DAQ-2024-007579

1

DAQC-362-24
Site ID 12825 (B5)

MEMORANDUM

TO: CEM FILE – UTAH ASSOCIATED MUNICIPAL POWER SYSTEMS (UAMPS)

THROUGH: Harold Burge, Major Source Compliance Section Manager

FROM: Rob Leishman, Environmental Scientist

DATE: April 18, 2024

SUBJECT: Source: Nebo Generating Facility Natural Gas Turbine Generator
Contact: Dave Gammell (Plant Manager) – 801-925-4012
Cheyney Guymon – 801-794-2950
Location: 1265 Bamberger Road, Payson, Utah County, UT
Test Contractor: Montrose Air Quality Services, LLC
FRS ID#: UT0000004904900234
Permit/AO#: Title V operating permit 4900234004 January 18, 2022
Subject: Review of RA/PST Protocol dated April 9, 2024

On April 12, 2024, Utah Division of Air Quality (DAQ) received a protocol for a RA/PST (relative
accuracy/performance specification test) of the UAMPS Nebo power station in Payson, Utah. Testing will
be performed on May 29, 2024, to determine the relative accuracy of the O2, CO2, NOX, and CO
monitoring systems.

PROTOCOL CONDITIONS:

1. RM 3A used to determine dry molecular weight of the gas stream: OK
2. RM 7E used to determine NOX concentrations of emissions: OK
3. RM 10 used to determine CO concentrations of emissions: OK
4. RM 19 used to determine volumetric flow: OK

DEVIATIONS: No deviations were noted in the protocol.

CONCLUSION: The protocol appears to be acceptable.

RECOMMENDATION: Send attached protocol review and test date confirmation notice.

