Solicitation Amendment 47PM0024R0004_0001 2024 01 19.pdf

Offers must acknowledge receipt of this amendment prior to the hour and date specified in the solicitation or as amended, by one of the following methods:

(a) By completing items 8 and 15, and returning or (c) By separate letter or electronic communication which includes a reference to the solicitation and amendment numbers. FAILURE OF YOUR ACKNOWLEDGMENT TO BE RECEIVED AT THE PLACE DESIGNATED FOR THE RECEIPT OF OFFERS PRIOR TO THE HOUR AND DATE SPECIFIED MAY RESULT IN REJECTION OF YOUR OFFER. If by virtue of this amendment you desire to change an offer already submitted, such change may be made by letter or electronic communication, provided each letter or electronic communication makes reference to the solicitation and this amendment, and is received prior to the opening hour and date specified.

E. IMPORTANT: Contractor is not is required to sign this document and return copies to the issuing office.

AMENDMENT OF SOLICITATION/MODIFICATION OF CONTRACT 1. CONTRACT ID CODE

2. AMENDMENT/MODIFICATION NUMBER 3. EFFECTIVE DATE 4. REQUISITION/PURCHASE REQUISITION NUMBER 5. PROJECT NUMBER (If applicable)

7. ADMINISTERED BY (If other than Item 6) CODE

STANDARD FORM 30 (REV. 11/2016)

Prescribed by GSA FAR (48 CFR) 53.243

FACILITY CODE

9A. AMENDMENT OF SOLICITATION NUMBER

9B. DATED (SEE ITEM 11)

10A. MODIFICATION OF CONTRACT/ORDER NUMBER

10B. DATED (SEE ITEM 13)

11. THIS ITEM ONLY APPLIES TO AMENDMENTS OF SOLICITATIONS

The above numbered solicitation is amended as set forth in Item 14. The hour and date specified for receipt of Offers is extended. is not extended.

12. ACCOUNTING AND APPROPRIATION DATA (If required) copies of the amendment; (b) By acknowledging receipt of this amendment on each copy of the offer submitted;

13. THIS ITEM APPLIES ONLY TO MODIFICATIONS OF CONTRACTS/ORDERS.

IT MODIFIES THE CONTRACT/ORDER NUMBER AS DESCRIBED IN ITEM 14.

CHECK ONE A. THIS CHANGE ORDER IS ISSUED PURSUANT TO: (Specify authority) THE CHANGES SET FORTH IN ITEM 14 ARE MADE IN THE CONTRACT ORDER

NUMBER IN ITEM 10A.

B. THE ABOVE NUMBERED CONTRACT/ORDER IS MODIFIED TO REFLECT THE ADMINISTRATIVE CHANGES (such as changes in paying office, appropriation data, etc.) SET FORTH IN ITEM 14, PURSUANT TO THE AUTHORITY OF FAR 43.103(b).

C. THIS SUPPLEMENTAL AGREEMENT IS ENTERED INTO PURSUANT TO AUTHORITY OF:

D. OTHER (Specify type of modification and authority)

Except as provided herein, all terms and conditions of the document referenced in Item 9A or 10A, as heretofore changed, remains unchanged and in full force and effect.

15C. DATE SIGNED

15A. NAME AND TITLE OF SIGNER (Type or print)

16C. DATE SIGNED

16A. NAME AND TITLE OF CONTRACTING OFFICER (Type or print)

14. DESCRIPTION OF AMENDMENT/MODIFICATION (Organized by UCF section headings, including solicitation/contract subject matter where feasible.)

PAGE OF PAGES

6. ISSUED BY CODE

8. NAME AND ADDRESS OF CONTRACTOR (Number, street, county, State and ZIP Code) (X)

CODE

15B. CONTRACTOR/OFFEROR

(Signature of person authorized to sign)

16B. UNITED STATES OF AMERICA

(Signature of Contracting Officer)

Previous edition unusable

WPH1B

Ingrid Blair, Contracting Officer

This amendment 0001, 47PM0024R0004 for the Title V Emissions and Boiler Tuning solicitation is to supply the answer the submitted questions from 1/10/24 site visit. The proposal submission due date remain the same at January 29, 2024 by 1 pm

EST.

