques summarized in
Table C-45.
Water Resources
Baseline Data Gathering Programs-
Hydrology—The baseline hydrogeological characteristics of the Talley-
Frac/Rock Springs site have been determined by the study of geologic structure and
lithology, downhole television logging, and pump tests at six observation wells.
Six wells were developed for pump testing. Three (01, 02, and 03) were deep
wells drilled to a depth of 172.2 m (565 ft). Three (04, 05, and 06) were shallow
wells drilled to a depth of 118.8 m (390 ft). Drawdown rates were measured at
each of these wells using submersible pumps 94.6 1pm (25 gpm rate) and electric
water level indicators. The locations of these wells are presented in Figure C-56.
Water quality—Prefracture groundwater samples were taken from each of the
six observation wells and were analyzed according to two different sampling
schedules, A and B. An A analysis was performed on April 13, 1978. Two sets of B
analyses were performed on all six wells on April 11 and 13, 1978. Both sampling
schedules are illustrated in Tables C-U6 and C-U7. The wells were sampled using a
simple bailing device.
Surface water samples have been taken at six sites along Bitter Creek and the
Green River near the site. The responsible agencies include the USGS, EPA, and
Western Wyoming Community College (WWC).
C-199
-------
TABLE C-44. TALLEY-FRAC/ROCK SPRINGS AMBIENT AIR QUALITY AND
METEOROLOGY MONITORING SITES AND PARAMETERS MEASURED
Company
Number of
monitoring
sites
Parameter
measured
Details
Allied Chemical
Texas Gulf Sulfur
1
1
4
1
4
1
1
1
3
Total suspended
particulates
Meteorology
Total suspended
particulates
Meteorology
Total suspended
particulates
Meteorology
Meteorology
24-30
NO
SO*
Total suspended
particulates
Coefficient of
haze
Total settleable
particulates
Continuous
Wind speed, wind direction
Wind speed, wind direction
Wind speed, wind direction
Surface (6.1 m):
Wind speed
Wind direction
Temperature
Humidity
Solar radiation
Upper (30.5 m) •.
Wind speed
Wind direction
Temperature
Upper (61 m):
Wind speed
Wind direction
Wind components (U.V.W.)
Temperature
Temperature Differential
(6.1 - 61 m):
Periodic
Continuous
Continuous, high-volume
Periodic
Sulfation plates
Dustfall buckets
C-200
-------
TABLE C-45. ENVIRONMENTAL MONITORING TECHNIQUES USED DURING
OPERATION OF THE TALLEY-FRAC OIL SHALE DEVELOPMENT
Description
Methodology
1. Water quality analysis
2. Ambient particulate levels
3. Meteorological equipment
k. Air quality monitoring
a. NOx
b. S02
Emission spectroscopy and wet chemical
analysis.
High-volume sampling.
Mechanical weather station will collect data
on temperature and precipitation. A 10 m (33
ft) tower will be employed to measure surface
wind speed and direction and collect solar
radiation and relative humidity data. Pibals
will be taken seasonally to provide data on
upper level winds. Pan evaporation rates will
be measured onsite, and an analysis of onsite
snow water content will be provided.
Chemiluminescence.
Pulsed fluorescence.
C-201
-------
0
1
to
o
N>
\
0-6
©
©0-1
P-l
V
P-10
p-11
W P-12
®
®
P-4
©
®
p-e
P-9
®
P-16
®
©°"4
' S®5 ®3.2 'a"
S® ©0-1
P-14
®
P-13
®
P-5
®
®
P-6
®
LEGEND
0 - Observation Well*
P,S other Hells
Figure C-56. Pattern of observation wells at the Talley-Frac development.
-------
TABLE C-46. ANALYTICAL METHODS FOR SCHEDULE A WATER
ANALYSIS AT THE TALLEY-FRAC DEVELOPMENT3
Parameter
Method
Accuracy
(mg/1)
Ammonia
Gas sensing electrode
0.1
Antimony
Flame atomic absorption
0.05
Arsenic
Arsine generation, colorimetric
0.05
Barium
Flame atomic absorption
0.05
Bicarbonate
Alkalinity titration
5.
Bismuth
Flame atomic absorption
0.5
Boron
Curcumin colorimetric
0.05
Bromide
Chloramine-T, colorimetric
2.
Cadmium
Flame atomic absorption
0.002
Calcium
Flame atomic absorption
0.05
Carbonate
Alkalinity titration
5.
Total organic
Oxidation, IR detection
1.
Carbon
Cesium
Flame atomic absorption
0.1
Chloride
Mercuric nitrate titration
1.
Chromium
Flame atomic absorption
0.01
Cobalt
Flame atomic absorption
0.01
Conductivity
Conductivity cell
2 yhos
Copper
Flame atomic absorption
0.01
Fluoride
Specific ion electrode
0.1
Iodine
Leuco crystal violet colorimetric
0.1
Iron
Flame atomic absorption
0.01
Lead
Flame atomic absorption
0.01
Magnesium
Flame atomic absorption
0.05
Manganese
Flame atomic absorption
0.005
Mercury
Cold vapor atomic absorption
0.00002
Molybdenum
Flameless atomic absorption
0.005
Nickel
Flame atomic absorption
0.01
Nitrate
Colorimetric, Cd reduction
0.01
pH
Electrode
0.01 units
phosphorus
Digestion-oxidation, colorimetric
0.1
Potassium
Flame emission
0.1
Silver
Flame atomic absorption
0.01
Sodium
Flame emission
0.1
Dissolved solids
Filtering evaporation, 180 C
1.
Strontium
Flame emission
0.01
Sulfate (as S0^=)
BaSO^ precipitate
10
Tin
Flame atomic absorption
0.5
Zinc
Flame atomic absorption
0.005
aSource: Reference 75.
C-203
-------
TABLE C-47. ANALYTICAL METHODS FOR SCHEDULE B WATER ANALYSIS3
Parameter
Method
Accuracy
(mg/1)
Alkalinity, total
Standard acid titration
0.1
Ammonia
Electrode-instrumental
0.01
Bicarbonate
Standard acid titration
10.
Calcium
Atomic absorption-instrumental
0.1
Carbonate
Standard acid titration
0.1
Chloride
Mercuric nitrate titration
0.1
Conductivity
Conductivity bridge, instrumental
1 ymhos
Fluoride
Specific ion electrode, instrumental
0.01
Hardness
EDTA titration
0.1
Magnesium
Atomic absorption, instrumental
0.1
Nitrate
Cadmium reduction, colorimetric
0.01
PH
Hydrogen ion electrode, instrumental
0.01
Phosphate
Persulfate digestion, colorimetric
0.01
Potassium
Atomic absorption, instrumental
0.1
Sodium
Atomic absorption, instrumental
0.1
Sulfate
Barium precipitation, gravimetric
0.1
COS
Evaporation and drying, 180 C
10.
aSource: Reference 75.
-------
A presentation of the surface water sampling sites and a description of their
locations are provided in the following listing:
1. Bitter Creek below Little Bitter Creek; USGS #09216880; Latitude
M°3r0"f Longitude 109°18'15M.
2. Bitter Creek near Green River, Wyoming; USGS #09216950;
Latitude 41°31'25", Longitude 109°25'41".
3. Bitter Creek at Green River Confluence; EPA; Latitude 41o30'59",
Longitude 109°25'9".
4. Bitter Creek at Green River Confluence; WWC #562; Latitude
^l°3r0", Longitude 109°25,0".
5. Green River near Green River, Wyoming; USGS #09217000; Latitude
^1°31'59", Longitude 109°26'5V\
6. Green River below Green River, Wyoming; USGS #09217010;
Latitude 41°29W, Longitude 109°26,17"
Post-Hydraulic-Fracture Data Gathering Programs—
At the conclusion of hydraulic fracturing at the Rock Springs site, static water
levels and water quality were sampled and analyzed (analysis schedule B) at all six
observation wells. The measurements were conducted on May 25, June 22, and July
28, 1978.
Water quality analyses (analysis schedule B) were also run at three Bitter
Creek surface water sampling stations.
Post Rubblization Data Gathering Programs—
At the conclusion of fracturing, static water level and water quality analyses
(analysis schedule B) were conducted at the previously described six observation
wells.
Biological Resources
The study of baseline biological resources in the Talley-Frac/Rock Springs
project area was performed by evaluating information already gathered by the
Wyoming Water Resources Research Institute and the Wyoming Game and Fish
Department, and by conducting random field surveys of the area.
Solid Waste Disposal, Revegetation
All areas disrupted by earth moving, digging, well digging, etc. were reclaimed
at the termination of project development. All raw and processed shale stockpiled
during project development were to be revegetated and terraced in the manner most
acceptable from an environmental and practical standpoint. However, since no
shale was stockpiled, this procedure did not occur. The access road and other
facilities will be covered over and revegetated with a perennial grass to permit the
eventual influx of woody species to their native habitat.
C-205
-------
Noise
The Talley-Frac site was categorized as a rural undeveloped locale, and
typical EPA noise levels were assigned to the area. Onsite background noise levels
were also monitored; however, no details of the monitoring program are published in
the reviewed documents.
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One, September 1977 through November 1977: Year-End Report. Vols. 1 and
2. Gulf Oil Corp. and Standard Oil (Indiana), Denver, Colorado, 197S.
7. Rio Blanco Oil Shale Project Modular Development Phase Monitoring Report
Two, December 1977 through May 1978: Mid-Year Report. Vols. 1 and 2.
Gulf Oil Corp. and Standard Oil (Indiana), Denver, Colorado, 1978.
8. Oil Shale Tract C-a Supplemental Material to Revised Detailed Development
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May 1977. Vol. 3. Gulf Oil Corp. and Standard Oil (Indiana), Denver,
Colorado, 1977.
C-206
-------
12. Cole, G. P. Range Survey Guide. U.S. Department of the Interior,
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Areas, December 8, 1976. Gulf Oil Corp. and Standard Oil (Indiana), Denver,
Colorado, 1977.
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and Standard Oil (Indiana), Denver, Colorado, September, 1977.
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Summary and Trends Report, November 1974 to October 1975. Ashland Oil
and Shell Oil, Grand Junction, Colorado, 1976.
24. Oil Shale Tract C-b Environmental Baseline Program: Final Report, November
1974 to October 1975. Ashland Oil and Occidental Oil Shade Inc., Grand
Junction, Colorado, 1978.
25. Oil Shale Tract C-b Interim Monitoring Report No. 1 (November 1976 through
August 1977) C-b Oil Shale Venture Submitted to AOSS. Ashland Oil Inc. and
Shell Oil Inc., Grand Junction, Colorado, 1978.
26. Oil Shale Tract C-b Interim Monitoring Report No. 2 (September 1977 to
March 1978): C-b Shale Oil Venture Submitted to Area Oil Shale Supervisor.
Ashland Oil Inc. and Occidental Oil Shale Inc., Grand Junction, Colorado, 1978.
C-207
-------
27. Development Monitoring Program for Oil Shale Tract C-b: Supplemental
Information, Ashland Oil Inc. and Occidental Oil Shale Inc., Grand Junction,
Colorado, 1978.
28. 1978 C-b Annual Report: Summary of Development Activities, Cost and
Environmental Monitoring, C-b Shale Oil Project, Vol. 1. Occidental Oil Shale
Inc., Grand Junction, Colorado, 1979.
29. 1978 C-b Annual Report: Environmental Analysis, C-b Shale Oil Project, Vols.
2 and 2A. Occidental Oil Shale Inc., Grand Junction, Colorado, 1979.
30. First Year Environmental Baseline Report: White River Shale Project, Tracts
U-a, U-b, Vols. 1 and 2. VTN, Colorado, Inc., Denver, Colorado, 1976.
31. Final Environmental Baseline Report: White River Shale Project, Tracts U-a,
U-b. VTN, Colorado, Inc., Denver, Colorado, 1977.
32. 40 CFR 53, 1969.
33. Progress Report: Environmental Programs 1977, WRSP Federal Prototype Oil
Shale Leases U-a, U-b. White River Oil Shale Project, Vernal, Utah, August,
1977.
34. Progress Report: Environmental Programs 1977, WRSP Federal Prototype Oil
Shale Leases U-a, U-b. White River Oil Shale Project, Vernal, Utah, July,
1978.
35. Work Plan: Lease Suspension Period, Environmental Programs, November 1,
1976, October 31, 1977, WRSP Federal Prototype Oil Shale Leases U-a, U-b.
White River Oil Shale Project, Vernal, Utah, December, 1976.
36. WRSP Detailed Development Plan: Federal Lease, Tracts U-a, U-b, Vols. 1
and 2. White River Shale Project, Vernal, Utah, 1976.
37. APHA. Standard Methods for the Examination of Water and Wastewater. In:
Rio Blanco Oil Shale Project Modular Development Phase Monitoring Report
Three, December 1977-November 1978: Year End Report, Vols. 1-3. Gulf Oil
Corp. and Standard Oil (Indiana), 1979.
38. Methods for Collection and Analysis of Water Samples for Dissolved Minerals
and Gases. In: Techniques of Water-Resources Investigations of the U.S.
Geological Survey, Book 5. United States Geological Survey, Washington,
D.C., 1970.
39. Jennrich, R. I., and F. B. Turner. Measurement of Non-Circular Home Range.
J. Theoretical Biology, 22:227-237, 1969.
40. Schnabel, Z. E. Estimation of the Total Fish Population of a Lake. American
Math, Monthly, 75:348-352, 1938.
41. Overton, W. S. A Modification of the Schnabel Estimator to Account for
Removal of Animals from the Population. J. Wild. Man., 29:392-395, 1965.
C-208
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42. Usinger, R. L. Aquatic Insects of California. U. of California, Berkeley Piers,
1971.
43. Quarterly Report No. 4. White River Oil Shale Project, Vernal, Utah.
44. Smith, G. M. Raptors in the Eastern Great Basin of Utah. Science Bulletin,
Biological Series, 18:30, Brigham Young University, Provo, Utah, 1950.
45. Patrick, R., and C. W. Reiner. The Diatoms of the United States. Academy of
National Science, Pennsylvania, 1966.
46. Weber, C. I. A Guide to the Common Diatoms at Water Pollution Surveillance
System Stations. U.S. Environmental Protection Agency, Cincinnati, 1971.
47. Achieving Effective Revegetation of Disposed Processed Oil Shale: A
Program Emphasizing Natural Methods in an Arid Environment.
48. Final Report: Revegetation Studies for Disturbed Areas and Processed Shale
Disposal Sites. Utah State University, Institute for Land Rehabilitation.
49. Methods for the Measurement of Sound Pressure Levels. ANSI.
50. An Environmental Reconaissance Study for Sweetwater County In Situ Oil
Shale Research, Completion Report, 3uly 31, 1975.
51. Environmental Assessment Report: Oil Shale In Situ Processing Research,
Biological Section 18; Sl/2 corner T 18 N; R 106W; April 3, 1977.
52. Environmental Assessment: Oil Shale In Situ Processing Research Projects for
Laramie Energy Technology Center, September 1978.
53. Inventory of Vegetation and Wildlife for In Situ Oil Shale Research Sites, Rock
Springs, Wyoming, December 14, 1976.
54. Potential Research Related to Evaporation of Produced Water at Rock Springs
Site 12, September 1978.
55. A Water Quality Monitoring Plan for Rock Springs Site 12, August 1978.
56. Summary and Analysis of Water Quality at Oil Shale Study Sites, July 8, 1977.
57. Pre-operational Surface and Groundwater Evaluation Study of Proposed
Primary and Alternate Modified In Situ Oil Shale Research Site Near Rock
Springs, Wyoming: Completion Report, September 30, 1976.
58. The Colony Environmental Study, Parachute Creek, Garfield County,
Colorado, Vols. 1, 2, and 3. Thorne Ecological Institute, Boulder, Colorado,
1973.
59. Air Studies, Environmental Impact Analysis Appendix 13. Colony Development
Operation, Denver, Colorado, March 1974.
c-209
-------
60. Transport and Diffusion of Airborne Pollutants Emanating from a Proposed
Shale Oil Production Plant. Colony Development Operation, Denver,
Colorado.
61. Air Quality Impact Assessment. Colony Development Operation, Denver,
Colorado, 1978.
62. An Analysis of the Colony Development Operation's Ability to Comply with
Current Ambient Air Quality Standards, June 1978. Colony Development
Operation, Denver, Colorado, 1978.
63. Air Quality Baseline Data, April 1978. Colony Development Operation,
Denver, Colorado, 1978.
64. Fugitive Dust Control Plan Activities, June 1978. Colony Development
Operation, Denver, Colorado, 1978.
65. Air Quality Impacts of Different Urbanization in Grand Junction, Glenwood
Springs. Colony Development Operation, Denver, Colorado, 1974.
66. Vegetation Data and Analysis for July 1977 at Logan Wash Site. Claremont
Engineering Corp., Claremont, California.
67. G. V. Skogerboa and Wright Water Engineers. Water Studies, Parachute Creek,
Colorado, Environmental Impact Analysis Appendix 12. Colony Development
Operation, Denver, Colorado, 1974.
68. Ecological Studies, Environmental Impact Analysis Appendix 10. Colony
Development Operation, Denver, Colorado, 1974.
69. Environmental Research Plan for the Geokinetics Oil Shale Group
Investigation of the Horizontal In Situ Oil Shale Retorting Process, November
30, 1977. Geokinetics, Inc., Concord, Calif ornia.
70. Bloch, M. B., and P. D. Kilburn. Processed Shale Revegetation Studies 1965-
73. In: Environmental Impact Assessment at Colony Development Operation,
Appendix 6. Colony Development Operation, Denver, Colorado, 1973.
71. Culbertson, W. J., T. D. Nevens, W. Heley, L. R. Terrell, and Dames and Moor.
Environmental Impact Assessment at Colony Development Operation,
Appendix 5. Colony Development Operation, Denver, Colorado, 1974.
72. Investigation of the Geokinetics In Situ Oil Shale Retorting Process, Quarterly
Report, October, November, December 1978. Geokinetics, Inc., Concord,
California.
73. Environmental Analysis: In Situ Process for Extraction of Energy from
Devonian Shale, Soulace County, Michigan. Dow Chemical Company.
74. Environmental Research Plan for the BX In Situ Oil Shale Project. U.S.
Energy Research and Development Administration and Equity Oil Co.,
Washington, D.C., June 23, 1977.
C-210
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75. Methods for Chemical Analysis of Water and Wastes. Water Quality Office,
U.S. Environmental Protection Agency, Washington, D.C., 1974.
76. Standard Methods for the Examination of Water and Wastewater, 14th Ed.
American Public Health Association Inc., New York, New York
77. Hydrology of the Occidental Oil Shale, Inc., D.A. Shale Area, A Progress
Report, November 1, 1976 to October 31, 1977. Geothermal Surveys, Inc.,
South Pasadena, California, January 1978.
78. Water Quality Studies of D.A. Tract and Vicinity: A Baseline Report, August
28, 1978. Occidental Oil Shale Inc., Grand Junction, Colorado 1978.
79. Permit for In Situ Oil Shale Retort Number 6, Logan Wash Site. Colorado
Department of Health, Denver, Colorado, 1978.
80. Environmental Assessment for the Occidental Oil Shale, Inc., Project PON
Number 2, Garfield County, Colorado. Occidental Oil Shale, Inc., Grand
Junction, Colorado, 1977.
81. Air Quality Measurements at Logan Wash, Colorado, March 30, 1977 to
October 26, 1977. H. E. Cramer Company, Inc., Salt Lake City, Utah,
February 1978.
82. Baseline Air Quality Measurements at Logan Wash, Colorado, October 1977.
H. E. Cramer Company, Inc., Salt Lake City, Utah 1978.
83. Verification of the Diffusion Model Used by the H. E. Cramer Company to
Calculate the Stack Height for Room Number 4 at Logan Wash, Colorado,
February 1, 1976. H. E. Cramer Company Inc., Salt Lake City, Utah, 1976.
84. Comparison of Upper Air Data at Grand Junction, Colorado, February 1, 1976.
H. E. Cramer Company Inc., Salt Lake City, Utah, 1976.
85. Wirtz, W. O., II. Vertebrate Populations at the Occidental Oil Shale, Inc.,
Logan Wash Site, Summer 1977. Claremont Engineering Corp., Claremont,
California, 1978.
86. West, N. E. An Ecological Baseline Study of Flora, Vegetation, and Soils on
the Occidental Oil Shale, Inc., Logan Wash Site near De Beque, Colorado,
March 26, 1976. Claremont Engineering Corp., Claremont, California, 1976.
87. An Ecological Survey of the Occidental Oil Shale, Inc., Logan Wash Oil Shale
Site, September 1975 (Summary Report, Supplements I, II, and III). Claremont
Engineering Corp., Claremont, California, 1975.
88. Environmental Assessment for the Occidental Oil Shale, Inc., Project in
Response to PON Number 2, Garfield County, Colorado, Department of
Energy. Occidental Oil Shale, Inc., Grand Junction, Colorado, 1977.
C-211
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89. Environmental Research Plan for the Occidental Oil Shale, Inc., Logan Wash
Project, October 27, 1977. Occidental Oil Shale, Inc., Grand Junction,
Colorado, 1977.
90. Petersen, C. F. Sound Level Measurements in Grand Valley, Colorado,
December 12, 1975. Claremont Engineering Corp., Claremont, California,
1976.
91. Focke, A. B. Background Noise Measurements in the Vicinity of De Beque
and Grand Valley, Colorado, March 1 to November 1, 1975. Claremont
Engineering Corp., Claremont, California, March 1976.
92. Chew, R. T., L. C. Bender, and I. G. Studebaker. Environmental
Considerations for a Proposed Mineral Waste Disposal Pile in Logan Wash.
Occidental Oil Shale, Inc., Grand Junction, Colorado, December 29, 1975.
93. Occidental Vertical Modified In Situ Process for the Recovery of Oil from Oil
Shale Phase I Summary Report, November 1, 1976-October 31, 1977, Vols. 1
and 2. Occidental Oil Shale, Inc., Grand Junction, Colorado, 1977.
94. Statement of Work and Estimate of Costs for Phase IV of Cooperative
Agreement Number ET-76-A-03-1787, September 15, 1977, Revised July 1,
1978. Files U.S. Department of the Interior, Area Oil Shale Office, Grand
Junction, Colorado, 1979.
95. Environmental Impact Assessment: Oil Shale In Situ Research for
Geokinetics, Inc., May 1977. Geokinetics, Inc., Concord, California.
96. Geokinetics Shale Group. Environmental Studies, Uintah County, Utah,
Reports 6B01, 7B01, and 3C01. Geokinetics, Inc., Concord, California, 1977.
97. Landscape and Erosion Control Plan, Geokinetics Shale Group, Environmental
Studies, Uintah County, Utah. Geokinetics, Inc., Concord, California, 1977.
98. Environmental Monitoring Plan. Environmental Research Institute of
Michigan, May 1977.
99. Science Applications, Inc. Preliminary Phase I Hydrological and Water
Quality Plan for the Talley-Frac Site, January 25, 1978. Talley Energy
Systems, Inc., Scottsdale, Arizona.
100. Science Applications, Inc. Environmental Research Plan. Talley Energy
Systems, Inc., Scottsdale, Arizona, September 1977.
101. Science Applications, Inc. TESI Site Post Hydrofracture Water Quality and
Hydrology Report. Talley Energy Systems, Inc., Scottsdale, Arizona, August
1978.
102. Science Applications, Inc. TESI Site Prefracture Water Quality and
Hydrology Report. Talley Energy Systems, Inc., Scottsdale, Arizona, May
1978.
c- 212
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103. Science Applications, Inc. Environmental Impact Assessment for the Talley-
Frac Site. Talley Energy Systems, Inc., Scottsdale, Arizona, November 1977.
104. Science Applications, Inc. Environmental Research Plan, Talley-Frac Oil
Shale Site. Talley Energy Systems, Inc., Scottsdale, Arizona, November 1977.
105. Science Applications, Inc. Final Report: Talley-Frac Oil Shale Site,
February 1979. Talley Energy Systems, Inc., Scottsdale, Arizona, 1979.
C-213
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Terry Thoem
APPENDIX D
APPLICABLE FEDERAL, STATE, AND LOCAL
LEGISLATION, STANDARDS, AND REGULATIONS
LEGISLATION
Federal and State (Colorado, Utah, and Wyoming) pollution control is
identified below for the media of air, water, solid waste, noise, radiation, and
general.
Air
Federal - The Clean Air Act Amendments of 1977 (PL 95-95)
Colorado - Air Pollution Control Act of 1970, S.B. 69, 1970
Utah - Air Conservation Act, Title 26, Chapter 24
Wyoming - Environmental Quality Act, Articles 1-11
Water
Federal - The Clean Water Act Amendments of 1977 (PL 95-217)
The Safe Drinking Water Act of 1974 (PL 93-523)
Water Quality Control Act, CRS 1973, Title 25, Article 8
Water Pollution Control Act, Title 73, Chapter 14
Protection of Public W ater Supply Act
Colorado
Utah
Wyoming
Solid Waste
Federal
Colorado
Utah
Wyoming
The Resource Conservation and Recovery Act of 1976 (PL 94-580)
Solid Waste Disposal Sites and Facilities Act, CRS 1963,
Chapter 36, Article 23 (now CRS 1973 30-20-101 through
30-20-115)
None
Solid Waste Law, Statutes 35-462 through 35-466
Noise
Federal - The Noise Control Act of 1972 (PL 92-574)
Colorado - Noise Abatement Law, CRS 1963, Chapter 66, Article 35
(now CRS 1973, Title 25, Article 12)
Utah - None
Wyoming - None
-------
Radiation
Federal
Colorado
Utah
Wyoming
General
Clean Air Act (Section 122)
Resource Conservation and Recovery Act (Section 3001)
None
Radiation Protection Act, Title 26, Chapter 25
Radioactive Isotopes Law, Chapter 35, Article 3
Federal - The Toxic Substances Control Act of 1976 (PL 94-469)
- The National Environmental Policy Act of 1969 (PL 91-190)
Colorado - Colorado Mined Land Reclamation Act
Utah - Utah Mined Land Reclamation Act
Wyoming - Wyoming Mined Land Reclamation Act
STANDARDS
Legislation provides for the establishment of national and State ambient
standards. Table D-l presents the NAAQS; Table D-2 presents the state ambient air
quality standards for Wyoming (Utah has adopted the NAAQS); and Table D-3
presents a special form of ambient standard, i.e., the PSD increments. These are
maximum allowable concentrations (predicted via computer modelling) superimposed
upon "baseline" concentrations. The PSD legislation/regulations provided for special
areas including National Parks and Wilderness Areas to be designated as Class I.
Table D-4 lists the Class I areas in Colorado, Utah, and Wyoming. Figure D-l shows
those Class I areas near oil shale country.