1 8 2
LTTAH DEPARTMENT OF
ETURONMENTAL QUATTTY
APR 12 2C?-4
DIVTSION OF AIR QUALITY
MM?HT+fiIH
,.PRETEST PROTOGOL TO CONDUCT EPA COMPLIANCE
TESTTNG FOR CONTTNUOUS EMTSSIONS MONITORS (CEM)
RELATIVE AGCURAGY TEST AUDITS (RATAS) ON UTAH
ASSOCTATED MUNTCTPAL POWER SYSTEMS (UAMPS) NEBO
GE FRAME 7EAIHRSG GAS.FIRED TURBINE AT THE PAYSON,
UTAH GENERATING STATION."
UDEQ Title V Air Quallty Permit Number: 4900234004
Proposed Test Dates: |{,ay 29,2024
MONTROSE AIR QUALITY SERVIGES, LLC.
6823 South 3600 West
Spanish Fork, Utah 84660
(801) 794-2e50
April 9, 2024
SOURCE INFORMATION
Facility Name: Utah Association of Municipal Power Systems (UAMPS)
Units to be tested: GE Frame 7EA dHSRG Unit
(Natural Gas-Fired Combined Cycle Combustion Turbine)
Mailing Address: UAMPS
155 North 400 West, Suite 480
Salt Lake City, Utah 84103
PlantAddress: NEBO Power Station
1265 N. Bamberger Road
Payson, Utah 84651
AIRSS lD No. 49-049-00234
ORISPL No.56177
UDEQ Title V Operating Permit No. 4900234004
Phone: [phone]
Plant Contact: Mr. Dave Gammell, PIant Manager
Test Date: May 29,2024
CONTRACTOR OR TEST FIRM
Name: Montrose Air Quality Services, LLC.
Address: 6823 South 3600 West, Spanish Fork, Utah 84660
Phone: [phone]
Contact Gheyney Guymon, Field Project Manager MAQS
Email : chg [e-mail]
Document Number: GP081AS-039393-PP-830
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Servlces, LLC.
Pretest Protocol - Apnl 2024
REASON FOR TESTING AND OPERATING PERMIT EMISSION
LIMITATIONS
The current Title V Operating Permit (UDEO No. 4900234004 - dated January
18,2022) mandates that annual testing be conducted (see Section ll: Special
Provisions) for flow, CO, NOr, and Oz. A copy of the Title V Operating Permit is
included in Appendix'4".
Parl 75 of the Code of Federal Regulations (CFR) requires that Relative
Accuracy Test Audits (RATAs) be conducted on the following emissions
analyzer on the GE Frame 7EA Gas Turbine/HSRG Unit at least once every
four operating quarters:
A. Oxides of Nitrogen (NOx)
Part 60 of the Code of Federal Regulations (CFR) requires that Relative
Accuracy Test Audits (RATAs) be conducted on the following emissions
analyzer on the GE Frame 7EA Gas Turbine/HRSG Unit be quantified
annually:
A. Carbon Monoxide (CO)
EPA TEST METHODS REQUIRED
Gas Analysis
1. Reference Method: EPA Method 3A
2. The 02 analyzer used in the CEM system has a range of O-25o/o
Nitrogen Oxide Emissions
1. Reference Method: EPA Method 7E
2. NEBO has a dual range NO, Analyzer for their CEMs instrument.
The ranges are 0-20 ppm and 0-200 ppm. The applicable
standard is 97.12 ppmdv when the turbine is operated in
combined or simple cycle mode.
C. Carbon Monoxide Emissions
1. Reference Method: EPA Method 10
2. The CO analyzer used for the CEM system is also a dual range
instrument, 0-100 ppm and 0-1000 ppm. The applicable
standard for this emission is 25.0 ppmdv corrected to 15.0% Oz
when operated in simple cycle and 10.0 ppmdv when the turbine
is operated in a combined cycle mode.
D. Nitrogen Oxides Mass Emission Rates
1. Reference Method: EPA Method 19
A.
B.
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Sewices, LLC.
Pretest Protocol - Apnl 2O24
Relative Accuracy Test Audit (RATA) for NOx
1. Reference Method: EPA Performanoe Specification (PS) 2. The
Relative Accuracy for the NOx analyzer needs to be less than
7 .5o/o (on an annual basis).
Relative Accuracy Test Audit (RATA) for Oz and COz
1. Reference Method: EPA Performanc,e Specification (PS) 3. The
relative Accuracy for the Oz analyzer needs to be Iess than 7.5o/o
(on an annual basis).
Relative Accuracy TestAudit (RATA) for CO
1. Reference Method: EPA Performance Specification (PS) 4a
a). Stratification Verifi cation Tests.
Prior to starting the Relative Accuracy Test Audits (RATA) MAQS wil!
conduct a "stratification Evaluation". The stratification, as outlined in
40CFR75, Appendix A 6.5.6.1 was completed for the Iocation of the
GEMs probe during the 2008' testing that conducted on site. MAQS
will complete a stratification evaluation for the location of the traverse
points for the RATA testing. Sampling locations will be determined
after the stratification tests are completed.
bl. Relative Accuracv Test Audit.
MAQS will use EPA Reference Methods 3A, 7E and 10 to check the
relative accuracy of the UAMPS CEMs. MAQS will run up to twelve
(12) twenty-one (21) to thirty (30) minute tests depending on our
response time. Reference Method results will be compared with the
UAMPS reading of the same time frame. From these comparisons the
relative accuracy of UAMPS analyzers will be calculated using a
standard spread sheet. The NOx will be reported in ppm corrected to
15o/o Oz and in lbs./MMBtu. The CO wil! be reported in ppm corrected
to 15.0olo Oz.
EPA Methods 3a, 7E and 10 are instrumentation methods. This sample train
incorporates taking a sample line from the stack, conditioning the sample, and
finally running it through the analyzer. Figure I is a schematic of the analyzer
sample train, showing both the sample line location and the calibration line
Iocation.
E.
F.
(r-
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Qualfi Services, LLC.
Prctest Protocol - Apfl 2024
Contl nuous Ernissions Antl Uzars
Exhaust Stack
Sample Poi nt:T
Moisture
IHp-
Crli bration Gas l-'lanifold
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Tubine/HSRG
Montrose Air Quality Seruices, LLC.
Pretest Pmtocol - Apnl 2024
CALIBRATION DATA AND SAMPLE CALCULATION
The EPA and State agencies require various calibrations for specific equipment
used during testing. The current calibration data is included in Appendix uB". A
sample of all field data forms will be made available at the job site.
REFERENCE METHODS
The methods that will be employed are found in 40 CFR Part 60 - Appendix A,
and the EPA 'Quality Assurance Handbook for Air Pollution Measurement
Systems." Any deviation from these methods will first be approved by the
administrator.
STACK SCHEMATIC AND TRAVERSE POINT LOGATIONS
Attached are the schematics showing plan and elevation of ducting and stack
arrangements including sample port positions relative to upstream and
downstream disturbances. Also included are cross-sectional sketches of the
stack at the sampling locations.
Figure ll is a stack diagram of the GE Frame 7EA Gas Turbine/HRSG Unit
at the Payson Generating Facility.
Traverse point locations for the GE Frame 7EA Gas Turbine/HSRG Unit
are shown in Table l.
1.
2.
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Services, LLC.
Pretest Protocol - April 2024
Fiqure II
UAMPS - NEBO Power Plant 6 Montrose Air Quality Services, LLC.
GE Frame 7EA Combined Cycle Turbine/HSRG Pretest Protocol-Apnl2O24
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574.5" =A= 2.90 Dameters
125.5' = B = 6.20 D[ameters
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[_1e8"___-_l
o
4 Ports
Located 90 degrees
apart from each other
4'l.D.
4" Long
Table I
Plani:
Date:
Source:
Distance X:
Distance Y:
Stack l.D:
Stack Area:
#of
UAMPS
414t2024
GE Frame 7EA Turbine
202.5 in
4in
198.5 in
214.91 tr2
Traverse Points:24 sample locations
Traverse
Point
Number
Percent of Stack l.D. Product of
Stack l.D. inches col.2 &3
(to 1/8 in)
Distance
Y
(inches)
Traverse Point Loction from outside
of ports (sum of columns 4 & 5)
1,7,13 & 19
2,8,14 &20
3, 9,15 & 21
4,10,'.t6 &22
5, 11, 17 & 23
6,12,18 &24
2.1
6.7
11.8
17.7
25
35.6
198.5
198.5
198.5
198.5
198.5
198.5
4.17
13.30
23.42
35.13
49.63
70.67
4
4
4
4
4
4
8.17 = 8114
17.30 = 17 114
27.42 = 27 318
39.13 = 39
53.63 = 53 5/8
74.67 = 74 518
inches
inches
inches
inches
inches
inches
SAFETY CONSIDERATIONS AND OTHER REQUIREMENTS
Alltesting stations will be accessible from OSHA scatfolding or platforms. MAQS
will require 1 - 480V, 30 amp, three-phase circuits to be provided by UAMPS in
order to perform the emissions testing.
Montrose will comply with all safety requirements at the facility. The facility plant
safety coordinator is responsible for ensuring routine compliance with plant entry,
health, and safety requirements. The facility plant site safety coordinator has the
authority to impose or waive facility restrictions. The Montrose test team leader
has the authority to negotiate any deviations from the facility restrictions with the
plant site safety coordinator. Any deviations must be documented.
Montrose has a comprehensive health and safety program that satisfies State
and Federal OSHA requirements. The program includes an Illness and lnjury
Prevention Program, site-specific safety meetings, and training in safety
awareness and procedures. The basic elements include:
. Written policies and procedures
o Routine training of employees and supervisors
o Use of personal protection equipment (PPE)
. Hazard communication
. Pre-test and daily safety meetings
UAMPS - NEBO Porer PIaNt
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Services, LLC.
Pretest Protocol - April2024
o Routine surveillance and inspection of on-going work
r Near-miss and accident reporting procedures
o Following Federal Motor Carrier Safety Administration
(FMCSA) regulations, as applicable
Montrose will provide all PPE to its employees. The PPE wil! include, but is not
limited to; hard hats, safety shoes, safety glasses with side shields (or goggles),
hearing protection, and hand protection
All on-site personnel will adhere to the following standard safety measures:
. All OSHA and facility mandated safety training and
accreditation will be completed before arrival. This will include
MSHA, OSHA 1O-hr, TWIC, AerialWork Platform, etc., as
required.
. Complete any site-specific training as necessary
. Complete Site Safety Plan before work activities begin
. Daily Tool Box Meetings
o Confine themselves to the testing and administration areas
only
. Wear all mandated PPE & Know the location of flrst aid and
fire extinguishers
o Know the location of first aid equipment and fire extinguishers
OTHER COMMENTS. RECOMMENDATIONS. OR PROPOSED
MODIFICATIONS
1. An "S" Type Pitot Tube will be used to measure the velocity of the gas
stream using EPA Method 2 (if the stack is 12.0" inches or greater). An
inclined manometer will be used to measure the velocity head. The first
mark on the manometer is 0.01 inches of water column from the zero
mark. For sources where the velocity head is less than 0.05 inches of
water column, or where the stack diameter is less than 12 inches, MAQS
will use a Standard Pitot with an expanded manometer.
2. EPA Method 3A will be used to determine the dry molecular weight of the
gas stream. The gas analysis will be conducted at the job site using
oxygen and carbon dioxide analyzers.
3. Barometric pressure will be measured at the sampling position via an
aneroid barometer.
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Seruices, LLC.
Pretest Protocol - Apfl 2024
4.
5.
For the RATA requirements, at least nine (9) CEM runs and up to twelve
(12) will be conducted to determine relative accuracy of the NOx, CO and
Oz analyzers in the GE Frame 7EA exhaust stack. These runs will be
twenty-one (21) and thirty (30) minutes in length depending on analyzer
response times.
The test team will consist of the Beckie Hawkins District Manager project
oversight, one Client Project Manager and two Field Technicians. The
CIient Project Manager is responsible for overseeing sample and data
collection, while the Fietd Technicians work at the sample location. lt is
anticipated that Cheyney Guymon, will be assigned to the role of Client
Project Manager. The staff assignment for the Field Technicians positions
will be Austin Tramell lead and one other qualified technician. The team
will be fully qualified to perform all test methods listed in this test plan.
Montrose converts the raw field, laboratory, and process data to reporting
units consistent with the permit or subpart. Calculations are made using
proprietary computer spreadsheets or data acquisition systems. One run
of each test method is also verified using a separate example calculation.
The example calculations are checked against the spreadsheet results
and are included in the final report. The "Standard Conditions" for this
project are 29.92 inches of mercury and 68 "F. Both qualitative and
quantitative factors contribute to field measurement uncertainty and
should be taken into consideration when interpreting test results.
Whenever possible, Montrose Air Quality Services personnel reduce the
impact of these uncertainty factors using approved and validated test
methods. In addition, Montrose personnel perform routine instrument and
equipment calibrations and ensure that the calibration standards,
instruments, and equipment used during test events meet, at a minimum,
test method specifications as well as the specifications of our Quality
Management System and ASTM D 7036-04. The limitations of the various
methods, instruments, equipment, and materials utilized during a test are
reasonably considered, but the ultimate impact of the cumulative
uncertainty for each project cannot be fully identified.
Montrose will prepare a final report to present the test data,
calculations/equations, descriptions, and results. Prior to release by
Montrose, each report will be reviewed and certified by the project
manager and their supervisor, or a peer. Source test reports will be
submitted to the facility or appropriate regulatory agency (upon client
approval) within 30 days of the completion of the field work. The report will
include a series of appendices to present copies of the intermediate
calculations and example calculations, raw field data, laboratory analysis
data, process data, and equipment calibration data.
6.
7.
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Services, LLC.
Pretest Protocol - Apfl 2024
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DATA ANALYSIS. VALIDATION. AND UNCERTAINTY
Montrose converts the raw field, laboratory, and process data to
reporting units consistent with the permit or subpart. Calculations
are made using proprietary computer spreadsheets or data
acquisition systems. One run of each test method is also verified
using a separate example calculation. The example calculations
are checked against the spreadsheet results and are included in
the final report. The "Standard Conditions' for this project are 29.92
inches of mercury and 68 'F.
Both qualitative and quantitative factors contribute to field
measurement uncertainty and should be taken into consideration
when interpreting test results. \A/henever possible, Montrose Air
Quality Services personnel reduce the impact of these uncertainty
factors using approved and validated test methods. ln addition,
Montrose personne! perform routine instrument and equipment
calibrations and ensure that the calibration standards, instruments,
and equipment used during test events meet, at a minimum, test
method specifications as well as the specifications of our Quality
Management System and ASTM D 7036-04. The limitations of the
various methods, instruments, equipment, and materials utilized
during a test are reasonably considered, but the ultimate impact of
the cumulative uncertainty for each project cannot be fully
identified.
QUALITY STATEMENT
Montrose is qualified to conduct this test program and has
established a quality management system that led to accreditation
with ASTM Standard D7036-04 (Standard Practice for Competence
of Air Emission Testing Bodies). Montrose participates in annual
functional assessments for conformance with D7036-04 which are
conducted by the American Association for Laboratory
Accreditation (A2LA). All testing performed by Montrose is
supervised on site by at least one Qualified lndividual (Ql) as
defined in D7036-04 Section 8.3.2. Data quality objectives for
estimating measurement uncertainty within the documented limits
in the test methods are met by using approved test protocols for
each project as defined in D7036-04 Sections 7.2.1 and 12.10.
Additional quality assurance information is included in the report
appendices. The content of this report is modeled after the EPA
Emission Measurement Center Guideline Document (GD-043).
UAMPS - NEBO Power Plant
GE Frame 7EA Combined Cycle Turbine/HSRG
Montrose Air Quality Services, LLC.
Pretest Protocol - Apil 2024
10
ffi Department of
Environmental Quality
KimbcrlyD, Shelley
Executive Directo, 1,2g25
DWISION OF AIR QUALITY
Bryce C. Bird
Director
State of Utah
SPENCERJ. COX
Govertor
DEIDRE IIENDERSON
Lieutenant Govemor
Title V Operating Permit
PERMIT NUMBER: 4900234004
DATE OX'PERMIT: January 18,2022
Date of Last Revision: January t8,2022
This Operating Permit is issued to, and applies to the following:
Name of Permittee:
Utah Assoc. Municipal Power Systems
155 North 400 West, Suite 480
Salt Lake Ciry, UT 84103
UTM coordinates:
SIC code:
437,750 m Easting, 4,434,700 m Northing
491 1 (Elecfic Services)
Permitted Location:
Nebo @ayson) Power Plant
1265 BarnbergerRd
Payson, UT 84651
Prepared By:
Jennifer He
[e-mail]
By:
,4rr>l
Bryce C. Bird, Director
195 Norlh 1950 Wsst . S.lt Irke City, tlT
Mailing Ad&c.ss: P.O. Box ltt4820 . Salt Late City, UT 84114-4820
Telcphom (801) 53il000 . Fu (801) s364099 . T-D-D. (80D 903-3978
www,deq,uuh,gov
Prinrd on 100/o rccycledpaper
ENT'ORCEABLE DATES AND TIMELII\-ES
The following dates or timeframes are referenced in
Section I: General Provisions of this pernrit.
Annuat Cefiification Due: January 30 of every calendar year that this permit is in force.
Renewal application due:
Permit expiration date:
July 18,2026
January 18,2027
Definition of "prompf': written notification within 14 days.
ABSTRACT
Utah Associated Municipal Power Systems operate an electric generating facility, udffu a nqminal elechic output
of 141 MW, on the north end of Payson, Utah County. The facility utilizes a natural gas-fired combustion
turbine generator (CTG) operating either in simple cycle mode or in a combined-cycle mode with a heat