WPH1B

GSA, PBS R11 Office of Acquisition Building Services Division (BSD) 1800 F St. NW, 4th Floor Washington, DC 20405 USA

GSA, PBS R11 Office of Acquisition Building Services Division (BSD) 1800 F St. NW, 4th Floor Washington, DC 20405 USA

EQWPSA-24-0002

47PM0024R0004

1 377

1/19/2024

12/20/2023

01/19/2024

RFI ques�ons from Title V Emissions 1/10/2024 Site Visit RFP 47PM0024R0004

Confirming the next opacity off-stack due in 2024 and is it the intention to perform the off-stack once every 3 years (2027) on all six units during one mobilization. Should there be a second line item for these services?

Yes, off-stack stack testing is required once every three (3) years. Off-stack testing is included in this 5-year contract in separate line items scheduled for the Base period (2024 after April 1) under CLIN # 0014, and in the third option period (2027 after April 1) under CLIN # 3014.

Will Central Heating & Refrigeration Plant (CHRP) Heating Operation & Transmission Division (HOTD) be providing CEMS service parts, as well as linearity test gases for both the NOX/CO and the O2 systems.

Yes – GSA will provide/purchase service parts. The contractor is expected to recommend, identify exact parts, and provide a quote for required parts. GSA will purchase parts as needed. GSA will provide all test gasses for both the NOX/CO and the O2 systems for linearity.

Sec�on C.1.2 Rela�ve Accuracy Test Audits (RATA): what are the stack eleva�ons for each stack?

Ans:

Boilers Stack Eleva�on B1/Stack 1 130 � B2/Stack 2 130 � B3/Stack 3 133 � B5/Stack 4 133 � B5/Stack 5 133 � B6/Stack 6 133 �

Sec�on C.1.3.2 Off stack Calibra�on of Opacity Monitors: are the NIST traceable filter lenses needed to complete these tasks to be provided by us or will these be provided by the plant?

GSA has a full set of opacity filters. GSA arranges for annual filter cer�fica�on, so the filters are ready to use for any relevant opacity tes�ng.

Sec�on C.1.3.3 Repair Parts: please clarify that any unwarranted parts necessary for repairs, quality assurance, and quality control of the CEMS system will be billed separately following the service visits.

Parts are purchased using a quote, budget approval, then purchase process. The vendor should not provide a bunch of parts then bill prior to approval. The vendor should recommend service parts prior to service. (i.e., annual maintenance should include a known list of parts). In a repair situa�on GSA will do it’s best to describe symptoms and then the tech will come to the site to diagnose an issue.

Some�mes the tech can bring parts with other �mes the vendor will have to order parts for delivery. In urgent scenarios, GSA will pay for rush delivery.

What is the plan for performing linearities on boilers that rarely run/never run certain quarters. Will we be able to request they run up a boiler for testing purposes.

We do not start boilers for testing and then turn them off. Boiler linearity testing is dependent on operation. If a boiler does not operate in a calendar quarter, it will not require NOx/O2 testing for that calendar quarter. CGA and Opacity is performed on 6 boiler opacity units every quarter, regardless of operation or not. The vendor will get paid for the number of linearity tests performed in a given quarter. Additional expense is limited to billing for extra mobilizations if boilers come online after the linearity service visit.

Please provide the most recent RATA and linearity test reports for either Boilers 1, 2, or 6, 3 or 4 and 5.

Ans: Please see attached:

Please provide the bid tabulation results for the current contract.

The tabulations are to be submitted according to the SF1449 sheet per service performed (4 RATA per year, 6 Linearity testing reports. Payment will be provided in accordance with the services performed.