Colorado Ambient Air Quality Standards,* ug/m3**
1. Suspended particulate matter "Oil Shale Country"
Annual 45
24 hour 150
2. Sulfur dioxide concentration-incremental over an established
baselioe concentration. Colorado I, II, and III SO2 increments
correspond with the same value as the PSD Class I, II, and III
values.
Category I areas include ail existing National Parks, all existing
National Monuments greater than 5,000 acres, all existing National
Forest Service Wilderness or Primitive areas of at least 5,000 acres, and
Gunnison Gorge Recreation Area. Category II areas include the
remainder of the State and Category III areas include the "Front Range"
of Colorado.
* Colorado Code of Regulations - Regulation No. 3
** Reference conditions = ambient conditions
D-2
-------
TABLE D-l.
NATIONAL AMBIENT AIR QUALITY STANDARDS,
UG/M3***
Averaging
Primary
Secondary
Pollutant
time
standard
standard
SO
Annual
80
24 hour
365
3 hour
1,300
Particulate matter
Annual
75
60
24 hour
260
150
NO (as NO_)
Annual
100
100
x 2
°3
1 hour
240
240
CO
8 hour
10,000
10,000
1 hour
40,000
40,000
Lead
Quarterly
1.5
1.5
HC (non CH^)
3 hour
160***
160***
* 40 CFR Part 50
** Reference conditions = 760 mm Hg and 25°C
*** Not a standard; a guide to show achievement of the standard
D-3
-------
TABLE D-2. AMBIENT AIR QUALITY STANDARDS-WYOMING
Standard
Annual
Month 24-hour 8-hour 3-hour 1-hour 1/2-hour
Particulate, ug/m 60 G.M.
, COH/1,000 ft 0.4
3
S02, ug/m 60
, sulfation mg SC>3/100 cm /day 0.25
, 3
CO, mg/m
0.50
150**
260**
10**
1,300**
40**
NO , ug/m
x
HC, ug/m3
100 A.M.
160**
Oxidants, ug/m"
160**
HF, total, ppb
forage-ppmw ^
gaseous-ug/cm
H2S, ug/m3
25
0.3
*40 twice/5
days
*70 twice/5
days
* Not to be exceeded more than
** Not to be exceeded more than once per year
G.M. Geometric Mean
A.M. Arithmetic Mean
-------
TABLE D-3. PREVENTION OF SIGNIFICANT DETERIORATION OF
AIR. QUALITY (PSD) STANDARDS*
3
Maximum Allowable Increase, mg/m
Pollutant
Averaging
time
Class I
Class II
Class III
Particulate matter
Annual
5
19
37
24 hour
10
37
75
S°2
Annual
2
20
40
24 hour
5
91
182
3 hour
25
512
700
* 40 CFR 52.21 and 42 USC 7401 et seq section 163.
Notes:
1. Variances to the Class I increments are allowed under certain
conditions as specified at Section 165(d)(c)(ii) and (iii) and
at 165(d)(D)(i) of the Clean Air Act of 1977.
2. EPA was to have promulgated similar increments for HC, CO, 03 and
NO^ by August 7, 1979; they cure under development. Increments
for Pb are due to be promulgated by October 5, 1980.
D—5
-------
TABLE 0-4. DESIGNATED CLASS I AREAS OF COLORADO, UTAH AND WYOMING
Location ¦ site (Acr«»l
Colorado
Mesa Verde NP
51,
,488
Rocky Mountain NP
263,
,138
Black Canyon of the Gunnison WA
U,
,180
Eagles Nest WA
133,
,910
Flat Tops WA
235,
,230
Great Sand Dunes WA
33,
,450
La Garita WA
48,
,486
Maroon 9all9-snownaa< WA
71,
,060
Mt. Zirkel WA
72,
,472
Rawah WA
26,
,674
Weminuche WA
400,
,907
West Elk WA
61,
,412
Additional >rui designated by the state
Florissant Fossil B«da (MM)
Great Sand Dunes (NM)
Colorado (NM)
Dinosaur (NM)
BlacJc Canyon at the Gunnison (NM)
tJncompahgre (PA)
Wilson Mountain (PA)
Gunnison Gorge
Utah
Arches NP 63,098
Bryca Canyon NP 33,832
Canyonlands NP 337,S70
Capitol Reef UP 221,396
Zion NP 142,462
Wyoming
Grand Taton NP 303,504
Yellowstona NP 2,020,625
Bridger WA 392,160
Fitxpatrick HA 191,103
North Absaroka 331,104
Tston VIA 337,311
Mashakla WA 686,384
NP ¦ National Park
HA - Wilderness Araa
NMP • National Manorial Park
NPS • National Park Service
FS • Forest Service
rwa • Fish and wildlifa Servica
PA m Primitive Area
D-6
-------
WYOMING
MOFFAT
c . f ROUTT
UINTAH
•RANCELV
RIO BLANCO
P
mo BLANCO
GARFIELD
OA A MO VALLTr.
GRAND
MESA
DELTA
MONTROSE
GUNNISON
LSGENO: -
AREA DESIGNATIONS
Colorado catiqorv i uui (.«.•
BRACT MOMIII (MPS) CLASS I ARIAS
CLASS I AREAS
I FLAT TORS WILOIRNISS • SLACK CANVOH OR TM
X MOUNT ZIRKfl WILOCRNItS OUNNISON WILOCRNCSS
S MAROON SClLS-SNOWMAtt VMLDCRNKSt I COLORADO NATIONAL MONUMENT
4 wear ILK VILDIRMISS T ARCMKS NATIONAL PARK
S DINOSAUR NATIONAL MONUMENT
Figure D-l. Designated Class I areas in oil shale region.
D-7
-------
Streams are classified according to their designated/desired use. Water
quality standards and criteria differ according to this classification. As an example,
the water quality criteria are much more stringent for a stream designated as a cold
water fishery than for a stream designated for agricultural use. Figure D-2 shows
the current classifications for Colorado and Utah. Tables D-5, D-6, and D-7 list the
present water quality standards. Colorado is in the process of developing stream
designations and water quality standards. Numeric levels as shown in Table D-8
through D-ll are to serve as a guide in this process. These standards will be
finalized by early 1981.
The 208 planning process was briefly discussed in Section 1 (Applicable Federal
and State Pollution Control Regulations). Figure D-3 shows the proposed stream
-classifications for Colorado. Tables D-12 and D-13 list the proposed classification,
use criteria, and exceptions for the White River and Colorado River Basins,
respectively. Table D-14 lists the water quality criteria associated with each
designated use.
Because of local, regional, and international aspects the topic of salinity in the
Colorado River System deserves some special emphasis. Section 303 (c) of the
Clean Water Act of 1977 requires adoption of salinity water quality standards
applicable to interstate waters. These standards must be reviewed at least every
three years. Pursuant to that requirement, the EPA, on Wednesday, December 18,
1974, promulgated regulations that required the Basin States (Arizona, California,
Colorado, Nevada, New Mexico, Utah, and Wyoming) to adopt ambient water quality
standards for salinity and an implementation plan to achieve the goal that...the
flow-weighted average annual salinity in the lower main stem of the Colorado River
be maintained at or below the average value found during 1972. It was further
required that such numerical standards and implementation plans be established on
or before October 18, 1975. In order to prepare a uniform response to this
requirement, the seven states formed the Colorado River Basin Salinity Control
Forum, an interstate body made of State water pollution and water resource
officials. In June 1975 the Forum submitted proposed "Water Quality Standards for
Salinity Including Numeric Criteria and Plan of Implementation for Salinity Control"
and on August 26, 1975 an amendment to that plan was submitted. The 1975 Forum
Report set the following numerical limits:
Location Salinity - mg/l» lbs/gal*
Below Hoover Dam 723 6.03x10"®
Below Parker Dam 747 6.23x10"*
Imperial Dam 879 7.34x10~s
* Flow-weighted average annual numeric criteria
The implementation plan sets forth basic policies and procedures to achieve
the specified standards in addition to specifying specific Federal and non-Federal
control measures. Components of the implementation plan of interest to oil shale
development are "a no-salt return policy whenever practical" for industrial
D-8
-------
UTAH
Y
Clo |
MEEKER
STREAM CLASSIFICATION
3CAND4
NO CLASSIFICATION
Figure D-2. Current stream classification for oil shale country.
-------
TABLE D-5. SUMMARY OF COLORADO WATER QUALITY STANDARDS
Standard
Settleable solids;
floating solids;
taste, odor, color;
and toxic materials
Free from
Free from
Free from
Free from
Oil and grease
Cause a film or
other discoloration
Cause a film or
other discoloration
Cause a film or
other discoloration
Cause a film or
other discoloration
Radioactive
material
Drinking water
standards
Drinking water
standards
Drinking water
standards
Drinking water
standards
Fecal coliform
bacteria
Geometric mean less
than 200/100 ml
Geometric mean less
than 200/100 ml
Geometric mean less
than 1000/100 ml
Geometric mean less
than 1000/100 ml
Turbidity
No increase of more
than 10 J.T.U.'s
No increase of more
than 10 J.T.U.'s
No increase of more
than 10 J.T.U.'s
No increase of more
than 10 J.T.U.'s
P«
Temperature
6.5-8.5
Maximum 68 F
Change 2°F
6.5-8.5
Maximum 90°F
Change:
ro„
Streams 5 F
Lakes 3°F
6.0-9.0
Maximum 68 F
Change 2°F
6.0-9.0
Maximum 90°F
Change:
Streams 5°F
Lakes 3°F
Fecal
s treptococcus
Monthly average
less than 20/100 ml
Monthly average
less than 20/100 ml
No standard
No standard
-------
tuu 0-4. MCMUuem. mwuiM nm mocktzom or irnium mm or mm
Q«MIU0
HMTMUOa 4
Aquae
le
Agri-
tadaa*
lowrc*
AMtlMUM
Mi 14U (•
euicuro
ay
Jpaciai
C9fltCiCiMf>C
a
IC
21
5*
U
3B
3C
3D
4
1
4
•aetaclolofleal (No./lOO ail
(30*day qoeoatffle a*4a>
— total eollfotw
1
SO
3,300
1.000
9,000
a
4
b
a
4
e
e
ww rooal coiifotoa
•
*
2,000
200
2.000
4
4
b
4
4
e
«
fbyaieal
total illNlVtd fU«|
«
4
4
4
4
d
d
b
4
4
a
€
JtlaiM 00 iof/U
*
4
9.1
9.9
9.9
4.0
b
9.3
4
e
e
«*-«—— c«p«rttur<
4
4
4
4
a
20*C
27*C
b
4
4
e
e
waaljw taap. chaafa
*
4
4
4
a
2 C
4 C
b
4
4
0
e
M f
6.5-9.0
4.5-9.0
4. S-9.0
4.5-9.0
4.9-9.0
4.5-9.0
4.3-9.0
b
4.5*9.0
4.5-9.0
e
e
Turbidity Uwriut
4
4
a
io *n
10 NH
io *ro
io wn
b
19 IRQ
' a
e
0
Chaoieal (naaiaiai a«A)
tnmie, diaaalvtd
.99
.09
.01
*
a
a
a
b
a
.1
0
0
lacM> di««olv«4
1
1
i
4
a
4 _
a
b
4
a
«
«
Cateia> dliMlnd
.010
.010
.010
4
a
.0004*
.004™
b
a
.01
e
a
Cixoaiua. dlaaolvad
.39
.09
.OS
•
a
.10
.10
b
.10
.10
a
e
Coppor, diaoolvod
4
4
4
a
a
.01
.01
b
a
.3
0
e
Cyanida
•
4
4
a
a
.009
.009
b
a
4
e
e
Iron* diaaolrod
4
4
4
4
a
1.0
1.0
b
1.0
4
a
e
Load, dlaaolvad
.09
.09
.04
a
a
.09
.09
b
a
.1
9
e
Mveuiy. total
.003
.003
.002
4
a
.00009
.00009
b
.00009
a
9
e
Phonol
4
4
«
a
a
.31
.01
b
a
a
«
«
SoUaiua, Jiaaolvod
.31
.01
.01
a
a
.OS
.OS
b
a
.09
«
lilvar. dlaaolvod
.09
.09
.OS
a
a
.01
.01
b
a
4
0
s
Sine. dloaalvod
4
4
4
4
4
.09
.09
b
4
4
4
o
aa SI (ua-ioaisad)
• 4
4
4
a
4
.03
.03
b
a
a
O
«
Quoriaa .
4
4
*
a
a
.003
.003
b
a
a
0
«
riuarida, diaaolvod
1.4-3.4
1.4*2.4
1.4-2.4
a
a
a
a
b
a
a
0
c
M0. M H
10
10
10
Mm, dlaaolvad
4
4
a
4
a
a
a
b
a
.79
a
1,1
a
4
a
4
a
.003
.01
b
4
4
o
c
rtfi
4
4
4
a
a
a
a
b
a
1200
0
9
4 Samffldlaat andaaea to v
uriat t&a aatablii
itHAt Of
auoarioa.
1 atawdar
1. Ualta aMlfitod oa oi
taa-by-aa
•a baaia
b Hinilinti will bo ilataraln
K « • «
Mt-Dy am baiia
Sao >WMillt o>.
IUMiiM will ba on earn by um buii.
' Hot to IHBIli 110% Of MMTItlM.
' Tfcaaa Ualta u« not 4»0lid«bU to lava* watat lawtla of
! for CIumi U. ]|, U, »4 3t it biekfiwai Imii of 100 Wi m fnatir. * 10* tiornw Ualt will bo aaod
vmluaa Unit. r»* CUat 30 u hatfcfimaU l«t»U of IU WTOa m fmtw, a 10% UttHM Unit will
of tfca nuMfle *al«a llatad. Short
i miMMi mr ba eoaaidavod oa a biii by wn Molt.
Uoit full ba twiMri thmfoU if CaCOj ImiiiM la Mtu «im4i ISO o*/l.
iuiUm «wi«a UNidiAf M tba daily
WA
2.4
3. 3
2.0
1.0
1.0
1.4
12.4 aad bdlow
12.1 to 14.4
14.7 to 17.4
17.7 to 31.4
21.9 to 24.2
24.3 to 33.9
Total d
laaalvod Mllda (TDd) I
Dt>H
-------
TMU W. (aeiiMJHJ»4>
Caiutiea*it
U
OcaaatiB
lotfw
IC
x«crMtiM a
Aoatbodea
u :s
Ik
30
4
9
4
fca4J.oloflcal mm¦¦ pCl/l)
Aron Alpha
19
13
IS
a
a
13(1)
;is<«)
b
15 iV
13(f)
e
«
ftodiw 221. 221 caotaiAotf
3
3
3
a
a
a
a
b
a
a
«
e
Seroneiu* 90
4
•
2
a
a
a
a
b
a
a
a
a
TrlUus
20.000
20.000
29.000
a
a
a
a
b
a
a
e
0
(MliM Vif/l)
CsdrlA
.2
.2
.2
a
a
.004
.004
b
.004
a
«
e
Lifl4*A«
4
4
4
a
a
.01
.01
b
.01
a
o
e
aaUnurychlo*
100
100
100
a
a
.0)
.0)
b
.03
a
«
o
s
9
s
a
a
.MS
.001
b
.90S
a
•
«
2. 4*0
100
1C0
100
a
a
a
a
b
a
a
e
a
2. 4. S-TT
10
10
10
0
9
Pollution indicator*^
UMI b«t« (pCX/1)
90
so
so
a
a
so
10
b
90
SO
«
9
¦00 (Sf/l)
a
a
3
S
S
s
s
b
S
3
e
«
JW* aa S (af/1).
4
4
4
4
b
a
a
«
0
»oJ 4a 9 (a«/l)*
•
•
*
.OS
.09
.09
.OS
b
a
a
e
e
ZAtuf&elaat mdine« to vwt«t tM oiablt
-------
TABLE D-7. NUMERICAL STANDARDS FOR PROTECTION OP CLASS X HATER USE
Paranatar
Oaacrlotion
Physical
Minimum 0.0. (mg/1) 5a
Maximum tamparacura 2 7°c
Maximum tamparatura chanqa 4°C
pH C.5*9.0
Turbidity incraaaa (NTO) 15c
Chamical (Maximum iwj/1)
Cadmium, diaaolvad - T 0.004
Chromium, diaaolvad - T 0.1.
Coppar, diaaolvad - T 0.01
Cyanid* 0.00S
Iron, diaaolvad - T 1.0
Laad, diaaolvad - T 0.05
Marcury, total 0.000S va 0.00005
Phanol 0.01
Salanium, diaaolvad - T 0.05
Silvar, diaaolvad - T 0.01
Zinc, diaaolvad - T 0.05
Chlorina 0.2 va 0.01-0.00?
HjS 0.02 va 0.002
Radiological (Maximum pCi/1)
Groaa Alpha IS
Gross Bata 30
Paaticidaa (Maximum ag/1)
Endrin 0.004
Lindana 0.01
Maxoxychlor 0.03
Toxaphana 0.00S
d
Pollution Indicators
BOO (ng/1) 5.0
M0j as H (mg/1) 4.0
Ninimua 0.0 (mg/1) limitation la 4 in tha following sagmantsi
San Rafaal Rivar and tributaries, fro® confluanca with Sraan ILivar to confluanca with
rarron craak
Malad Rivar and tributarias, from confluanca with Baar Rivar to stata Una
b Maximum tamparatura limitation ia 35°C in tha following sagmantai
Virgin Rivar and tributaries from atata lina to haadvatars axcapt aa liatad in Appandix B
e At background lavals of ISO HTO'a or graatax, a 10% incraaaa limit will ba uaad instaad
of tha numaric valuas. Short tan variances may ba conaidarad on • caaa-by-caaa baais.
d Investigations should ba eonductad to davalop mora information whara thaaa pollution
indicator lavals ara axcaadad.
D-13
-------
TABU? 0-8. PHYSICAL AND BIOLOGICAL PARAMETERS
Parameter Recreational Aquatic Life Agriculture Domestic Water Supply
Class 1
Primary
Contact
Class 2
Secondary
Contact
Class 1
Cold Water
Biota
Class 1
Warm Kat«r
Biota
Class 2
Class 1
Class 2
Physical:
D.O. (¦g/H*
pH (Std. Units)
Suspended solids (mg/1)
ft Turbidity
Temperature (°C)
Aerobic** (A)
|.5-9.0(B )
Aerobic*1 (A)
d
6.0C(G) 7.0-Spawn
jj.5-9.0(A)
Max 20°C
w/3°C increase(G)*
5.0(A)
jj.5-9.0(A)
Max 30°C
w/3 C increase(G)
* Aerobicb(AJ
*
*
*
•
Acrobicb(A)
5.0-9.0(A)
1.0 TIME)
Aerobicb(A)
J.0-9.0(A)
Biological:
Fecal coliforms per 100 ml
(Geometric mean)
200(A)'
2000{c")f
•
o'«>
2000(E)
%here diisolvod oxygen levels less titan these levels occur naturally* a discharge shall not cause a further reduction in dissolved oxygen in receiving
water.
**An effluent shall be regulated to maintain aerobic conditions* and a guideline of 2.0 mg/liter dissolved oxygen in an effluent should be Maintained,
unless demonstrated otherwise.
CA 7 mg/liter standard* during periods of spawning of cold water fish, shall be set on a case-by-case basis as defined in the NPDBS permit for those
dischargers whose effluent would affect fish spawning.
^Suspended solid levels will be controlled by Effluent Limitation Regulations, Basic Standards* and Best Management Practices (BMP's).
CTemperature shall maintain a normal pattern of diurnal and seasonal fluctuations with no abrupt changes and shall have no increase In temperature of a
magnitude* rate* and duration deemed deleterious to the resident aquatic life. Generally, a maximum 3 C increase over a minimum of a four-hour period*
lasting for 12 hours maxlsNim* is deemed acceptable for discharges fluctuating in volume or temperature. Where temperature increases cannot be maintained
within this range using BMP* BATEA, and BPWTT control measures* the Division will determine whether the resulting temperature increases preclude an
aquatic life classification.
*Fecal coliform is an indicator only. It may Indicate the presence of pathogenic organisms: however, fecal coliform counts from agriculture or urban
runoff may not indicate organisms detrimental to htasan health.
9For drinking water with or without disinfection.
*To be established on a case-by-case basis.
-------
TABLE D-9. INORGANIC PARAMETERS
Parameter
Recreational
Aquatic Life
Agriculture
Domestic
Water Supply
Class 1 Class 2
Primary Secondary
Contact Contact
Class 1
Cold Water
Biota
Class 1 Class 2
Warn Water
Biota
Class 1
Class 2
Inorganics:
Asvaonia (mg/1 as N)
0.02 unionized(A)
0.06 unionized(G) *
0.5*(B)
0.5a(B)
Chlorine Mg/1) -
Total Residual
0.003(H)
0.003(H) •
Cyanide - Free (ag/l)
0.005(10
0.005(H) *
0.2(G)
0.2(B,d")
0.2(B,d")
Fluoride (ag/l)
•
b(E)
''(E)
Nitrate img/1 as HO
•
100°(8)
10(A,B)
10(A,B)
Nitrite («g/l as N)
0.05 (G)
0.5(G) *
10C(BI
1.0a(B)
1.0a(B)
Sulfide as tt^S (mg/X)
0.002
Undi ssociated (X)
0.002 •
Undissociated
0.05(F)
0.05(F)
Boron Imq/X)
•
0.7S(A,B)
Chloride imq/l
*
250(F)
250(F)
Sulfate (*g/l)
*
250(F)
250(F)
aTo be applied at the point of Mater supply intake.
bFluoride levels vary froa 2.4 aj/lltec at 12.0°C and below, to 1.4 ag/liter between 26.3°C and 32.5°C, based upon the annual avera9e of the uiiaw daily
air tem|>erature (see National Interim Primary Drinking Hater Regulations for specific limitations or any modification thereto).
CXn order to provide a reasonable Margin of safety to allow for unusual situations such as extremely high water ingestion or nitrite formation in slurries,
the NOj-N plus MO^-H content in drinking waters for livestock and poultry should be limited to 100 ppm or less, and the NO^-N content alone be limited to
10 pps or less.
*To be established on a case-by-case basis.
-------
TAB!M 0-I». ICTU, PABANRTBBS
IWfMllc Life
Total Nttala - Total
com. I« «*/!
Claea 1
Pilawy
Contact
Clans »
leonterf
CnaUct
6 to 100
Claoa 1
Cold Mater a*4 Ibca Mater Biota
Meter RirdMiv or fllllallalty (a|/l)
lOO lo aoo 300 to 200 MO tft tuo
400 pine
Or Bioaeaay
lAff>llratlon
factor, or
other I*
Claaa 1
Claaa 1
Cla*« 2
klaalwa (aoliAlal
O.MCI
0.1 CO
ft.llci
0.1(C)
0.1(C)
Bioaasoy
•
ftraaale
0.«(C|
0. OS let
o.ostct
0.0SIC)
0.03(C)
Bkooaaay
• 0.1(A)
O.OS(S)
O.O^IC)
larlaa
a
1.0IBJ
1.0(C)
Beryl llw
0.0I1AI
o. ucl
0.4(C)
0.MCI
1.11*1
Bloaaaay
• 0.1(Aft)
Carfailwn
0.004 (A.C,N)
0.0OI U.C.HI
O.OOMC.W)
o.moic.m
O.OIS(C.B)
Bloaaaay
* 0.01(0)
O.OlOtR)
O.OtO(K)
Cbronlwe-Tt Ivalant
0.1 tm
0.1 INI
0.1 (N|
o.nm
0.1 IB)
• O.KIOI
0.05(1)
0.«5(K)
Oiwalw M*alw*le»t
0.02S(N|
0.02*00
0.02S1MI
0.025(H)
0.0*5
A.4tC>
0.0(0
i.««i
Bloaaaay
«
tine
0.05 (C,M>
O.OSIC.II)
o. lotc.M
O.tfllC.K)
o.MHc.m
O.OlftfU)
• 2.0(B)
s.ocri
5.0(F)
of total alkalinity oc other ctiiitUitf n*»t» attributable to anailclr*!, InAntdil or otbrr dlichtifei or tqdnUitftl |Wk<.llc«( shoald
not alttf tin total alkalinity or otlwt chelating >»i»t» of th* rtcrliiAf water by aort than 20%. Whore tfw ctapltilnq cai»aclty of the receiving water
la altered by anra that >0% or alwra afMti aca to tbn receiving water whidi «r* not natnrally cfearactetlettc of that water, specific
ffltamk llaritotiona for pertinent puawtvra al»«11 be la.j» caa« aKall InetreM wxllHratton or alteration of total alkalinity or othnr
cbrlatln* aywta la panltM without cealwloi Mthorlaatlon.
Sfcrra [efwlred, bioaaaey procntarea aaay be aard to ottabllab ataadarta far a particular el toetlne.
Cfo» bleMuy, Im<1 cMHHWtr«ti«i la baaed cm Mlabla Imrf wamMentii i.e., aan-fllterahle leaf ealn4 * ®-W aictw filter.
•to bo aatablliM on a caac-bycaM baaia.
-------
TABLE 0-11. ORGANIC PARAMETERS
FtTHeter
Recreational
Aquatic Life
Agriculture Domestic Water Supply
Class 1
Priaary
Contact
Class 2
Secondary
Contact
Class 1
Cold Water and Wan Water Biota
Class 2
Class 1 Class 2
Organic lmq/l):
Chlorinated Pesticides
Aldrlnb
Dleldrin
DDT (DOO C DDE)
Endrin
Heptachlor
Lindane
Methoxychlor
Hires
Tosaphene
Orthophosphate Pesticides
Desetoi
Endosnlfan
Guthion .
Nalathlou
Parathlon
Chlorcphenosys (Herbicides)
2,4-0
PCS (polychlorinated
Bipltenyls)
Chlorophenol
Honohydric phenol
Benzidine
0.000003(A,H,I)
0.000003(A,H,X)C
0.000001(A,H.X)
0.000004(A)
0.000001(A)
0.00001(A,H)
0.00001(A)
0.000001(A,H)
O.OOOOOS(A,H,I)
0.0001 (A.H)
0.000003(A)
0.00001 (A,H)
0.0001 (A.Hl
0.00004 (A, H)
0.000001(A,H,X)
0.001 (A,H)
0.5(H)
0.0001(A,I)
0.0002(E)
0.004(E)
0.1(E)
0.005(E)
0.1(E)
d
0.O01 (A)
0.001(A)
0.0001(E)
0.0002(E)
0.004(E)
0.1(E)
0.005(E)
0.1(E)
d
0.001(A)
0.001(A)
0.0001(E)
*All organic* not on this partial list are covered under Basic Standards, Section 3.1.11.
''ike persistence, bloaccuaulation potential, and carcinogenicity of these organic compounds cautions hunan exposure to a alniiHsa (EPA).
CAldrin and dleldrin in combination should not exceed 0.000003 sig/1.
'every reasonable effort should be stade to stiniaise hisaan exposure (EPA).