recovery steam generator (IIRSG) and a steam turbine. The HRSG is equipped with a supplemental,
intermittent-fired duct burner with maximum heat input capacity of 312 million British Themral Units @TtI)
perhour. The ptant is subjectto 40 CFR 60, Subpart GG (Standards of Performance for Stationary Gas
Tr:rbines) and Subpart Da (Standard of Performance for Electric Utility Steam Generating Units for which
Constuction is Commenced after September 18, 1978) and 40 CFR 63 Subpart TZZZ (National Emission
Standaxds for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines). The plant
is a Phase tr Acid Rain source.
Project OPP0128250008 Page 2 Title V Operating Permit #f4900234004
OPERATING PERMIT IIISTORY
PermiUActivitv Date Issued Recorded Chanees
Title V renewal application
(Proi ect #OPP 0 12825 0008 )
Ur8t2022 Changes: Minor changes on the rule's citations
Title V administative
amendment - enhanced AO
(Froiect #OPP0 I 28250006)
08t2112017 Changes: to incorporate changes approved under AO
DAQE-ANI 28250007 -17, dated lvne 14, 2017
Title V renewal application
(Project #OPP0 1 28250005)
0112412017 Changes: minor changes in conditions II.B.2.c.3 and
II.B.3.b.3 regarding the excess emission reporting
Title V renewal application
(Froject #OPP0 1 28250004)
tr/t6t20rl Changes: NESHAP ZZZZrequkements are included in the
renewal permit.
Title V initial application
0roiect #OPP0 128250001)
0710y2006 Chenges: Enter project description here.
Project OPP0128250008 Page 3 fitle V Operating Permit tf4900234004
Table of Contents
EIM'ORCEABLE DATES A}[D TIMELII{ES
ABSTRACT....
OPERATING PERMIT HISTORY
SECTION I: GENIERAL PROVISIONS................
Administative Permit Amendments .....'...9
Title IV and Other, More Stringent Requirements ........12
SECTION II: SPECIAL PROYISIONS............... .........................13
Emission Unit(s) Pennitted to Discharge Air Contaminants. ............ ............... 13
Conditioru on Permitted Source (Source-wide) ............13
Conditions on GE Frame 7-EA Generator (in Simple Cycle Mode) @missiou Unit #1). ..............17
Condition on GE Frame 7-EA Generator (in Combined Cycle Mode) @mission Unit#2). ................................21
Conditions on Emergency Generator @mission Unit #3)................ .........................25
SECTION Itr: PERMIT SHTELD
SECTION IV: ACID RAIN PROVISIONS 31
Utah Acid Rain Program Authority. .......31
Recordkeepiug aud Reporting Requirements ................32
REVIEWER COMMENTS
2
t
Project OPP0128250008 Page 4 Tttle V Operating Permlt M900234A04
I.A
Issued under authority of Utah Code Ann. Section 19-2-104 and 19-2-109.1, and in accordance with
Utah Administrative Code R307-415 Operating Permit Requirements.
All definitions, terms and abbreviations used in this permit conform to those used in Utah Administrative
Code R307-l0l and R307-415 @ules), and 40 Code of Federal Regulations (CFR), except as otherwise
defined in this permit. Unless noted otherwise, references cited in the permit conditions refer to the Rules.
Where a permit condition in Section I, General Provisions, partially recites or summarizes an applicable
rule, the full text of the applicable portion of the rule shall govern interpretations of the requirements of the
rule. In the case of a conflict between the Rules and the pennit terms and conditions of Section tr, Special
Provisions, the permit terms and conditions of Section tr shall govern except as noted in Provision I.M,
Permit Shield.
SECTION I: GENERAL PROYISIONS
Federal Enforcement.
All terrrs and conditions in this permit, including those provisions desigued to limit the
potential to emit, are enforceable by the EPA and citizens under the Clean Air Act of 1990
(CAA) except those terms and conditions that are specifically designated as "State
Requirements". (R30741 5-6b)
Permltted Actlvitv0es).
Except as provided in R307415-7b(1), the permittee may not operate except in compliance
with this permit. (See also Provision I.E, Application Shield)
Dutv to Complv.
The permittee must comply with all conditions of the operating permit. Any pennit
noncompliance constitutes a violation of the Air Conservation Act and is grounds for any of
the following: enforcement action; permit termination; revocation and reissuance;
modification; or denial of a pennit renewal application. (R307415-6a(6Xa)
It shall not be a defense for a permittee in an enforcement action that it would have been
necessary to halt or reduce the permitted activity in order to maintain compliance with the
conditions of this permit. (R3074154a(6Xb)
The perrnittee shall furnish to the Director, within a reasonable time, any information that
the Director may request in writing to determine whether cause exists for modiffing,
revoking and reissuing, or terminating this permit or to determine corrpliance with this
pemrit. Upon reguest, the permittee shall also funrish to the Director copies ofrecords
required to be kept by this permit or, for information claimed to be confidential, the
permittee may fumish such records directly to the EPA along with a claim of
confidentiality. (R30741 5-6a(6)(e))
This permit may be modified, revoked, reopened, and reiszued, or terminated for cause.
The filing of a request by the permittee for a permit modification, revocation and
reissuance, or temrination, or of a notification of planned changes or anticipated
noncorrpliance shall not stay any permit condition, except as provided under R307415-
7f( 1) for minor permit modifi cations. (R3 07-4 I 5-6a(6)(c))
Permit Exoiration and Renewal.
I.B
I.C
I.C.1
r.c.2
I.C.3
1.C.4
I.D
Project OPP0128250008 Page 5 Tifle V OperatingPermit j#l900234i.D04
I.D.l This permit is issued for a fixed term of five years and expires on the date shown under
"Enforceable Dates and Timelines" at the front of this permit. (rc07a15-6a(2))
1.D.2 Application for renewal of this permit is due on or before the date shown under
"Enforceable Dates and Timelines" at the front of this permit. An application may be
submitted early for any reason. (R307415-5a(1)(c))ID3 *#,:l?J}*:-:ffi:ff:if;li:1;lr"n:*::.1t,1l:"!,'"ilt3;?#ffi#lllt
relieve the perrrittee of any enforcement actions resulting from submitting a late
application. (H07a 1 5-5a(5))
I.D.4 Permit expiration terrninates the permittee's right to operate unless a timely and complete
renewal application is submitted consistent with R307415-7b (see also Provision I.E,
Application Shield) and R307-415-5a(1)(c) (see also Provision IiD.z). (B07al5-7c(2))
I.E Application Shield.
If the permittee submits a timely and complete application for renewal, the permittee's
failure to have an operating permit will not be a violation of R307415, until the Director
takes final action on the permit renewal application. ln such case, the terms and conditions
of this permit shall remain in force until permit renewal or denial. This protection shall
cease to apply if, subsequent to the completeness determination required pursuant to R307-
415-7a{3), and as required by R307415-5a(2), the applicant fails to submit by the deadline
specified in writing by the Director any additional infonnation identi{ied as being needed to
process the application. @3074 l5-7bp))
I.F Severabilitv.
In the event of a challenge to any portion of this permit, or if any portion of this permit is
held invalid, the remaining permit conditions remain valid and in force. @307a15-6a(5))
I.G Permit Fee.
I.G.I The pennittee shall pay an annual emission fee to the Director consistent with R307415-9.
(ru07a15-6a(7)
I.G.z The emission fee shall be due on October 1 of each calendar year or 45 days after the source
receives notice of the amount of the fee, whichever is laGr. (R307415-9( )(a))
I.H No Pronertv Rishts.
This permit does not convey any property rights of any sort, ot any exclusive privilege.
(R307415-6a(6)(d)
I.I Revision Exception.
No permit revision shall be required, under any approved economic incentives, marketable
permits, emissions trading and ottrer similar programs or processes for changes that are
provided for in this permit. (807a15-6a(8))
I.J Inspection and Entry.
Project OPP012t250008 Page 6 Title V Operating Permit #4900234004
I.J.1 Upon presentation of credentials and other documents as may be required by law, the
permittee shall allow the Director or an authorized representative to perform any of the
following:
Enter upon the permittee's premises where the source is located or emissions related
activity is conducted, or where records are kept under the conditions of this permit.
(R307415-6c(2Xa)
Have access to and copy, at reasonable times, any records that must be kept under
the conditions of this permit. (R307415-6c(2Xb)
Inspect at reasonable times any facilities, equipment (including monitoring and air
pollution control equipment), practice, or operation regulated or required under this
pennit. (R307-415-6c(2Xc))
Sample or monitor at reasonable times substances or parzilneters for the purpose of
assuring compliance with this permit or applicable requirements. (R307415-
6c(2)(d))
Any claims of confidentiality made on the information obtained during an inspection shall
be made pursuant to Utah Code Ann. Section 19-1-306. (R307415-6c(2)(e))
Cerffication.
Any application forrn, report, or compliance certification submitted pursuant to this permit
shall contain certification as to its truth, accuracy, and completeness, by a responsible
official as defined in R307415-3. This certification shall state that, based on inforrnation
and belief formed after reasonable inquiry the statements and information in the document
are true, accurate, and complete. (R307415-5d)
Comnliance Certification.
Pemrittee shall submit to the Director an annual compliance certification, certiffing
compliance with the terms and conditions contained in this permit, including emission
limitations, standards, or work practices. This certification shall be submitted no later than
the date shown under "Enforceable Dates and Timelines" at the front of this permit, and that
date each year following until this perrrit expires. The certification shall include all the
following (permittee may cross-reference this permit or previous reports): (R30741 5-
6c(5))
The identification of each term or condition of this permit that is the basis of the
certification;
The identification of the methods or other means used by the permittee for
determining the compliance stafirs with each term and condition during the
certification period. Such methods and other means shall include, at a minimum, the
monitoring and related recordkeeping and reporting requirements in this permit. If
necessary, the permittee also shall identiS any other material information that must
be included in the certification to comply with section 113(c)(2) ofthe Act, which
prohibits }nowingly making a false certification or omitting material information;
The status of compliance with the terms and conditions of the permit for the period
covered by the certification, including whether compliance during the period was
continuous or intermittent. The certification shall be based on the method or means
I.K
I.J.1.a
I.J.1.b
I.J.1.c
r.J.1.d
T.J.2
I.L
I.L.1
I.L.1.a
I.L.1.b
I.L.1.c
Project OPP0128250008 Page 7 Tltle V Operating Permit #4900234004
designated in Provision I.L.l.b. The certification shall identiff each deviation and
take it into accourt in the compliance certification. The certification shall also
identiff as possible exceptions to compliance any periods during which compliance
is required and in which an excursion or exceedance as defined under 40 CFR Part
64 occurred; and
I.L.l.d Such other facts as the Director may require to determine the compliance status.
I.L.2 The permittee shall also submit all comptance certifications to the EPA, Region VI[, at the
following address or to such other address as may be required by the Director: (R307415-
6c(s)(d))
Environmental Protection Agency, Region VIII
Office of Enforcement, Compliance and Environmental Justice
(mail code SENF)
1595 WynkooP Sheet
Denver, CO 80202-1129
I.M Permit Shield.
I.M.1 Compliance with the provisions of this perrrit shall be deemed compliance with any
applicable requirements as of the date of this permit, provided that:
I.M.l.a Such applicable requirements are included and are specifically identified in this
permit, or (R30741 5-6(1Xa)
I.M.l.b Those requirements not applicable to the source are specifically identified and listed
in this permit. (R307415-6(1Xb)
I.M.2 Nothing in this permit shall alter or affect any of the following:
l.M.2.a The emergencyprovisions of Utah Code Ann. Section 19-1,-202 and Section 19-2-
LIZ,andthe provisions of the CAA Section 303. (R307415-6f(3Xa))
I.M.2.b The liability of the owner or operator of the source for any violation of applicable
requirements under Utah Code A:rn. Section L9A-rc7Q)(a)(xiii) and Section 19-2-
110 prior to or at the time of issuance of this permit. (R307415-6f(3)O)
I.M.2.c The applicable requirements of the Acid Rain Program, consistent with the CAA
Section 408(a). (R307415-6(3Xc))
I.M.2.d The ability of the Director to obtain information from the source under Utah Code
Ann. Section 19-2-120, and the ability of the EPA to obtain information from the
source under the CAA Section 114. (R307415-6f(3Xd)
I.N Emereencv Provision.
I.N.l An "emergency" is any situation arising from sudden and reasonably unforeseeable events
beyond the control of the source, including acts of Go4 which situation requires immediate
corrective action to restore normal operation, and that causes ttte source to exceed a
technology-based emission limitation under this permit, due to unavoidable increases in
emissions attributable to the emergency. An emergency shall not include noncompliance to
the extent caused by improperly designed equipment, lack of preventive maintenance,
careless or improper operation, or operator error. (R307a15-69(1)
Project OPP0128250008 Page I Title Y Operating Permit #4900234004
I.N.2 An emergency constitutes an affrrmative defe,nse to an action brought for noncompliance
with such technology-based emission limitations if the affirmafive defense is demonstrated
through properly signed, contemporaneous operating logs, or other relevant evidence that:
I.N.2.a An emergency occurred and the perrrittee can identiff the causes of the emergency.
(R307415-6e(gxa))
I.N.2.b The permitted facility rvas at the time being properly operated. (R307415-
6e(3Xb))
I.N.2.c During the period of the emergency the permittee took all reasonable steps to
minimize levels of emissions that exceeded the emission standards, or other
requirements in this permit. (R3 074 I 5-6g(3)(c))
I.N.2.d The permittee submitted notice of the emergency to the Director within two
working days of the time when emission limitations wete exceeded due to the
emergency. This notice must contain a description of the emergency, any steps
taken to mitigate emissions, and corrective actions taken. This notice fulfills the
requirement of Frovision L S.2.c below. (R3 074 1 5 -69(3Xd))
I.N.3 ln any enforcement proceeding, the permittee seeking to establish the occurrence of an
emergency has the burden of proof. (rc07a15-6g(a)
I.N.4 This emergency provision is in addition to any emergency or upset provision contained in
any otler section of this permit. (ru07415-6g(5))
LO Onerational Flexibilitv.
Operational flexibility is governed by R307415-7d(1).
LP Off-permit Chanses.
Off-permit changes are governed by R3 074 I 5 -7 dQ) .
LQ Administrative Permit Amendments.
Administrative pennit amendments are govemed by R307415-7e.
I.R Permit Modilications.
-r.*,
-***oons are governed by R307415-7f.
I.S Records and Reportins.
I.S.1 Records.
I.S.l.a The records of all required monitoring data and support inforrration shall be
retained by the permittee for a period of at least five years from the date of the
monitoring sample, measurgment, report, or application. Support information
includes all calibration and maintenance records, all original strip-charts or
appropriate recordings for continuous monitoring instrumentation, and copies of all
reports required by this permit. (R307415-6a(3)(b)(ii))
Project OPP0128250008 Page 9 Tltle V Operating Permtt #4900234004
I.S.l.b For all monitoring requirements described in Section II, Special Provisions, the
source shall record the following information, where applicable: (R307415-
6a(3XbXi))
I.S.1 .b.1 The date, place as defined in this permit, and time of sampling or
measurement.
I.S.1.b.2 The date analyses were performed'
I.S.1.b.3 The company or entity that perfomred the analyses.
I.S.1.b.4 The analytical techniques or methods used.
I.S.1.b.5 The results of such analyses.
I.S.1.b.6 The operating conditions as existing at the time of sampling or
measurement.
I.S.l.c Additional record keeping requirements, if any, are described in Section tr, Special
Provisions.
I.S.2 Reports.
I.S.2.a Monitoring reports shall be submitted to the Director every six months, or more
frequently if specified in Section IL AII instances of deviation from perrrit
requirements shall be clearly identified in the reports. (R307415-6a(3)(c)(i))
LS.2.b A1l reports submitted pursuant to Provision I.S.2.a shall be certified by a
responsible official in accordance with Provision I.K of this permit. (R307415-
6a(3XcXi)
I.S.2.c The Director shall be notified promptly of any deviations from pennit requirements
including those atftibutable to upset conditions as defined in this permit, the
probable cause ofsuch deviations, and any corrective actions orpreventative
measures taken. Prompt, as used in this condition, shall be defined as written
notification within the number of days shown under "Enforceable Dates and
Timelines" at the front of this perrnit. Deviations from pennit requirements due to
breakdowns shall be reported in accordance with the provisions of R307-107.
(R307-4 1s-6a(3)(c)(ii))
I.S.3 Noti.fication Addresses.
I.S.3.a All reports, notifications, or other submissions required by this permit to be
submitted to the Director are to be sent to the following address or to such other
address as may be required by the Director:
Utah Division of Air Quality
P.O. Box 1,M820
Salt Lake city, uT 841144824
Phone: [phone]
I.S.3.b All reports, notifications or other submissions required by this permit to be
submitted to the EPA should be sent to one of the following addresses or to such
other address as may be required by the Director:
Project OPP012t250008 Page 10 Title Y Oporating Permit 1t4904234004
For annual compliance certifi cations:
Environmental Protection Agency, Region VIII
Office of Enforcernent, Compliance and Environmental Justice
(mail code SENF)
1595 Wpkoop Street
Denver, CO 80202-1129
For reports, notifications, or other correspondence related to permit modifications,
applications, etc.:
Environmental Protection Agency, Region Mtr
Air Pennitting and Monitoring Branch (mail code SARD-PM)
1595 Wynkoop Sfreet
Denver, CO 80202-1129
Phone: [phone]
I.T Reopenins for Cause.
I.T.1 A permit shall be reopened and revised under any of the following circumstances:
I.T.l.a Newapplicable requirements become applicable to the permittee and there is a
remaining permit term of tlree or more years. No such reopening is required if thei :r,T::LH::i.'[#:Hfl:tHiff:r,il,i:#;]]n"*H,*"ffiffi,*1"
to R307-4 1 5-7c(3), application shield. (R307 415 -7g( lXa)
I.T.l.b The Director or EPA detennines that this permit contains a material mistake or that
inaccurate statements were made in establishing the emissions standards or other
tenns or conditions of this pennit. (R307415-7e(1Xc)
II I.T. t .. EPA or the Director determines that this permit must be revised or revoked to
ssure compliance with applicable requirements. (R3074 1 5-7e( I Xd))
I.T.l.d Additional applicable requirements are to become effective before the renewal date
of this permit and are in conflict with existing perrrit conditions. (R307415-
7e(lXe))
' 1.T.2 Additional requirements, including excess emissions requirements, become applicable to a
Title tV affected source under the Acid Rain Program. Upon approval by EPA, excess
i ;f.;i;ff
offset plans shall be deemed to be incorporated into this permit. (R30741s-
I.T.3 Proceedings to reopen and issue a permit shall follow the same procedures as apply to initial
pennit issuance and shall affect only those parts of this permit for which cause to reopen
exists. @307a$-7gQ))
LU Inventorv Requirements.
An emission inventory shall be submitted in accordance with the procedures of R307-150,
Emission Inventories. (R307-l 50)
Project OPP0128250008 Page 11 Tttle Y Operattng Permtt #490023401)4
LV fitle W and Other. More Strlnsent Reouirements
Where an applicable requirement is more stringent than an applicabte requirement of
,
regulationspromulgatedurderTitle IV of the Act, AcidDeposition Contol, both
provisions shall be inoorporated into this permit. (R307415-6a(1)O)
i
fi{e Y Opemthg Permft #4900234004Prolect OPP012E25ln0t Page 12
SECTION II: SPECIAL PROVISIONS
II.A Emission Unit(s) Permltted to Discharge Alr Contaminants.
(R3 074 I 5 4(3Xa) and R307 41 s -4(4))
II.A.I Permitted Source
Source-wide
ll.A.2 #1: GE Frame 7-EA Generator (in Simple Cycle Mode)
Gas turbine generator equipped with dry-low-NO* btrmers and an inlet evaporative cooler. The maximum
heat input is 880 MMBTU/hr (ffi{\D at the baseload. NSPS GG.
II.A.3 #22 GE f,'rame 7-EA Generator (in Combined Cycle Mode)
Gas nrbine generato equipped with one HRSG and steam turbine generator set, with maximum heat
input of 992 MMBtu/hr (fH\D at the baseload. The duct burner (NSPS Da) with maximum firing rate at
312 MM BTU/hr (LHV), equipped with a SCR forNO* control.
II.A.4 #3: Emergency Generator
One diesel fred emergency generatorrated at 60 kW, constructed before June 12, 2006. NESHAP
ZZZZ,
II.A.5
#4: Cooling Tower
One cooling tower with 3 cells. No-unit specific applicable requirements.
tr.8
Rgquirements and Limitations
The following emission limitations, standards, and operational limitations apply to the permitted facility
as indicated:
tr.B.1
Conditions on Permitted Source (Source-wide).
II.B.l.a
Condition:
At all times, including periods of startup, shutdown, and malfunction, the permittee shall, to the extent
practicable, maintain and operate any pemritted plant equipment including associated air pollution
control equipment in a manner consistent with good air pollution control practice for minimizing
emissions. Determination of whether acceptable operating and maintenance procedures are being used
will be based on information available to the Director which may include, but is not limited to,
monitoring results, opaclty observations, review of operating and maintenance procedures, and inspection
of the source. [Origin: DAQE-ANI 28250007 -17]. [R30740 1 -8]
tr.B.l.a.l Monitoring:
Records required for this permit condition will serve as monitoring.
tr.B.I.a.2 Recordkeeping:
The permittee shall document activities performed to assure proper operation and maintenance.
Records shall be maintained in accordance with Provision I.S.l of this permit.
Project OPP012t250008 Page 13 Title V Operating Permit t14900234004
tr.B.l.a.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
tr.B.l.b Condition:
Combined CO emissions shall be no greater than 96.46 tons per l2-month lelling period. IDAQE-
ANl 282s00 07 -17). [R30740 1 -8]
tr.B.I.b.l Monitoring:
The emissions shall be detennined on a rolling l2-month total. Within the fust 20 days of each
month, the total shall be calculated for each calendar month and added to the previous 11 months
data.
Monthly emissions shall be the sum of emissions from the gas turbine, duct burner, and
emergetrcy generator. Emissions from the gas tr:rbine and the duct bumer shall be obtained from
CEMS recorded data. Emissions from the emergency generator shall be obained by multiplying
the engine mting, recordedhours of operation and emission factors from the Vendor data if
available or EPA's Compilation of Air Pollutant Emission Factors, AP42.
Hours of operation for emergency generator shall be deterrnined by the operations log.
tr.B.l.b.2 Recordkeeping:
Daily consumption or usage records shall be maintained for all periods of operation. Results of
monitoring shall be maintained in accordance with Provision I.S.l of this permit.
II.8.1.b.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
tr.8.1.c Condition:
Combined NO* emissions shall be no greater than 69 tons per 12-month rolling period. IDAQE-
ANl 28250007 -171. [R30740 1 -8]
tr.B.l.c.l Monitoring:
The emissions shall be detemrined on a rolling l2-month total. Within the first 20 days of each
month, the total shall be calculated for each calendar month and added to the previous 11 months
data.
Monthly emissions shall be the sum of emissions from the gas turbine, duct bumer, and
emergency generator. Emissions from the gas turbine and the duct burner shall be obtained from
CEMS recorded data. Emissions from the emergency generator shall be obtained by multiplying
the engine rating, recorded hours of operation and emission factors from the Vendor data if
available or EPA's Compilation of Air Pollutant Emission Factors, 4P42.
Hours of operation for emergency generator shall be determined by the operations log.
Project OPP0128250008 Page 14 Title V Operating Permit #4900234004
' tl.B.l.c.2 Recordkeeping:
i 3:*fftrffi"1ii:HHffi::Tf"::tH:ffi*li#lsrfltu"J;g#on Resu*sof
II.8.1.c.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
tr.B.l.d Condition:
The perrrittee shall use only natural gas as fuel in the gas turbine and duct burner. Fuel oil #2 or better
shall be used as fuel in the emergency generator. [DAQE-AN128250007-17]. [R307401-8]
U.B.l.d.l Monitoring:
In lieu of fuel monitoring, the report required for this permit condition will serve as monitoring.
tl.B.l.d.2 Recordkeeping:
The annual certification required for this permit condition shall be maintained as described in
Provision I.S.1 of the permit
tr.8.1.d.3 Reporting:
I tn addition to the reporting requirements specified in Section I of this permit, the pennittee shall
certiff with each annual certification report that fuel usages in each affected unit comply with the
permit condition during the reporting year.
tr.8.1.e Condition:
The sulfir content of fuel oil burned shall be no more than 0.0015% by weight unless otherwise specified
in this permit. TDAQE-AN 128250007 -171. [R307401-8]
tr.B.l.e.l Monitoring:
Sulfir content shall be determined either by testing each fuel delivery of fuel oil or by inspection
of the fuel zulfur-content specifications provided by the vendor in purchase records. Sulfur
content in either instance shall be determined in accordance with ASTM-D4294-89, or approved
equivalent.
tr.8.1.e.2 Recordkeeping:
' *"sults of monitoring shall be maintained in accordance with Provision I.S.1 of this pennit.
tr.B.I.e.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
Project OPP0128250008 Page 15 Title V Operating Permit #4900234004
tr.8.1.f Condition:
The permittee shall comply with the applicable requirements for recycling and emission reduotion for
class I and class II refrigerants pursuant to 40 CFR 82, Subpart F - Recycling and Emissions Reduction.
[40 cFR 82.1s0O)]. [40 crR 82]
II.B.l.f.l Monitoring:
The permittee shallcertiff, in the annual compliance statement required in Section I of this
permit, its compliance status with the requirements of 40 CFR 82, Subpart F.
II.B.1.f.2 Recordkeeping:
All records required in 40 CFR 82, Subpart F shall be maintained consistent with the
requirements of Provision S.1 in Section I of this permit.
tr.8.1.f,3 Reporting:
All reports required in 40 CFR 82, Subpart F shall be submitted as required. There are no
additional reporting requirements except as outlined in Section I of this permit.
II.B.1.g Condition:
The permittee shall develop, maintain, and implement a written Emissions Minimization Plan that
desoribes, in detail, procedures for operating and maintaining the GE Frame 7-EA Generator, including
associated air pollution control and monitoring equipment, during events of startup and shutdown.
The plan shall contain detailed steps to minimize, to the maximum extent practicable, the frequency and
duration of operation in startup or shutdown aud shall be followed at all times. This shall include, but not
necessarily be limited to: careful and detailed design, planning, operation, and maintenance so its to avoid
unnecessary, preventable, or unreasonably frequent or lengthy startups and shutdowns.
The permittee should periodically revise the plan as necessary to satisff the requirements of this condition
or to reflect sfoanges in equipment or procedures at the affected source. Each such revision must be
submitted to the Director. IDAQE-AN 128250007 -L7]. [R30740 I -8]
II.B.1.g.1 Monitoring:
Recordkeeping requirement required in this permit condition shall serve as monitoring
requirement.
A..8.1.9.2 Recordkeeping:
The permittee shall maintain records demonsftating the procedures in the Emissions
Minimization Plan were followed. These records shall include the date and time of occurrence
and duration of each startup and shutdown, total hours of startup and shutdown every calendar
year for each affected unit, emissions during startup and shutdown as well as other pertinent
information. All records shall be maintained in accordance with Provision I.S.1 of this permit.
II.8.1.g.3 Reporting:
There are no additional reporting requirements for this provision except those specified in Section
I ofthis permit.
Project OPP012E25000E Page 16 Title Y Operating Permit 114900234004
tr.8.1.h Condition:
The following shall be installed and operational:
(l) The gas turbine shall be equipped with an inlet evaporative cooler;
(2) The HRSG shall be equipped with a Selective Catalytic Reduction System for abatement ofNO*
emissions from the duct burner and the gas turbine;
(3) Continuous Emission Monitoring Systems forNO*, CO and 02 (CEMS) shall be provided for
monitoring emissions from the gas turbine bypass stack, when operating in a simple cycle mod; or gari
turbine, HRSG and duct buner main staclg when operating in combined cycle mode;
(a) The height of the gas turbine bypass stack shall be no less than 100 feet as measured from the base of
the stack;
(5) The heigbt of the main stack shall be no less than 150 feet as measured from the base of the staclc
IDAQE-AN r282s0007 -t7]. [R307-40 1 -8]
tr.8.1.h.1 Monitoring:
Recordkeeping requirement required iu this permit condition shall serve as monitoring
requirement.
tr.8.1.h.2 Recordkeeping:
i fiiil?,*:tf fxJ,T#::'*?rY"*:,'J;?,J:i:iffi lln:"*'o"d
Arr records sha, be
tr.8.1.h.3 Reporting:
i
' There are no additional re,porting requirements for this provision except those specified in Section
I
, of this pemft.
i tr.8.2 Conditions on GE Frame 7-EA Generator fin Simole Cvcle Mode) (Emission Unit #1).
| 1..8.2.a Condition:
I
visible emission shall be no greater than 10 Yo opacity. [DAQE-AN128250007-L7]. [R307401-8]
tr.B.2.a.I Monitoring:
The annual certification required for this perrnit condition will serve as monitoring.
1I.8.2.a.2 Recordkeeping:
i fte annual certification required for this permit condition shall be maintained as described in
Provision I.S.1 of the permit
11.8.2.a.3 Reporting:
In addition to the reporting requirements specified in Section I of this pennit, the permittee shall
certiff each annual certification report that only pipeline quality natural gas is used as fuel during
the reporting year.
Project OPP0128250008 PrgelT Title V Operating Permtt #4900234004
II.B.2.b Condition:
Emissions of CO fromthe gas turbine atthe simple cycle mode shall be no greaterthan 25 ppmdv (1'5%
Oz, dry) based on 8-hour block average under steady state operation (not including startup and shutdown).
IDAQE-AN t282s0007 -r7]. [R30740 1 -8]
II.8.2.b.1 Monitoring:
The emission of CO shall be monitored by continuous emission monitoring system (CEMS)
consisting of CO and Oz monitors. The Oz monitor shall be used to adjust the measured CO
concenftations to L5% Oz. The permittee shall calibrate, maintain, and operate a CEMS as
required by R307-170 to determine compliance with CO concentation. The quality assurance
requirements of R307-170, Continuous Emission Monitoring Systems Program shall be used to
fuIfiII data quallty assurance requirements. The hourly average of CO emissions shall be
calculated every hour and the 8-hour block average shall be calculated using the hourly average
data.
n.8.2.b.2 Recordkeeping:
Results of CO monitoring shall be recorded and maintained as required in R307-170 and as
described in Provision I.S.1 of this permit.
U.8.2.b.3 Reporting:
The perrnittee shall comply with the reporting provisions in R307-170-9 and all the reporting
provisions contained in Section I of this permit. The quarterly reports required in R307-170-9 are
considered prornpt noffication of permit deviations required in Provision I.S.2.c of this permit if
all information required by Provision I.S.2.c is included in the report.
il,.8.2.c Condition:
Emission of NOx from the gas turbine at the simple cycle mode shall be no greater than 9 ppmdv (15%
Oz, dry) based on 30 day rolling average under steady state operation (not including startup and
shutdown) and shall be no greater thar,97.l2 ppmdv (li%o Oz, dry) during all periods of unit operation.
TDAQE-AN128250007-17 and40 CFR 60.332(aX1)1. [40 CFR 60 Subpart GG., R307401-8]
tr.B.2.c.l Monitoring:
(a) The permittee shall install, certiff, maintain, operate, and quality'assure a continuous
emission monitoring system (CEMS) consisting of NOx and Oz monitors to determine
compliance with the applicable NOx limitatious. The CEMS shall be installe4 certifie(
maintained and operated as follows:
(1) Each CEMS must be installed and certified according to PS 2 and 3 (for diluent) of 40 CFR
part 60, appendix B, except theT-day calibration drift is based on unit operating days, not
calendar days. Appendix F, Procedure 1 is not required. The relative accuracy test audit (RATA)
of the NO* and diluent monitors may be performed individually or on a combined basis, i.e., the
relative
accuracy tests of the CEMS may be performed eitler:
(D On a ppm basis (forNOx) and a percent Oz basis for orygen; or
(ii) On a ppm at 15 percent Oz basis.
Project OPP0128250008 Page 18 Tifle Y Operating Permtt #4900234{104
U..8.2.c.2
II.B.2.c.3
(2) As specified in 40 CER 60.13(e)(2), during each fuIl unit operating hour, each monitor must
complete a minimum of one cycle of operation (sampling, analyzing, and data recording) for each
lS-minute quadrant of the hour, to validate the hour. For partial unit operating hours, at least one
valid data point must be obtained for each quadrant of the hour in which the unit operates. For
unit operating hours in which required quality assurance and maintenance activities are
performed on the CEMS, a minimum of two valid data points (one in each of two quadrants) are
required to validate the hour.
(3) For purposes of identiffing excess emissions, CEMS data must be reduced to hourly averages
as specified in 40 CFR 60.13(h).
(i) For each unit operating hour in which a valid hourly averlge, as described in paragraph (a)(2)
of this section, is obtained forboth NOx and diluent, the data acquisition and handling system
must calculate and record the hourly NOx emissions in the units of percent NOx by volume, dry
basis, corrected to 15 percsnt Oz. For any hour in which the hourly average 02 concentratior
exceeds 19.0 percent Oz, a diluent cap value of 19.0 percent Oz may be used in the emission
calculations.
(ii) A worst case ISO correction factor may be calculated and applied using historical ambient
data. For the purpose of this calculation, substitute the maximtrm humidity of ambient air (Ho),
minimum ambient temperature (Ta), and minimum combustor inlet absolute pressure @o) into