-------
w
i
w
V
ft
K5
SBMirr-\
L£§£ti£
CLASS I. (A,W,R,AG)
CLASS 2. (W,R,AG)
CLASS 3. (R.A6)
CLASS 4. (AG)
Figure D - 3. Proposed stream classifications.
D-18
-------
TABLE D-12. PROPOSED
STREAM CLASSIFICATIONS AND CRITERIA EXCEPTIONS - WHITE RIVER BASIN
«
Llaitlnq parameters6
Proposed
K
T. T.
T. T. *. T.
D.
T. T. T. T. T.
Sujwint classification
Criteria
A1 Cd
Cu Fe Pb Nn
Mn
Hg No Se Ag Zn SO^ PO^ P Alk
FC
1>H TbS TSS Temp
Hhite River from Trappers'
Class 1
A
• •
XXX
X * • * X •
0 • 0
Lake to Piceance Creek
M
•
X
X
X
o •
R
X
0
0
AG
• •
XX *
X
o
O
White River from Piceance
Class 2
II
•
*
*
O •
Creek to Douglas Creek
It
X
0
o
AG
• • •
• X *
X
o
o
Hhite Kiver from Douglas
Class 3
AG
• •
* • •
•
o
•
South Fork Nhite River
Class 1
A
• •
• •
w
R
•
MS
•
Millar Creek
Class 1
A
•
•
M
X
•
R
•
AG
Curtis Creek
Class 3
AG
Coal Creek
Class 3
AG
Little Beaver Creek
Class 3
AG
X
Piceance Creek botweon
Class 2
W
•
•
•
Ryan Gulch and 14 Mile
R
X
Creek
AG
Black Sulfur Gulch
Class 3
AG
Stewart Gulch
Class 3
AG
H. Pork Stewart Gulch
Class 3
AG
Corral Gulch
Class 3
AG
Bos Bldcr Creek
Class 3
AG
E. and M. Douglas Creek
Class 3
AG
'class 1 - Combination of A,
, W. R, and AG
um criteria
bA
- Aquatic Life
°T. ¦ Total • - Permanent Exception
good fishing, high quality water.
w
- Hater Supply
D. ¦ Dissolved X - Temporary Exception* 10 years
Class 2 - Combination of W,
, R, and AG use
¦ criteria,
R
• Recreation
0 - Temporary Exception, 5 years
domestic water supply.
AG
* Agriculture
• - No violations
in this*stream segment, but
Class 3 - Agricultural use
only.
violations
occur in other reaches of stream.
More data needed.
-------
TABU D-13. PROPOSED STREAM CLASSIFICATIONS AND CRITERIA EXCEPTIONS - COLORADO RIVER BASIN
Limiting Parameters
Secpaent
Proposed # Use ^
classification criteria
t^ t". t: t~. d: tT T. tI tT"
Cd Fe Pb Hn Mn Hg Ho Se Zn CI Na SO.
HH,
P04 P Alk BOO FC Mg pH TDS TSS Temp
K>
O
Colorado River from
Garfield County line
to Canyon Creek
Colorado River from
Canyon Creek to
Plateau Creek
Colorado River froa
Plateau Creek to
Utah line
Roaring Fork River
from Study Area
boundary to Colorado
River
Fourmile Creek
Crystal River fcon
Study Area boundary
to Roaring Fork River
Headwaters of E.
U. Divide Creek to
National Forest boundary
Divide Creek below
National Forest boundary
Roan Creek above
Clear Creek
Roan Creek below
Clear Creek
Brush Creek
Class 1
Class 2
Class 2
Class 1
Class 1
Class 1
Class 1
Class 3
Class 1
Class 3
Class 1
A
H
R
AG
W
R
AG
W
R
AG
A
W
R
AG
A
W
R
AG
A
W
R
AG
A
W
R
AG
A
W
R
AG
A
W
R
AG
XX*
X
* 0
o
o
o
o
o
Class 1 - Combination of A, W, R« and AG use criteria,
good fishing, high quality water.
Class 2 - Combination of W, R, and AG use criteria,
domestic water supply.
Class 3 - Agricultural use only.
A
w
R
AG
* Aquatic Life
- Mater Supply
- Recreation
- Agriculture
T.
D.
Total
Dissolved
• - Permanent Exception
X - Temporary Exception, 10 years
0 - Temporary Exception* 5 years
* - No violations in this stream Segment, but violations
occur in other reaches of stream. Hore data needed.
(continued)
-------
TABLE D-13. (continued)
Segaent
Proposed
Classification
Li»itiit9 ParaMters6
Ose
criteria
"TT
CdPePbftaltoHgNoSeZnClNa S04 PO^ P Alk BOD PC Hg pll TDS TSS Temp
V
to
Clear Creek
Rifle Creek above
Rifle Gap Reservoir
Parachute Creek
Neat Fork of
Parachute Creek
Plateau Creek above
Mesa Creek
Plateau creek below
Mesa Creek
eiq Salt Wash
Salt Creek
M. Salt Creek
i River
Kanoah Creek above
Grand Mesa National
Forest Boundary
Kannah Creek below
Forest boundary
Dolores River
Class 3
Class 1
Class 3
Class 1
Class 1
Class 2
Class 1
Class 3
Class 3
Class 3
Class 2
Class I
Class 3
Class 2
AG
A
H
It
AG
AG
A
V
II
AG
A
H
R
AG
M
R
AG
A
It
It
AG
AG
AO
AC
It
R
AC
A
It
II
AG
AG
It
R
AG
• *
#
• • • 0
Class 1 - Combination of A, W, R, and AG use criteria,
good fishing, high quality water.
Class 2 - Combination of W, R, and AG use criteria,
domestic water supply.
A - Aquatic Life
H - Mater Supply
R - Recreation
AG - Agriculture
T. » Total S - Permanent Exception
D. ¦ Dissolved X - Temporary Exception, 10 years,
O - Temporary Exception, 5 years
• - No violations in this streaa segment, but violations
occur in other reaches of streaa. More data needed.
-------
TABLE 0-14. RECOMMENDED MATER QUALITY CRITERIA
Water us.s
P»r«m»t«r Wttt supply . Aquatic Lif./wlldlif. Racr.atlon
Alkalinity as CaCO^
—
30-130 ag/l*#
—
Aluainua - Total
—
0.I ng/1
Aluainua - Dissolved
—
0.1 ag/1**
Total Aaannia as N
0.5 ag/1**
—-
Unionized Aiibii inla as M
0.02 ag/l
Arsenic - Total
0.01 ag/1
0.05 ag/1
aariun - Total
1.0 ag/1
—
Berylliua - Total
1.1 ag/1
Boron
1.0 ag/l**
—
Cadaiua - Total
0.01 ag/1
0.003 ag/1
Chloride - Total
250 ag/1
Chroaiua - Total
0.05 ag/1
0.3 nq/!•
Fecal Coliform
2000/100 ml*
2000/100 al*#
200/100 ml
Color
75 color units**
Copper - Total
1.0 ag/1
0.030 ng/1
Cyanide
0.20 ag/1
0.00S ag/1
Hardness
Iron - Total
—-
1.0 ag/1
...
Iron - Distolvd
0.J ag/1
0.3 ag/1"
Lead - Total
0.05 ag/1
0.03 ng/1
...
Manganese - Total
0.05 ag/1
1.0 ag/1
Manganeee - Dissolved
0.05 ag/1
...
Mercury - Total
0.002 ag/1
0.00005 ag/1
Molybdenum - Tot£i
—-
...
Nickel - Total
0.1 ng/1
Nitrate - N
10 ag/1
—
...
Dissolved Oxygen
4.0 ag/1*
5.0 - 6.0 ag/1 Min.
2.0 ng/1 Min
PH
5.0 - 9.0
6.5 - 9.0
6.5 - 9.0
Phenols
0.001 ag/1
0.001 ag/1
Total PO -P
—-
0.025 ag/1 - lakas**
Phthalate Esters
0.003 ag/1
...
pa
0.000001 ag/1
SalenXun - Total
0.01 aq/1
0.05 ag/1 f
...
Silver - Total
0.05 ag/1
0.0001 - 0.0025 ag/1
Silver - Dissolved
0.0001 ag/1
...
Sodiua
270 ag/l*•
—
...
sulfate - Total
250 ag/l
TDS
500 ag/l**
...
TSS
25 ag/l-aadi*n^
...
H,S (undiisociated)
0.05 ag/l
0.002 ag/1
Tiaperature
——
h
—-
Zinc - Total
5.0 ag/l
0.03 ag/1
Unless otherwise indicated the recaaawnded criteria corresponds with Proposed Stata Standards.
* Diffara froa Proposed Stata standards.
•• CWA 208 RaffiB—ndatlon only (no Proposed Stata Standard).
*** For agricultural uaes, th. hqcc, except in a few instances, did not distinguish between irrigation and livestock
uses. The cm 208 attempted to distinguish the differences. Therefore! under livestock there are numerous dif-
faraneaa between 208 and HQCC ntaabers. Under irrigation tha lower recaaaendad criteria match hqcc nuabers,
'continuous irrigation, all aoils (Batch NQCC Proposed State Standards).
bShort-tera irrigation, neutral to alkaline fina t.xtured aoils.
CLong-tarsi irrigation on sensitive crops.
dNaxioua concentration for a aoderttely restricted sodiia diet.
'water froa which no detriaantal effects will usually be noticed. 500 ag/l
Water which can have datriaental affects on sanaitiv. erope. 500 - 1000 ag/1
water that nay have adverse effects en aany crops and requiree careful aanagamnt practices. 1000 - 2000 ag/1
Hater that can be used for tolerant plants on permeable soils with careful aanagaaent practices. 2000 - 5000 ag/1
'limiting concentration dependant on hardness.
'value represents aaxlawa increase in aabiant concentration due to discharge.
hCold water maniiw la 20°C, war* water aanlaua is 30°C, and both categoria* liait teaperatura changes to 3°C.
(continued)
D-22
-------
TABU D-14. (continued)
Watar uaaa
_J£*ramat*r__
Alkalinity K CaCOj
Aluminun - Total
Aluainua - Diisolvad
Total Mnonia as H
unionizad Aooonia as s
Arsanic - Total
Baritsi - Total
Barylliun - Total
Boron
CadaiiM - Total
Chlorida - Total
Chrooiua - Total
racal Colifonn
Color
Coppar - Total
Cyanid*
Hardnass
Iron - Total
Iron - Dissolvad
Laad - Total
Manganasa - Total
Manganasa - Dissolved
Marcury - Total
Molybdanun - Total
stickal - Total
Nitrata - N
Dissolvad Oxygan
P«
Phanols
Total PO.-P
Phthalata Estars
PCB
Salaniua • Total
Silvar - Total
Silvar - Dissolved
Sodi.ua
Sulfate - Total
IDS
TSS
H-S (undissociated)
Taaperatur*
Zinc - Total
Irrigation
S.O ag/1®, 30.0 ag/lb«
0.1 ag/1
0.1 ag/l*. O.S ag/lb«*
0.7Sag/l°
0.01 ; 0.0S ag/l°»
0.1 ag/l*, 1.0 a»/lb*«
1000/100 Ml
0.2 ag/1*, S.O ag/lb
0.2 a»/l
s ag/l\ 20 a»/ib«
i ag/i\ lo a»/ib*
0.2 ag/I*. 10 ag/l*«
0.01 ag/1*. 0.0S a»/lb
0.1 ag/1*
100 ag/1
2.0 ag/1
4.5 - ».0*»
2.0 wq/X
Livaitoclc
S.O ag/1*
0.2 ag/l«*
S.O ag/l*«*
0.05 m/l***
0.1 ag/1
1000/100 ml
O.S ag/l*«
0.2 ag/1
0.1 ag/1
0.00005 ag/1"
0.5 ag/1
NO. * HO, 100 ag/1
2.d wt/X*
O.S ag/1
MOO ag/1"
25 ag/1 •••
onlass otharviaa indicatad, the race—andsrt criteria correspeadt with >ropos*d ttata standards.
• Differs froa Proposed Stat* Standards.
*• cm 208 Recoaaendation only (no Proposed Stat* Standard).
por agricultural us**, the NQCC, except in 4 few inatancas, did Mt distinguish batwaan irrigation and livaatock
usas. Tha cn 208 attempted to distinguish tha diffareneea. Therefore, oader livestock thsra ara nuaxrou* aif-
faraneas batwaan 208 and NQCC aabtn. Under irrigation th* lower rs«Ma*aJ*d criteria Mtch nqcc nuaiber*.
'continuous irrigation, all aoils (aatch NQCC Proposed (tat* Staadarde).
bShort-t«r» irrigation, nautral to alkaline fine textured soils.
cLong-tera irrigation on senaitive crops.
dWnr1—- concentration for a aoderataljr rastrictad *odiua disc.
"water froa which no' datriasntal effects will usually ba not!cod.
Matar which can hava detrlaental affacts on sensitive crops.
Matsr that nay hava advarsa affacts on Mny crops and requires caraful aaaageaent praoticas.
Matar that can ba uaad far tolarant planta on paraeabla soils with earafwl aanagaaant practices.
'iJLmitin? concantration dapandant on hardaass.
*Value raprasants ¦axiaiia incr*asa in aablent concentration das to disaharga.
sCold watar maxiaua ia 20°C, waca watar aawiraia is J0°c, aad both cetogorioe Uait teaperatura ehangaa 3°C.
500 ag/1
500-1000 ag/1
1000-2000 ag/1
2000-5000 ag/1
D-23
-------
discharges, disposal of blow-down water from power plants in a manner to avoid
return of salts to the river system, use of saline maine drainage water for
compacting spent shale as well as in plant processing operations, and control of
drainage water from spent shale deposits. In large part the philosophy is concerned
with reducing the dissolved solids content of waters over which one has control due
to use in some industrial or agricultural process. A concurrent and major effort in
controlling salinity in the Colorado River is reduction in salinity produced by natural
sources.
In November of 1976 EPA approved the Forum's adopted water quality
standards and implementation plan. Subsequently EDF et al. challenged the
approval. The litigation was recently ruled upon in favor of EPA. Pursuant to the
provision in Section 303 that the standards be reviewed every 3 years the Forum has
proposed certain revisions to the water quality standards and the implementation
plan. The Forum adopted the "Policy for Implementation of Colorado River Salinity
Standards through the NPDES Permit Program" in February 1977 and developed the
"Proposed 1978 Revision, Water Quality Standards for Salinity including Numeric
Criteria and Plan of Implementation for Salinity Control" in August 1978. Utah
adopted the 1978 revision on July 2, 1979 and Colorado held a hearing in February
1980. However the basic numeric criteria on the lower stem of the Colorado River
remains the same. The key components of the 1978 Forum Report include the
following:
1. Construction of salinity control units including the Grand Valley, Meeker
Dome, Glenwood Springs, and Unita Basin projects in "oil shale country"
2. Implementation of the 208 Water Quality Management Plans
3. Placing of effluent limits on industrial and municipal discharges via the
NPDES program
Since the oil shale developers are directly affected by Provision #3, the
NPDES provision merits further discussion. The objective for discharges adopted by
the Forum and by the State of Colorado is "a no-salt return wherever practicable".
This provision is waived for the individual discharger if his salt load reaching the
main stem is less than .9 tonne (1 ton) per day or 318 tonnes (350 tons) per year. In
cases where a no-salt return is not practicable the discharger must:
1. Describe the project, the proposed salt load, and water supply
2. Describe alternative plans for the elimination of the salt discharge
including how the removed salts will be prevented from reentering the
surface or groundwater
3. Give costs of the alternatives
Municipal discharges are allowed an incremental MO mg/1 TDS (3.3
-------
oil shale related facilities. Possible treatment schemes were discussed in Section 4
of this document.
Drinking water standards have been promulgated under the Safe Drinking
Water Act. Community water supplied must comply with these values. Also the
standards provide criteria for the designation of hazardous and solid wastes via the
RCRA hazardous waste criteria. These standards are listed in Tables D-15 and
D-16.
PERMIT PROGRAMS - EXISTING
Enabling legislation and environmental standards are attained and maintained
through the promulgation and enforcement of emissions/effluent regulations.
Section 6 of this document summarizes applicable guidance for the establishment of
these emission/effluent regulations.
Air NSPS for oil shale related facilities are listed in Table D-17. Section 6
describes BACT limits in PSD permits which have been issued. Figures D-4 and D-5
and the Colorado limitations shown below provide information on Colorado emissions
regulations.
Colorado Emission Limitations
Regulation No. 1 *
III. B.6.d. vi and vii.
0.3 pounds of SO2 (for the sum of all SO* emissions from a
facility) per barrel of oil provided/processed
*1. Sources producing less than 1000 BPD are exempt
2. Emission limits apply to production and refining of shale oil
Regulation No. 8
No person shall cause emissions of hydrogen sulfide into the
ambient air which exceed 142 micrograms per cubic meter
(0.10 ppm).
NPDES permits are issued to facilities which have, or have the potential for, a
discharge to a navigable surface water course. The history, philosophy, and criteria
for these source standards is provided below.
Under the River and Harbor Act of 1886 (recodified in the Rivers and Harbors
Act of 1889) effluent limitations were required by some states. The Federal Water
Pollution Control Act Amendments (FWPCA) of 1977 changed the thrust of
enforcement water quality standards to effluent limitations where the effluent
limitations are described as:
D-25
-------
TABLE 0-15. PROMULGATED DRINKING WATER STANDARDS (40 CFR 141)
The following are the maximum contaminant levels for inorganic chemical! other than fluoride:
Contaminant Level, mg/1
Arsenic O.OS
Barium 1.
Cadmium 0.010
Chromium O.OS
Lead O.OS
Mercury 0.002
Nitrate (a* N) 10.
Selenium 0.01
Silver O.OS
When the average of the maximum daily air temperatures for the location in which the community water system is
situated is the following, the maximum contaminant levels for fluoride are:
mg/1
Temperature, °F
1 °C
Level
53.7 and below
12.0 and below
2.4
53.8 to 58.3
12.1 to 14.6
2.2
58.4 to 63.8
14.7 to 17.6
2.0
63.9 to 70.6
17.7 to 21.4
1.3
70.7 to 79.2
21.5 to 26.2
1.6
79.3 to 90.5
26.3 to 32.5
1.4
Tha following are the maximum contaminant laveIs for organic chemicals. They apply only to cosmunity water systems.
Compliance with maximum contaminant levels for organic chemicals is calculated pursuant to Section 141.24.
Level, mg/1
a. Chlorinated hydrocarbons:
Endrin (1,2,3,4,10, 10-hexachloro-6.7-epoxy- 0.00002
1,4,4a,5,6,7,8,8a-oetahydro-l.4-endo-5,8-
dimenthano naphthalene).
Lindane (1,2,3,4,5,6-hexachlorocyclohexane, 0.004
gamma isomar) 1
Methoxychlor (l,l,l-Trichloro-2,2-bis (p-mathoxyphenyl) 0.1
ethane).
Toxapliene
2,4-D, (2,4-Dichlorophenoxyacatic acid). 0.1
2,4,5-T7 Silvex (2,4,5-Trichlorophenoxypropionic acid). 0.01
D-26
-------
TABLE D-16.
PROPOSED SECONDARY
DRINKING WATER REGULATIONS4
Contaminant
Proposed level
Principal effects
Chloride
250 mg/lb
taste
Color
15 color units
appearance
Copper
1 mg/1
taste, fixture staining
Corrosivity
(Noncorrosive)
deterioration of pipes, unwanted
metals in drinking water
Foaming agents
0.5 mg/1
foaming, adverse appearance
Hydrogen sulfide
0.05 mg/1
taste, brown stains on laundry
and fixtures
Manganese
0.05 mg/1
taste brown stains, black
precipitates
Odor
3 Threshold
Odor Number
odor
pH
6.5 - 8.5
corrosion below 6.5 - incrustation:
bitter taste, lowered germicidal
activity of chlorine over 8.5
Sulfate
250 mg/1
taste, laxative effects
Total dissolved solids
.500 mg/1
taste, reduction in life of hot
water heaters, precipitations in
cooking utensils
Zinc
5 mg/1
taste
aRecommended limits and principal effects associated with each contaminant.
Milligrams per liter; same as "parts per million."
D-27
-------
TABLE D—17. NEW SOURCE PERFORMANCE STANDARDS
FOR "OIL SHALE RELATED FACILITIES"
40 CFR 60.40 Subpart D (NSPS for Fossil Fuel Fired Steam Generators)
TSP
0
4
O
S°2
0.80
NO
0.20
X
0.30
60.100
Subpart
h2s
0.10
HC Floating roof or vapor recovery if true vapor pressure is
>1.5 psia but <11.1 psia reporting requirements only if true
vapor pressure is <1.5 psia.
40 CFR 60 (NSPS for Refinery Claus Sulfur Recovery Plants)
Gaseous fuel burning 0.1 grain/dscf
Sulfur recovery
oxidation system 250 ppm S02
reduction system 300 ppm total S
10 ppm H^S
Proposed NSPS
6
1. Gas Turbines >10 x 10 Btu/hour
75 ppmv NO at 15% O
150 ppmv SO*
2. Coal Gasification (Guideline)
250 ppmv total S
99.0 percent total S removal
100 ppmv HC
3. Field gas processing units
Gaseous fuel burning 160 ppmv H2S
Sulfur recovery 250 ppmv S02 (oxidation)
300 ppmv S (reduction)
D-28
-------
1.0
« 0.04
0.03
0.02
0.01 —-J ' I I I UN M » I 1 | Mil I.I.J I I I Mill I I 1 _ ———l—LL .
0.1 1.0 10.0 100.0' 800.0 1000.0
TOTAL INPUT
MILLIONS OF BTU'8/HR.
Figure d - 4. Fuel burning equipment - particulate emission.
-------
100.0
T
30.0
10.0
1.0
0.1
O.OI
O.I
1.0
30.0
100.0
1000.0
10.0
TON8/HOUR
Figure D - 5. Process weight rate - particulate emission.
-------
...restrictions on quantities, rates, and concentrations of chemical,
physical, biological, and other constituents discharged from any
discernible, confined, and discrete conveyance (point source) from which
pollutants are or may be discharged.
These effluent limitations effectively allow water quality to be protected
through the refined identification and development of water use and treatment
procedures that are to be applied at the source of potential pollutants (i.e., the
discharge itself). The Act (FWPCA) requires that:
By 1 July 1977, there be achieved effluent limitations for point sources
(excluding publicly-owned treatment works) which shall require the application
of the best practicable control technology currently available (BPT).
By 1 Duly 1977, there be developed pretreatment requirements for discharges
of "noncompatible" pollutants to publicly-owned treatment works.
By 1 July 1977, there be developed effluent limitations based upon secondary
treatment in publicly-owned treatment works.
By 1 July 1977, any more stringent limitations necessary to meet other laws
must be achieved, including Water Quality Standards.
By 1 July 1984, there must be achieved effluent limitations for point sources
(other than publicly-owned treatment works) where application of the best
available technology economically available (BAT) is required for
nonconventional and toxic pollutants as defined in the Act.
By 1 July 1984, there must be achieved effluent limitations for point sources
where application of the best conventional pollutant control technology for
conventional pollutant (TSS, pH, BOD, and fecal coliform).
The Act also established effluent requirements for toxic pollutants. BAT must
be defined by July 1, 1980 for the 129 priority pollutants for the 21 industrial
categories identified below. The present EPA schedule shows proposals for these
categories are being completed by the end of 1980. Data for oil shale related
facilities are shown in parentheses.
Automatic and Other Laundries
Coal Mining (12/80)
Electroplating
Inorganic Chemicals Manufacturing
Iron and Steel Manufacturing
Leather Tanning and Finishing
Machinery and Mechanical Products Manufacturing
Miscellaneous Chemicals Manufacturing
Nonferrous Metals Manufacturing
Ore Mining
Organic Chemicals Manufacturing
Point and Ink Formulation Printing
Paving and Roofing Materials
Petroleum Refining (5/80)
D-31
-------
Plastic and Synthetic Materials Manufacturing
Pulp and Paperboard Mills and Converted Paper Products
Rubber Processing
Soap and Detergent Manufacturing
Steam Electric Power Plants
Textile Mill
Timber Products Processing
Oil shale facilities are not one of the listed industries. However, compliance
with BAT standards for individual toxic pollutants established pursuant to Section
307 must be met by July 1, 1984. Oil shaJe facilities must comply with any of these
"307" standards. In the absence of BAT for the oil shale industry, BAT must be
defined on the basis of best engineering judgement via the issuance of an individual
NPDES permit. Table D-18 provides a schedule for implementing BAT and BCT.
The control of discharge of pollutants from point sources is accomplished
through establishment and enforcement of effluent limitations. Enforcement of
effluent limitations is carried out through the "National Pollutant Discharge
Elimination System" (NPDES) as outlined in Sections ^01 and 402 of the ACT
(FWPCA). It is the intent that each state administer this program but in some cases
the states have not yet passed required legislation and thus the program is
administered by the EPA. In general, to accept the program the states must be able
to prohibit discharges of permit requirements and must be able to administer the
program. It is useful to note that in order to assume the NPDES program a state
must also have procedures which control the disposed of pollutants into wells in
order to protect the public health and welfare and to prevent pollution of ground and
surface water resources. The program is being implemented by Colorado but not by
Utah.
To better understand the NPDES program it is appropriate to quote some of
the definitions used in the program. These definitions are:
"The term pollutant means dredged spoil, solid waste, incinerator
residue, sewage, garbage, sewage sludge, munitions, chemical wastes,
biological materials, radioactive materials, heat, wrecked or discarded
equipment, rock sand, cellar dirt, and industrial, municipal, and
agricultural waste discharged into water. Excluded is water, gas, or
other material injected into a well to facilitate production of oil, gas, or
produced water disposed of in a well if the latter is approved."
Point source is defined to mean:
...Any discernible, confined, and discrete conveyance, including but not
limited to any pipe, ditch, channel, tunnel, conduit, well, discrete
fissure, container, rolling stock, concentrated animal feeding operation,
or vessel, or other floating craft from which pollutants are or may be
discharged.
Navigable waters are defined as including:
1. All navigable waters of the United States
D-32
-------
TABLE 1>-18- LEVELS OF CONTROL APPLICABLE TO EXISTING SOURCES UNDER 1977 AMENDMENTS TO FWPCA
Pollutant
Conventional
None of) ven t i on a 1
Toxic
Best Conventional Pollutant
Control Technology
Best Available Technology
Economically Achievable
Best Available Technology
Economically Achievable
Effluent Standards
(or Prohibitions)
Best Management
Practices
o
u>
u>
Abbreviation
Statutory
Deadline
301(c) Economic
Variance
301 (g) Environmental
Variance
BCT
July 1. 1984
BAT
July 1( 1984/as appro-
priate. Never later than
July 1, 1987
Yes
BMP1S
July 1, 198g/as
appropriate
Up to one year
after promulgation/
as appropriate
No
*July 1, 1984, or throe years after limitations are established, whichever is later. Never later than July 1, 1987.
kjuly 1# 1984 for those 129 toxic pollutants which appeared at 43 Federal Register 4108 (January 30, 1978}. For other pollutants which may be added to
the toxics list, three years after limitations for such pollutants are established.
°The effective date for an effluent standard for a toxic pollutant stay be extended to three years after the standard is promulgated if earlier compliance
is technically infeasible.
-------
2. Tributaries of navigable waters of the United States
3. Interstate waters
i*. Intrastate lakes, rivers, and streams which are utilized by interstate
travelers for recreational or other purposes
5. Intrastate lakes, rivers, and streams from which fish or shellfish are
taken and sold in interstate commerce
6. Intrastate lakes, rivers, and streams which are utilized for industrial
purposes by industries in interstate commerce
The term "effluent limitation" means any restriction established by State or
the Administrator of quantities, rates, and concentration of chemical, physical,
biological, and other constituents which are discharged from point sources into
navigable waters, the waters of the contiguous zone, or the ocean, including
schedules of compliance.
The term "discharge of a pollutant" means any addition of any man-made or
man-induced material which alters the chemical, physical, biological, and
radiological interity of a navigable water. Not much is left out—so, it is best to
assume that if there is or may be a discharge, a permit must be applied for. One
should stress the "may be" component. It is not uncommon in the West to assume
that retention facilities will not discharge and then find that an unusual
precipitation event threatens the integrity of the system since no discharge was
assumed.
Establishment of effluent guidelines arid standards is addressed in "Title III -
Standards and Enforcement" of the Act (FWPCA). Effluent limitations for existing
point sources are discussed in Section 302. It is required that when, in the judgment
of the Administrator, the discharge of pollutants from a point source would
interfere with the attainment or maintenance of water quality under the provisions
of the Act, effluent limitations (including alternate effluent control strategies) for
such point sources shall be established.
Section 306 of Title III required the Adminstrator to propose, publish, review
and revise when appropriate, standards of performance for new sources (sources
whose construction is commenced after publication of the regulation). A minimum
of 28 industrial categories (Group I) was identified. Although oil shale facilities
were not identified, petroleum refinery BAT, BPT, and NSPS may serve as
guidelines.
For Petroleum Refining as a whole the significant waste water constituents
identified as BODs, COD, TOC, TSS, oil and grease, phenolic compounds, ammonia
(N), sulfides, and total and hexavalent chromium and were subsequently selected as
the basis for the effluent limitations.
Best Practicable Control Technology Currently Available (BPT) was based
upon the following treatment procedures:
o Sour water stripping to reduce ammonia and sulfide
D-34
-------
o Elimination of once-through barometric condenser water
o Segregation of sewers
o Elimination of polluted once-through cooling water
o Oil and solids removal at end of pipe
o Carbonaceous wastes removal at end of pipe
BPT effluent limits established in 40 CFR 419.52 are shown in Table D-19.
Best Available Technology Economically Achievable (BAT) was defined in the
context of using additional treatment methods now practiced by some plants in the
petroleum refining industry, and include:
1. Use of air cooling equipment.
2. Reuse of sour water stripper bottoms in crude desalters.
3. Reuse of once-through cooling water as make-up to the water treatment
plant.
4. Using wastewater treatment plant effluent as coolant water, scrubber
water, and influent to the water treatment plant.
5. Reuse of boiler condensate as boiler feedwater.
6. Recycle of water from coking operations.
7. Recycle of waste acids from aikylation units.
8. Recycle of overhead water in water washes.
9. Reuse of overhead accumulator water in desalters.
10. Use of closed compressor and pump cooling water system.
11. Reuse of heated water from the vacuum overhead condensers to heat the
crude. This reduced the amount of cooling water needed.
12. Use of rain runoff as cooling tower make-up or water treatment plant
feed.
The numerical effluent limitations for BAT published at 40 CFR 419.53 are
shown in Table D-20.
New source standards (NSPS) represent controls that are equal to or better
than BAT (Table D-21). Sources are subject to NSPS if they have not commenced
construction prior to the proposal of NSPS. Oil shale NSPS have not yet been
proposed.
D-35
-------
TABLE D-19. BPT EFFLUENT LIMITS AS ESTABLISHED IN 40 CFR 419.52
Effluent limitations
Average of daily Average of daily
Maximum for values of 30 con- Maximum for values of 30 con-
Effluent characteristic any 1 day secutive days any 1 day secutive days
shall not exceed shall not exceed
Metric units (kg per 1,000 m
of feedstock)
English units (pounds per 1,000 bbl
of feedstock)
bod5
TSS
COD
Oil and grease
Phenolic compounds
Ammonia as N
Sulfide
Total chromium
Hexavalent chromium
PH
54.4
37.3
388
17.1
0.40
23.4
0.35
0.82
0.068
28.9
23.7
198
9.1
0.192
10.6
0.158
0.48
0.032
19.2
13.2
136
6.0
0.14
8.3
0.124
0.29
0.025
10.2
8.4
70
3.2
0.068
3.8
0.056
0.17
0.011
Within the range of 6.0 to 9.0
Within the range of 6.0 to 9.0
-------
TABLE D-20. BAT EFFLUENT LIMITATIONS PER 40 CFR 419.53
Effluent limitations
Average of daily
Average of daily
Maximum for
values of 30 con- Maximum for
values of 30 con-
any 1 day
secutive days any 1 day
secutive days
Effluent characteristics
shall not exceed
shall not exceed
BOD_
D
TSS
COD
Oil and grease
Phenolic compounds
Ammonia as N
Sulfide
Total chromium
Hexavalent chromium
PH
Metric units (kg per 1,000 m"
of feedstock)
8.8
8.4
47
1.7
0.041
5.6
0.19
0.44
0.0092
7.1
7.1
38
1.4
0.029
4.2
0.12
0.37
0.0059
English units (pounds per 1,000 bbl
of feedstock)
3.2
3.0
16.8
0.60
'0.015
2.0
0.066
0.15
0.0033
2.6
2.6
13.4
0.48
0.010
1.5
0.042
0.13
0.0021
Within the range of 6.0 to 9.0
Within the range of 6.0 to 9.0
-------
TABLE D-21. REFINERY NEW SOURCE PERFORMANCE STANDARDS AS PER 40 CFR 419.55
Maximum for
any 1 day
Effluent limitations
Average of daily
values of 30 con- Maximum for
secutive days any 1 day
shall not exceed
Average of daily
values of 30 con-
secutive days
shall not exceed
Metric units (kg per 1,000 m"
of feedstock)
English units (pounds per 1,000 bbl
of feedstock)
0
1
u>
00
bod5
TSS
COD
Oil and grease
Phenolic compounds
Airanonia as N
Sulfide
Total chromium
Hexavalent chromium
PH
41.6
28.1
295
12.6
0.30
23.4
0.26
0.64
0.052
22.1
17.9
152
6.7
0.14
10.7
0.12
0.37
0.024
14.7
9.9
104
4.5
0.105
8.3
0.093
0.220
0.019
7.8
6.3
54
2.4
0.051
3.8
0.042
0.13
0.0084
Within the range of 6.0 to 9.0
Within the range of 6.0 to 9.0
-------
New sources must meet standards of performance (for the control of the
discharge of pollutants) which reflect the greatest degree of effluent reduction
which the EPA Administrator determines to be achievable through application of the
best available demonstrated control technology, processes operating methods or
other alternatives including, where practicable, no discharge of pollutants . A "no
discharge of process waste water pollutants" may be, considered in any stage of
effluent limitations development.
Water quality as affected by thermal discharges is addressed in Section 316 of
the Act. Any point source subject to the provisions of Section 301 "Effluent
Limitations" or Section 306 "National Standards of Performance" may attempt to
demonstrate that any proposed effluent limitation for thermal control of a discharge
is more stringent than necessary to assure the protection and propagation of a
balanced, indigenous population of shellfish, fish, and wildlife in and on the receiving
body of water. Based on such demonstration, the Administrator (or, if appropriate,
the State) may impose an alternate limitation (316a).
Any standard established pursuant to the requirements of the Act shall require
that the location, design, construction, and capacity of cooling water intake
structures reflect the best technology available for minimizing adverse
environmental impacts (316b).
Notwithstanding any other provisions of the Act, any point source modified
after the' enactment of the Act (FWPCA) to meet required thermal effluent
limitations shall not be subject to more stringent thermal limitations during a 10-
year period from date of modification or during the period of depreciation of the
facility, whichever comes first.
EPA is in the process of defining industry specific and compound specific
effluent limitations for the 129 "priority" pollutants. Table D-22 lists these
pollutants.
D-39
-------
TMLI >22. LIST 0T 129 SKCX7IC VOUOtMRS COWOCJHO NM8
1. •iCWlftpiltlUM
2. Mcrolain
3. •acrylonitrila
4. *bniau
i. •banxldina
6. 'carboa tatrachlorlda (tatxa-
chlocBachaM)
•Chlorinatad baaxanaa (othar thaa
dichlorobanxanaa) i
7. chlorotoanxana
3. 1,2,4-erlchlorobaniana
9. haxacblorobaiuana
*Gilorinaead athanaa (including
I,2-diehlarathana, 1,1,1-tri-
ctiloroaciiana and huaehloraathaaa)
10. 1,2-dlchlezeathana
11. 1,1,1-trlchloroathaoa
12. haxacMosoacJiana
12. 1,1-dichloroatliana
14. l<](]-tcleU«n«hui
13. 1,1,2,2-fcaezachloroachana
1<. ehloroathana
•ChloroaDcyl athaxi (chloroaachyl,
chloroathyl and alxad athara)i
X7. bla (ehlaro—thy!) aehar
II. bia (2-ehloxoathyl) athar
19. 2-ehlcroathyl vinyl tathar
(alxadl
*CUerlnaead oaphthalaaaa i
20. 2-ehloroaaphehalana
¦Oilorlnatad pfaanola (ochar Chan
eheaa llacad alaawharai includa#
trlehlorephanola and ehlwiuttd
eraaola)t
21. 2,4. t-txlctilorophanol
22. peraehloeeawti craaol
23. *ehlace. *athylbanaaae
19. 'tlnoranthawa
•Haloaehara (othar thaa thoaa liatad
alaavhara)
40. 4-chlosophaayl pbanyl athac
41. 4 tretnihanyl pbanyl athar
42. bla (2-chloroaopropyl) athar
43. bla (2-etaloroathoay) nachan*
•Haloaaehaaaa (othar than thoaa
liatad alaawhara)
44.
¦athylaaa ehlorlda (dlchloro-
¦aaliaaa k
45.
¦NMMf
Mchy 1 ehlaclda (ehlareaatKaaa)
44.
aaehyl braaida (brwnaathina)
47.
braanfoa (trlbroaoaathana)
4S.
dlCUoCOkfOHMthlM
49.
er±ehlereflae*eae«haae
50.
dieUorodifluaxoaachana
51.
52.
•haxacnlorobutadlaea
53.
*hasaeliloney«lapaacadtaea
54.
•ljaphorena
5S.
•Baphttwlaa*
SC.
•altzebeasaee
•NitropbaaeU (including 2,4-diaitro-
ptiaaol aad dinitrocraaol) >
57. 2-aitzephaaol
!». 4-altiophanol
59. •2,4-dlaltrpphanal
CO. 4,*>41altro-o-erMol
»l. S-eitroaodleatiiyLaeiee
•2. S-nitxoaodiphaaylaaiaa
•3. »-«itxaaodl -g-mnrlMlw
44. *pan each iorop bano 1
45. *phanol
¦Vhthalaea aatarii
M. bia (2-attaylhwyl) phtftalaca
•7. butyl baasyl phthalata
M. dl-n-bueyl phthalata
6). di-n-octyl phthalata
70. diathyl phthalata
71. dlaathyl phthalata
•tolynuciaar aroaatle hydrocarbon* i
72. ban*o (a) aathracMa (1,2-banxaa-
ehsacaaa)
73. banso (a) pyrana (3,4-baasepyraoa)
74. 3,4-baniofluora&thana
75. banse (k) fluoranthana (11.12-baaao-
fluoranehaaa)
76. etiryaaaa
77. acanaphehylana
7S. anthxaeana
79. banso (flhil parylana (1.2-banzo-
parylaaa)
•0. fluoraaa
81. phanathraita,
•2. dlbann (a-h) anthraeaaa <1,2.5,
6-dUeasathraceeel
•3. lodaao
phanylanapyrana)
•4. pyrana
•S. tatraeUomthrlaM
H. *toluaaa
•7. •trlchloroaehylaaa
M. *rlj»yl chlerida (chloroathylaoa)
PaaClddat and Natabolieaai
M. 'aldria
90. Mlaldria
91. •chlordana (technical aixtura t
aaeaboUtaa)
•00T aad Mtabolieaa
921. 4,4*-SOT
91. 4i4'»D0C Ip-p'-OOX)
94. 4,4,-00C [p.p'-TOl)
~andaamlftn aad antabelltaa
95. » andnaul fan-Alpha
94. h an*»«
-------
TABLE D-22. (continued)
98. endrin
99. endrin aldehyde
•haptachlor and metabolite*>
100. heptachlor
101. heptachlor epoxide
•hexachlorocyclohexane (all isooari)
102. a-BHC-Alpha
103. b-BHC-Beca
104. r-BHC (lindane)-Gamma
105. g-BHC-Delt*
•polychlorinated biphenylj (PCB's):
106. PCB-1242 (Arochlor 1242)
107. PCB-1254 (Arochlor 1254)
108. FCB-1221 (Arochlor 1221)
109. PCB-1232 (Arochlor 1232)
110. PCB-1248 (Arochlor 1248)
111. PCB-1260 (Arochlor 1260)
113. *Toxaphene
114. 'Antimony (Total)
115. 'Arianic (Total)
116. 'Asbestos (Fibrous)
117. 'Beryllium (Total)
118. 'Cadmium (Total)
119. 'Chromium (Total)
120. 'Copper (Total)
121. 'Cyanids (Total)
122. 'Lead (Total)
123. •Mercury (Total)
124. •Nickel (Total)
125. *Seleniun (Total)
126. *Silver (Total)
127. •Thallium (Total)
128. *Zinc (Total)
129. •*2,3,7,B-tetrachlorodibenzo-p-dioxin (TCDO)
D-41
-------
P. Mills
APPENDIX E
QUALITY ASSURANCE BIBLIOGRAPHY
Adams, 3. W., T. E. Doerfler, and C. H. Summers. 1978. Effect, of Handling
Procedures on Sample Quality. EPA-600/7-78-017, U.S. Environmental
Protection Agency, Research Triangle Park, N.C. 50 pp.
Barnett, P. R., and E. C. Mallory, Jr. 1971. Determination of Minor Elements in
Water by Emission Spectroscopy. In: Techniques of Water-Resources
Investigations of the United States Geological Survey, (Book 5, Chapter A2),
U.S. Govt. Printing Office, Washington, D.C. 31 pp.
Bellar, T. A., and J. 3. Lichtenberg. 1974. The Determination of Volatile Organic
Compounds at the mg/1 Level in Water by Gas Chromatography. EPA-670/4-
74-009, U.S. Environmental Protection Agency, Cincinnati, Ohio. 28 pp.
Bordner, R. H., 3. A. Winter, and P. Scarpino. 1978. Microbiological Methods for
Monitoring the Environment: Water and Wastes. EPA-600/8-78-017, U.S.
Environmental Protection Agency, Cincinnati, Ohio. 354 pp.
Buchanan, 3. W., and D. E. Wagoner. 1975a. Guidelines for Development of a
Quality Assurance Program: Volume V - Determination of Sulfur Dioxide
Emissions from Stationary Sources. EPA-650/4-74-005-e, U.S. Environmental
Protection Agency, Washington, D.C. 102 pp.
Buchanan, 3. W., and D. E. Wagoner. 1975b. Guidelines for Development of a
Quality Assurance Program: Volume VI - Determination of Nitrogen Oxide
Emissions from Stationary Sources. EPA-650/4-74-005-f, U.S. Environmental
Protection Agency, Washington, D.C. 107 pp.
Buchanan, 3. 1976a. Development and Trial Field Application of a Quality
Assurance Program for Demonstration Projects. EPA-600/2-76-083, U.S.
Environmental Protection Agency, Research Triangle Park, N.C. 84 pp.
Buchanan, 3. W., and D. E. Wagoner. 1976b. Guidelines for Development of a
Quality Assurance Program: Volume VII - Determination of Sulfuric Acid Mist
and Sulfur Dioxide Emissions from Stationary Sources. EPA-650/4-74-005-g,
U.S. Environmental Protection Agency, Washington, D.C. 118 pp.
Buchanan, 3. 1976. Guidelines for Demonstration Project Quality Assurance
Programs. EPA-600/2-76-081, U.S. Environmental Protection Agency,
Research Triangle Park, N.C. 52 pp.
E-l
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Budde, W. L. and 3. W. Eichelberger. 1979. An EPA Manual for Organics Analysis
Using Gas Chromatography-Mass Spectrometry, EPA-600/8-79-006, U.S.
Environmental Protection Agency, Cincinnati, Ohio. 164 pp.
Eichelberger, 3. W., W. M. Middleton, and W. L. Budde. 1975. Analytical Quality
Assurance for Trace Organics Analysis by Gas Chromatography/Mass
Spectrometry. EPA-600/4-75-G07, U.S. Environmental Protection Agency,
Cincinnati, Ohio. 13 pp.
Environmental Monitoring and Support Laboratory of U.S. Environmental Protection
Agency. 1979. Handbook for Analytical Quality Control in Water and
Wastewater Laboratories. EPA-600/4-79-019, U.S. Environmental Protection
Agency, Cincinnati, Ohio. 164 pp.
Everett, L. G., K. D. Schmidt, R. M. Tinlin, and D. K. Todd. 1976. Monitoring
Groundwater Quality: Methods and Costs. EPA-600/4-76-023, U.S.
Environmental Protection Agency, Cincinnati, Ohio. 141 pp.
Goerlitz, D. F., and E. Brown. 1972. Methods for Analysis of Organic Substances in
Water. In: Techniques of Water-Resources Investigations of the United States
Geological Survey, (Book 5, Chapter A3), U.S. Govt. Printing Office,
Washington, D.C. 40 pp.
Guy, H. P., and V. W. Norman. 1970. Field Methods for Measurement of Fluvial
Sediment. In: Techniques of Water-Resources Investigations of the United
States Geological Survey, (Book 3, Chapter C2), U.S. Govt. Printing Office,
Washington, D.C. 59 pp.
Hampton, N. F. 1976. Monitoring Ground Water Quality: Data Management'
EPA-600/4-76-019, U.S. Environmental Protection Agency, Las Vegas,
Nevada. 63 pp.
Health Effects Research Lab. 197S. Directory of Short Term Tests for Health and
Ecological Effects. EPA-600/1-78-052, U.S. Environmental Protection
Agency, Research Triangle Park, N.C. 218 pp.
Huibregtse, K. R., and 3. H. Moser. 1976. Handbook for Sampling and Sample
Preservation of Water and Wastewater. EPA-600/4-76-049, U.S.
Environmental Agency, Cincinnati, Ohio. 258 pp.
Kopp, 3. F., and G. D. McKee. 1979. Manual-Methods for Chemical Analysis of
Water and Wastes, 1978. EPA-600/4-79-020, U.S. Environmental Protection
Agency, Cincinnati, Ohio. 460 pp.
National Bureau of Standards. 1978. Standard Reference Materials: Guide to U.S.
Reference Materials. NBS Special Publication 260-57, U.S. Department of
Commerce, Washington, D.C. 47 pp.
National Bureau of Standards. 1979. NBS Standard Reference Materials Catalogue
1979-80 Edition. NBS Special Publication 260, U.S. Department of Commerce,
Washington, D.C. 102 pp.
-------
PEDCo Environmental, Inc. 1978. Handbook - Industrial Guide for Air Pollution
Control. EPA-625/6-78-004, U.S. Environmental Protection Agency,
Washington, D.C.
Quality Assurance Branch of the Environmental Monitoring and Support Laboratory
and PEDCo-Environmental Specialists, Inc. 1976. Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume 1 - Principles.
EPA-600/9-76-005, U.S. Environmental Protection Agency, Research Triangle
Park, N.C. 180 pp.
Quality Assurance Branch of the Environmental Monitoring and Support Laboratory
and PEDCo-Environmental Specialists, Inc. 1977. Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume II - Ambient Air
Specific Methods. EPA-600/4-77-027a, U.S. Environmental Protection
Agency, Research Triangle Park, N.C. 316 pp.
Quality Assurance Branch of the Environmental Monitoring and Support Laboratory
and PEDCo-Environmental Specialists, Inc. 1977. Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume III - Stationary
Source Specific Methods. EPA-600/4-77-024b, U.S. Environmental Protection
Agency, Research Triangle Park, N.C. 404 pp.
Shelley, P. E. 1977. Sampling of Water and Wastewater. EPA-600/4-77-039, U.S.
Environmental Protection Agency, Cincinnati, Ohio. 311 pp.
Smith, F., and A. C. Nelson, Jr. 1973. Guidelines for Development of a Quality
Assurance Program: Measuring Pollutants for Which National Ambient Air
Quality Standards Have Been Promulgated. EPA-R4-73-028-e, U.S.
Environmental Protection Agency, Washington, D.C. 163 pp.
Smith, F., and D. E. Wagoner. 1974a. Guidelines for Development of a Quality
Assurance Program: Volume 11 - Gas Analysis for Carbon Dioxide, Excess Air,
and Dry Molecular Weight. EPA-650/4-74-005-b, U.S. Environmental
Protection Agency, Washington, D.C. 60 pp.
Smith, F., and D. E. Wagoner. 1974b. Guidelines for Development of a Quality
Assurance Program: Volume IV - Determination of Particulate Emissions from
Stationary Sources. EPA-650/4-74-005-d, U.S. Environmental Agency,
Washington, D.C. 185 pp.
Smith, F., D. E. Wagoner, and A. C. Nelson, Jr. 1974. Guidelines for Development
of a Quality Assurance Program: Volume in - Determination of Moisture in
Stack Gases. EPA-650/4-74-005c, U.S. Environmental Protection Agency,
Washington, D.C. 66 pp.
Smith, F., D. E. Wagoner, R. P. Donovan. 1975. Guidelines for Development of a
Quality Assurance Program: Volume VIII - Determination of CO Emissions
from Stationary Sources by NDIR Spectrometry. EPA-650/4-74-005h, U.S.
Environmental Protection Agency, Washington, D.C. 96 pp.
E-3
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Smith, F., and 3. Buchanan. 1976. IERL-ITP Data Quality Manual. EPA-600/2-76-
159, U.S. Environmental Protection Agency, Research Triangle Park, N.C.
89 pp.
Stevens, H. H. Jr., J. F. Ficke, and G. F. Smoot. 1975. Water Temperature -
Influential Factors, Field Measurement, and Data Presentation. In:
Techniques of Water Resources Investigations of the United States Geological
Survey, (Book 1, Chapter Dl), U.S. Govt. Printing Office, Washington, D.C.
65 pp.
Tinlin, R. M. (ed). 1976. Monitoring Groundwater Quality: Illustrative Examples.
EPA-600/4-76-036, U.S. Environmental Protection Agency, Las Vegas, Nevada.
82 pp.
Todd, D. K., R. M. Tinlin, K. D. Schmidt, and L. G. Everett. 1976. Monitoring
Groundwater Quality: Monitoring Methodology. EPA-600/4-76-026, U.S.
Environmental Protection Agency, Las Vegas, Nevada. 155 pp.
Wohlschlegel, P. S., F. Smith, and D. E. Wagoner. 1976. Guidelines for
Development of a Quality Assurance Program: Volume XI - Determination of
Beryllium Emissions from Stationary Sources. EPA-650/4-7M)05k, U.S.
Environmental Protection Agency, Research Triangle Park, N.C. 157 pp.
Wohlschlegel, P. 1976. Guidelines for Development of a Quality Assurance
Program: Volume XV - Determination of Sulfur Dioxide Emissions from
Stationary Sources by Continuous Monitors. EPA-650/4-7^-005-o, U.S.
Environmental Protection Agency, Washington, D.C. 123 pp.
E-4
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Prepared by The Pace Company Consultants & Engineers, Inc.,
a Division of Jacobs Engineering Group Inc.
APPENDIX F
FEDERAL AND STATE PERMITS REQUIRED FOR OPERATION
OF AN OIL SHALE FACILITY
Operation of an oil shale facility requires the filing of dozens of permits from
Federal, State, and local government agencies. Because of varied and overlapping
regulations and statutes, it is often difficult to know which agencies to contact and
what permits are required.
This appendix was designed to be used as a guide for prospective oil shale
operators and government officials who may not be aware of the requirements and
their respective governing agencies. This appendix provides information on the
major permit and approval requirements from Federal agencies, the States of
Colorado, Utah, and Wyoming, and appropriate local agencies. A basis for this
section was provided by lists of permits and approvals applied for by oil shale Tracts
U-a and U-b, C-a and C-b, the Colony Development Operation, and through
discussions with Federal and State personnel in charge of permit applications.
Though this appendix may not be entirely complete, it is a base from which to
start when filing all needed requirements. A complete permit program can only be
accomplished when all details of an individual operation are known. Each operation
varies in its requirements, and operators must work closely with government
agencies throughout all phases of operation.
Before construction of any operation, it is recommended that the operator
contact the following lead agencies for further information:
Colorado: Executive Director
Department of Natural Resources
1313 Sherman Street
Denver, Colorado 80203
(303) 839-3311
Executive Director
Colorado Department of Health
Air Pollution Control Division
^210 E. 11th Avenue
Denver, Colorado 80220
(303) 320-8333
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Wyoming:
Utah:
Federal:
Garfield County, Colorado:
Department Director
Department of Environmental Quality
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7391
Executive Director
Department of Natural Resources
438 State Capitol
Salt Lake City, Utah 84114
(801) 533-5356
Regional Administrator
U.S. Environmental Protection Agency
Region VIII
1860 Lincoln Street
Denver, Colorado 80203
U. 5. Department of Energy
Regional Office
1075 South Yukon Street
P. O. Box 26247
Belmar Branch
Lakewood, Colorado 80226
(303) 234-2420
Ray Baldwin, Planning Director
GCP Department
2014 Blake Street
Glenwood Springs, Colorado 81601
(303) 945-8212
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Rio Blanco County, Colorado: Glen Payne, County Planner
RBCP Department
P. O. Box 599
Meeker, Colorado 81641
(303) 878-5081
Uintah County, Utah: Jess Miller, Administrator
Uintah County, Planning and Zoning Board
220 South 500 East
Vernal, Utah 84078
(801) 789-4382
Sweetwater County, Wyoming: Dennis Watt, Planning Director
Sweetwater County Planning Department
P. O. Box 791
Green River, Wyoming 82935
(307) 875-2611, ext. 270
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
OccuDational Safetv and Health Regulations
LEGAL CITATION
79 (TP 1900-1999
RESPONSIBLE AGENCY/CONTACT
U.S. Department of Labor (303) 837-3883
Occupational Safety and Health
Administration
Region VIII Office
1961 Stout Street, Room 15010
Denver, Colorado 80202
ABSTRACT |jhe Occupational Safety and Health Administration (OSHA) was estab-
lished in 1970 by PL 91-596; 29 USC 651-678 (the Williams-Steiger OS&H Act). This
Act affects all companies except self-employed perons. Small businesses (fewer than
10 employees) do not have to keep records but are still affected by the regulations.