the ISO correction equation.
(iii) If the permittee has installed a NOx CEMS to meet the requirements of 40 CFR Part 75, ard
is continuing to meet the ongoing requirements of 40 CFR Paxt 75, the CEMS may be used to
meet the requirements of this section, except that the missing data substitution methodology
provided for at 40 CFR Part 75, subpart D, is not required for purposes of identi$ing excess
emissions. lnstead, periods of missing CEMS data are to be reported as monitor downtime in the
excess emissions and monitoring performance report required in 40 CFR 60.7(c).
(b) Each continuous emission monitoring system shall meet the Specifications and Test
Procedures required by 40 CFR PNt75, Appendix A.
(c) The permittee shall implement Quality Assurance and Quality Control Procedures required by
40 CFR Part7s, Appendix B.
(d) The quahty assurance requirements of R307-170, Continuous Emission Monitoring Systems
Prograrn, shall be used in addition to 40 CFR PNt75 procedures to fuIfill data quality assurance
requirements.
(e) The daily average ofNOx emissions shall be calculated once for each day and the 30-day
rolling average shall be calculated by adding previous 30 days data on a daily basis.
Recordkeeping:
Results of NOx monitoring shall be recorded and maintained as required in R307-170, 40 CFR 60
subpart GG,40 CFR 75 subpart F, and as described in Provision I.S.1 of this permit.
Reporting:
(a) The permittee shall comply with the reporting provisions in R307-170-9, 40 CFR 75 Subpart
G, 40 CFR Subpart GG and all the reporting provisions contained in Section I of this permit.
(b) The permittee shall submit reports of excess emissions and monitor downtime, in accordance
Project OPP0128250008 Page 19 Title V Operating Permtt f14900234004
tr.8.2.d
tr.8.2.d.1
n.8.2.d.2
rr.B.2.d.3
with 40 CFR 60.7(c). Excess emissions shall be reported for all periods of unit operation,
including starhrp, shutdown and malfunction. For the purpose of reports requiredunder 40 CFR
60.7(c), periods of excess emissions and monitor downtime that shall be reported are defined as
follows:
(1) An hour of excess emissions shall be any unit operating hour in which the 4-hour rolling
average NOx concentration exceeds applicable NSPS erdssion standard of 97.12 ppmdv (15%
Or, dry). A "4-hour rolling average NOx concentation" is the arithmetic average of the average
NOx concenfration measured by the CEMS for a given hour (corrected to 15 percent Oz) and the
three-unit operating hour average NOx concenfrations immediately preceding that unit operating
hour.
Q) Aday of excess emission shatl be any unit operating period in which the 30-day rolling
average NOx concentration exceeds the applicabls limit. A "30-day rolling average NOx
emission rate" is tle arithmetic average of all hourly NOx emission data in ppm measured by the
CEMS for a given day and the twenty-nine unit operating days average NOx emission rates
immediately preceding that unit operating day. A new 30day average is calculated each unit
operating day as the average of all hourly NOx emissions rates for the preceding 30{lnit
operating days if a valid NOx emission rate is obtained for at least 75 percent of all operating
hours.
(3) A period of monitor downtime shall be any unit operating hour in which sufficient data are
not obtained to validate the hour, for either NOx concentration or diluent (or both).
(4) All reports of excess emissions and monitor downtime shall be postmarked by the 30th day
following the end of each 6-month period.
(c) The quarterly reports required in R307-170-9 and 40 CFR 75 Subpart G are considered
prompt notification of permit deviations required in Provision I.S.2.c of this permit if all
information required by Provision I.S.2.c is included in the report.
Condition:
Sulfur content of any natural gas burned shall be no more than 0.8 percent by weight. [40 CFR 60.333].
[40 CFR60 Subpart GG]
Monitoring:
The annual certification required for this pennit condition will serve as monitoring.
Recordkeeping:
The annual certification required for this permit condition shall be maintained as described in
Provision I.S.1 of the permit
Reporting:
In addition to the reporting requirements specified in Section I of this permit the permittee shall
certiff each annual certification report that that the gaseous fuel used in the reporting year meets
the definition of nahral gas in 40 CFR 60.331(u):
(a) The gas quality characteristics in a current, valid purchase contact, tariffsheet or
transportation contract for the gaseous fuel, speciffing that the maximum total sulfir content of
the fuel is 20.0 grains/l00 scf or less; or
Project OPP0128250008 Page 20 Title V Operatlng Permtt #{900234004
(b) Representative fuel sampling data which show that the sulfur content of the gaseous fuel does
not exceed 20 grains/IOO scf. At a minimum, the amount of fuel sampling data specified in
section 2.3.1.4 ot 2.3.2.4 of appendix D to 40 CFR Part 75 is required.
tr.B.3 Condition on GE f,'rame 7-EA Generator fin Combined Cvcle Mode) (Emlssion Unit #2).
rI'B'3'a
ffir::.sion shall be no greater than 10 %o opaclty.lDAeE-AI{1282s0007-171. tR307401-81
II.B.3.a.1 Monitoring:
The annual certification required for this permit condition will serve as monitoring.
II.B.3.a.2 Recordkeeping:
The annual certification required for this permit condition shall be maintained as described in
Provision I.S.1 of the permit
II.8.3.a.3 Reporting:
In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certiff each annual certification report that only pipeline quality natural gas is used as fuel during
the reporting year.
tr.8.3.b Condition:
I Emission of NOx from the gas turbine and duct burner exhaust stack shall be no greater than 5 ppmdv
(15%o Oz, dry) based on 30 day rolling average under steady state operation (not including startup and
shutdown) and shall be no greater than 97.12 ppmdv (LSYI Oz, dry) from the gas turbine during aU
periods of unit operation. [DAQE-AN128250007-17, 40 CFR 60.332(a)(1) and 40 CFR 60.,,14Da(dX2)].
[40 CFR 60 Subpart Da, 40 CFR 60 Subpart GG, R307401-8]
II.B.3.b.l Monitoring:
(a) The permittee shall install, certi$r, maintain, operate, and quality-assure a continuous
emission monitoring systern (CEMS) consisting of NOx and Oz monitors to determine
cornpliance wittr the applicable NOx limitations. The CEMS shall be installed, certified,
maintained and operated as follows:
(l) Each CEMS must be installed and certified according to PS 2 and 3 (for diluent) of 40 CFR
part 60, appendix B, except the Tday calibration drift is based on unit operating days, not
calendar days. Appendix F, Procedure I is not required. The relative accuxacy test audit (RATA)
of the NOx and diluent monitors may be performed individually or on a combined basis, i.e., the
relative
accuracy tests of the CEMS may be perfonned either:
(i) On a ppm basis (for NOx) and a percent Oz basis for oxygen; or
(ii) On a ppm at 15 percent Oz basis.
(2) As spocifiod in 40 CFR 60.13(e)(2), during each full unit operating hour, each monitor must
complete a minimum of one cycle of operation (sampling, ana$zing, and data recording) for each
l5-minute quadrant of the hour, to validate the hour. For partial unit operating hours, at least one
valid data point must be obtained for each quadrant of the hour in which the unit operates. For
Project OPP012E250008 Page2l Tltle V Operating Permtt #14900234004
tr.B.3.b.2
tr.8.3.b.3
unit operating hours in which required quality assurance and maintenance activities ate
performed on the CEMS, a minimum of two valid data points (one in each of two quadrants) are
required to validate the hour.
(3) For purposes of identiffing excess emissions, CEMS data must be reduced to hourly averages
as specified in 40 CFR 60.13(h).
(i) For each unit operating hour in which a valid hourly ayera5e, as described in paragraph (a)(2)
of this section, is obtained forboth NOx and diluent, the data acquisition and handling system
must calculate and record the hourly NOx emissions in the units of perce,nt NOx by volume, dry
basis, corrected to 15 percent Oz. For any hour in which the hourly average 02 concentration
exceeds 19.0 percent Oz, a diluent cap value of 19.0 percent Oz may be used in the emission
calculations.
(ii) A worst oase ISO correction factor may be calculated and applied using historical ambient
data. For the purpose of this calculation, substitute the rnaximum humidity of ambient air (Ho),
minimum ambient temperature (Ta), and minimum combustor inlet absolute pressure (Po) into
the ISO correction equation.
(iii) If the perrrittee has installed a NOx CEMS to meet the requirements of 40 CFR Part 75, and
is continuing to meet the ongoing requirements of 40 CFR Part75, the CEMS may be used to
meet the requirements of this section, except that the missing data substitution methodology
provided for at 40 CFR Part 75, subpart D, is not required for pu4toses of identiffing excess
lmissions. Instead, periods of missing CEMS data are to be reported as monitor downtime in the
excess emissions and monitoring performance report required in 40 CFR 60.7(c).
(b) Each continuous emission monitoring system shall meet the Specifications and Test
Procedures required by 40 CFR Part75, Appendix A.
(c) The permittee shall implement Quality Assurance and Quality Contol Procedures required by
40 CFR Part7s, Appendix B.
(d) The quallty assurance requirements of R307-170, Continuous Emission Monitoring Systems
Program, shall be used in addition to 40 CFR Part 75 procedures to fuIfiIl data guality assurance
requirements.
(e) The daily average of NOx emissions shall be calculabd once for each day and the 30-day
rolling avefage shall be calculated by adding previous 30 days data on a daily basis.
Recordkeeping:
Results of NOx monitoring shall be recorded and maintained as required in R307-170, 40 CFR 60
subpart GG, 40 CFR 75 subpart F, and as described in Provision I.S.l of this permit.
Reporting:
(a) The perrrittee shall comply with the reporting provisions in R307-170-9, 40 CFR 75 Subpart
G, 40 CFR Subpart GG and all the reporting provisions contained in Section I of this permit.
(b) The permittee shall submit reports of excess emissions and monitor downtime, in accordance
with 40 CFR 60.7(c). Excess emissions shall be reported for all periods of rmit operation,
including startup, shutdown and malfinction. For the purpose of reports required under 40 CFR
60.7(c),periods of excess emissions and monitor downtime that shall be reported are defured as
follows:
Project OPP0128250008 Page22 Title V Operating Permit 114900234004
tr.B.3.c
tr.B.3.c.1
11.8.3.c.2
II.8.3.c.3
(1) An hour of excess emissions shall be any unit operating hour in which the 4-hour rolling
average NOx concentation exceeds applicable NSPS emission standard of 97.L2 ppmdv (15%
Or, dry). A "4-hour rolling average NO* concentration" is the arithmetic average of the average
NOx concentration from the gas turbine for a given hour (corrected to 15 percent Oz) and the
three-unit operating hour average NOx concentrations immediately preceding that unit operating
hour.
(2) A day of excess emission shall be any unit operating period in which the 30day rolling
average NOx concentration exceeds the applicable limit. A "30-day rolling average NOx
emission rate" is the arithmetic average of all hourly NOx emission data in ppm measured by the
CEMS for a given day and the twenty-nine-unit operating days average NOx emission rates
immediately preceding that unit operating day. A new 30day average is calculated each unit
operating day as the average of all hourly NOx emissions rates for the preceding 30-unit
operating days if a valid NOx emission rate is obtained for at least 75 percent of all operating
hours.
(3) A period of monitor downtime shall be any unit operating hour in which sufficient data are
not obtained to validate the hour, for either NOx concentration or diluent (or both).
(4) AII reports of excess emissions and monitor downtime shall be postmarked by the 30th day
followingthe end of each 6-month period.
(c) The quarterly reports required in R307-170-9 and 40 CFR 75 Subpart G are considered
prompt notification of permit deviations required in Provision I.S.2.c of this permit if all
information required by Provision I.S.2.c is included in the report.
Condition:
Emissions of CO from the ps turbine at combined cycle mode shall be no greater than 10 ppmdv (15%
Or, dry) based on 8-hour block average under steady state operation (not including startup and shutdown).
IDAQE-AN1282'0007 -171. [R307401 -8]
Monitoring:
The emission of CO shall be monitored by continuous emission monitoring system (CEMS)
consisting of CO and Oz monitors. The Oz monitor shall be used to adjust the measured CO
concentrations to 15% Oz. The pennittee shall calibrate, maintain, and operate a CEMS as
required by R307-170 to determine compliance with CO concentration. The quality assurance
requirements of R307-170, Continuous Emission Monitoring Systems Program shall be used to
fulfill data qualrty assurance requirements. The hourly average of CO emissions shall be
calculated every hour and the 8-hour block average shall be calculated using the hourly average
data.
Recordkeeping:
Results of CO monitoring shall be recorded and maintained as required in R307-170 and as
described in Provision I.S.1 of this perrrit.
Reporting:
The permittee shall comply with the reporting provisions in R307-170-9 and all the reporting
provisions contained in Section I of this permit. The quarterly reports required in R307-170-9 is
Project OPP0128250008 Page23 Title V Operating Permtt #f900234004
considered prompt notification of permit deviations required in Provision I.S.2.c of this permit if
all inforrration required by Frovision I.S.2.c is included in the report.
II.B.3.d Condition:
Sulfur content of any natural gas burned shall be no more than 0.8 percent by weight. [40 CFR 60.333].
[40 CFR 60 Subpart GG]
tr.B.3.d.l Monitoring:
The annual certification required for this permit condition will serve as monitoring.
tr.8.3.d.2 Recordkeeping:
The annual certification required for this permit condition shall be maintained as described in
Provision I.S.1 of the permit
tr.8.3.d.3 Reporting:
In addition to the reporting requirements specified in Section I of this permit, the pennittee shall
certiff each annual certification report that only pipeline quality natural gas is used as fuel during
the reporting year.
II.B.3.e Condition:
Emissions of PM shall be no gleater than 0.03 lb/IdMBtu heat input from the duct bumer. [40 CFR
60.aZD4a)1. [40 CFR 60 SubpartDa]
tr.B.3.e.l Monitoring:
Stack testing shall be perfomred as specified below:
(a) Frequency. Emissions shall be tested at least once every five years, based on the date ofthe
last test. Tests may also be required at the direction of the Director.
(b) Notification. At least 30 days before the test, the source shall notiS the Director of the date,
time, and place of testing and provide a copy of the test protocol. The source shall attend a
pretest conference if determined necessary by the Director.
(c) Methods.
(1) The dry basis F factor (Oz) procedures in Method 19 shall be used to compute the emission
rate of particulate matter.
(2) For the particular matter concentation, Method 5 shall be used at affected facilities without
wet FGD systems and Method 58 shall be used after wet FGD systems.
(i) The sampling time and sample volume for each run shall be at least 120 minutes andL.70
dscm (60 dscf). The probe and filter holder heating system in the sampling train may be set to
provide an average gas temperature of no greater than 160 + 14oC (320 +.25"F).
(ii) For each particulate run, the emission rate correction factor, integrated or grab sampling and
analysis procedures of Method 38 shall be used to determine the Oz concentation. The Oz
sample shall be obtained simultaneously with, and at the same traverse points as, the particulate
Project OPP0128250008 Page24 Tifle V Operating Permlt #4900234004
run. If the particulate run has more than 12 traverse points, the Oz traverse points may be reduced
to 12 provided that Method I is used to locate the 12 Oz fiaverse points. If the grab sarrpling
procedure is used, the Oz concentation for the run shall be the arithmetic mean of the sample Oz
r concentrations at all traverse points.
(d) Production Rate During Testing. The production rate during all compliance testing shall be
no less lhar-9}% of the ma:rimumproduction achieved inthe previous three (3) years.
II.B.3.e.2 Recordkeeping:
Results of all stack testing shall be recorded and maintained in accordance with the associated test
metlod and Provision S.1 in Section I of this permit.
tr.8.3.e.3 Reporting:
The results of stack testing shall be submitted to the Director within 60 days of completion of the
::'sfi *:":ffi :+l:l.:H'*':1fl,T:HT#"ffi',ffi #:#ffi il:ffi T;l,"sr"T."ep,hose
specified in Section I of this permit. The results of stack testing shall be submitted to the Director
within 60 days of completion of the testing. Reports shall clearly identi$, results as compared to
pennit limits and indicate compliance status. There are no additional reporting requirernents for
this provision except those specified in Section I of this permit.
tr.8.4 Condltions on Emersencv Generetor (Emission Unit #3).
II.B.4.a Condition:
Visible emission shall be no greater than}0% opacity. [DAQE-AN128250007-17]. [R307401-8]
II.B.4.a.1 Monitoring:
i
An opacity observation of each affected emission unit shall be conducted once every six months
by an individual trained on the observation procedures of 40 CFR 60, Appendix A, Method 9.
The individual is not required to be a certified visible emissions observer (VEO). If any visible
emissions are observed, an opaclty determination of that emission unit shall be performed by a
certified VEO in accordance with 40 CFR 60, Appendix A, Method 9 witttin 24 hours of the