These standards do not apply to conditions subject to other Federal regulations,
although this does not exempt production on Federal Leases administered by USGS.
OSHA encourages States to assume responsibility for administration of
OS&H programs. The Federal law permits any State to assert jurisdiciton, under State
law, over any occupational or health standard not covered by a Federal standard. Any
State may also assume responsibility for development and enforcement of its own
standards for those areas now covered by Federal standards. Colorado, Utah, and
Wyoming have State standards approved by OSHA, and therefore, the State offices must
be contacted. The Region VIII office can tell you whom to contact for specific State
requirements.
SCHEDULING MILESTONES
Depends on regulations requirements.
PERMIT APPLICATION LEAD TIME
rVnPnds on rpniiirf»ments
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Environmental ImDact Statement (EIS)
Federal
LEGAL CITATION
P.L. 91-190, 43 U.S.C. 4321 et seq. (NEPA), 83 Stat. 852-856.
RESPONSIBLE AGENCY/CONTACT
U.S. EPA, Region VIII (303) 837-4831
Mr. 3. William Geise, Chief
Environmental Evaluation Board
1860 Lincoln Street
Denver, Colorado 80295
U.S. Environmental Protection Agency
Mr. Peter Cook, Director (202) 755-0790
Office of Federal Activities
Room 537 West Tower
407 M Street, SW
Washington, D.C. 20460
ABSTRACT
The National Environmental Policy Act (NEPA) directs all Federal
agencies to identify and develop methods and procedures that will ensure
that presently unquantified environmental amenities and values are given appropriate
consideration in decisionmaking along with economic and technical considerations. The
act directs that all agencies prepare a detailed statement on all actions significantly
affecting the quality of the human environment. The statement is required to include:
• The environmental impact of the proposed action,
• Any adverse environmental effects that cannot be avoided should the proposal
be implemented.
• Alternatives to the proposed action,
• The relationship between local short-term uses of man's environment and
the maintenance and enhancement of long-term productivity, and
• Any irreversible and irretrievable commitments of resources that would be
involved in the proposed action should it be implemented.
The act originally established that the President report to Congress
annually concerning the environmental quality of the Nation, it also established the
Council on Environmental Quality (CEQ), which was deemed responsible for the review
of environmental impact statements. In 1977, under President Carter's government
reorganization, the CEQ staff of 40 was virtually eliminated. EIS review responsi-
bilities are now handled by EPA, and the remaining CEQ personnel are acting in an
advisory fashion on environmental policies.
A draft statement is prepared under guidlines
set forth in P.L. 91-190 Section 102(2)(C).
Comments will be incorporated into a final statement. The agencies who will review
the EIS depend on its nature. Scheduling depends on the complexity of the statement.
Timing will vary from 6 months to 2 or more years.
SCHEDULING MILESTONES
PERMIT APPLICATION LEAD TIME
2 to 3 years.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Resource Recovery and Conservation—definition and control
Federal
LEGAL CITATION
Resource Recovery and Conservation Act of 1976. P.L. 94-580 k2 U.S.C.
3251 et. sea. as amended.
RESPONSIBLE AGENCY/CONTACT
U.S. Environmental Protection Agency
Mr. Hank Schroeder - (303) 837-2221
Waste Management Branch
Region VIII
1860 Lincoln Street, Suite 900
Denver, Colorado 80203
ABSTRACT „ .. .
The overall objectives are to promote the protection of health and the
environment and to conserve material and energy resources by establishing a co-
operative effort toward improving solid waste management among Federal, State, and
local governments and private enterprise. The protection of health and the environ-
mental includes runoff, protection of air quality, disease and vector control, safety, and
esthetics associated with land disposal sites.
Provisions in the act call for integration with, but not duplication of, the
requirements set forth by provisions of the Clean Air Act, the Federal Water Pollution
Control Act, the Federal Insecticide, Fungicide and Rodenticide Act, the Hazardous
Materials Transportation Act, and other acts as grant regulatory authority to the EPA
Administrator.
Final RCRA regulations appeared in the Federal Register on February 26 and May
19, 1980. Spent shale previously suspected of being labled "hazardous", is now classified
as a "solid" waste due to a ten-fold increase in leachate toxicity levels. Thus, spent
shale is now not applicable to RCRA regulations. In the future, after more research is
conducted, the RCRA mutagenicity test may affect oil shale.
SCHEDULING MILESTONES
Regulations pertaining to RCRA permit requirements are contained in the Consoli-
dated Permit regulations published in the May 19, 1980, Federal Register.
PERMIT APPLICATION LEAD TIME
None at this time.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Toxic Substances—definition and control
Federal
LEGAL CITATION Tnvir Snhstanrp'; rnntrnl Art fP.T
(90 Stat. 2003; 15 U.S.C. 2601 et. seq.)
RESPONSIBLE AGENCY/CONTACT
Mr. Lou Johnson
Toxic Substances Branch
Environmental Protection Agency
1860 Lincoln Street
Denver, Colorado 80203
(303)837-3926
Mr. John B. Ritch Jr.
Director, Office of Industry Assistance
Office of Toxic Substances TS-788
Environmental Protection Agency
401 M. Street S.W.
Washington, D.C. 20460
(202) 755-0535
ABSTRACT ^ct reqUires that the EPA compile a list that includes each chemical
substance that was manufactured or processed in the United States in quantities greater
than 100,000 lbs in 1977, and that is being sold in commerce.
If the chemical is not being sold in commerce by the producer, it is classified as an
R&D substance and does not need to be listed. If a company now under the R&D
criterion begins to market the chemical, it would then come under the pre-manufactu-
ring criterion. Manufacturers of new chemical substances must give EPA 90 days notice
before manufacture of the substance. Any substance not listed on EPA's inventory of
existing chemicals is considered "new" for purposes of the premarket notice requirement.
An initial inventory listing over 44,000 commercially produced chemical substances
was published in the May 15, 1979 Federal Register. Ten synthetic fuels were identified
on this list, including shale oil. Being on the list does not "protect" a product from
possible control requirements.
EPA may prohibit or limit the manufacturing, processing, distribution, or use in
commerce of any substance that EPA finds to present risk of injury to health or the
environment. Manufacturers are required to keep records of the processes used and to
conduct tests to assure compliance with regulations. EPA can, if necessary, go to
Federal district court and seek an injunction to block production of a chemical until test
results are completed. Civil penalties are possible for violations.
SCHEDULING MILESTONES
Not applicable
PERMIT APPLICATION LEAD TIME
Not applicable
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
National Pollutant Discharge Elimination Systems (NPDES)
Federal—
LEGAL CITATION
The Federal Water Pollution Control Act (P.L. 95-217), Section 402
RESPONSIBLE AGENCY/CONTACT
Mr. Bob Burm
Consolidated Permits
Environmental Protection Agency
1860 Lincoln Street, Suite 900
Denver, Colorado 80295
(303) 837-4901
An NPDES permit must be obtained under requirements of Section 402 of
the Act if water is discharged to a navigable stream. Specific New Source Performance
Standards (NSPS) have not yet been promulgated for the oil shale industry. However, in
their absence NPDES effluent limits are established on a best engineering basis. NSPS
for the oil shale industry are scheduled to be promulgated 30 months after completion of
all EPA guidance documents on the industry. Currently this is scheduled for April 1981,
putting promulgation of the NSPS in 1983-1984. It should also be noted that through
litigation, the definition of an NPDES permit has been changed from an operations
permit to a construction permit in the case of a new source.
In situations where a permit is issued prior to the publication of the effluent
guidelines, such as in oil shale, there is considerable flexibility in the determination of
the precise effluent limitations which will be mandated by the permit. At the present
time, petroleum refining industry guidelines give an indication of potential oil shale
guidelines. Even after promulgation guidelines, the applicant may seek modification of
limits in the permit by means of a variance clause. A careful engineering analysis of
proposed permit limits is definitely required.
Procedural requirements for the NPDES permit program and parts of the EPA toxic
pollutant strategy are implemented under the Consolidated Permit regulations.
SCHEDULING MILESTONES
Applications for proposed new discharges must apply
at least 180 days before the date the discharge is due to begin, unless a delay is granted
by the approved State agency or by EPA. Permits may be issued for up to a five-year
period. Reapplication and existing permits are covered under 40 CFR 122.53.
PERMIT APPLICATION LEAD TIME
180 days.
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OIL SHALE PERMIT
PERMIT TITLE
Prevention of Significant Air Quality Deterioration
JURISDICTION
LEGAL CITATION
The Clean Air Act Amendments of 1977 (Pub. L. 95-95) CFR Title 40, Part 51.24.
RESPONSIBLE AGENCY/CONTACT
EPA Region VIII
Mr. 3ohn Dale, Director
Air and Hazardous Materials Division
1860 Lincoln Street, Suite 900
Denver, Colorado 80295
(303) 837-3763
b lOn December 5, 1974, EPA published regulations under the 1970 version
of the Clean Air Act (Pb. L. 91-604) for the prevention of significant air quality
deterioration (PSD). These regulations, codified at 40 CFR 52.51, established a program
for protecting areas with air quality cleaner than the national ambient air quality
standards (NAAQS). Congress sanctified and modified the PSD concept in P.L. 95-95.
Under EPA's regulatory program, clean areas of the Nation are designated under
any of three classes. Specified numerical increments of air pollution are permitted
under each class up to a level considered to be significant for that area. Class I
increments permit only minor air quality deterioration; class II increments, moderate
deterioration; and class III increments, deterioration up to 50% of the secondary NAAQS.
In general, national parks, wilderness areas, memorial parks, and international parks are
aermanentiy designated as Class I areas, and all other clean air areas are designated
Class II. Provisions are included for redesignating an area to a higher or lower
classification. All sources subject to PSD review must employ Best Available Control
Technology (BACT) of controlled air pollutant emissions greater than 100 tons per year.
Topics of concern to States choosing to develop their own PSD programs are
discussed in the rulemaking found in PSD program 40 CFR 52.51. Thus the two rules, 40
CFR 52, and 40 CFR 51, should be read together to determine whether an EPA permit is
required in addition to the State permit.
SCHEDULING MILESTONES
At present, air quality monitoring guidelines do not exist for oil shale. EPA Region VIII
is currently granting oil shale PSD permits on a case-by-case basis. Also, PSD permits
ire now subject to the Consolidated Permit Regulations.
PERMIT APPLICATION LEAD TIME |
One year maximum (average is 6 months).
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OIL SHALE PERMIT
PERMIT TITLE
Spill Prevention Control and Countermeasure (SPCC)
JURISDICTION
LEGAL CITATION
Reference: See Federal Register Tuesday, December 11, 1973,
Vol. 38, No. 237
RESPONSIBLE AGENCY/CONTACT
U.S. Environmental Protection Agency
Region VIII
Emergency Planning and Response Branch
1860 Lincoln 5treet
Denver, Colorado 80203
(303) 837-2468
ABSTRACT |The two important sections under this requirement pertain to applicability
(Sec. 102.1) and to guidelines for development of the plan (Sec. 112.7).
The requirement applies to oil storage or production (extraction) in
excess of 660 gal. that has the potential of spillage into surface waterways. If there
is no waterway in the area that may be affected, then a plan is not necessary.
Generally, the guidelines for such a plan include: (1) discussion of previous
spills and their means of correction, (2) probable spills, including what quantity and
type of oil may be lost and where it may flow, (3) and what specific steps to be taken
for secondary containment. The plan is usually implemented by construction of dams,
dikes, or other diversion measures.
Other requirements include: (1) commitment of management approval that converson
facilities will be constructed, and (2) certification of plans by a registered professional
engineer.
The plan is kept on file at the facility office where the oil is stored. A copy does
not go to EPA. Review of the plan will be made during onsite inspection of the facility
if and when a failure (spill) occurs.
SCHEDULING MILESTONES
Preparation of plans only.
PERMIT APPLICATION LEAD TIME
None.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Underground Injection Control—definition and control
Federal
LEGAL CITATION
Safe Water Drinking Act, 42 U.S.C. Section 300f et. seq.
RESPONSIBLE AGENCY/CONTACT
U.S. Environmental Protection Agency
Mr. Paul Osborne
Region VIII
1860 Lincoln Street
Denver, Colorado 80203
(303) 837-2731
ABSTRACT
Under the UIC Program, states will be given authority for enforcement
under a state approval plan 40 CFR Part 123.7. State programs must be submitted to the
EPA within 270 days after promulgation of the final Consolidated Permit regulations.
The program is divided into five classes of wells. Class III wells include in situ/oil
shale operations. All wells existing before the rules are finalized must be repermitted
within five years of the final program (40 CFR Part 122.37) New wells must be
permitted under the applicable UIC Program (40 CFR Part 122.36). Permits are required
for both in situ operation and for mine dewatering re injection. The State of Colorado
also requires reinjection permits under existing regulations.
Monitoring (40 CFR 146.34) and mitigation measures (40 CFR 122.42) to prevent
the endangerment of the groundwater system are requirements under these regulations.
Monitoring requirements will include: testing of physical and chemical data with
sufficient frequency to yield representative data; installation of continuous recording
devices for injection pressure, flow rate and volume; demonstration of mechanical
integrity at least every five years; weekly monitoring of fluid level and water quality in
the monitoring wells; quarterly monitoring of any water supply wells adjacent to the site;
and maintenance of the required monitoring results for three years.
SCHEDULING MILESTONES
Application for existing injection wells must be submitted no later than 4 years after
approval of UIC program. For new wells, a "reasonable" time before construction begins.
PERMIT APPLICATION LEAD TIME
ong enough, a temporary permit may be granted for 90 days.
For new wells, if permit lead time is not
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OIL SHALE PERMIT
PERMIT TITLE
Consolidated Permit Regulations
JURISDICTION
Federal
LEGAL CITATION
40 CFR Parts 122, 123, 12^, and 125
RESPONSIBLE AGENCY/CONTACT
U.S. Environmental Protection Agency
Mr. Bob Burm, Consolidated Permits
1860 Lincoln Street, Suite 900
Denver, Colorado 80295
(303) 837-4901
ABSTRACT
governing tne
This rule establishes consolidated permit program requirements
u Hazardous Waste Management program under the Resource Conservation
and Recovery Act (RCRA), the Underground Injection Control (UIC) program under the
Safe Drinking Water Act (SDWA), the National Pollutant Discharge Elimination System
(NPDES) program and State Dredge or Fill ("404") programs under the Clean Water Act
(CWA), and the Prevention of Significant Deterioration (PSD) program under the Clean
Air Act, for three primary purposes:
(1) To consolidate program requirements for the RCRA and UIC programs with
those already established for the NPDES program.
(2) To establish requirements for State programs under the RCRA, UIC, and
Section 404 programs.
(3) To consolidate permit issuance procedures for EPA-issued Prevention of
Significant Deterioration permits under the Clean Air Act with those for the
RCRA, UIC, and NPDES programs.
These regulations shall become effective as follows: All regulations shall become
effective as to UIC permits and programs July 18, 1980, but shall not be implemented
until the effective date of 40 CFR Part 146. All regulations shall become effective as to
RCRA permits and programs November 19, 1980. All other provisions of the regulations
shall become effective July 18, 1980.
SCHEDULING MILESTONES
See individual permit discussions.
PERMIT APPLICATION LEAD TIME
See individual permit discussions.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Dredge and Fill Permit
Federal
LEGAL CITATION
Section 404 of P.L. 92-500, 33 CFR Sections 322.4 and 323.4.
RESPONSIBLE AGENCY/CONTACT
U.S. Army District—Sacramento
Operations Division
404 Permit Section
650 Capitol Mall
Sacramento, California 95814
(916) 440-2232
ABSTRACT
Section 404 of the Clean Water Act authorizes the Corps of Engineers to
issue permits for the discharge of dredged or fill material into the navigable waters at
specified disposal sites. Although this most obviously applies to the disposal of spoil
from dredging navigation channels, the authority also extends to every situation where a
pile is driven or any other structure installed in the navigable waters. Statutory
responsibility for the total program is divided between the Corps and EPA. Sections
404(b) and (c) of the Clean Water Act empower EPA to issue criteria for the selection of
environmentally acceptable disposal sites and to prohibit the selection of any individual
area if it is environmentally not acceptable.
Specific activities are exempt from permit requirements, including normal agri-
cultural, silvicultural and ranching operations, maintenance of dams and levees, and
construction or maintenance of farm ponds and forestry roads. With respect to permits
for industrial projects, however, the Corps of Engineers clearly plays the dominant role.
Permits may be individual permits authorizing a single specified discharge, or
general permits authorizing specified types of discharges in a specified waterway for
group of waterways. Nationwide permits have been issued for discharges of dredged or
fill material into certain smaller or minor waters of the United States and for certain
types of activities in all waters of the United States.
SCHEDULING MILESTONES
Allow 90 days minimum barring public objections. Public notice and public hearings are
required if there are objections. A complicated permit could take a year or more for
PERMIT APPLICATION LEAD TIME
90 days.
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OIL SHALE PERMIT
PERMIT TITLE
Major Fuel Burning Installation Approval
JURISDICTION
Federal
LEGAL CITATION
10 CFR 303-309
RESPONSIBLE AGENCY/CONTACT
U.S. Department of Energy
Economic Regulatory Agency Region VIII
1075 South Yukon Street
Lakewood, Colorado 80226
(303)234-2^20
ABSTRACT
A major fuel-burning installation (MFBI) is defined in 303.2 to include any
boiler, burner, or other combustion or any combination of the above at a single site that
burns fossil fuels. It does not include power plants, which are units that sell electricity.
The regulations apply to any person owning, leasing; operating or controlling an MFBI.
Any MFBI that will be firing at a rate of 100 million Btu/hr or greater must file FEA
Form C-607-S-O (MFBI-Early Planning Process Identification Report). This includes an
MFBI that has two or more units with 50 million Btu/hr at the same location.
SCHEDULING MILESTONES | Schedules A1 and A2 under form FEA-C-607-S-Q arp
required to be filed on or before the 15th day of the month following the month that a
preliminary study for the MFBI is completed. If there is no preliminary study, the form
must be filed following the earliest of: (1) the formation of a contract for design of an
MFBI, (2) the decision to initiate design work, or (3) the approval of construction funds.
PERMIT APPLICATION LEAD TIME
90 days.
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OIL SHALE PERMIT
PERMIT TITLE
Rights of Way Across Public Lands
JURISDICTION
Federal
LEGAL CITATION
30 USC 18(5 and 43 USC 1761-1771; See also 43 CFR 2800
RESPONSIBLE AGENCY/CONTACT
U.S. Dept. of Interior
U.S. Bureau of Land Management
Colorado State Office
1600 Broadway, Room 700
Denver, Colorado 80202
(303)837-4481
ABSTRACT
The Secretary, with respect to the public lands, and the Secretary of
Agriculture, with respect to lands within the Naitonal Forest System (except in each
case of land designated as wilderness), are authorized to grant, issue, or renew rights-
of-way over, upon, under, or through such lands for—
(1) reservoirs, canals, pipelines, and other facilities and systems for the
impoundment, storage, transportation, or distribution of water;
(2) pipelines and other systems for the transportation or distribution of liquids
and gases other than water and other than oil, natural gas, synthetic liquid or gaseous
fuels, or any refined product produced therefrom, and for storage of such materials in
connection therewith;
(3) pipelines, slurry and emulsion systems, and conveyor belts for transportation
and distribution of solid materials, and facilities for the storage of such materials in
connection therewith;
(4) systems for generation, transmissions, and distribution of electric energy,
except that the applicant shall also comply with all applicable requirements of the
Federal Power Commission under the Federal Power Act of 1935 (49 Stat. 847; 16
U.S.C. 791);
(5) systems for transmission or reception of radio, television, telephone,
telegraph, and other electronic signals, and other means of communication;
(6) roads, trails, highways, railroads, canals, tunnels, tramways, airways, live-
stock driveways, or other means of transportation, except where such facilities are
constructed and maintained in connection with commercial recreation facilities on
lands in the National Forest System; or
(7) such other necessary transportation or other systems or facilities that are
in the public interest and that require rights-of-way over, upon, under, or through
SCHEDULING MILESTONES
(cont)
PERMIT APPLICATION LEAD TIME
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Rights of Way Across Public Lands (cont)
LEGAL CITATION
RESPONSIBLE AGENCY/CONTACT
ABSTRACT
such lands.
Any temporary use of public lands that is related to a right of way, such as
construction of a temporary road, is authorized through issuance of a Temporary Use
Permit. Forms and Procedures are available in most BLM Offices.
A right-of-way application consists of four elements:
1) A written request, general in nature, describing the type of right-of-
way sought, its proposed location (township, range, etc.), and dimensions.
No specific format is required, (see 43 CFR 2802. 1-1)
2) Evidence of applicants qualifications (see 43 CFR 2802. l-4(a)).
3) Survey maps as required by 43 CFR 2802.1-5 (a).
4) Right-of-way fees as designated in 43 CFR 2802.12.
In addition, special land use permits for activities not mentioned may be applied
for by written application.
SCHEDULING MILESTONES
Scheduling is dependent on complexity of project and should be discussed with the
local BLM district office manager.
PERMIT APPLICATION LEAD TIME 1
Depends on project.
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OIL SHALE PERMIT
PERMIT TITLE!
JURISDICTION
Scientific, Pre-Historic, Historic and Archeological
Federal
LEGAL CITATION
Archeological and Historic Data Conservation Act of 1974
RESPONSIBLE AGENCY/CONTACT
U.S. Dept. of Interior
Bureau of Land Management
Colorado State Office
1600 Broadway
Denver, Colorado 80203
(303) 837-4481
ABSTRACT
The Secretary of Interior must be notified whenever a Federal or Federally
assisted or licensed project could caus$ irreparable harm to areas of significant, pre-
historic, historic, or archeologic value. Before any agency decision concerning an
action, the State historic agency official must identify the properties within the
confines of the impacted area that are included in or eligible for inclusion in the
National Register.
The agency official must consult with the State Historic Preservation Officer in
order to apply the National Register criteria to the evaluation of the proposed study
area. Should disagreement exist after this step has been taken, the Secretary of the
Interior's opinion is conclusive. It is the responsibility of the agency official to seek
this opinion by written request.
SCHEDULING MILESTONES
Dependent of project. A survey will be conducted before disturbing the site. If
impacts cannot be mitigated, the project may be stopped.
PERMIT APPLICATION LEAD TIME
Depends on project.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Sundry Notices and Reports on Wells
Federal
LEGAL CITATION
RESPONSIBLE AGENCY/CONTACT
U.S. Dept. of Interior
Geological Survey
Area Oil Shale Supervisor
131 N. 6th Street, Suite 300
Grand Junction, Colorado 81501
(303)245-6700
ABSTRACT
Every change of work on a well is required to be reported to the Geologica
Survey. These changes include intentions to drill, re-drill, repair a well, abandon well
test water, shoot or acidize, pull or alter a casing. Each change for each well requires
the filing of a separate form. Form asks for Well number, loction, elevation, anc
description of work.
SCHEDULING MILESTONES I
File a report or notice of intention only.
PERMIT APPLICATION LEAD TIME
None.
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Oil Shale Mineral Rights Lease
7ederal
LEGAL CITATION |
30 U.S.C. 181-263; 43 CFR
RESPONSIBLE
AGENCY/CONTACTL
U.S. Dept. of Interior
Area Oil Shale Supervisor
131 N. 6th Street, Suite 300
Grand Junction, Colorado 81501
(303) 245-6700
ABSTRACT
Under the terms and conditions of this lease, the lessee is granted the right to
prospect for, mine, process by retorting or by in situ methods, or otherwise utilize and
dispose of all leased deposits. In addition, the lessee has the right to construct
buildings, structures, roads, powerlines, and additional facilities that may be necessary
or convenient for mining, processing, or preparation of products of the leased deposits
for market, and for the housing and welfare of employees, agents, and contractors. The
lease is for a minimum period of 20 years and may continue as long as production
continues. Terms of the lease are also subject to bonuses, royalties, rentals, and
payments, as detailed in the regulations, all State and local water pollution control,
water quality, air pollution control, and air quality laws, regulations, and Standards.
SCHEDULING MILESTONES
Before any development operations under the lease, the lessee is required to
conduct a 2-year baseline monitoring and data collection program and a detailed
development plan.
PERMIT APPLICATION LEAD TIME
Depends on project.
F-19
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OIL SHALE PERMIT
PERMIT TITLE
Detailed Development Plan
JURISDICTION
Federal
LEGAL CITATION
30 CFR 231, 43 CFR 23, 43 CFR
RESPONSIBLE AGENCY/CONTACT
Peter A. Rutledge
U.S. Dept. of Interior
Geological Survey
Area Oil Shale Supervisor
131 N. 6th Street, Suite 300
Grand Junction, Colorado 81501
(303)24S-fi7nn
ABSTRACT
Under Section 10 of the Oil Shale Lease, the lessee must file with the Mining
Supervisor on or before the third anniversary date a detailed development plan (DDP).
This plan includes: (1) a schedule of the planning, exploratory, development, pro-
duction, processing, and reclamation operations and all other activities to be conducted
under the lease; (2) a detailed description pursuant to 30 CFR 231 and 43 CFR 23 of the
procedures to be followed to assure that the development plan will meet and conform to
the environmental criteria and controls incorporated in the lease; and (3) a requirement
that the lessee use orderly development to attain at the earliest time consistent with
compliance of all provisions of the oil shale lease, production at a rate at least equal to
the rate on which minimum royalty is completed under terms of the lease.
SCHEDULING MILESTONES |
Requires a 2-year baseline monitoring and data collection program.
PERMIT APPLICATION LEAD TIME
Must be filed within 3 years of lease date.
F-20
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OIL SHALE PERMIT
PERMIT TITLE
Collection of Environmental Data and
Monitoring Program
JURISDICTION
Federal
LEGAL CITATION
30 CFR 231, 43 CFR
RESPONSIBLE AGENCY/CONTACT
Peter A. Rutledge
U.S. Dept. of Interior
Geological Survey
Area Oil Shale Supervisor
131 N. 6th Street, Suite 300
Grand Junction, Colorado 81501
(303)245-6700
ABSTRACT
Under the environmental stipulations of the oil shale lease, completion of a 2-year
baseline monitoring and data collection program is required, one year before the
detailed development plan is submitted to the Mining Supervisor. The lessee is required
to compile data to determine the conditions existing before any development operations
under the lease and conduct a monitoring program before, during, and subsequent to
development operations.
SCHEDULING MILESTONES
This 2-year program before release of the detailed development plan requires
monitoring before any operations are permitted.
PERMIT APPLICATION LEAD TIME
2 years.
F-21
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Exploration and Mining Plans
Federal
LEGAL CITATION
30 CFR 231, 43 CFR 23
RESPONSIBLE AGENCY/CONTACT
Peter A. Rug ledge
U.S. Dept. of Interior
Geological Survey
Area Oil Shale Supervisor
131 N. 6th Street, Suite 300
Grand Junction, Colorado 81501
(303) 245-6700
ABSTRACT
Under terms of the oil shale lease, any exploration and/or mining must have must
have approval before any disturbance to the land occurs. The plan is a detailed report
describing every aspect from sampling and drilling to reclamation, including any
baseline monitoring. This is usually prepared in conjunction with the detailed
development plan.
SCHEDULING MILESTONES |
Prepared with detailed development plan.
PERMIT APPLICATION LEAP TIMEl
None.
F-22
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OIL SHALE PERMIT
PERMIT TITLE
Mine Safety and Health-
definition and control
JURISDICTION
Federal
LEGAL CITATION
Federal Mine Safety a
nd Health Amendments Act of 1977 P.L. 95-164
RESPONSIBLE AGENCY/CONTACT T1 c _ . ,T .
U.S. Dept. of Labor
Mine Safety and Health Administration
Region VIII
Denver Federal Center
Lakewood, Colorado 80225
(303)234-4378
ABSTRACT
Each operator of a mine is now required to have a mandatory health and safety
training program approved by the Secretary of Labor. Some of the requirements
include: (1) new miners must have no fewer than 40 hrs of training if they are to work
underground. Training includes use of the self-rescue device and respiratory devices,
procedures, instruction on basic ventilation, basic roof control, electrical hazards, first
aid, etc.; (2) all miners must have at least 8 hrs of refresher courses once each year;
and (3) special training must be provided for miners having no previous experience in a
specific area.
Upon completion of each training program, each operator is to complete a form
stating that the miner has received the training. A certificate for each miner is to be
maintained by the operator and is to be available for inspection at the mine site, with a
copy given to each miner.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F—23
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OIL SHALE PERMIT
PERMIT TITLE
Notice of Intent to Prospect
JURISDICTION
Colorado
LEGAL CITATION
Colorado Mined Land Reclamation Act CRS 1973, 34-32-101 et seo.
RESPONSIBLE AGENCY/CONTACT
Director
Colorado Dept. of Natural Resources
Colorado Mined Land Reclamation Board
1313 Sherman Street, Room 718
Denver, Colorado 80202
(303)839-3311
ABSTRACT
Any person desiring to prospect is required to file a Notice of Intent to Conduct
Prospecting Operations on a form provided by the Board. Regulations required under
such notice include:
1. Confinement of operations near roads or trails;
2. Plugging or capping of drill holes;
3. Reclamation of affected lands;
4. Dispersing or burying materials removed from a hole;
5. Backfilling and revegetating any pits; and,
6. Sealing, where necessary, aquifers to prevent intermingling of water.
Specific rules on reclamation are found under Rule 6, CRS 1973, 34-32-101.
SCHEDULING MILESTONES TTrw. miner _r «. . „
JUpon filing, the applicant shall post surety not to
exceed $2000/acre to be disturbed. Upon completion is required to be filed. Whithin 90
days, the Mined Land Reclamation Board shall notify the applicant of steps to be taken
for reclamation. Within 30 days after completion of reclamation, the board is to
inspect the land. If the reclamation is found to be satisfactory, the Board will release
the surety.
PERMIT APPLICATION LEAD TIME
Board treatment is on a case-by-case basis. No specific lead time is given.
F-24
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OIL SHALE PERMIT
PERMIT TITLE
Permits for Special Operators
JURISDICTION
Colorado
LEGAL CITATION
Colorado Mined Land Reclamation Act, 1976 CRS 1973. 34-32-101. et sea.
RESPONSIBLE AGENCY/CONTACT
Harris Sherman
Colorado Dept. of Natural Resources
Colorado Mined Land Reclamation Board
1313 Sherman Street, Room 718
Denver, Colorado 80202
(303)839-3311
ABSTRACT
Application for a special permit is required for any sand, gravel, or quarry
aggregate operation that is to be operated for the sole purpose of obtaining materials
for road, highway, utility, or similar-type construction under a Federal, State, county,
city, town, or special district contract where the contract calls for work to be
commenced within a specifically short time and which will affect 10 acres or less.
The application shall contain owners of surface and subsurface lands; conformance
to existing zoning; map; legal description; identification of mining operation; recla-
mation costs; description of wildlife, plan. An application fee of $200 plus $15/acre is
required.
SCHEDULING MILESTONES
Upon filing, the Mined Land Reclamation Board will set the time, date, and place
for consideration of the application. Public notice and newspaper distribution is
required. Protests are due by 4:00 p.m. the day before the Board hearing.
PERMIT APPLICATION LEAD TIME
At least 10 days between application filing and Board hearing.
F-25
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OIL SHALE PERMIT
PERMIT TITLE
Permit for Limited Impact Operations
JURISDICTION
Colorado
LEGAL CITATION
Colorado Mined Land Reclamation Act, 1976 CRS 1973. 34-32-101 et spg
RESPONSIBLE AGENCY/CONTACT
Harris Sherman
Colorado Dept. of Natural Resources
Colorado Mined Land Reclamation Board
1313 Sherman Street, Room 718
Denver, Colorado 80202
(303) 839-3311
A8STRACT
Application for a limited impact permit is required for a mining operation
affecting less than 10 acres for the life of the mine and extracting less than 70,000 tons
of mineral, overburden, or combination thereof per calendar year. The application does
not require any exhibits, but it does require information such as ownership of surface
and subsurface rights, maps, legal descriptions, identification of mining operation,
reclamation plan and costs, and information on wildlife, water resources, vegetation,
soils, etc. A small application fee based on acreage is required.
On each anniversary date, the operator must file a notice of intent to continue
mining, an annual fee of $50, statement of work accomplished over the preceding year,
and land to be affected for the coming year.
SCHEDULING MILESTONES) Upon filing the appUcation, the operator must place a
copy of the application in public review, publish a notice in the newspaper for general
circulation for 2 weeks, and notify land owners. The Board will give notice of time,
date, and place for consideration within 30 days after filing. Objections must be filed
within 5 days of the last date of publication of public notice or 48 hrs before
consideration by the Mined Land Reclamation Board. A public hearing may be held if
the Board determines protests to be valid.
PERMIT APPLICATION LEAD TIME
At least 30 days between filing of application and Board hpnrin^.
F-26
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OIL SHALE PERMIT
PERMIT TITLE
Permit for Regular Mining Operations
JURISDICTION
Colorado
LEGAL CITATION
Colorado Mined Land Reclamation Act, 1976 CRS 1973, 34-32-101 et. sea
RESPONSIBLE AGENCY/CONTACT
Harris Sherman
Colorado Dept. of Natural Resources
Colorado Mined Land Reclamation Board
1313 Sherman Street, Room 718
Denver, Colorado 80202
(303) 839-3311
ABSTRACT
Application for a permit for any mining operation affecting 10 acres or
more, or extracting 70,000 tons or more of mineral overburden, or combination thereof
per calendar year. Exhibits required under permit application include: Legal
description, index map showing regional location, pre-mining and mining plan maps of
affected land (surface area) and owner(s) of substance to be mined. An application fee
is required that shall not exceed $2000.
On the anniversary date of each permit year, the operator is required to submit a
report and map indicating the phases of the reclamation plan completed. In addition, an
annual fee of from $275 to $350 is required.
SCH PULING MILESTONES |Upon fi^ng Qf the application, a copy is to be provided
for public review. Notices must be published in a newspaper for circulation for 4
weeks, and copies mailed to owners of surface rights. Proof of mailing and newspaper
publication is required. Upon filing, the Mined Land Reclamation Board will set the
date, time, and place for review of the application. This must be done within 90 days of
the filing. If objections are raised, the board may elect to conduct a public hearing to
consider protests. Objections must be raised within 20 days of the last published public
notice.
PERMIT APPLICATION LEAD TIME
(until Board meets for approval).
At least 90 days after filing application
requirements of the application.
Several months may be needed to complete the
F-27
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Storage of Flammable Liquids
Colorado
LEGAL CITATION
CRS 1963, S7-4-18
RESPONSIBLE AGENCY/CONTACT piro„tor
Colorado Dept. of Natural Resources
Colorado Division of Mines
1313 Sherman Street, Room 719
Denver, Colorado 80203
(303) 839-3401
ABSTRACT
Storage of flammable liquids underground in excess of 55 gal requires a special
permit from the Commissioner of Mines.
SCHEDULING MILESTONES!
Subject to approval, review, and inspection by District Inspector.
PERMIT APPLICATION LEAD TIME
2 to 4 weeks.
F-28
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Application for Diesel Permit—Underground Operations
Colorado
LEGAL CITATION
CRS 1963, 57-11-53
RESPONSIBLE AGENCY/CONTACT
Director
Colorado Dept. of Natural Resources
Colorado Division of Mines
1313 Sherman Street, Room 719
Denver, Colorado 80203
(303) 839-3401
ABSTRACT
Any operation of diesel-powered equipment used underground in all metal mines,
reclamation tunnels, clay mines, tunnel projects, or any underground mining operation
(except coal mines) is required to have approval of the Division of Mines. Permit must
be secured from the Division before equipment is taken underground.
SCHEDULING MILESTONES
A 10-day verbal temporary permit may be granted from the District Mining
Inspector during the time a formal application is pending. Application approval is
subject to review and possible inspection by the District Inspector.
PERMIT APPLICATION LEAD TIME
2 to 4 weeks.
F-29
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Operator's Notice of Activity
Colorado
LEGAL CITATION
CRS 1973, 34-47-123
RESPONSIBLE AGENCY/CONTACT Director
Colorado Dept. of Natural Resources
Colorado Division of Mines
1313 Sherman Street, Room 719
Denver, Colorado 80203
(303)892-3401
ABSTRACT
An operator or owner is required to notify the Division of Mines when work is
commenced or stopped at any of the following operations: mine, mill, placer, quarry,
open pit mine, dam project, tunnel project, or any public or quasi-public excavation.
SCHEDULING MILESTONES
Requirements are the mailing of the form only.
PERMIT APPLICATION LEAD TIME
None.
F-30
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Hoistman Certificate
Colorado
LEGAL CITATION
CRS 1973, 34-47-123
RESPONSIBLE AGENCY/CONTACT
Colorado Dept. of Natural Resources
Colorado Division of Mines
1313 Sherman Street, Room 719
Denver, Colorado 80203
(303) 892-3401
ABSTRACT
Every employer is required to have a competent employee who is a qualified
hoisting engineer or hoistman to be on duty continuously at any manually controlled
hoist where men are working above or below. Before being allowed to operate a hoist
on which two or more employees are to be handled daily, the hoistman must be
examined by a responsible doctor and must secure a certificate of health as prescribed
by the Bureau of Mines. All hoistmen are required to be familiar with hoisting engines,
must be able to read and write English, and must be between 18 and 65 years of age. A
yearly examination and certificate renewal is required.
SCHEDULING MILESTONES
Subject to physical examination and approval of examining doctor. There is
current debate on whether the Division of Mines or Division of Labor should have
authority over this certificate.
PERMIT APPLICATION LEAD TIME
None.
F-31
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Application to Store, Transport and Use Explosives
Colorado
LEGAL CITATION
CRS 1973, 34-27-101; 34-47-103; 9-7
RESPONSIBLE AGENCY/CONTACT
Norman Blake, Director
Colorado Dept. of Natural Resources
Colorado Division of Mines
1313 Sherman Street, Room 719
Denver, Colorado 80203
(303)892-3401
ABSTRACT
Any operator intending to use, store, or transport explosives for either surface or
underground operations is required to fill out an application. Applications require such
information as location of mine, location in mine of explosives, kind and amount of
exlosives, distances from other explosives, number of employees using explosives,
magazine construction, and a sketch of the facility. A separate form is required for
each type of explosive used.
SCHEDULING MILESTONES
Application is subject to review and approval by the District Inspector, who may
elect to inspect facilities. Applicant should seek advice from the Colorado Mined Land
Reclamation Board, who determines whether or not this application is necessary. There
is current debate over whether the Division of Mines or Division of Labor should have
authority over this application.
PERMIT APPLICATION LEAD TIME
Two weeks for review and approval.
F-32
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Reservoir Construction
Colorado
LEGAL CITATION
CRS 148-5-5 through 148-5-7
RESPONSIBLE AGENCY/CONTACT r1m.enrp K|||
Dept. of Natural Resources
Division of Water Resources
1313 Sherman Street, Room 818
Denver, Colorado 80202
(303) 839-3581
ABSTRACT
Any reservoir that has a capacity of more than 1,000 acre-ft or that has a dam or
embankment in excess of 10 ft in vertical height, or that has a surface area at a high
water line in excess of 20 acres requires approval of the State Engineer before
construction. The owners of these reservoirs are required to pay the State Engineer the
actual expenses he incurs in making a personal inspection and those incurred by any
deputy assistants hired for supervision. The State Engineer shall also determine the
amount of water that is safe to impound. All plans and specifications to be submitted
must be approved by a registered professional engineer. These requirements are
detailed in CRS 148-5-5 through 148-5-7.
SCHEDULING MILESTONES
Proper plans and specifications are to be submitted to the State Engineer.
PERMIT APPLICATION LEAD TIME
Depends on project.
F-33
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Water Well and Pump Installation (requirements)
Colorado
LEGAL CITATION
CRS 1963 148-20-4(l)(d) and 148-20-10(2)
RESPONSIBLE AGENCY/CONTACT
Clarence Kuiper
Colorado Dept. of Natural Resources
Division of Water Resources
1313 Sherman Street, Room 818
Denver, Colorado 80202
(303)839-3581
ABSTRACT
Rules under this Colorado code provide minimum standards for location, construc-
tion, modification, or abandonment of watqr wells and installation, modification or
repair of pumping equipment. A permit shall be obtained from the Office of the State
Engineer before construction, deepening, enlarging, or increasing the yield of a water
well and before initial pump installation or installation of a pump with a yield in excess
of the registered yield of that well.
Work is to be performed only by or under supervision of a person having a valid
license issued by the State Board of Examiners of Water Well and Pump Installation
Contractors unless exempt under provisions of Section 148-20-6(3), CRS 1963 as
amended. '
Other specific requirements under these regulations apply to 'pollution sources.
Permeability, horizontal and vertical distances from contaminants, draw-down charac-
teristics, and other conditions of the aquifer must be considered. Municipal or county
governments must be consulted when locating a well.
SCHEDULING MILESTONES! Specific requirements must be met before approval.
On permits to use groundwater and to construct a well, if within 6 months requirements
do not meet the approval of the Division of Water Resources, the permit will be
automatically rejected.
PERMIT APPLICATION LEAD TIME
Six months, maximum.
F-34
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Air Contaminant Emission Notices
Colorado
LEGAL CITATION Air Quality Control and Ambient Air Qualitv Standards.
Colorado Air Pollution Control Act; CRS 1973, 25-7-102 et seq. Regulation 3.
RESPONSIBLE AGENCY/CONTACT
Executive Director
Colorado Dept. of Health
Colorado Air Pollution Control Division
1420 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT
No person shall permit emission of air contaminants from, or construction or
alteration of, any facility, process, or activity from which air contaminants are or are
to be emitted unless and until an Air Contaminant Emission Notice has been filed with
the Air Pollution Control Division with respect to such emission. (Exceptions are
outlined in Regulation No. 3, Section n.E.) A revised emission notice is required any
time any change in emissions is anticipated or shall have occurred.
Each notice shall specify the following: the location at which the proposed
emission will occur; the name and address of the person operating or owning such
facility, process, or activity; and an estimate of the quantity and composition of the
expected emission. The Division has available at all pollution control authority offices
appropriate forms on which this information should be furnished.
A filing fee of $40 shall accompany each Air Contaminent Emission Notice.
SCHEDULING MILESTONES
Filing of forms and payment of fee required.
PERMIT APPLICATION LEAD TIME
None.
F-35
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OIL SHALE PERMIT
PERMIT TITLE
Land Use Special Permit
JURISDICTION
Colorado
LEGAL CITATION
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Natural Resources
Division of Wildlife
6060 North Broadway
Denver, Colorado 80216
(303)825-1192
ABSTRACT
A Land Use Special Permit may be required if monitoring work is done on Division
of Wildlife lands.
SCHEDULING MILESTONES
Contact Department for specific requirements.
PERMIT APPLICATION LEAD TIME
Depends on project.
F-36
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Air Contaminant Emission Permit
Colorado
LEGAL CITATION ^ir Oualitv Control and Ambient Air Qunlity Rtnnd«rH<5 r.nlnmHn
Air Pollution Control Act; CRS 1973, 25-7-102 et. seq. Regulation 3.
RESPONSIBLE AGENCY/CONTACT
Executive Director
Colorado Dept. of Health
Colorado Air Pollution Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT n0 construction or operation of any new direct air contamination
source or substantial alteration of an existing air contamination source will be allowed
without first obtaining or having a valid emission permit from the Division.
(Exemptions are listed under Regulation No. 3, Section II.E.)
Applications for an emission permit will generally include (1) equipment infor-
mation, and (2) plans, descriptions, and plans and drawings to provide engineering
evaluations to determine whether appropriate air pollution control regulations, or-
dinance, and ambient air quality standards will be met. The Division may determine
that it be necessary for the application to include acceptable ambient air monitoring
and meteorological data, modeling results, and other evaluative techniques, procedures,
and information sufficient in scope to determine if applicable ambient air quality
standards will be met.
A filing fee of $40 is charged. The actual emission permit fee for a direct source
is assessed at the time the Division issues final approval. The fee is calculated by a fee
schedule based on the number of hours the Division spends in processing the permit, not
to exceed $15,000 for all emission permits required for a contiguous plant site.
SCHEDULING—MILESTONES within 20 days of filing, the Division will make public
its comments. Applications subject to public comment are limited to those stationary
direct sources that show annual emissions exceeding 25 tons. Notices for public
comment are limited to those stationary direct sources that show annual emissions
exceeding 25 tons. Notices for public comment are made within 15 days after comment
by the Air Pollution Control Division. Thirty days are then allowed for receipt of public
comment. Within 15 days after preparation of its preliminary analysis where no delay
for public comment is required, or within 30 days following the period for public
comment, the Division will grant or deny the permit.
PERMIT APPLICATION LEAD TIME
AJIftw 90 riavs for flonlioBtion review and nrncpsging-.
F-37
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Fugitive Dust Permit
Colorado
LEGAL CITATION Ajr qunijty rnntrnl and Amhi*»nt Air Quality StnnHnrrtc
Air Pollution Control Act; CRS 1973, 25-7-102 et seq. Regulation 3.
RESPONSIBLE AGENCY/CONTACT Exeeutive Director
Colorado Department of Health
Colorado Air Pollution Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT
See Air Contaminant Emission Permit, under which fugitive dust is covered. In
addition to the filing fee for a direct source, a $25 fee for processing a Fugitive Dust
Permit is required.
SCHEDULING MILESTONES
See Air Contaminant Emission Permit.
PERMIT APPLICATION LEAD TIME
90 days.
F-38
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION 1
Open Burning Permit
Colorado
LEGAL CITATION
1973 CRS, 25
-7-120
RESPONSIBLE
AGENCY/CONTACT
Scott Miller
Colorado Department of Health
Air Pollution Control Division
125 N. 8th Street
Grand Junction, Colorado 81501
(303)245-2400
ABSTRACT
Open burning is prohibited throughout the State unless a permit has been granted.
In granting or denying a permit, the authority shall base its action on the potential
contribution to air pollution in the area, climatic conditions on the day or days of
burning, and the authority's satisfaction that there is no practical alternative method
for the disposal of the material to be burned.
Before a burn, notification must be given to the local fire control agencies. Burns
are allowed between 10 a.m. and sunset. If there are any complaints of pollution from
anyone in the area, the local fire agencies will require that the burn be immediately
extinguished.
SCHEDULING MILESTONES
The form is available from the Air Pollution Control Division and is usually
approved in a few weeks. Permit are renewed on an annual basis.
PERMIT APPLICATION LEAD TIME
30 days.
F-39
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Subsurface Disposal Permit
rv>lnm<1n
LEGAL CITATION
CRS 1963, 66-28-400
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Health
Water Quality Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT
Any person proposing to construct or operate a subsurface disposal system is
required to obtain a permit. The Division will issue a permit pursuant to public hearings
(1) if no waters of the State will be polluted, or (2) if the pollution will be limited to
waters in a specified limited area from which there is no risk of significant migration,
and (3) if the proposed activity is justified by public need.
SCHEDULING MILESTONES
Public notice and public hearings are required for all surface and mineral owners
of record within a 2-mile radius of any subsurface disposal system to voice complaints.
PERMIT APPLICATION LEAD TIME
Allow 3 months.
F-40
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Discharge Permit
Colorado
LEGAL CITATION se^^ng 25-8-501 through 508 CRS 1973 in conformity with the
Federal Water Pollution Control Act Amendments of 1972, the Clean Water Act of
1977, and regulations promulgated thereunder.
RESPONSIBLE AGENCY/CONTACT
Director
Colorado Department of Health
Water Quality Control Commission
4210 E. 11th Avenue
Denver, Colorado 80220
(303)388-6111
ABSTRACT {rhe permjt applies to all operations discharging to waters of the State
¦ NAm n. . L .'i. ' 1 • * • . a • . . ...
from a point source. Prohibitions of a discharge permit include, but are not limited to,
the following:
1. No discharge is allowed that will violate State, regional, or local land use
plans unless all requirements and conditions of applicable Federal and State
statutes and regulations are met or will be met according to a schedule of
compliance. Similarly, no discharge is permitted that by itself or in
combination with other pollutants will result in pollution of the receiving
waters in excess of standards, unless the permit contains effluent limita-
tions and a schedule of compliance with water quality requirements.
2. No discharge of any radiological, chemical, or biological warfare agent or
high level radioactive waste is permitted. Limits of radiological wastes that
may be discharged are determined by State water quality standards.
3. No discharge from a point source that is in conflict with an established
water quality management plan promulgated under Sections 201, 208, 209,
and 303(e) of the Federal Water Pollution Control Act of 1972 and the Clean
Water Act of 1977 is permitted unless the waste discharge permit contains
limitations and a schedule of compliance approved by the Division.
Frequency of measuring, monitoring, and reporting is dependent on specific
discharges.
SCHEDULING MILESTONES
An applicant is to apply for a permit at least 180
days in advance of the date the discharge is to
jegin. In some cases, the Division may determine that a site visit or extra information
s necessary. In such a case, the applicant has 60 days to reply. Reapplication for
continuance of a permit is required 180 davs before expiration of thp permit.
PERMIT APPLICATION LEAD TIME
180 days.
F-41
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OIL SHALE PERMIT
PERMIT TITLE
Waste Disposal Plant Operator Certificate
JURISDICTION
LEGAL CITATION
1963 CRS. 36-23-3
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Health
Water Quality Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT
Any person desiring to operate a solid waste disposal site and facility within the
unincorporated portion of any county shall make application to the board of county
commissioners of the county in which such site and facility is or-is proposed to be
located for a certificate of designation. Such application shall contain such enginee-
ring, geological, hydrological, and operational data as may be required by the
department by regulation. The application shall be referred to the department for
review and for recommendation as to approval or disapproval, which shall be based on
criteria established by the State Board of Health, the State Water Pollution Control
Commission, and the Air Pollution Control Commission.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F-42
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OIL SHALE PERMIT
PERMIT TITLE
Potable Water Supply and Safety Compliance
JURISDICTION
Colorado
LEGAL CITATION
1963 CRS 66-1-7
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Health
Water Quality Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303) 320-8333
ABSTRACT
The Colorado Department of Health has the authority to examine plans, specifi-
cation, and other related data pertaining to the proposed construction of any and all
publicly or privately owned community water facilities submitted for review of sanitary
engineering features before construction of such facilities. Facilities are inspected and
reports are submitted to the Department of Health and local health departments on a
regular basis.
SCHEDULING MILESTONES
Forms are available from the Colorado Department of Health. Time of approval
is dependent of size of facility, inspection, and additional requested data.
PERMIT APPLICATION LEAD TIME
Depends on project.
F-43
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Sewage Plant Site Approval and Plant Approval
Colorado
LEGAL CITATION
CRS 1973, 25-8-
200-, 25-8-704
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Health
Water Quality Control Division
4210 E. 11th Avenue
Denver, Colorado 80220
(303)320-8333
ABSTRACT
No operation of sewage treatment facilities is allowed until site approval and
discharge permits have been filed and reviewed. No person shall commence construc-
tion or expansion of any sewage treatment works intended to serve more than 20
persons until the previous requirements have been met. In determining the suitability
of a site location for any sewage treatment works, the Division shall consider the long-
range comprehensive planning for the area and the consolidation of sewage treatment
works to avoid proliferation of small sewage treatment works.
SCHEDULING MILESTONES
Depends of project.
PERMIT APPLICATION LEAD TIME
Depends on project,.
F-44
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Purchase, TransDortat on. and Storae-e of Exnlosivps
rVilnrnrtn
LEGAL CITATION
CRS 1963, 53-7-1 et. seq.
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Labor
Industrial Commission
251 E. 12th Avenue, Room 304
Denver, Colorado 80203
(303) 839-2446
ABSTRACT
Permits must be obtained for manufacture, sale, storage, transport, or use of
explosives or blasting agents in the interest of life, health, and safety of employees and
the general public, and for the protection of property. Permits are issued under the
classes of manufacture, sale, storage, transport, or use and are renewed at the
beginning of the calendar year.
SCHEDULING MILESTONES
Application for a permit is made on Division of Labor forms. If a permit is
desired, a hearing may be conducted, and an appeal may take place.
PERMIT APPLICATION LEAD TIME
Generally, 2 months.
F-45
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Oil Facility Inspection
Colorado
LEGAL CITATION
NFPA pamphlet No. 30 (National Fire Prevention Association)
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Labor
Oil Facility Division
1313 Sherman Street
Denver, Colorado 80203
(303)289-5643
ABSTRACT
Approval is necessary for gasoline storage in excess of 1,500 gal. A plot plan
showing storage location in relation to buildings and roads, and size of tanks is required.
Approval is immediate (1 to 2 weeks).
SCHEDULING MILESTONES 1
File plot plan.
PERMIT APPLICATION LEAD TIME
1 to 2 weeks.
F-46
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Boiler Inspection Permit
Colorado
LEGAL CITATION
RESPONSIBLE AGENCY/CONTACT
Colorado Department of Labor
Boiler Inspection Division
1313 Sherman Street
Denver, Colorado 80203
(303) 289-5641
ABSTRACT
AH boilers in use require a permit. Permits are updated by inspection on an
annual basis.