initial observation.
fr..8.4.a.2 Recordkeeping:
Results of monitoring shall be maintained in accordance with Provision LS.I of this permit.
II.B.4.a.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
tr.8.4.b Condition:
Emergency generators shall be used for electricity production only during periods when electric power
from the public utilities is intemrpted, except for routine engme maintenance and testing. [DAQE-
ANl 28250007 -r7). [R3 0740 I -8]
Proiect OPP0128250008 Page25 Tltle V Operating Permit #4900234004
tr.8.4.b.1 Monitoring:
An operation log shall be used to record the following information for each usage: date(s), total
hours used, and reason for usage.
fr.8.4.b.2 Recordkeeping:
Results of monitoring shall be maintained in accordance with Provision I.S.l of this pennit.
tr.8.4.b.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.
tr.B.4.c Condition:
At all times the permittee shall operate and maintain any affected source, including associated air
pollution confiol equipment and monitoring equipment, in a manner consistent with safety and good air
pollution contol practices for minimizing emissions. The general duty to minimize emissions does not
require the perrrittee to make any further efforts to reduce emissions if levels required by this standard
have been achieved. Determination of whether such operation and maintenance procedures are being used
will be based on information available to the Director which may include, but is not limited to,
monitoring results, review of operation and maintenance procedures, teview of operation and
maintenance records, and inspection of the source. [Origrn: 40 CFR 63.6595(a)(1), 40 CFR 63.66050)].
[40 CFR 63 Subpart 7ZZ-21
II.8.4.c.1 Monitoring:
Records required for this permit condition will serve as monitoring.
il..8.4.c.2 Recordkeeping:
The pennittee shall keep the records described in 40 CFR 63.6655(a)(l)-(5) as applicable. The
permittee shall document acfivities performed to assure proper operation and maintenanoe.
Records shall be maintained in accordance with 40 CFR 63.6660 and Provision I.S.1 of this
permit.
tr.8.4.c.3 Reporting:
There are no reporting requiremrents for this provision except those specified in Section I of this
perrnit.
II.B.4.d Condition:
The permittee shall comply with the following operating limitations at all times for each emergency
affected emission unit:
(1) The permittee shall operate the affected emission unit according to the requirements in paragraphs
(1)(a) through (lXc). Any operation other ttran emergency operation, maintenance and testing, and
operation in non-emergency situations for 50 hours per year, as described in 1.a through 1.c, is prohibited.
If the engine is not operated in accordance with paragraphs 1.a through 1.c, it will not be considered an
emergency engrne and shall meet all requirements for non-emergency engines.
Froject OPP0128250008 Page26 Tltle V Operating Permit 114900234004
tr.B.4.d.1
(a) There is no time limit on the use of "*.rgio"y stationary RICE in emergency situations.
(b) Operation for the purposo of rraintenance checks and readiness testing is limited to 100 hours per
calendar year, provided that the tests axe recommended by Federal, State or local government, the
manufacturer, the vendor, or the insurance company associated with the engrne. A petition for approval of
additional hours to be used for maintenance checks and readiness testing is not required if the permittee
maintains records indicating that Federal, State, or local standards require maintenance and testing of
emergency RICE beyond 100 hours per year.
(c) The pennittee may operate up to 50 hours per calendar year in non-emergency situations, but those 50
hours are counted towards the 100 hours per calendar year provided for maintenance and testing and
emergency demand response provided in 40 CFR 63.6640(f)Q).
(2) The perrrittee shall meet the following requirernents at all times, except during periods of startup:
(a) Change oil and filter every 500 hours of operation or annually, whichever comes first;
(b) Inspect air cleaner every 1,000 hours ofoperation or annually, whichever comes first, and replace as
necessary;
(c) Inspect all hoses and belts every 500 hours of operation or annually, whichever comes firs! and
replace as necessaxy.
(3) The permittee have the option to utilize an oil analysis program as dessribed in 40 CFR 63.6625(i) n
order to extend the specified oil change requirement in paragraph (2)(a) of this condition.
(4) During periods of startup the permittee shall minimize the engine's time spent at idle and minimizs ths
engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30
minutes, after which time the non-startup emission limitations apply.
(5) The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as identified in
Table 8 of 40 CFR 63 Subpart ZZ2Z.
[Origin:40 CFR 63.6603(a),40 CFR 63.6605(a),40 CFR 63.66256),40 CFR 63.6640(0,40 CFR
63.6665,40 CFR 63 Subpart ZZ7-Z Table 2d(4), 40 CFR 63 Subpart ZZZZ Table 2d(foohote 1), 40 CFR
63 Subpart ZZZZ Table 81. [40 CFR 63 Subpart ZZZQ
Monitoring:
The pemrittee shall install a non-resettable hour meter if one is not already installed. [40 CFR
63.662s(Dl
If an emergency engine is operating during an emergency and it is not possible to shut down the
engine in order to perfonn the management practice requirements on the required schedule or if
performing the management practice on the required schedule would othenrise pose an
unacceptable risk under Federal, State, or local law, the management pmctice can be delayed until
the emergency is over or the unacceptable risk under Federal, State, or local law has abated. The
management practice shall be performed as soon as practicable after the emergency has ended or
the unacceptable risk under Federal, State, or local law has abated. [40 CFR 63 Subpart 7ZZZ,
Table 2d Footnote 2l
The permittee shall demonstrate continuous compliance by operating and maintaining the
stationary RICE and after-treatment conhol device (if any) according to the manufacturey's
emission-related written operation and maintenance instructions or develop and follow their own
maintenance plan which must provide to the extent practicable for the maintenance and operation
Project OPP0128250008 Parge27 Title V Operating Permit tt4900234004
n.8.4.&2
II.B.4.d.3
of the englne in a manner consistent with good air pollution confrol practice for minimizing
emissions. [40 CFR 63.6625(e),40 CFR 63.6640(a),40 CFR 63 SabpartZ-7-ZZ Table 6]
The pemrittee has the option of utilioing an oil analysis program in order to extend the specified
oil change requirement in accordance with 40 CFR 63.6625(i).
The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identified in Table 8 of 40 CFR 63 Subpart ZZZZ,.
[40 cFR 63.666s1
Recordkeeping:
The permittee shall keep the records described in 40 CFR 63.6655(aXl)-(5) as applicable. [40
CFR 63.6655(a)l
For each affected emission unit that does not meet the standards applicable to non-emergency
engines, the permittee shall keep records of the hours of operation ofthe engine that are recorded
through the non-resettable hour meter. The permittee shall document how many hours are spent
for emergency operation, including what classified the operation as emergency and how many
hours are spent for non-emergency operation. If the engines are used for demand response
operation, the pernrittee shatl keep records of the notification of the emergency situation, and the
time the engme was operated as part of demand response. [40 CFR 63.6655(0]
If additional hours are to be used for maintenance checls and readiness testing, the permittee
shall maintain records indicating that Federal, State, or local standards require nraintenance and
testing of emergency RICE beyond 100 hours per yeax. [40 CFR 63.6640(0(2Xi)]
The pemrittee shall keep records that demonstrate continuous compliance with each applicable
operating limitation including, but not limited to, the manufacfirer's emission-related operation
and maintenance instructions or the permittee-developed maintenance plan. [40 CFR 63.6655(d),
40 CFR 63 Subpart ZZZZ Table 6l
Records of the maintenance conducted shall be kept in order to demonstrate that the permittee
operated and maintained the afFected emission unit and after-treatuent confrol device (if any)
according to their own maintenance plan. [40 CfR 63.6655(e)]
The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identifred in Table 8 of 40 CFR 63 Subpart ZZZZ. [40 CFR 63.66651
Records shall be maintained in accordance with 40 CFR 63.6660 and Provision I.S.1 of this
permit.
Reporting:
The perrrittee shall report any failure to perform the management practice on the schedule
required and the Federal, State or local law under which the risk was deemed unacceptable. [40
CFR 63 Subpart TZZZTable 2d Footnote 2l
The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identified in Table 8 of 40 CFR 63 Subpart ZZZZ. [40 CFR 63.6665]
The permittee shall also report each instance in which it did not meet the applicable requirements
in Table 8. [40 CFR 63.66a0(e)]
Project OPP0128250008 Page 28 Title V Operating Permlt #4900234004
There are no additional reporting requirements for this provision except those specified in Section
I of this permit.
U.C Emissions Tradins.
Not applicable to this source.
II.D Alternative Operatins Scenarios.
Not applicable to this source.
tI.E Source-specific Definitions.
The following definitions apply to the permittee. They include terms not defined in state or federal rules
or clari$ or expand on existing definitions.
II.E.I Startup: Startup begins when the fuel flow is detected and gas turbine generator load is less or equal to 45
MW.
II.E.2 Shutdown: Shutdown begins when the gas turbine generator load is less or equal to 45 MW. Shutdown
ends when the fuel flow is not detected
II.E.3 Downtime: Downtime is that time between the end of shutdown and the beginning of starflrp.
II.E.4 Maintenance Outage: The removal of a unit from service availability to perform work on specific
components that can be defened beyond the end of the next weekend, but requires the equipment be
removed from seryice before the next planned outage. T1pically, a Maintenance Outage may occur
anytime during the year, have a flexible start date, and may or may not have a predetermined duration.
tt.E.s Planned Outage: The removal of a unit from service availability for inspection and/or general overhaul of
one or more major equipment groups. This outage usually is scheduled well in advance.
Projcct OPP012t250008 Page 29 Tltle V Operating Permit #490023lll)04
A permit shield was not granted for any specific requirements.
;
!i
Project OPP012t250008 Page 30 Tltle Y Opentug Permft 1t490023401X
SECTION IV: ACID RAIN PROYISIONS
IV.A
Authority to imple,ment the Acid Rain Progra:n is contained in R307-417, Permits:
Acid Rain Sources, and R307-415-6a(4), Standard permit requirernents [for operating
permitsl.
IV.B Permit Requirements.
IV.B.I The designated representative of the source and each affected unit at the source shall:
IV.B.I.a Submit a complete Acid Rain perrnit application (including a compliance plan)
under R307-417 and,40 CFR Pxt72 in accordance with the deadlines specified
in 40 CFR 72.30; and
IV.B.1.b Submit in a timely manner any supplemental information that the Director
determines is necessary in order to review an Acid Rain permit application and
issue or deny an Acid Rain pennit;
IV.B.2 The owners and operators shall:
IV.B.2.a Operate each affected unit at the source in compliance with a complete Acid
Rain permit application or a superseding Acid Rain permit issued by the
Director; and
IV.B.2.b Have an Acid Rain Permit.
ry.C Sulfur Dioxide Requirements.
N.C.l The owners and operators of each affected unit at the source shall:
IV.C.l.a Hold allowances, as of the allowance hansfer deadline, in the unit's compliance
subaccount (after deductions under 40 CFR B3a@D not less than the total
annual emissions of sulfur dioxide for the previous calendar year from the unit;
I and
ry.C.l.b Comply with the applicable Acid Rain emissions limitations for sulflr dioxide.
\1.C.2 Each ton of sulfir dioxide emitted in excess of the Acid Rain emissions limitations for
sulfur dioxide shall constitute a separate violation of the Act.
IV.C.3 An affected unit shall be subject to the requirements under Provision IV.C.l. of the
sulfur dioxide requirements as follows:
IV.C.3.a Starting January 1, 2000, an affected unit under 40 CFR 72.6(a)Q); or
IV.C.3.b Starting on the later of January l, 2000 or the deadline for monitor certification
under 40 CFR Part 75, an affected unit under 40 CFR 72.6(a)(3).
IV.C.4 Allowances shall be held itt, deducted from, orffansferred amongAllowance Tracking
System accounts in accordance with the Acid Rain Program.
Project OPP0128250008 Page 31 Title V Operatlng Permlt l#900234004
ry.C.s An allowance shall not be deducted in order to comply with the requirements under
Provision tV.C.l.a. of the sulfur dioxide requirements prior to tle calendar year for
which the allowance was allocated.
IV.C.6 An allowance allocated by the Adminisfrator, USEPA, under the Acid Rain Prograrn is
a timited authorization to emit sulfur dioxide in accordance with the Acid Rain
Program. No provision of the Acid Rain Program, the Acid Rain permit application,
the Acid Rain permit, or the written exemption under 40 CFR72.7 and72.8 and no
provision of law shall be construed to limit the authority of the United States to
terminate or limit such authorization.
IV.C.7 An allowance allocated by the Administrator, USEPA, under the Acid Rain Program
does not constitute a property right.
IV.D Nitroeen Oxides Reouirements.
The owners and operators for each affected unit at the source shall be compliance
with the applicable Acid Rain emissions limitations for nifrogen dioxide.
IV.E Monitorine Reouirements.
IV.E.I The owners and operators an{ to the extent applicable, designated representative of
each affected unit at the source shall comply with the monitoring requirements as
provided in 40 CFR Pafis74,75, and76.
IV.E.2 The emissions measurements recorded and reported in accordance with 40 CFR Part7s
shall be used to detemrine compliance by the unit with the Acid Rain emissions
limitations and emissions reduction requirements for sulfur dioxide and niffogen oxides
under the Acid Rain Prograrn.
IV.E.3 The requirements of 40 CFR Parts 74 and 75 shatl not affect the responsibility of the
owners and operators to monitor emissions of other pollutants or other emissions
characteristics at the unit under other applicable requirements of the Act and other
provisions of the operating pennit for the source'
IV.F Recordkeenins and Reoortine Reouirements.
IV.F.I Unless otherwise provided, the owners and operators for each affectedunit at the source
shall keep on site at the sor:rce each of the following doct ments for a period of 5 years
from the date the document is created. This period may be extended for cause, at any
time prior to the end of 5 years, in writing by the Administrator, USEPA, or Director:
IV.F.1.a The certificate of representation for the designated representative for the source
and each affected unit at the source and all documents that demonstrate the
truth of the statements in the certificate of representation, in accordance with 40
CEL72.24;provided that the certificate and documents shall be retained on site
at the source beyond such S-year period until such documents are superseded
because of the submission of a new certificate of representation changing the
designated representative;
IV.F.1.b All emissions monitoring information, in accordance with 40 CFR Part 75;
Project OPP012t250008 Page32 Tifle V Operatlng Permlt #4900234004
IV.F.1.c
rv.F.1.d
w.F.2
ry.G
rv.G.1
ry.G.2
IV.G.2.a
rv.G.2.b
IV.H
IV.H.1
frr.H.2
IV.H.3
w.H.4
IV.H.5
ry.H.6
Copies of all reports, compliance certifications, and other submissions and all
records made or required under the Acid Rain Prograrn; and,
Copies of all documents used to cornplete an Acid Rain pennit application and
any other submission under the Acid Rain Progra:n or to demonstrate
compliance with the requirements of the Acid Rain Program.
The designated representative of each affected unit at the source shall submit the reports
aad spmpliance certifications required under the Acid Rain Program, including those
under 40 CFR Part 72 Subpart I and 40 CER Part 75.
Excess Emissions Requirements.
The designated representative of an affected unit that has excess emissions in any
calendar year shall submit a proposed offset plan to the Administrator, USEPA, as
required under 40 CFR Part 77.
The owners and operators of an affected unit that has excess emissions in any calendar
year shall:
Pay without demand the penalty required, and pay upon demand the interest on
that penalty, to the Adminishator, USEPA, as required by 40 CFR Part77; and
Comply with the terms of an approved offset plan, as required by 40 CFR Part
77.
Liabilitv.
Any person who lnowingly violates any requirement or prohibition of the Acid Rain
Program, a complete Acid Rain perrrit applicatioq an Acid Rain permit, or a nritten
exemption under R307-417, 40 CFR 72.7 or 40 CFR 72.8, including any requirement
for the palment of any penalty owed to the United States, shall be subject to
enforcement pursuant to section 113(c) of the Act.
Any person who knowingly makes a false, material statement in any record,
submission, or report under the Acid Rain Frogram shall be subject to criminal
enforcementpursuantto section 113(c) of the Act and l8 U.S.C. 1001.
No pennit revision shall excuse any violation of the requirements of the Acid Rain
Program that occurs prior to the date that the revision takes effect.
Each affected source and each affected udt shall meet the requirements of the Acid
Rain Program.
Any provision of the Acid Rain Program that applies to an affected source (including a