SCHEDULING MILESTONES
Arrange for an appointment for an inspection. If approved, operator or owner will
be billed and mailed a certificate within 30 days.
PERMIT APPLICATION LEAD TIME
None.
F-47
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Oil Shale Leases
Utah
LEGAL CITATION
UCA 65-1-111 throueh 65-1-114
RESPONSIBLE AGENCY/CONTACT
Utah Department of Natural Resources
Board and Division of State Lands
105 State Capitol
Salt Lake City, Utah 84114
(801) 533-5381
ABSTRACT
The State Land Board is authorized to participate with its oil shale lessees in
programs for the development of technology for the economic recovery of fuel
substances from oil shale. State law provides for the authorization of the Board and
Division of State Land's participation in the development of oil shale technology by
crediting against future annual oil shale lease rentals in excess of fifty cents per acre
the costs of lessee-financed programs for development. (Laws 1969, ch. 220).
Application is made on forms provided by the Division. Most of the leases extend
for a primary term of 20 years, and for as long afterward as oil shale, kerogen, or
elements of oil shale are being produced in commercial quantities.
SCHEDULING MILESTONES
If an application is deficient, it will be returned to the applicant with instructions
for its amendment or completion. Processing time is dependent on amount of land and
plans for development.
PERMIT APPLICATION LEAD TIME
At least 4 months.
F-48
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Ground Water Well Application
Utah
LEGAL CITATION
Utah Administrative Rule Code A28-03-17 Part HI UCA 73-3-25
RESPONSIBLE AGENCY/CONTACT
Utah Department of Natural Resources
State Engineer
Division of Water Rights
435 State Capitol
Salt Lake City, Utah 84114
(801) 533-6071
ABSTRACT
Specific plans should be submitted to the Division for approval. In the appli-
cation, a detailed report should be submitted showing sites available, the existence of
sink holes, caves, test holes, abandoned wells, borings, sewerage in area, other wells,
other water supply sources, and geology. Unless previously submitted, a summary of the
design including information relative to test well drilling, geophysical prospecting
specific yield, and chemical analysis should be provided. Detailed plans should also be
submitted. These include a plot of the site, sources of pollution, elevations, and a
schematic drawing.
All drilling permits expire at the end of the calendar year. A bond of $500 is
required under the regulations.
SCHEDULING MILESTONES
After application is received and reviewed by the State Engineer, public notice of
application is given once a week for 3 weeks, after which, a 30-day period is given to
recieve public protests. Any protests go to a hearing, after which a judgement may be
made.
PERMIT APPLICATION LEAD TIME
If there are no protests, 4 months.
F-49
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
ADDlication for Water Riehts
Utah
LEGAL CITATION
UCA: 73-3-1 et. seq.
RESPONSIBLE AGENCY/CONTACT Dircctor
Utah Department of Natural Resources
Division of Water Rights
231 E. 400 South, Room 200
Salt Lake City, Utah 84111
(801) 533-6071
ABSTRACT
Application for right to use unappropriated public water shall file application with
the State Engineer. Blank forms are available and require the name and address of
person, corporation, or association making application, the nature of proposed use, the
quantity of water or flow to be appropriated, the time during which it is to be used
every year, the name of stream or other source from which the water is to be diverted,
and the nature of the diverting works.
The State Engineer may issue a temporary permit to drill a well at any time after
filing of an application to appropriate water if fees are paid and if there is
unappropriated water available, and if there is no likelihood of impairment of existing
rights.
SCHEDULING MILESTONES!
After application is received and reviewed by the State Engineer, public notice of
application will be given once a week for 3 weeks. After the third notice, 30 days are
to be allowed for written public protest, after which a public hearing may be held.
After the public hearing, judgement will be made. A maximum fee of $150 is possible.
PERMIT APPLICATION LEAD TIME |
If there are no protests. 4 months.
F-50
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Mined Land Reclamation
Utah
LEGAL CITATION
UCA 40-6-3 amended, Laws of Utah Chapter 176 H.B. No. 323 passed May 12, 1975.
RESPONSIBLE AGENCY/CONTACT
Utah Department of Natural Resources
Mined Land Reclamation
Division of Oil, Gas, and Mining
1588 West North Temple
Salt Lake City, Utah 84116
(801) 533-7771
ABSTRACT
Before commencement of mining operations, the operator shall file a notice of
intent for each mining operation. The form of the notice shall be provided for in the
rules and promulgated by the Division.* The notice shall require the operator to detail a
plan of reclamation of the lands affected. In connection with the notice, the operator
shall furnish evidence in the form of acceptable insurance policies or other factual data
that the operator will be financially responsible during the proposed mining operations
for the payment of offsite public liability or property damage claims for which he may
become liable.
SCHEDULING MILESTONES
Within 30 days of receipt of notice of intention, the Division of Oil, Gas, and
Mining will complete its review and will make further inquiries, inspections, or
examinations, as may be necessary. The operator will be notified of objections and
given opportunity to respond. Within 30 days following the last action, the Division will
make a tentative decision with respect to approval and will publish public notice. If no
factual written protests are received within 30 days, final approval will be given.
PERMIT APPLICATION LEAD TIME
Bflrrinc ohipr'tinns from thp Division nr thp public Qfl Hnyc
F-51
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION |
Permit for Exploration and Excavation
Utah
LEGAL CITATION
UCA 63-11-2 (1969)
RESPONSIBLE AGENCY/CONTACT
Utah Department of Natural Resources
Division of Parks and Recreation
1596 West North Temple
Salt Lake City, Utah 84116
(801) 533-6011
ABSTRACT
Before any exploration or. excavation in or on any prehistoric ruins, pictographs,
hieroglyphs, or any other ancient markings or writing or archaeological or paleonto-
logical deposit in Utah on any public lands, either State or Federal, shall be undertaken,
a permit shall first be obtained from the division of parks and recreation. The board of
parks and recreation is authorized to promulgate for division enforcement such
regulations as it may deem needful to protect from vandalism or injury and prehistoric
ruins and relics and archaeological and paleontological deposits of. the State and also all
natural bridges and natural scenic features and formations. No person shall remove
from the State of Utah any part of any such ruins or deposit except with the consent of
the Division of Parks and Recreation. As a condition to such consent, the Division may
require that a portion of such relics, materials, or deposit remain the property of the
State or of the county wherein such ruins or deposits are found. Any person violating
this act or the rules and regulations promulgated by the Board of Parks and Recreation
pursuant thereto shall be guilty of a misdemeanor and upon conviction thereof shall, in
addition to any other penalties imposed, forfeit to the State all articles and materials
discovered by or through his efforts.
SCHEDULING MILESTONES Description of area, work to be done, and descrip-
tion of ruins or deposits on a detailed scale is submitted for evaluation. Notice is set
for public protest, and public hearings may result based on protest.
PERMIT APPLICATION LEAD TIME
Depends on extent of work, area, and potential historic value.
F-52
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Open Burning
Utah
LEGAL CITATION
UCA 26-24, Air
Conservation Regulations A 28-03-2b
RESPONSIBLE AGENCY/CONTACT TT.„U ^ A .
————————————————— Utah Department of Social Services
Division of Environmental Health,
Bureau of Air Quality
72 East 4th South, Suite 305
Salt Lake City, Utah 84102
(801) 533-6108
ABSTRACT
When not prohibited by other laws or officials having jurisdictions and
when a nuisance is not created, the following types of open burning are
permissible following written application and appropriate hearing:
1) Open burning of solid or liquid fuels or structures for removal of hazards or
eyesores,
2) Open burning in remote areas of highly explosive or other hazardous
materials for which there is no other known practical method of disposal,
3) Open burning of tree cuttings and brush within right of ways or for other
clearance,
4) Other special purposes or under unusual circumstances.
SCHEDULING MILESTONES
No time frame.
PERMIT APPLICATION LEAD TIME
None.
F-53
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Fuel Burning—Sulfur Content Exemption
Utah
LEGAL CITATION
UCA 26-24 Air Conservation Regulations A-28-03-2d
RESPONSIBLE AGENCY/CONTACT
Utah Department of Social Services
Division of Environmental Health,
Bureau of Air Quality
72 East 4th South, Suite 305
Salt Lake City, Utah 84102
(801) 533-6108
ABSTRACT
Any person engaged in operating fuel-burning equipment using coal or fuel oil may
apply for an exemption from the restrictions of no more than 1.0 percent sulfur by
weight or 1.5 percent sulfur by weight for coal and fuel oil, respectively. The
application shall furnish evidence that the equipment is operating in such a manner as
to prevent the emission of sulfur dioxide in excess of the limitations. Control apparatus
to continuously prevent the emission of sulfur greater than provided by the limitations
must be specified in the application for an exemption. Application is made with the
Executive Secretary.
SCHEDULING MILESTONES
No time frame.
PERMIT APPLICATION LEAD TIME
None.
F-54
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Permit to Construct Facilities that are Sources of Air Pollution
Utah
LEGAL CITATION J
UCA 26-24-9, Air Conservation Act
RESPONSIBLE AGENCY/CONTACT
Utah Department of Social Services
Division of Environmental Health,
Bureau of Air Quality
72 East 4th South, Suite 305
Salt Lake City, Utah 84102
(801) 533-6108
ABSTRACT (Notice must be given to the Executive Secretary by any person planning
to construct a new installation or modify an existing installation that may be a direct or
indirect source of air pollution. This also includes any person planning to install an air-
cleaning device or other equipment intended to control emission of air contaminants.
The Executive Secretary may require, as a condition precedent to the construction,
installation, or establishment of the air contaminant source, the submission of plans,
specifications, and other such information as he deems necessary to determine whether
the proposed construction, installation, or establishment will be in accord with
applicable rules and regulations in force under this act.
Plan approval for an indirect source may be delegated by the Executive Secretary
to a local authority when requested and upon assurance that the local authority has and
will maintain sufficient expertise to ensure that the planned installation will meet the
requirements established by law.
SCHEDULING MILESTONES ^ within 90 days after the receipt of plans, specifi-
cations, or other information required under this section, the executive secretary
determines that the proposed construction, installation, establishment, or any part of it
will not be in accord with the requirements of this act or the applicable rules and
regulations, or that further time (not to exceed three extensions of 30 days each) is
required by the committee to review adequately the plant, specifications, or other
information, he shall issue an order prohibiting the construction, installation, or
establishment of the air contaminant source or sources in whole or in part.
In addition to any other remedies available on account of the issuance of an order
either granting or denying a request for the construction of a new installation, and
before invoking any such remedies, any person or persons aggrieved by this shall, upon
request, in accordance with the rules of the committee, be entitled to a hearing.
Following the hearing, the permit may be affirmed, modified, or withdrawn.
PERMIT APPLICATION LEAD TIME
At least 90 days.
F-55
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Permit to Construct and Operate Treatment Works
Utah
LEGAL CITATION
UCA 73-14-5
RESPONSIBLE AGENCY/CONTACT
Utah Department of Social Services
Division of Environmental Health
Committee on Water Pollution
44 Medical Drive
Salt Lake City, Utah 84112
(801) 533-6111
ABSTRACT
It is unlawful for any person to carry on any of the following activities without
first securing a permit from the Division, as is required, for the disposal of all wastes
that are or may be discharged into the waters of the State: (1) The construction,
installation, modification, or operation of any treatment works or part thereof or any
extension or addition thereto; (2) the increase in volume or strength of any wastes in
excess of the permissive discharges specified under any existing permit; (3) the
construction, installation, or operation of any establishment or any extension or
modification thereof or addition thereto, the operation of which would cause an
increase in the discharge of wastes into the waters of the State or would otherwise
alter the physical, chemical, or biological properties of any waters of the State in any
manner not already lawfully authorized; (4) the construction or use of any new outlet
for the discharge of any wastes into the waters of the State.
SCHEDULING MILESTONES!
The Division of Environmental Health has no special forms. A report must be
prepared by an engineer showing the design basis and construction plans. If all
information is supplied when first submitted, processing takes about 1 month. If
additional data are required, processing may take an additional 2 to 3 months.
PERMIT APPLICATION LEAD TIME
Approximately 3 months.
F-56
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Water Quality—Definition and Control
Utah
LEGAL CITATION
Standards for Water Quality A28-03-11 UCA 26-15-4 and 73-14-1 et seq. (1953) amended.
RESPONSIBLE AGENCY/CONTACT
Utah Department of Social Services
Division of Environmental Health
Committee on Water Pollution
44 Medical Drive
Salt Lake City, Utah 84112
(801) 533-6111
ABSTRACT
Waters whose existing quality is better than the established standards will be
maintained at high quality unless it has been affirmatively demonstrated to the State
that a change is justifiable as a result of necessary economic or social development and
will not preclude present and anticipated use of such waters. Any industrial, public, or
private project or development that would constitute a new source of controllable
pollution or an increased source of controllable pollution to high quality waters will be
required to provide waste treatment to maintain high quality water to the extent that
such treatment is practicable. In implementing this policy, the Secretary of the
Interior will be kept advised of and will be provided with such information as he will
need to discharge his responsibilities under the Federal Water Pollution Control Act as
amended.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F-57
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Permit to Operate Solid Waste Disposal Site
Utah
LEGAL CITATION
Code of Solid Waste Disposal Regulations A28-03-19 UCA 26-15-5 (1953) amended.
RESPONSIBLE AGENCY/CONTACT
Utah Department of Social Services
Division of Environmental Health
44 Medical Drive
Salt Lake City, Utah 84112
(801) 533-6111
ABSTRACT
It is unlawful for any person to deposit any solid waste in any place except at a
site that has been designated by a city, county, district, or other properly designated
agency, and.approved by the Utah State Division of Health. This requirement does not
include the deposition of inert construction debris used as fill material or mine tailings
and overburden, provided such deposition does not cause a public nuisance or hazard or
contribute to air or water pollution. Provisions are available for solid wastes.
Design plans and related information shall be submitted to the Division for review
and approval before construction. Plans include: location, characteristics of area, type
of waste, soil description, provisions of fire control, land ownership or lease agreement,
etc., and any other information requested by the Division.
SCHEDULING MILESTONES!
Approval is required before construction. Approval includes limitations on types
of wastes to be accepted.
PERMIT APPLICATION LEAD TIME
90 days.
F-58
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Notice of Intention to Operate Or Suspend Operations
Utah
LEGAL CITATION Nonmetal Federal Mandatory Standards with State codes.
Administrative Rule A71-02-10 Sec. 5.
RESPONSIBLE AGENCY/CONTACT
Utah Industrial Commission and
Labor Relations Board
Division of Safety
350 East 5th South
Salt Lake City, Utah 84111
(801) 533-6411
ABSTRACT
The owner, operator, or person in charge of any metal or nonmetal mine shall
notify the Industrial Commission of Utah, before starting operations, of the approxi-
mate or actual date of commencement of mine operations. The notification shall
include mine name, location, company name, mailing address, person in charge, and
whether operations will be continuous or intermittent.
When any mine is closed, the person in charge shall "notify the Industrial
Commission of Utah, as provided above, and indicate whether closure is temporary or
permanent.
SCHEDULING MILESTONES
Filing of forms only.
PERMIT APPLICATION LEAD TIME
None.
F-59
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OIL SHALE PERMIT
PERMIT TITLE|
JURISDICTION
Hoist man-Qualifications
Utah
LEGAL CITATION | Metal ^ Nonmetal Federal Mandatory Standards with State
Codes. Administrative Rule A71-02-10 Sec. 66.
RESPONSIBLE AGENCY/CONTACT TT4, u T ^ . .
— Utah Industrial Commission and
Labor Relations Board
Division of Safety
350 East 5th South
Salt Lake City, Utah 84111
(801) 533-6411
ABSTRACT
Hoistmen and motormen who regularly transport men in shafts or along slopes
planes, raises or inclines, or along main haulage roads on the surface and underground'
shall undergo physical examinations to determine their physical fitness before beine
assigned to such duties, and at least annually thereafter. A copy of the examining
physician's report, on a form provided by the Industrial Commission, shall be returned to
the mine superintendent or other authorized official who, if satisfied as to the general
competency of such person to perform such duties, shall so certify on that codv and
forward it to the Industrial Commission. The Commission, if satisfied as to the
applicant's fitness to perform such duties, shall issue an appropriate certificate
Hoistmen certificates shall be posted in the hoist rooms, and motormen certificates in a
suitable and conspicuous place in the mine. Certificates shall expire on the first dav of
January each year. Applications for certificate renewal shall be submitted to the
Industrial Commission within 30 days preceding expiration date.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F-60
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OIL SHALE PERMIT
PERMIT TITLE
Escape and Evacuation Plans
JURISDICTION
Utah
LEGAL CITATION
Utah Administrative Rules A71-02-1
RESPONSIBLE AGENCY/CONTACT
Utah State Industrial Commission and
Labor Relations Board
Division of Safety
448 South 4th East
Salt Lake City, Utah 84111
(801) 533-6411
ABSTRACT
A specific escape and evacuation plan suitable to the conditions and mining
system of the mine and showing responsibilities of all key personnel in the event of an
emergency shall be developed by the operator and set out in written form. Copies of
the plan and revisions shall be available to the Division. Also, copies of the plan shall
be posted at locations convenient to all persons on the surface and underground. The
plan is to be updated and reviewed once every 6 months.
SCHEDULING MILESTONES
Preparation and updating of plans are only requirements.
PERMIT APPLICATION LEAD TIME
None.
F-61
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Boiler and Pressure Vessel—definition and control
Utah
LEGAL CITATION
Utah Administrative Rules A71-02-5
RESPONSIBLE AGENCY/CONTACT TTtoh stnte Indurtriol Commtaion and
Labor Relations Board
Division of Safety
448 South 4th East
Salt Lake City, Utah 84111
(801) 533-6411
ABSTRACT
All boilers and pressure vessels used where workman or the public may be exposed
to risks shall be designed, constructed, inspected, stamped, and installed in accordance
with the applicable ASME Boiler and Pressure Vessel Code Rules and Regulations;
In addition, boilers and pressure vessels shall be registered with the National
Board and shall bear a registration number. A copy of the manufacturer's data report
shall be filed with the Chief Inspector through the National Board before installation in
the State of Utah.
If a boiler or pressure vessel is of special design or one that cannot bear ASME
stamping, details of the proposed construction, including shop drawings, shall be
admitted to the Chief Inspector, and approval as "State of Utah Special" for construc-
tion and installation must be obtained from the Commission before construction is
started.
SCHEDULING MILESTONES |
None.
PERMIT APPLICATION LEAD TIME
None.
F-62
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Storage of Explosives
Utah
LEGAL CITATION
UCA 40-5-4
RESPONSIBLE AGENCY/CONTACT TJtah stQtc Commission and
Labor Relations Board
Division of Safety
350 East 5th South
Salt Lake City, Utah 84111
(801) 533-6411
ABSTRACT
It is unlawful to have stored at any shaft house or within the underground
workings of any mine at one time more than enough powder or other high explosive to
do the work for each 24 hours without first having obtained written permission from the
Industrial Commission. Any violation is punishable by fines of from $100 to $1000.
SCHEDULING MILESTONES
Written consent needed.
PERMIT APPLICATION LEAD TIME
1 to 2 weeks.
F-63
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Construction of Wastewater Ponds and Holding Facilities
Wyoming
LEGAL CITATION
WSA 35-502-18
RESPONSIBLE AGENCY/CONTACT
Wyoming Department of Environmental
Quality
Division of Water Quality
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7781
ABSTRACT
Any construction, installation, or modification of an existing treatment works,
disposal system, or holding facility capable of causing or contributing to pollution is to
submit a written application on a form provided by the Division of Water Quality. All
plans and specifications must carry the approval of a registered State Engineer.
The application includes all designs, specifications, plans, and other pertinent
information covering the project as determined by the Administrator.
SCHEDULING MILESTONES
Applications must be submitted 60 days before construction. No construction may
commence until a permit is issued. When the application is deemed complete, the
review of the application will be completed within 45 days by the Administrator.
PERMIT APPLICATION LEAD TIME
4 to 6 months.
F-64
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Construction of Sewage Facility
Wyoming
LEGAL CITATION |
WSA 35-502-
¦18
RESPONSIBLE
AGENCY/CONTACT
William Garland, Administrator
Wyoming Department of Environmental
Quality
Division of Water Quality
Hathaway Building
Cheyenne, Wyoming 82002
(307)777-7781
ABSTRACT
Any construction, installation, or modification of an existing sewage facility
requires the submission of a written application with the approval of a registered State
Engineer. In some cases, small facilities may obtain from a local authority approved for
construction within 10 days. The application must include all plans, specifications, and
designs and other pertinent information as determined by the Administrator.
SCHEDULING MILESTONES
Applications are usually submitted 60 days before construction. No construction
may commence until a permit is issued. When the application is deemed complete, the
review will be completed within 45 days. In the case of a small facility, approval may
be granted by a local authority in 10 days.
PERMIT APPLICATION LEAD TIME
4 months.
F-65
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Subsurface Discharges
Wyoming
LEGAL CITATION
WSA 35-11-101 through 1104
-
RESPONSIBLE
AGENCY/CONTACT
William Garland, Administrator
Wyoming Department of Environmental
Quality
Division of Water Quality
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7781
ABSTRACT
The purpose is to control groundwater pollution by establishing a permitting
process for subsurface discharges through wells for underground waste management,
artificial recharge, and special process discharges to prevent the endangerment of
groundwaters of the State that are or have the potential for being beneficially used.
The administrator will review the application for completeness. The applicant
may be contacted for submittal of additional information. Information includes, maps,
geological data, type of discharge, dates of operation, plan of program, and others.
Permits may be issued on a well-by-well basis, or by project, field block, area or
other appropriate method, providing wells covered by a single permit are all within a
single, legally definable parcel of land and under control of one legal entity. Permits
may be issued for up to a period of 5 years.
SCHEDULING MILESTONES!
Within 60 days of receipt of a completed application, the administrator will make
a tentative determination with respect to issuance or denial of a permit. If determined
sufficient, a draft permit is made available for public inspection. A public hearing may
be requested within 30 days. Once all requirements are satisfied, a permit will be
issued.
PERMIT APPLICATION LEAD TIME
At least 90 to 120 days.
F-66
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Mining Permit, Mining and Reclamation Plan
Wyoming
LEGAL CITATION
WSA 35-11-405 and 406
RESPONSIBLE
AGENCY/CONTACT
Walter Ackerman, Administrator
Wyoming Department of Environmental
Quality
Land Quality Division
Hathaway Building
Cheyenne, Wyoming 82002
(307)777-7756
ABSTRACT
A mining permit is the certification that the tract of land described may be mined
by an operator licensed to do so in conformance with an approved mining and
reclamation plan. No mining operation is allowed to commence until a valid permit has
been obtained.
Application includes a mining and reclamation plan dealing with the extent to
which the mining operation will disturb, change, or deface the lands to be affected, the
proposed future use or uses, and the plan whereby the operator will reclaim the
affected lands to the proposed future use or uses. The mining and reclamation plan
shall be consistent with the objectives and purposes of the Environmental Quality Act
rules and regulations defined under WSA 35-11-406. In addition, the Administrator may
deny an application in an area where prior scientific investigations affirm the existence
of significant artifacts, fossil, or other articles of archeological or paleontological
interest. Upon recommendation, the Administrator may require an evaluation of such
area before issuance of the permit.
SCHEDULING MILESTONES
Applications are subject to 90-day State review for completeness; within 15 days
following assurance of completeness, a 30-day notice for public comment is made.
Interested parties then have 20 days to make complaints, and a decision will then be
made within 30 days after completion of notice period.
PERMIT APPLICATION LEAD TIME
At least 6 months, if no complaints are voiced.
F-67
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Notification of Mining Operations (control)
Wyoming
LEGAL CITATION |
WSA 30-2-214 through 3-2-317
RESPONSIBLE AGENCY/CONTACT w„ltpp Arkprm(nij Ar1ministrat0P
Wyoming Department of Environmental
Quality
Land Quality Division
Hathaway Building
Cheyenne, Wyoming 82002
(307)777-7756
ABSTRACT
Notice must be given to the inspector of mines for abandonment or commence-
ment of a mining operation, or change of ownership of mining property. Notice of
abandonment must be given far enough in advance so that a final inspection may be
made before it is closed down. Within 30 days after commencement of any mining
operation, the owner or operator is required to notify the inspector of mines of the date
and place of commencement.
SCHEDULING MILESTONES
Notice must be given 30 days before abandonment and 30 days after commence-
ment of operations.
PERMIT APPLICATION LEAD TIME
^Igne.
F-68
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Discharges—In Situ Mining
Wyoming
LEGAL CITATION
WSA 35-11-101
through 425
RESPONSIBLE AGENCY/CONTACT AJ . . 4 4
Administrators
Wyoming1 Department of Environmental
Quality
Water Quality and Land Divisions
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7391 .
ABSTRACT
The purpose is to establish a permitting process to protect the surface waters and
groundwaters of the State from pollution, to control the injection and recovery of fluids
and pollutants into and from groundwaters, and to reclaim any land disturbance that
may result from in situ mining activities.
The owner or operator of an in situ mining facility must apply for a permit.
Application requirements include: a site facility description; soils, vegetation, and
surface hydrology information; a waste control plan and program; geologic information;
groundwater information; proposed hydrologic testing; and plans for monitoring, ground-
water restoration, and land reclamation programs.
SCHEDULING MILESTONES
Application is submitted for review by the Administrator, who will notify
applicant within 90 days if application is incomplete. Public inspection and public
hearings are allowed for any protests. A period of 20 days is allowed for public
protests. After all requirements are satisfied, a permit will be issued.
PERMIT APPLICATION LEAD TIME
At least 120 days.
F-69
-------
OIL SHALE PERMIT
PERMIT TITLE
Construction and Operating Permit for
on to Existing Facility
JURISDICTION
New or Modificati
Wyoming
LEGAL CITATION
Air Quality Star
idards and Regulations, Section 21
RESPONSIBLE AGENCY/CONTACT | Ran(Mph Woo
-------
OIL SHALE PERMIT
PERMIT TITLE
Open Burning Permit
JURISDICTION
Wyoming
LEGAL CITATION
Wyoming Environmental Quality Act, Sections 35-502, 10 et.
seq. Section 13, Wyoming Quality Standards and Regulations, 1978
RESPONSIBLE AGENCY/CONTACT
Randolph Wood, Administrator
Wyoming Department of Environmental
Quality
Air Quality Division
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7391
ABSTRACT
Open burning is prohibited throughout the State unless a permit is issued. In
granting or denying a permit, the Air Quality Division shall base its action on the
potential contribution to air pollution in the area, climatic conditions on the day or days
of burning, and the authority's satisfaction that there is no practical alternative method
for the disposal of the material to be burned. This last requirement is governed by very
stringent rules, and very few permits are issued because of it.
Before any burn, if a permit is obtained, notification must be given to the local
fire authorities, and requirements given by them must be met.
SCHEDULING MILESTONES
No specific form is available. Information is to be provided to the Air Quality
Division in letter form. No specific time frame is given—application aproval depends on
situation.
PERMIT APPLICATION LEAD TIME
Depends on project.
F-71
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Permit to Dispose of Hazardous Wastes
Wyoming
LEGAL CITATION TT „ .
Wyoming Environmental Quality Act, Article 5, Section 35-
502. 24 et. seq. Solid Waste Management Rules and Regulations, Section 11.
RESPONSIBLE AGENCY/CONTACT Charles A(jministrator
Wyoming Department of Environmental
Quality
Solid Waste Division
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7752
ABSTRACT
If any hazardous wastes are to be disposed of in a mining operation, a permit must
be obtained. Guidelines for specific information to be provided are found in the
Wyoming Environmental Quality Act Rules and Regulations. Basically, the owner or
operator must submit a plan of operation, including a map, plot plan, description of
area, proposed dates of operation, types of waste, types of disposal, geologic conditions,
groundwater and surface water conditions, etc.
SCHEDULING MILESTONES
No public hearings are involved, although EPA is proposing that States implement
hearings into their regulations. After a 60-day review, if no additional information is
necessary, a temporary permit will be issued. Construction of disposal facility may
commence, and after completion, a final inspection and permit will be issued.
PERMIT APPLICATION LEAD TIME
6Q tiav
F-72
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
ADDroval for Construction and Operation of Waste Facilitv
Wvominer
LEGAL—CITATION | Wyoming Environmental Quality Act, Article 5, Section 35-502.
42 et. seq. Solid Waste Management Rules and Regulations, Section 11.
RESPONSIBLE AGENCY/CONTACT
Charles Porter, Administrator
Wyoming Department of Environmental
Quality
Solid Waste Division
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7752
ABSTRACT
It is unlawful for any person to dispose of any industrial wastes without first
obtaining a permit. Guidelines for specific information for filing an application can be
found in the Solid Waste Management Rules and Regulations. Generally, a plan of
operation is required for approval in obtaining a permit. The plan requires a map of the
area, a plot plan, description of area and work, proposed dates of operation, types of
waste, method of disposal, geologic, ground, and surface water characteristics, etc.
SCHEDULING MILESTONES
No public hearings are involved. After a 60-day review of the application by the
Solid Waste Division, if the application is complete, a temporary permit is given
allowing construction to begin. After construction completion, a final field inspection
is conducted, and upon approval, a final permit is issued.
PERMIT APPLICATION LEAD TIME
60 days.
F-73
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OIL SHALE PERMIT
PERMIT TITLE
Construction and Operating Permit
:ation to Existing Facility
JURISDICTION
for New or Modifi<
Wyoming
LEGAL CITATION
Wyoming Environmental Quality Act, Sections 35-502.10 et. seq.
and Regulations, Section 21.
Air Quality Standards
RESPONSIBLE AGENCY/CONTACT
Randolph Wood, Administrator
Wyoming Department of Environmental
Quality
Air Quality Division
Hathaway Building
Cheyenne, Wyoming 82002
(307)777-7391
ABSTRACT
Application must be made by any person planning to construct a new installation
or to modify an existing installation that may be a direct or indirect source of air
pollution. This includes any installation of air Cleaning devices to control emission of
air contaminants. The permit is required before construction. Information required
includes an impact analysis, potential emission rates, size of facility, location, etc.
Forms are available from the Air Quality Division with guidelines that pertain
specifically to surface mining. The Division encourages prospective applicants to meet
with them before filing.
After startup, a facility has 120 days to obtain an operating permit. During that
time, the facility must show that it is in compliance with all air quality emission
standards.
SCHEDULING MILESTONES
The Division has 30 days to review form for completeness, followed by a 60-day
review. At that time, the Division will announce its decision in public notice and allow
30 days for public comment. Based upon public comment, a final decision may or may
not be made.
PERMIT APPLICATION LEAD TIME
followed by 120 days after startup for operating permit.
At least 120 days for construction permit,
F-74
-------
OIL SHALE PERMIT |
PERMIT TITLE
JURISDICTION
Exploration Permit, License to Explore
Wyoming
LEGAL CITATION
WSA 35-11-405 and 406
RESPONSIBLE
AGENCY/CONTACT
Walter Ackerman, Administrator
Wyoming Department of Environmental
Quality
Land Quality Division
Hathaway Building
Cheyenne, Wyoming 82002
(307) 777-7756
ABSTRACT
When conducting an exploration program, an exploration permit is required. When
drilling, a drilling program and plan must be submitted for approval, along with a
minimum $10,000 bond.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME 1
1 week.
F-75
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Industrial Zone Change
Sweetwater Countv
LEGAL CITATION
Sweetwater County Zoning Resolution, Adopted August 8,1972
RESPONSIBLE AGENCY/CONTACT
Dennis Watt, Planning Director
Sweetwater County Planning Department
P. O. Box 791
Green River, Wyoming 82935
(307) 875-2611
ABSTRACT
If a change in zoning requirements is necessary, a Petition for a Zone Change and
a Zoning Permit Application must be, filed. The information needed on these forms
includes a legal description, reason for requesting the change, a map of the property
and adjacent properties, and a listing of all owners of the property and all adjacent
property owners. The zoning permit grants one or a combination of (1) construction and
alteration, (2) use, (3) certificate of occupancy, and (4) temporary use.
SCHEDULING MILESTONES
Two public hearings are required; normally, each require 30 days notice. Sweet-
water County, however, puts notice in paper for both hearings simultaneously with
different hearing dates. One hearing is for the Statutory Planning and Zoning
Commission, and one is for the Board of County Commissioners.
PERMIT APPLICATION LEAD TIME
Maximum 50 davs.
F-76
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Conditional Permit
Sweetwater County
LEGAL CITATION
Sweetwater County Zoning Resolution. August 1972
RESPONSIBLE AGENCY/CONTACT
Dennis Watt, Planning Director
Sweetwater County Planning Department
P. 0. Box 791
Green River, Wyoming 82935
(307) 875-2611 ext. 270
ABSTRACT
A conditional permit would be necessary if the oil shale activity involved any of
the following: explosives manufacture or storage, above-ground storage of flammable
liquids or gases exceeding 5,000 gal at one site, or the manufacture or storage of
poisonous or toxic materials recognized as dangerous to animals and/or human beings.
This conditional permit would normally be issued in conjunction with the consi-
deration of the requested zone change. Special conditions of Sweetwater County may
be imposed. There are no forms utilized, but these conditions are noted on the
application for zoning permit.
SCHEDULING MILESTONES
In conjunction with zone change.
PERMIT APPLICATION LEAO TIME
Tn wninvtlnn with tnna
F-77
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Mineral Extraction
Sweetwater County
LEGAL CITATION
None.
RESPONSIBLE AGENCY/CONTACT Pennit Wattj PlQnning Diroctor
Sweetwater County Planning Department
P. O. Box 791
Green River, Wyoming 82935
(307) 875-2611 ext. 270
ABSTRACT
Specific revisions are proposed for mineral extraction industries, but these have
not been formalized or adopted.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAP TIME
None.
F-78
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION |
Rights-of-Way Approvals
Sweetwater County
LEGAL CITATION
No citation
RESPONSIBLE AGENCY/CONTACT
Sweetwater County Engineer
P. O. Box 632
Green River, Wyoming 82935
(307) 875-2611
ABSTRACT
Approvals for pipeline or other right-of-way crossings and for proposed roads
didicated for public use are administered by the Office of the County Engineer. Normal
procedure is for the applicant to forward a letter detailing his request for review to the
County Engineer.
After this review, the County Engineer forwards his recommendations with the
applicant's letter to the Sweetwater County Board of Commissioners for their formal
approval.
SCHEDULING MILESTONES
Depends on complexity of request.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-79
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Solid Waste Disposal
Sweetwater County
LEGAL CITATION
See State of Wyoming Solid Waste Management Rules and Regulations
RESPONSIBLE AGENCY/CONTACT
Rock Springs-Sweetwater County Solid
Waste District No. 1 Board
Mr. Fermelia, Sweetwater County Engineer
P. O. Box 632
Green River, Wyoming 82935
(307) 362-7519
ABSTRACT
The requirements for Sweetwater County are the State of Wyoming regulations.
No separate county regulations are required.
SCHEDULING MILESTONES |
Not applicable.
PERMIT APPLICATION LEAD TIME |
Not applicable.
F-80
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Rezoning Permit
Rio Blanco County
LEGAL CITATION
Rio Blanco County Ordinance 317.1 et. seq
RESPONSIBLE AGENCY/CONTACT
Glen Payne, County Planner
Rio Blanco County Planning Department
P. O. Box 599
Meeker, Colorado 81641
(303)878-5081
ABSTRACT
Application for an amendment to the ordinance is to be made on a form provided
by the Planning Commission and is to contain the following information: (a) description
of land arpas to be rezoned and requested new classification, along with a sketch to
scale showing boundries of area requested to be rezoned, along with the existing zoning
on all adjacent sides of the area; (b) a statement of justification for the rezoning; (c)
description and sketches of buildings or uses proposed is rezoning is granted, along with
a description of uses within 200 ft of the boundary of the proposed areas of change, in
all directions, and the effect of the proposed use upon the adjacent areas; (d) time
schedule for any contemplated new construction or uses; and (e) justification for any
new business or industrial zoning.
SCHEDULING MILESTONES
Applications are submitted to the Director of the Planning Commission, who may
hold any necessary hearings. Within 30 days after receipt, a recommendation will be
made to the County Commissioners for approval, disapproval, or for an alternate
proposal. At least 30 days notice must be given in a local newspaper before the
hearing.
PERMIT APPLICATION LEAD TIME
At least 60 to 90 days.
F-81
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Temporary Use Permit
Rio Blanco County
LEGAL CITATION
Rio Blanco County Ordinances 306.0 et. sea.
RESPONSIBLE AGENCY/CONTACT
Glen Payne, County Planner
Rio Blanco County Planning Department
Meeker, Colorado 81641
(303)878-5081
ABSTRACT
Upon application to the Zoning Enforcement Officer, a temporary use permit may
be issued for the construction of an office, incidental to construction of other facilities.
The permit is applicable to all Rio Blanco County zones for a period of up to 40 months.
Failure to terminate such temporary use by the specified time shall be considered a
misdemeanor and is punishable under section 314.0 of the Rio Blanco County
ordinances, which dictate the powers of the Board of County Commissioners.
SCHEDULING MILESTONES |
Application must be made to the Director of the Board of County Commissioners
stating the nature of the proposed use. This would most likely be made in conjunction
with the permit for a rezoning or a conditional use.
PERMIT APPLICATION LEAD TIME
Approximately 30 days.
F-82
-------
OIL SHALE PERMIT |
PERMIT TITLE
JURISDICTION |
Conditional Use Permit
Rio Blanco County
LEGAL CITATION
Rio Blanco Countv Ordinances 305.1 et. sea.
RESPONSIBLE
AGENCY/C0NTACT 1 Glen Payne, County Planner
Rio Blanco County Planning Department
P. O. Box 599
Meeker, Colorado 81641
(303)878-5081
ABSTRACT
Conditional uses described under section 305.2 are in part pertinent to mining
applications. Some of the conditions are outlined as follows: (a) water must be kept
out of underground mining workings, and facilities must be designed for this hazard; (b)
disturbance to the surface of the ground shall be minor and limited to air shafts
appropriate and necessary to the underground workings; (c) as new mining techniques or
techniques for refining minerals in place are of an experimental nature, zoning changes
rather than conditional use permits are appropriate, unless it can be shown that surface
efforts are virtually impossible; and (d) mineral research sites are considered conditional
provided that no permanent structures are built and provided that operatons will not
exceed a period of 2 years.
Other conditions are also discussed under the conditional use provisions. The main
goal is that the use should not scar the land and soil or leave such effects as denuded
slopes, uncovered soil piles, or unguarded holes or pits. Surface mining is covered under
other requirements.
SCHEDULING MILESTONES
After the Planning Department is satisfied that the application has been properly
filled out, the Board of County Commissioners shall, in public hearing, after 30 days of
public notice, take action on the recommendations of the Planning Commission. The
application is in two parts: Part I is to be accepted by the Department, and then Part II
is to be mutually reviewed and filled out with the aid of the Planning Department.
PERMIT APPLICATION LEAD TIME
Depends on extent of circumstances. Minimum time, 30 to 60 days.
F-83
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Building Permit
Rio Blanco Countv
LEGAL CITATION
Rio Blanco County Building Code, Chapter 500
RESPONSIBLE AGENCY/CONTACT
Glen Payne, County Planner
Rio Blanco County Planning Department
P. O. Box 599
Meeker, Colorado 81641
(303) 878-5081
ABSTRACT
A building permit is required for the construction of new buildings, the addition,
alteration, repair, or removal of an existing building, or the movement of a building to
another location. Separate permits are required for electrical, plumbing, heating,
ventilation, or air conditioning.
The permit is null and void if work or construction authorized is not commenced
within 120 days, or if construction or work is suspended or abandoned for a period of
120 days at any time after work is commenced.
A permit fee is required and is dependent on the assessed valuation of the building
according to the fee schedule listed in section 504. On industrial and commercial
buildings, an additional 65 percent fee is attached as a plan check fee.
SCHEDULING MILESTONES
Filing of a one-page building permit application.
PERMIT APPLICATION LEAD TIME
Approximately 30 days.
F-84
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
fineeinl Use Permit
Rio Blanco Countv
LEGAL CITATION
Rio Blanco County Ordinance 305.2 as amended (1974) and 1977 section 1000 et. seq.
RESPONSIBLE AGENCY/CONTACT
Glen Payne, County Planner
Rio Blanco County Planning Department
P. 0. Box 599
Meeker, Colorado 81641
(303) 878-5081
ABSTRACT
The Special Use Permit provides for mining operations, open mining, and
prospecting on land within the county that is zoned A (agricultural), H-I (heavy
industrial), and O (open district), upon approval by the Board of County Commissioners..
An impact analysis statement will be required with the application unless specifically
exempt by the Board of County Commissioners. The statement shall include such
information as short and long-term description of impacts, mitigating measures, and
alternatives to the proposed action; it is in essence a small EIS. Detailed requirements
include a mining plan, water, wildlife, revegetation actions, air, water, and waste
problems expected and the solutions to these problems.
SCHEDULING MILESTONES
The Planning Department will review the application for completeness of infor-
mation. Public hearing is held after a 30-day public notice by the Board of County
Commissioners. In determining completeness of application, the Planning Department
may hold one or more special sessions to review the application.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-85
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Sewage Disposal
Rio Blanco Countv
LEGAL CITATION
Rio Blanco County Ordinances, 1974 Chapter 800 Section 803.3
RESPONSIBLE AGENCY/CONTACT
Glen Payne, County Planner
Rio Blanco County Planning Department
P. O. Box 599
Meeker, Colorado 81641
(303) 878-5081
ABSTRACT
Before commencing construction, any person who wishes to install, alter, or repair
a sewage disposal system must obtain a permit from the Health Officer. The permit
asks for information pertinent to the location of the facility and characteristics of the
water, soil, and groundwater of the area.
This permit is only for systems of less that 2,000 gal of sewage/day. In the case
of any system with a design capacity over 2,000 gal/day, or which discharges into State
waters, or which is designed to serve 20 or more persons per day, the County Planning
Department may give its conditional approval or may disapprove the application.
Thereafter, the application, with the Department's recommendation, shall be forwarded*
to the Water Quality Control Commisiion for its review.
SCHEDULING MILESTONES
A Registered Professional Engineer acting on behalf of the Department shall
determine the type or types of disposal systems suitable for the property.
PERMIT APPLICATION LEAD TIME
Depends on size of system.
F-86
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Solid Waste Disposal Permit
Rio Blanco Countv
LEGAL CITATION
None
RESPONSIBLE AGENCY/CONTACT nion p
Rio Blanco County Planning Department
P. O. Box 599
Meeker, Colorado 81641
(303) 878-5081
ABSTRACT
Industry's plans for solid waste disposal submitted to the State are reviewed by a
county-selected engineering firm for completeness and accuracy. Industry is allowed to
select their own disposal site upon approval of the engineers, the State, and county
officials and residents. A public hearing at the county level is required. No formal
requirements or regulations exist currently at the county level.
SCHEDULING MILESTONES
Depends on extent of wastes and whether or not they involve hazardous materials.
PERMIT APPLICATION LEAO TIME
Depends on materials.
F-87
-------
OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Conditional Use Permit
Garfield County
LEGAL CITATION
Garfield County Zoning Resolution Sections 4.03 and 7.02
RESPONSIBLE AGENCY/CONTACT
Ray Baldwin, Planning Director
Gafield County Planning Department
2014 Blake Avenue
Glenwood Springs, Colorado 81601
(303)945-8212
ABSTRACT
The Conditional Use Permit applies to, but is not limited to, the
following: (a) utilities that are adequate to provide water and sanitation service based
on accepted engineering standards and approved by the Environmental Health Officer
and the Colorado State Department $f Health and that are either in place or to be
constructed in conjunction with the proposed use; (b) industrial operations, including
extraction, processing, water impoundments, and mineral waste disposal; (c) mobile
home as an accessory to a working operation; (d) aircraft landing; (e) street improve-
ments adequate to accommodate traffic volume generated by the proposed use and to
provide safe and convenient access; and (f) design of the proposed use to minimize
impact on and from adjacent uses of land.
In addition to this permit, an applicant for a permit for industrial operations is
required to submit to the Building Official two copies of an impact statement on the
proposed use, prescribing its location, scope, design, and construction schedule,
including explanation of operational characteristics. The statement shall show that the
use shall be designed and operated in compliance with all applicable laws and
regulations of the County, State, and Federal governments, and will not have significant
adverse impacts. Satisfactory land rehabilitation plans for the affected areas must also
be submitted.
SCHEDULING MILESTONES^ the industrial operations section applies and
an
impact statement is required, then the County Commissioners have 30 days to notify
the Building Official of their decision. A request for additional information may be
made before the 30-day limit. The County Commissioners shall then have an additional
30 days for review and subsequent decision.
PERMIT APPLICATION LEAD TIME
At least 60 to 90 days.
F-88
-------
OIL SHALE PERMIT
PERMIT TITLE
Special Use Permit
LEGAL CITATION
Garfield County Zoning Resolution Sections 4.03 and 7.03
RESPONSIBLE AGENCY/CONTACT! nn„ n . D. ' ~ "
Ray Baldwin, Planning Director
Garfield County Planning Department
2014 Blake Avenue
Glenwood Springs, Colorado 81601
(303) 945-8212
ABSTRACT
Application and requirements for a Special Use Permit are very similar to those
for the Conditional Use Permit. Applicants should seek assistance of the Director in
determining necessary filing requirements. Basically, the application for a special use
permit consists of: (a) supporting information, plans, letters of approval from
responsible agencies, and other information to satisfy requirements listed under
Conditional and Special Uses in Section 4.03 et seq. of the regulations; (b) a vicinity
map drawn to scale depicting the subject property, location of roads providing access to
the subject property, location and use of buildings and structures and adjacent lots, and
the names of owners of record of such lots, and (c) a letter to the County
Commissioners from the applicant explaining in detail the nature and character of the
special use requested.
SCHEDULING MILESTONES
The County Commissioners shall decide no later than 30 days following the
receipt of the application and the recommendation of the Building Official, and if no
negative public comments are received resulting from public hearing. The County
Commissioners shall approve or deny the application and notify the applicant of its
decision within 15 days following the public hearing.
PERMIT APPLICATION LEAD TIME
At least 60 days.
JURISDICTION
Garfield County
F-89
-------
OIL SHALE PERMIT
PERMIT TITLE
Sewage Disposal System
JURISDICTION
Garfield County
LEGAL CITATION
Garfield County Sewage Disposal Regulations
RESPONSIBLE AGENCY/CONTACT
Ray Baldwin, Planning Director
Garfield County Planning Department
2014 Blake Avenue
Glenwood Springs, Colorado 81601
(303)945-8212
ABSTRACT
These regulations are designed to comply with the guidelines as adopted by the
Colorado Board of Health pursuant to 66-44-4, C.R.S., 1963.
Before commencing construction, any person who wishes to install, alter, or repair
an individual sewage disposal system in Garfield County is required to obtain a permit
from the Health Officer. The permit shall contain the following information: (a) legal
description of the property, (b) owners(s), agents, and contractors names, addresses, and
phone numbers, (c) plot plan and size area, (d) type of buildings, water supply, and soil
or soil classification, (e). soil percolation or hydraulic conductivity tests when necessary
to the design of the disposal system, (f) location of bedrock and groundwater table, (g)
type and design of the disposal system, and (h) other pertinent information, as may be
required by the Health Officer.
After receiving an application form, a Registered Professional Sanitarian or
Registered Engineer shall have the perogative to visit the applicant's property to make
a preliminary investigation on behalf of the department.
Any system that has a design capacity over 2,000 gal/day, or that discharges into
State waters, or that is designed to serve more than 20 persons/day may subject to
approval by the State Water Quality Control Commission.
SCHEDULING MILESTONES
Depends on size of facility and whether situation involves county or State
approval.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-90
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Solid Waste Disposal
Garfield County
LEGAL CITATION
None
RESPONSIBLE AGENCY/CONTACT T,J „ x .
Ed Feld, Wastes Division
Garfield County Planning Department
2014 Blake Avenue
Glenwood Springs, Colorado 81601
(303) 945-8212
ABSTRACT
A solid waste site designation from commissioners is required with a $25 charge.
A form is available from the Wastes Division. Information to be submitted includes
proposed work, quantity of wastes, duration of dumping, proximity to streams and
groundwater sources, etc.
SCHEDULING MILESTONES
No public hearing is required. Processing time depends on situation.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-91
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OIL SHALE PERMIT
PERMIT TITLE
Installation of Utilities in Public Right-of-Ways
JURISDICTION
Garfield County
LEGAL CITATION
None
RESPONSIBLE AGENCY/CONTACT
Leonard Bowlby
Garfield County Planning Department
2014 Blake Avenue
Glenwood Springs, Colorado 81601
(303) 945-8212
ABSTRACT
Application form is available for a construction for installation of utilities in
public right-of-ways. Needed for the form is location and description of work.
Applicant will be responsible for repairs and maintanence of areas for 1 year.
SCHEDULING MILESTONES
No public hearing is involved. The final location will be mutually agreed on by
applicant and Board of Commissioners in accordance with details and specifications
shown on construction plans.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-92
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Driveway Permit Across County Roads
Garfield County
LEGAL CITATION
None
RESPONSIBLE AGENCY/CONTACT
Leonard Bowlby
Garfield County Planning Department
2014 Blake Avenue
Glen wood Springs, Colorado 81601
(303) 945-8212
ABSTRACT
A driveway approach is that portion of the highway right-of-way between the
pavement edge and the property line that is designed and used for the interchange of
traffic between the roadway pavement and the abutting property. Any driveways and
approaches must be paid for and maintained for 1 year by the applicant. This applies
only to county roads.
SCHEDULING MILESTONES
Depends on situation. No public hearing is required unless the request is unusual.
PERMIT APPLICATION LEAD TIME
Depends on situation.
F-93
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OIL SHALE PERMIT
PERMIT TITLE
JURISDICTION
Recreation Forest and Mining Zone
(RF&M) - definition and control
Uintah Cnnntv
LEGAL CITATION
Uintah County Zoning Ordinance No. 3-71 Section 02.0871 - 02.0878
RESPONSIBLE AGENCY/CONTACT T„ AJ . . ^ A
Jess Miller, Administrator
Uintah County Planning <5c Zoning Board
220 South 500 Street
Vernal, Utah 84078
(801) 789-4302
ABSTRACT
The Recreation Forest and Mining zone contains some deeply buried oil shale in
the facia interbedding of the Green River and Wasatch formations in the north-west
portion of the county. The zone is generally mountainous in an unincorporated area. It
also has grazing lands, ranches, resorts, outdoor recreational facilities, and mines and
related facilities. The following are some of the uses permitted in the zone:
(1) Wells, mining, extraction, processing and reduction of minerals, and
buildings, structures, and related facilities.
(2) Reservoirs, ponds, dams, power plants, transmission lines, and substation,
water pumping plants and pipelines, and public utility buildings and
structures.
(3) Water supply and sewage disposal in compliance with the Department of
Health Requirements (State).
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F-94
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OIL SHALE PERMIT
PERMIT TITLE „
[ining and Grazing Zone (M&G-l)
efinition and Control
JURISDICTION
D
Uintah County
LEGAL CITATION
Uintah County Zoning
Ordinance No. 3-71 Section 02.0860 - 02.0863
RESPONSIBLE AGENCY/CONTACT
Jess Miller, Administrator
Uintah County Planning and Zoning Board
220 South 500 East
Vernal, Utah 84078
(801) 789-4382
ABSTRACT
The mining and grazing zone encompasses most of the oil shale area suitable for
the near future development. The zone is characterized by large tracts of desert and
open-range land, with an occasional mine, cabin, dwelling, and/or corral incidental to
livestock operations. The following are permitted in this zone:
(1) Open-pit mines, mine waste dumps, underground mines, and buildings and
structures associated with mines and mine dumps.
(2) Storage and use of explosives, provided all activities are located at least 300
ft from a public street or building.
(3) Mineral reduction and processing plants.
(4) Sewerage treatment plants subject to approval by the Board of Adjustment
and State Department of Health.
(5) Reservoirs, dams, sumping plants, and water facilities.
(6) Other uses ruled by the Board of Adjustments to be harmonious with the
objectives and characteristics of the mining and grazing zone.
SCHEDULING MILESTONES
None.
PERMIT APPLICATION LEAD TIME
None.
F-95
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OIL SHALE PERMIT
PERMIT TITLE r.n
unty Requirements in Addition to the
&G-1) and Recreation Forest and Mining
ements
JURISDICTION
Mining and Grazing (M
(RF&M) Zonincr Reauir
Uintah Countv
LEGAL CITATION
Uintah County Z
[miner Ordinance 3-71
RESPONSIBLE AGENCY/CONTACT
Jess Miller, Administrator
Uintah County Planning and Zoning Board
220 South 500 East
Vernal, Utah 84078
(801) 789-4382
ABSTRACT
The county requires building permits, business licenses, and water and sewer
facilities to be approved by the State Board of Health. Site selection requirements and
approvals are required by the State Site Selection Committee in Conjunction with the
developer. The final site will be chosen from an alternative list approved by the
Committee.
Mining permits and plans for mined land reclamation, including dumps, are issued
by the State Division of Oil, Gas, and Mining, except where coal is involved on Federal
lands.
Air quality in most of the area zoned M&G-l is unclassified and would require a
State Air Quality Committee and or a Board of Health discharge permit.
SCHEDULING MILESTONES
See State requirements.
PERMIT APPLICATION LEAD TIME
None.
F-96
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