provision applicable to the designated representative ofan affected source) shall also
apply to the owners and operators of such source and of the affected units at the source.
Any provision of the Acid Rain Program that applies to an affected unit (including a
provision applicable to the desipated representative of an affected unit) shall also
apply to the owners and operators of such unit. Excep as provided under 40 CFR
72.44 @hase II repowering extension plans) and 40 CFR 76.11 (NO, averaging plans),
and except with regard to the requirements applicable to units with a common stack
under40 CFRpart 75 (including 40 CFR 75.16,75.17, and 75.18), the owners and
Project OPP0128250008 Page 33 Title Y Operating Permit H900234004
operators and the designated representative of one affected unit shall not be liable for
any violation by any other affected unit of which they are not owrers or operators or the
designated representative and that is located at a source ofwhich they are not the
owners and operators, owners or operators, or the designated representative.
IV.H.7 Each violation of aprovision of 40 CFRParts 72,73,74,75,76,77, and 78 by an
afflected source or affected unit, or by an owner or operator or designated representative
of such source or unit, shall be a separate violation of the Act.
IV.H.8 The owners and operators of a unit governed by an approved early election plan shall be
liable for any violation of the plan or 40 CFR 76.8 atthat trnit. The owners and
operators shall be liable, beginning January 1, 2000, for fulfilling the obligations
specified in 40 CFR Pafi17.
IV.I Effect on Other Authorities.
No provision of the Acid Rain Frogram, an Acid Rain permit application, an Acid Rain
perrrit, or a written exemption under 40 CFF.72.7 or 72.8 shall be construed as:
IV.I.I Except as expressly provided in Title IV of the Ac! exempting or excluding the owners
and operators and, to the extent applicable, the designated representative from
compliance with any other provision of the Act, including the provisions of Title I of
the Act relating to applicable National Ambient Air Quality Standards or the Utah State
Implementation Plan;
lV.l.2 Limiting ttre number of allowances a unit can hold; provided, that the number of
allowances held by the unit shall not affect the source's obligation to comply with any
other provisions of the Act;
IV.I.3 Requiring a change of any kind in any State law regulating electic utility rates and
charges, affecting any State law regarding such State regulatioq or limiting such State
regulation, including any prudence review reguirements under such State law;
IV.I.4 Modiffing the Federal Power Act or affecting the authority of the Federal Energy
Regulatory Commission under the Federal Power Act; or,
ry.I.s Interfering with or impairing any program for competitive bidding for power supply in
a State in which such program is established.
Project OPP0128250008 Page 34 Title V Operoting Permlt M900234004
This operating permit incorporates all applicable requirements contained in the following documents:
Incorporates DAQE-AN128250007-17 dated June 14,2017
1.Comment on an item originating in R307-203 regarding Pennitted Source
Sulfur Content Limit R307-203 limits sulfur content in fuel oil to 0.85 lbs/lvlMBtu and
BACT limits sulfur content to 0.0015% which is not more than0.$022lbsllvlMBtu.
Therefore, compliance with the BACT limit will demonsfrate the compliance with R307-
203 limit for the sulfir content. [Comment last updated on 6/24/2017]
Comment on an item originating in this permit regarding Permitted Source
40 CFR 64 Compliance Assurance Monitoring (CAM): CAM has been evaluated and
exempted as per 40 CFR 64.2(b)(1xvi) because continuous compliance methods are used
in this permit. [Comment last updated on6l20/2006]
Comment on an item originating in this permit regarding Perrnitted Source
Emission standards in lb/mmBTU in condition II.B.1.d of the AO: The lb/mmBTU limits
listed in AO are for reference only as an equivalent to the ppmvd @ 15% Oz dry, therefore,
are not calried over to the Title V permit [Comment last updated on 10/12/2021)
Comment on an item originating in this permit regarding Perrnitted Source
Source specific definition: Source specific definition: (1) Unit Operating Hour: Any clock
hour during which a unit combusts any fuel, either for part of the hour or for the entire
hour;
(2) Unit Operating Day: Any calendar day in which a unit combusts any fuel;
(3) CO 8-hour block average: For each operating hor:r, calculate the average CO
concentration measured by the CEMS corrected to 15 percent of Oz and the seven (7) unit
operating hours immediately preceding that unit operating hour.
(4) NO.4-hour rolling average: For each operating hour, calculate the average the NO"
concenfration measured by the CEMS corrected to 15 percent of Oz and the three (3) unit
operating hours immediately preceding that unit operating hour.
(5) NO, Daily Average: For each unit operating day calculate a daily average of NO*
emissions based on all valid unit operating hours during the day.
(6) NO" 30-day rolling average: For each unit operating day, calculate a 30-day rolling
average from the current daily average and the previous twenty-nine (29) NO. daily
averages. [Comment last updated on6115/2006)
Comment on an item originating in NSPS Subpart Da regarding tlZ: GE Frame 7-EA Generator (in
Combined Cycle Mode)
Duct Burner Da limit: (l) 40 cFR 60.42Da(a)(1) - PM limit of 0.03 lb/rnmBTU: the initial
stack test conducted in 2011 demonstrated that the duct burner was in compliance with the
Da limit and it is required to conduct stack testing once every five years in the Title V
permit.
(2) 40 CFR 60.a2Da$)Q) * the natural gas fired bumer is exempted from the opacity
limit.
(3) 40 CFR 60.43DaOX2) - SOz limit: natural gas is the only combustion fuel forthe duct
burner with the estimated emission rate of 0.0006 lb/mmBTU (Appendix D of Title V
application). Therefore, the duct burner is subjected to 40 CFR 60.43Da(bX2) which is
100 percent ofthe potential cornbustion concenfiation (zero percent reduction). No
2.
5.
Project OPP012t250008 Page 35 Tttle V Operating Permit #4900234004
6.
coopliance demonsfration is required.
(4) 40 CFR 60.4Da{d)Q) - NO* limit of 0.15 lb/mmBTubased on 30 days rolling
average (except during start up, shut down or malfunction): BACT limit for the combined
NO* emissions from the gas turbine and duct bumer is 0.0184 lb/mm BTU (based on 30
day rolling average). Therefore, compliance with the BACT limit will demonstate the
compliance witn NSpS Da limit for the duct burner. [Comment last updated on
t0lt2l202r)
Comment on an item originating in this Permitted Source
Renewal Pennit (2011): (l) NESAI{P Zzzzrequirements for the emergency generator are
included.
(2) The GHG emission in 2010 was reported as 179,776.9 metric tons. The GHG
applicability has bem reviewed and evaluated in this renewal permit and there ,re no
requirements included in this permit. [Last updated October 27 ,201L]
Comment on an item originating in this permit regarding Permitted Source
Arlministrate Amendment Q0L7):
(1) NO. emission limit is changed from 90 tons to 69 tons per rolling l2-month period;
(2) A written Emissions Minimization Plan is required;
(3) A plant wide combined PMro+NO,*SOz limitation has been removed. [Last updated
Jtme28,20l7l
7.
Project OPP0128250008 Page 36 Tttle V Operating Permit #14900234004
State of Utah
SPENCERI. COX
Govemor
DEIDREHENDERSON
Lieuterranl Goverrtor
Deparhent of
Environmental Quality
KimberlyD. Shelley
Execattive Director
DIVTSION OF AIR QUALTTY
Bryce C. Bird
Director
12825
January L8,2022
Mr. Mark SchwarE
Nebo Power Plant
1265 Bamberger Road
Payson, UT 84651
DAQO-OP0128250008-22
ELECTROMC MAIL
Dear Mr. Schwartz
Re: Operating Permit Application for Utah Assoc. Municipal Power Systems - Nebo (Payson) Power Plant
The application for an Operating Pennit for the above site was received on July 7,2021. The apptcation
was classified as a Title V renewal application, in accordance with R307415-7c.
Please review the enclosed copy of the permit thoroughly to assure that you and all affected staffmembers at
your organization are aware of its requirements. If you have any questions regarding this permit, please
contact me at [phone] or by e-mail at [e-mail].
Sincerely,
Signed By Jennifer IIe on January 18,2022
Jennifer He
Environmental Engineer
Operating Permit Section
195 North 1950 West. Sdt Lake City, UT
Mailing Ad&ess: P.O. Box 144820 . Sak Latc City, UT u1144820
Tclcphone [phone] . Fax [phone] . T-D-D. [phone]
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Montrose Air Quality Services
6823 South 3600 West Spanish Fork, Utah 84660
(801) 794-2e50 (801) 266:7111
Meter Box Calibration Data Form
(English Units)
Date
1t5t2024
Average Yi
1.006
Orfice Manometer
Setting aH
0.50
1.00
1.50
2.OO
3.00
4.00
Barometric Pressure
25.78
Average AH Calibrated By Std MeterYi
1.695 JA 0.99497
Meter Box Number
APEX XC-522
DGM No. 20227130
Std Test Meter
(Vs) Ft3
5.002
5.001
10.005
10.oo4
10.004
10.009
Dry Gas Meter
Outlet
(Td o) "F
58
60
61
62
62
67
67
71
71
73
72
75
Dry Gas Meter
(vd) Ft3
4.938
4.928
9.903
9.959
9.933
9.924
Std Test Meter
(Ts)'F
62
62
62il
04
66
66
68
6E
70
70
71
TimeA
Minutes
11.53
8.15
13.53
11.58
9.22
8.00
AH/',|3.6
0.04
0.07
0.11
o.15
o.22
o.29
, Std Test Meter
Average Temp.
62.00
.63.00
65.00
67.OO
69.00
70.50
lnlet
rrd D "F
59
65
66
71
71
78
77
81
76
79
78
82
Average
(Td) "F
60.50
65.00
69.50
74.00
74.75
76.75
Yi
1.004
1.011
1.010
1.007
1.0M
1.004
Average Yi
1.006
AH
1.711
1.701
1.757
1.715
1.639
1.648
Average AH
1.695
Montrose Air QualitY Services
6823 South 3600 West Spanish Fork, Utah 84660
(s01) 794-2950 [phone]
Meter Box Calibration Data Form
(English Units)
Date
1t212024
Average Yi
1.006
Orfice Manometer
Setting AH
0.50
1.00
1.50
2.OO
3.00
4.00
Barometric Pressure
25.56
Average AH Calibrated By Std MeterYi
1.718 JA 0.99497
Meter Box Number
APEX XC-522-10
DGM No.351501
lnlet
OdD"F
77u
76
87u
93
88
95
91
94
91
99
Average
od) "F
78.00
80.25
83.50
86.25
87.50
89.75
AII
'1.623
1.7U
1.765
1.773
1.685
1.678
Average AH
1.7'.18
Std Test Meter
(Vs) Ft3
5
5.004
10.001
10.oo3
10.04
10.001
Dry Gas Meter
Outlet
(Td o) "F
75
7A
81
77
77
80
80
82
82
83
84
85
Dry Gas Meter
(vd) Ft3
4.876
4.987
9.979
10.121
10.053
10.o22
Std Test Meter
(Ts) "F
74
75
76
76
76
76
7A
77
77
78
78
78
Time O
Minutes
11.10
8.23
13.40
11.65
9.30
8.02
AH/13.6
0.04
0.07
0.11
o.15
0.22
o.29
Yi
1.025
1.003
1.007
0.996
1.004
1.003
Average Yi
1.006
Std Test Meter
Average TemP.
74.50
76.00
76.00
76.50
77.50
78.00
Monhose Air Quality SeMces
6823 Souttr 3600 West Spanish Fork, Uhh 84660
(s01) 7e4-2e50 (801) 2ef,-7111
. Meter Box Callbrafion Data Form
(Engllsh Unrb)
Dab
nn024
AverageY
0.990
Orfice Manomerbr
Sefrng aH
0.50
1.00
1.50
2.OO
3.00
4.00
Barometic Pressure
25.61
AverageAH Gatlbrated By SH MebrY
1.682 ATT/JA 0.99497
Mebr Box Number
APD( XC-522-14
DGM No. 10'17791
lnlet
Odl)"F
75
75
72
80
78
89
85
9{
g0
95
95
97
AH
1.831
1.769
1.686
1.616
1.596
1.5%
AverageAH
1.682
SU Test MeEr
(Vs) FB
5.001
5.004
10.002
10
10
1o.oo1
Dry Gas Meter
Outet
(l'd o) "F
62
63u
66
66
70
70
73
73
7A
76
78
Dry Gas Meter
(vd) Ft3
5.1
5.096
10.1s5
10.194
10.175
10.136
Avenage
rrd) "F
68.75
70.50
75.75
79.75
83.50
86.50
sto resiMeer
frs)'F
60
65
65
65
65
68
68
70
70
70
70
72
TlmeQ
Mlnutes
11.97
8.3
13.25
11.22
9.12
7.9
AH/13.6
0.04
0.07.
0.11
o.15
0.22
0.29
Yi
0.986
0.984
0.989
0.990
0.994
0.999
Average V
0.990
Std Test Mehr
Average Temp.
62.50
65.00
66.50
69.OO
70.00
71.00
Monhose Air Quallty Services
6823 South 3600 West Spanlsh Fork, Utah 84660
(801) 7*2e50 (801 ) 2AA-7 11 1
Meter Box Gallbration Dab Form
(Engllsh UnlE)
Dab
1t101i2024
Aver4e Y
1.029
Orflce Manomebr
Sefiing AH
0.50
1.00
1.50
2-OO
3.00
4.00
Barometic Pressure
25.8
Meter Box Number
ES C-5000
DGM No.8219557
Average AH
1.632
SH Test Mebr
(vs) FB
5.001
5.001
9.999
1o.-oo2
10.003
10.002
DryGas Mebr
Outlet
(Id o) "F
57
59
59
60
60
63
63
66
66
dt
67
69
Calibrabd By Std MebrV
ATT 0.9s497
lnlet
rrd l)'F
58
61
61
64u
68
68
71
71
74
74
76
ATI
1.616
1.638
1.ff|
1.631
1.610
1.633
Average AH
1.A32
Dry Gas Meter
(vd) Fftl
4.75
4.786
9.584
9.5&4
9.5E
9.567
Avenage
(Td) "F
58.75
61.00
63.75
67.00
69.50
71.50
Std TestMebr
(Ts)'F
63
65
65
68
68
68
6A
70
70
71
71
73
TimeO
MinuEs
11.15
7.92
13.03
11.18
9.07
7.90
aH/13.6
0.04
o.o7
0.11
o.15
0.22
0.29
YI
1.036
1.O24
1.O25
1.029
1.O28
1.O28
Average Yi
1.O29
SH TestMehr
Average TemP.
64.00
66.50
68.00
69-OO
70.50
72.OO
Montrose Air Quallty Services
6823 South 3600 West Spanlsh Fork, Uhh 84660
(801) 79/-2950 (801 ) 26&7 111
ample Box Temperature Sensor Calibration Form
Sample Box Numben lmplnger Boxes (Gal)
DaF,:1181i2024
Galibrated Bf GG
Barometrlc Ptussur€: 25.55
ReErence: Digl-Sense 20250'92 SN:210429562
ReErence Point Source a Reference Thermocouple
Number (specify) Thermomebr Pobntlometer
TemPerafu re'F TemPerafu re'F
APD(
#1A(XC522)
APP(
#2A(XC5?2-1OI
APD(
ffiA (XC522-14)
ES
#1A(c-5000)
Probe on
Probe off
CPM
Oven on
Oven off
lmplnger lce
lmplngeramb.
Prcbe on
Prcbe off
CPM
Oven on
Oven off
lmplnger lce
lmplngeramb.
Probe on
Probe off
CPM
Oven on
Oven off
lmpinger ice
lmpingeramb.
Probe on
Probe off
GPM
Oven on
Oven off
lmplnger lce
lmplngeramb.
Temperafure
Difrrence b
%
4.14
0.00
0.19
-0.19
4.14
o.oo
-0.19
0.14
4.f I
0.00
0.19
0.00
0.00
-0.19
-0.14
0.19
0.19
0.19
0.00
o.20
0.00
0.00
0.19
0.00
-0.19
4.28
4.20
{.19
1
1
3
4
4
5
5
1
1
3
4
4
5
5
1
1
3
4
4
5
5
1
1
3
4
4
5
5
241
71
72
24
70
33
71
242
71
71
245
71
33
72
297
71
72
248
71u
72
246
72
70
245
71
33
72
251
71
72
24
73
34
72
238
70
72
248
72u
71
245
73
71
245
72
34
72
251
72
72
242
72
33
71
a Type of callbraflon system used.
b (raference temp. oF + 460) - (test thermometer temp- 0F + 480)
reference temPenafura oF + 460
* 100< 1.5%
Montose Air QualltY Services
6E23 Soutr 3600 West Spanlsh Fork, Uhh 84660
(801) 7 e+2950 (8ol ) 266-7 1 11
Sample Box Temperature Sensor CallbraUon Form
Sample Box Number Prcbes (Gal)
Date:118112U24
Calibrated BY: GG
Barometic Pressurq 25.55
ReErencs Dlgi€ense 20250'92 SN:210429562
35
160
220
250
350
4A1
35
rc2
222
248
350
464
,a)z',-A b)
c)
d)
e)
D
a)
z'.-B b)
c)
d)
e)
0
a)
3'-C b)
c)
d)
e)
0
ReErence Polnt Sourca a
Number (sPedfy)
Referenca ThermocouPle
Thermometer Pobnflomebr
Temperature'F TemPerature'F
35
161
221
249
352
460
36
162
221
249
352
463
3p-35
159 159
224 225
252 250
351 350
463 461
lce Water
HotWater
Boillng Water
Warm Oil
HotOil
Boillng Oil
lceWater
HotWater
Boillng WatEr
Warm Ol!
HotOil
Boiling Oil
lceWater
HotWater
Boiling Water
Warm Oll
HotOll
Bolling Oll
lce Water
HotWater
Boiling Water
Warm Oil
HotOil
Boillng Oil
Temperafure
Dlfierence b
%
0.00
-0.16
-0.15
0.14
4.25
0.11
-o.20
0.00
0.15
4.14
4.25
0.11
-o.20
0.00
-0.15
o.28
o.12
o.?2
-o.20
0.00
4.29
4.28
-o.12
-0.11
4'-A
a)
b)
c)
d)
e)
D
36
161
222
251
350
462
35
161
220
249
349
461
a Type of callbration system used.
b (refurence bmp- "F + 460) - (testthermomeErtemp. 'F + 460) * 100< 1-5%
reference temPerafure oF + 460
Montrose Alr QualitY Servies
6823 South 3600 West Spanish Fork, Utah 84660
(801) 7e4-2e50 (801 ) 266-7 1 11
Sample Box Temperafu re Sensor Callbratlon Form
Sample Box Numben Probes (Cal)
Date:11912024
Catlbnabd BY CG -ATT
Baromefic Prcssurc: 25.5
Reftrence: Dlgi-Sense 20250-92 SN:210429562
42
140
226
260
345
455
41
145
232
260
353
463
41
135
224
253
u1
449
41
'l.37
224
259w
451
42
't39
227
260
346
453
40
1M
233
259
a52
461
a)
6'-A b)
c)
d)
e)
0
a)
6'-8 b)
c)
d)
e)
0
a)
b)
c)
d)
e)
f)
a)
b)
c)
d)
e)
D
Refrrence Polnt Source a
Number (sPecfY)
Refurence ThermocouPle
Thermomehr Pobntomebr
Temperafure'F TemPerafirre'F
42
136
23
255
343
450
42
138
227
260
346
450
lce Water
HotWater
Boiling Water
Warm Oll
HotOll
Bolling Oil
lc,e Water
HotWabr
Bolllng WaEr
Warm Oil
HotOIl
Bolllng Oil
lce Wabr
HotWater
Bolllng Water
Warm Oil
HotOll
Boiling Oil
lce Water
HotWater
Bolllng Water
Warm Ol!
HotOll
Bolllng Oil
Temperature
Dlftrence b
o/o
4.20
4.17
0.15
4.28
4.25
-0.11
-0.20
4.17
-0.15
-0.14
-0.25
0.11
0.00
-o.17
0.15
0.00
o.12
-o.22
4.20
4.17
0.14
-0.14
-o.12
4.22
7'.-C
7',- D
aTypeof callbrEfion sysbm used.
b (rarturence bmp- "F + 460) - (test thermomebr temp. 'F + 460) ' 100< 1.5%
refiercnce hmPerafure oF + 460
Montrose Air Quality Serviges
Certlflcate of Balance Calabratlon
Addres: 6823 South 3600 West
Cty/state/zlp: Spanish Fork, Utah 84660
Manuf;actlrcr:
Model:
Serlal Number:
ldentlficatlon:
locadon:
Nomlnal Mass
1
20
50
100
2@
Comments:
Sartarius
Analytical
8a110530706871
AET#1
SmallTrailer
lndlcatlon
L
19.9999
49.9999
99.9998
199.9998
71412024
Error
0.0000
-0.0001
-0.0001
-0.(x)02
-o.0002
Nomlnal Mass
L
20
50
1(x)
2@
lndlcatlon
1.
19.9999
49.9999
99.9998
199.9998
CertlflcateNo.: U+z0?frl
Callb. Date: tl4lzilU
Technlclan: CheYneY GuYmon
Next Callbradon:
Reference Welghts Cal ld:
Err.or
0.0000
-1E-04
-0.(x)01
-0.(x)02
-0.0002
Pertlnent Informatlon:
The artlfact described herein has been catibrated using standards traceble to NIST. This is
to certify the data reported herein ts true and correct as the date callbrated. The
procedure used to callbrate the artlfact meets the requlrements to meet MAQS Standards.
Authorlzed Slgnaurc:
Montrose Air Quality Services
Certlflcate of Balance Calabratlon
Address: 5823 South 3500 West
clty/State/Zlp: Spanish Fork, Utah 84660
Manufacturcr:
Model:
SerlalNumber:
ldentlficatlon:
Location:
Shimadzu
Top Loader
D4u467tLAE'l#2439
AET#2
SmallTrailer
CertlficateNo.: U+2O24fi2
Glib. Date: U4l2O24
Technlcian: CheYneY GuYmon
Next Calibratlon:
Reference Weights Cal ld:
Nomlnal Mass
1"
20
50
100
200
Comments:
lndlcatlon
1.00
20
49.98
99.97
199.97
71412024
Error
0.00
o
-0.02
-0.03
-0.03
lndlcatlon
1.00
19.99
49.98
99.98
L99.97
Error
0
-0.01
-0.02
-0.02
-0.03
Nomlnal Mass
L
20
50
100
200
Pertlnent lnformatlon:
The artifact descrlbed heretn has been callbrated using standards traceble to NIST. This is
to certiff the data reported hereln is true and correct as the date calibrated. The
procedure used to calibrate the artifuct meets the requirements to meet MAQS Standards.
Authorlzed Slgnature:
Montrose Air QualitY Services
Certlflcate of Balance Calabratlon
Address: 5823 South 3600 West
Clty/State/zlp: Spanish Fork, Utah 84660
Manufacturer:
Model:
SerialNumber:
ldentlflcatlon:
Locatlon:
Nomlnal Mass
1
20
50
100
200
Comments:
OHAUS
Top Loader
8350103094
Arr#5
Gooseneck
lndlcatlon
1,
20
50
99.9
199.9
71412024
Certlficate No.: tl4'2024*5
catlb. Date: il412024
Techniclan: CheYneY GuYmon
Error
0
0
-o.1
0
-0.1
Next Calibatlon:
Reference Welghts Cal ld:
Error
0
0
o
-0.1
-0.1
Nomlnal Mass
1
20
50
100
200
lndlcatlon
L
20
49.9
100
199.9
Pertinent lnformation:
The artiftct described herein has been cattbrated uslng standards traceble to NIST. Thls ls
to certiff the data reported hereln is true and correct as the date calibrated. The
procedure used to catlbrate the artifact meets the requirements to meet MAQS Standards'
Authorlzed Slgnatur€:
Montrose Air QualitY Services
@rtificate of Balance Calabratlon
Address: 6823 South 3600 West
city/Sate/Zlp: Spanish Fork, Utah 84650
Manufachrrcr:
Model:
Serial Numben
ldentification:
locatlon:
OHAUS
Analytical
8329582368
AET#6
Gooseneck
lndlcatlon
1
20
49.9998
99.9998
199.9998
71412024
Error
0.0000
0
.-0.0002
-0.0002
-0.0002
Nomlnal Mass
1.
20
50
100
200
lndlcatlon
0.9999
20
49.9998
99.9997
199.9998
Error
-0.0001
0
-o.0002
-0.0003
-0.0002
Cartificate No.: U4-2O24*6
Gtib. Date: U4l2O24
Technlclan: CheYneY GuYmon
Next Callbratlon:
Reference Welghts Cal ld:
Nomlnal Mass
1,
20
50
100
2@
Comments:
Pertlnent lnformatlon:
The artifact described herein has been callbrated using standards traceble to NIST. This is
to certlff the data reported herein is true and correct as the date calibrated. The
procedure used to calibrate the artifact meets the requirements to meet MAQS Standards.
Authorlzed Slgnature:
Montrose Air QualitY Services
Certlflcate of Balance Calabration
Address: 6823 South 3600 West
Clty/State/Zip: Spanish Fork, Utah 84660
Manufacturer:
Model:
Serlal Number:
ldentlficatlon:
locatlon:
Firstaden
HC21404N
94L
MAqS-1
Laboratory
lndlcatlon
,1
20
49.9999
100
199.9999
71412024
Error
0.0000
0.0000
-0.0001
0
-0.0001
Nominal Mass
L
20
50
100
200
Certlftcate No.: 1/4'2024*8
Gllb. Date: U4l2o24
Technlclan: CheYneY GuYmon
Next CalibraUon:
Reference Weights Cal Id:
Nomlnal Mass
1
20
50
100
200
Comments:
lndlcatlon Errur
1 0.0000
20 0.0000
500
99.9999 -0.0001
200 0
Pertlnent lnformatlon:.
The artiftct described herein has been catibrated using standards traceble to NIST. This is
to certify the data reported herein ls true and correct as the date calibrated. The
procedure used to callbrate the artlfact meets the to meet MAQS Standards.
Autlorized Signature:
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SITE SAFETY PLAN BOOKLET
Customer:
Location:
Units:
Glient Proiect Manager:
Revision Date: December 2, 2019
rar' * filii"-Jirl t ttl. l;rl
Page 1 ofl
Site Safety Plan and JHA Purpose and lnstructions
Purpose
Employee safety is the top priority of Montrose Environmental Group. Allemployees must be
trained to assess and mitigate hazards. The District Manager and Project Manager are
responsible to ensure all hazards have been properly identified and managed. All employees
have Stop Work Authority in all situations where an employee feels they or their co-worker
cannot perform a job safely or if there is a task for which they have not been adequately trained.
The Site Safety Plan (SSP) has been developed to help assist Montrose test crews with
identifying physical and health hazards and determining how the hazards will be managed.
Additionatly, the SSP will help each crew manage the safety of the employees by providing
emergency procedures and information. The booklet contains a severalsafety forms that may
be required in the field.
lnstructions
The SSP consists of the following:
1. A Pre-Mobilization Test Plan - To be completed in it's entirety by the client project Manager
prior to the test.
2. A Job Hazard Analysis is a standardized, two-page, fillable form that is used to evaluated the
tasUsite's particular hazards and controls. The form also includes a daily toolbox topic and
daily hazard review with sign off by the team. The client Project Manager is responsible to
comptete the JHA form through section 8. Upon arrival at the test site, the team wil! review the
form for accuracy, making any corrections required and complete the remainder of the JHA.
Section 9 will require at least three tasks, hazards and controls be identified for the project.
Each team member has the option to discuss making changes or adding to the JHA and must
sign on the Job Hazard Analysis form in agreement and sign in Section 10. The JHA is to be
modified when conditions change. A toolbox meeting with a daily topic in addition to a review of
the hazard analysis is required daily for the duration of the test. An additional sheet of paper
with the toolbox topic and signatures can be added to the SSP packet,
3. Hazard Control Matrix - contains useful information on both engineering and
administrative controls that a crew can use to reduce or eliminate the hazards they have
observed plus applicable PPE that may be required.
4. Additional Forms, as applicable
a. Aerial Lift lnspection Form
b. Heat Stress Prevention Form Based on Heat lndex
c. Extended Hours Form
The SSP is a living document. The Project Manager should continually update their SSPs as
new information and conditions change or if new hazards are presented.
Each completed SSP should be maintained with the Test Plan in the office for a period of 3
years. There will be an audit process developed for the Site Safety Plans.
OOlAS.SAFETY-MM4
i*&; * iriit-i l\| i ii{ i,:} i
Page 1 of 2
PRE.MOBILIZATION TEST INFORMATION
Source Tvpe: New Source: _ Revisit:- Prj#/Dateffech:
CoalFired Electric Utility: _ Ethanol Plant: _ ChemicalMfg. of
CemenULime Kiln Plant: _ Special$ Mfg. of:
Anticipated Effluent Composition - check allthat apply and fill in expected concentration in ppm/%
lf other, explain:
Flammable: _, Toxic: Corrosive: Dust:
Engineering Controls to be lmplemented:
tr
co
u
NOx
tr
SOz
tl
other
tr
voc
PROJECT NAME/LOCATION:
TEST DATE:
PROJECT #:
PROJECT MANAGER:
TEST SCOPE:
SITE CONTACT: Name:Contact Phone:
Additional Safety Equipment Required:
Personal gas monitors: _
Respiratory Protection:
Half Face- Full Face- HEPA Filters- Supplied Air:
-
(Safety Dept. Approval)
Approximate Flue Gas Temperatures, (F)
below 210 210 to 450 450 to 950 above 950 other
lf other, explain:
Approximate Duct Pressure, (iwg):
trtr
-3 -3 to +3 +3 to +7
n
other
tr
above
lf other, explain:
+7
OOlAS.SAFETY-FM-1
fdfui , tr'it-i' i! ! irl ..'r,rt
Page2ot2
PRE-MOBI LIZATION TEST IN FORMATION
Sampling Location: Stack Port
-
Duct Port
-Approximate Sampling Platfornr Height, (ft)
below 6 6
lf other, explain:
Access and Protection:
Elevators: Ladders: Aerial Lift: _ Scaffold:
-
Equipment Hoist:
-Guardrails:
-
Toe plate:
-
Engineered Tie Off Points: Heat Shield: -
Other:
Describe how equipment will be mobilized to the sampling location:
tr
to 50
tr
to 100
n
above
tr
other100
Additional lnformation:
Effluent Ghemica! Requlatory Limits
Gas Name Chemica!
Formula
Cal OSHA PEL1
(ppm)
Cal OSHA
STEL2
(oom)
NIOSH REL
TWA3 (ppm)
Cal OSHA
Geiling
(ooml
IDLH4
(ppm)
Carbon Monoxide co 25 200 35 200 1,200
Nitric Oxide NO,25 ND5 25 ND 100
Sulfur Dioxide SOz 2 5 2 ND 100
Hvdroqen Chloride HCI 0.3 2 ND 2 50
Hydrogen Sulfide HzS 10 15 10 (10 min.)c 50 100
)alifomia Occupationa! Safety and Health Administration (OSHA) Permissible Exposure Limit (PEL) based on an ?-hour shifr;
2: Cal OSHA Short-term Exposure Limit (STEL) based on a 1S-minute pefiod;
3: Nalional lnstitute for Occupational Safety and Heatth (NIOSH) Recommended Exposure Limit (REL) Time-weighted Average (TWA) based
on an &hour shift;
4: lmmediately Dangerous to Life or Health (IDLH);
5: Not Defined (ND);
C: Ceiling Limft' - Maximum allowable human exposure limit for an aifuome or gaseous substance, which is not to be exceeded, even
momentarily.
Prepared by:
Reviewed by:
Date:
Date:
OOlAS-SAFETY-FM-1
]lient Contact Name )ate
Facility SSP Writer )M
Glient Rep I
Job Preparatlon
I loo Site Walk Through Completed tr
I Sate Work Permit Received from Client
Site Specific Training Complete
lf the heat index is expected to be above 91", fill out the Heat Stress Prevention Form.
qfi rti i r i'rl i irt il.,, i Job Hazard Analysis
Error Rlsk
E time Pressure E Remote Work Location E > 12 hr shift E wo*ing > 8 consecutive days
E Ucf of procedures E] E{reme temps, wind >30mph E Persona! illness/fatigue E Vague work guidance
E Monotonous Activity E first aay back after time off EI Uuttipte lou locations EI other:
1of3
1.
2.
3.
'acillty lnformatlon/Emergency Preparedness
lf non+mergency medical attention is needed, call: AXIOM #: 877-502-9466.
Plant Emergency #
EMS Location
Certified First Aid Person:
Evacuation Routes Rally Point
Severe Weather Shelter Location Eye Wash & Safety Shower Location
ElYes ENo
lnformation: (llst type):
Stack Gas Temp. ff) Stack Gas Press. ('HrO) Stack Gas Components:
Stack Gas lnhalation Potential? EYes E] tto tf ves. see List of Hazard chemicats.
Dust Hazards
Thermal Bum
Electrical Hazards
lnadequate Lighting
Slip and Tdp
Hand Protection
EI Xot Gloves EIHeat Shields El Otner Protective Clothing:
EI Connections Protected from Elements I Extemal GFCI EOther:
E Xe nating Requirement E lntrinsically Safe Requirement
E lnstall Temporary Lighting ! Headlamps
! Housekeeping E Banicade Area E Other:
E Cut Resistant Gloves E Pinch Pts. E General E Electrical I lmpacl Resistant
SecondaryPermits iEHotWo* EConfinedSpace IExcavatlon
Working from Heights ! E f"tting objects E Fallprotection EJ Orop zone protection E Phtform load ratings
see aleo soct.7 i E Scaffokl inspection E Ladder inspection El ganicaoes for equipmeni
Electrical i EI erpo"ed wire/connector I Verify equipment grounding E Arc Flash
Lifling ! EI Crane lift plan E Rigging inspection E fag fines used E Hoists in place
Respiratory ! E Unexpected exposure E Chemical E Dust (combustible) E PEL provided
E Cartridoes or suoolied air available E Gas detection
PPE EHardHats fisafetyGlasses fisafetyToeShoe/Boot flHearingProtection f]SafetySpotter
E ni-vis vests E Harness/Lanyard* E Goggles EI Personal Monitor Type:
E Metatarsal Guards fl ttot Gloves E Face Shield E Respirator Type:
EINomex/FRC E other PPE:
OOIAS-SAFETY-FM-6
.&, ,, rr;i r-,i; iul I lrr ,, "ll i Job Hazard Analysis
Addtttonal Wo* Place Hazards
ritical Procedures - check all that apply - *indicates additional form must be completed or collected from client
E tteat Stress Prevention' E Confined Space' E Rertal Work Platform* E Roof Work E Scafold
E CotO Weather Work I Hazardous Energy Controf E Exposure Monitoring E Other:
From Helghts
Fall protecgon iEf fixeO Guardrails/Toe boards E falt Prevention PPE Waming Line System
Falling objects protection !E Banicaoing tr Netting E House Keeping fiTethered Tools ElCatctr BlanketorTarp
Fall Hazard Communication itr AdjacenUOverhead Workers I Contraclor Contact E C[ent Contact
2o
7.
8.
9.
Other Conslderatlons
Environmental Hazards - Weather Forecast
E HeaUCotd Etigtrtning E Rain EI Snow EI lce E Tomado E wino Speeo
Steps for Mitigation:
actrical Safuty Plannlng
PtantHookup: EttoV fl22on4ov E +eov E cenerator Exarawiredintopanel
Elecbical Classified Area: EYes ! No Trailer Grounded: E yes E Ho Plug Type
Electrical Hook Up Responsibility:
ist of Hazardous Chemicals
E Acetone E Nitricecio ! Hyorogen Peroxide El compressed Gases
E Hexane ElSufiuric Acid E lsopropyl Alcohol I Fhmmable Gas
EIToluene E Hydrochloric Acid E t-iquiO Nitrogen fl Non-Flammable Gas
E Hzs E Carbon Monoxide
Steps for Mitigation:
rildlife/Fauna in Area
E Poison lvy f] Poison oak flhsects:IWildlife:
Personnel w/ known allergies to bees stings or other allergens? ! Yes EHo
Hazards and Steps
1
2
3
,l
2
3
1
2
3
1
2
3
Z.!t
2
3
,|
2
3
1
2
:3
!1
iz
is
OOIAS-SAFETY-FM--
{ iui,t--/i\ i. itr,i:r I Job Hazard Analysis 3 of3
JHA REVIEW: Crcw Names & Slgnatures
Prlnted Name Signature Date Printed Name Signature Date
11 JHAMeetinq & Review
to review:
r Change in conditions o Extended work hours o Daily Safety Topic
e New workers or contractors o Occurence of near misses or injuries
lnltlaling demonstrates that site condltlons and hazards have not changed from the origlnal SSP, lf changes did occur, make the
necessary updates to this JHA and add notes as applicable ln Saction 9.
Day Dlscuselon Topic lnltials
2
3
4
5
6
7
8
9
10
11
OOIAS-SAFETY-FM-5
4$r, n iiri t ., ir'\ h itt, J 't i
page 1 of 1
Daily Aerial Lift lnspection Form
All checks must be completed prior to each work shifr, before operation of the aerial lift. This checklist must be used at
the beginning of each shifi or following 6 to 8 hours of use.
Aerial Lift Model #:Serlal Number:
Make:Rented or Owned:
. Check Yes" if an item is adequate, operational, and safe.. Gheck "No" to indicate that a repair or other conective action is required prior to use.
. Check "N/A'to indicate "Not Applicable."
Items to be lnspected
1. All aerial lift componentrs are in working condition (i.e. no loose or missing parts, tom or loose
hoses, etc.) - if something can be easily loosened by hand then it is not sufficient.
2. Hydraulic fluid level is sufficient, with the platform fully lowered
3. Hydraulic system pressure (see manufacturer specs) is acceptable.
lf the pressure is low, determine cause and repair in accordance with accepted procedures
as outlined in service manual.
4. Tires and wheel lug nuts (for tightness)
5. Hoses and cables (i.e. worn areas or chafing)
6. Platform rails and safety gate (no damage present)
7. Pivot pins secure
8. Welds are not cracked and structural members are not bent or broken
9. Waming and instructional labels are legible and secure, and load capacity is clearly marked.
10. Manufacture/s lnstruction Manual is present inside the bucket
11. Base controls (switches and push buttons) can be properly operated
12. Platform conditions are safe (i.e. not slippery)
13. Fire extinguisher is present, mounted and fully charged, located inside the bucket
14. Headlights, safety strobe light and back-up alarm are functional
15. Workplace is free of hazards (overhead powerlines, obstructions, level surface, high winds,
etc.) *Do not operate if winds are 20 mph, unless otherwise speclfled by manufacturer
recommendatlons.
Yes
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D
No NrA
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Operator Name & Signature Location Date
Ground Control Name & Signature Location Date
Hamess lnspections:
Printed Name Signature Date
Prinled Nama Sianafi rrc
DatePrinted Name Signature
Page 1 of 1
Extended Hours Safety Audit
Project Number:Date:Time:
When a project is expected to extend past a 14-hour work day, this form must be completed to evaluate
the condition of the crew, and the safety of the work environment.
Permission to proceed into extended work hours must come from a District Manai;er (DM)or Regional Vice
President (RVP). Technical RVPs can authorize moving forward, if they are in the field or if they are
managing the project.
'4. Hold test crew meetinq Test crew initials:
The test leader should assess the environmental and hazardous concerns:
. Temperature and weather r Hoisting. Lighting o PPE (i.e. respirators, etc.). Working from Heights . Pollutant concentration in ambient air (SOz,
HzS, ect.)
Notifv DM'or RVP
The PM must contact either the DM or RVP to discuss the safety issues that may arise due to the
extended work period. During this time, they can come to an agreement on how to proceed. ltems
to discuss include:
a
a
I
a
Reason for extended hours
Reasoh for delay
Production limitaiions
lmpending Weather
Contact the client
The PM, DM or RVP must discuss with client any identified safety concerns, the client's needs and
mutually agree on how to proceed. Discussion should also include the appropriate rest period
needed before the next day's work shift can begin. The DM and/or a RVP must be informed on the
finaldecision.
Final Outcome:
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The test leader should look for signs of the following in their crews:
o lrritability. Lack of motivationo Headaches. Giddiness
o Fatigue. Depression. Reduced alertness, lack of concentration and
memory
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Heat Stress Prevention Form
This form is to be used when the Expected Heat lndex is above 91' F, and is to be kept with project
documentation.
Proiect Manaoer (PMl:Exoected Hiqh Temp:
Date(sl:Exoected Heat lndex:
Review the signs of Heat Exhaustion and Heat Sfoke
lf Heat lndex is above 91' F:. Provide cold water and/or sports drinks to allfield staff (avoid caffeinated drinks and energy
drinks which can increase core temperature).
o Bring no less than one gallon of water per employee
r tf employee(s) are dehydrated, on btood pressure medication or not acclimated to heat,
ensure they are aware of the heightened risk for heat illness
o Providecoolhead bandsfuests/etc.. Have ice available to employees. tmptement work shift rotations and breaks, particularly for employees working in direct
sunlight.o Provide as much shade at the jobsite as possible, including tarps, tents orother acceptable
temporary structures.. PM should interview each fietd straff periodically to evaluate for signs of heat illness
lf Heat lndex is above 103" F:o Employees must stop for drinks and breaks every hour (about 4 cups/hour)
r Employees are not permitted to work alone for more than one hour at a time without a
break ofiering shade and drinkso Emptoyees should wear coot bands and vests if working outside more than one hour at a
timeo PM should interview each field staff every 2 hours to evaluate for signs of heat illness
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