RELATIVE ACCURACY

TEST REPORT

Central Heating and Refrigeration Plant 325 13th and C Streets Southwest

Washington, DC 20407

Boiler 1

Job # 23-011

Test Date: 01-23-23 Report Date: 02-15-23

GSA

1-877-GCI-TEST | www.gcitest.com | Office Locations: Wellington, OH - Plainfield, IN - Conover, NC - Nixa, MO

February 15, 2023

I, Steve Teague, hereby certify that the data obtained for GSA at the Central Heating and

Refrigeration on Boiler 1 is in accordance with procedures set forth by the USEPA. This report accurately represents the data obtained from the testing procedures and analysis of this data.

I, Carl Vineyard, hereby certify that I have reviewed this report and to the best of my knowledge, the data presented herein is complete and accurate. GCI operated in conformance with the requirements of the ASTM D7036 during the test project.

I, Stacy Sword, hereby certify that the report was prepared under my direction in conformance with the requirements of ASTM D7036. To the best of my knowledge the data and results are complete and accurate.

. . . . . . 1-2INTRODUCTION

3-4SUMMARY OF TEST RESULTS

5-13

METHODS AND DISCUSSION

APPENDIX

17-23

24-36

37-46

Sample Calculations

Test Data Sheets

GCI Calibration Data

47-55Calibration and Gas Certification Sheets . . .

56-66

67-71

Plant Data

Accreditation

INTERMEDIATE CALCULATIONS

14-15

INTRODUCTION

This report presents the results of the Relative Accuracy test performed for GSA at the Central Heating and Refrigeration Plant on Boiler 1.

The purpose of the tests was to determine the Relative Accuracy of the plant

CEMS of the unit. The results can be found in the Summary of Test Results section of this report.

The testing was performed by Grace Consulting, Inc., located at 510 Dickson

Street, Wellington, OH 44090. Present during the testing from Grace Consulting, Inc. were Steve Teague and Kurt Kinter. Also present during the testing was Mark

Yohn with GSA.

The tests were performed on January 23, 2023 The testing was completed in accordance with USEPA test methods as published in the Federal Register.

The sampling and analytical procedures can be found in the Methods and

Discussion section of this report. The raw field data and the equations used to determine the final results are presented in the Appendix section.

SUMMARY OF TEST RESULTS

The following presents the results of the Relative Accuracy tests performed for Ga at the Central Heating and Refrigeration Plant on Boiler 1.

Date Monitor Units Difference RA Allowable Results

1/23/2023 NOx lb/mmBtu 4.82% 10% PASS

1/23/2023 CO ppm 0.287 ± 5 ppm PASS

1/23/2023 O2 Percent 3.95% 10% PASS

Bias

Results Bias

Monitor Mean of Confidence Factor Adj.

Date Monitor Designation Difference Coefficient Required Factor

1/23/2023 NOx lb/mmBtu 0.005 0.001 Yes 1.039

NO2 Gas Value Recorded Value

45.59 44.16 96.86%

Gas Type Low (zero) Mid PGVP# Exp. Date PGVP# Exp. Date

NOx CC151572 XC026911B B62022 10/31/2030 B62022 4/27/2030

CO CC151572 XC004907B B62022 10/20/2030 B62021 12/7/2029

O2 XC026911B CC151572 B62022 8/23/2030 B22017 7/10/2025

The complete results can be found on the computer printouts following.

PROTOCOL GAS

RELATIVE ACCURACY

NOx CONVERTER EFFICIENCY

CC434256

High

XC030336B

CC46579

1/23/2023

Date Converter Efficiency %

BIAS TEST RESULTS

INTERMEDIATE CALCULATIONS

Grace Consulting, Inc. Grace Consulting, Inc.

Start Stop Steam NOx lb/mmBtu Use Run Time Time Flow RM CEMS Difference

Y 1 8:15 8:35 111 0.120 0.114 0.006 Y 2 8:47 9:07 110 0.124 0.117 0.007 N 3 9:25 9:45 110 0.122 0.108 0.014 Y 4 9:58 10:18 110 0.123 0.117 0.006 Y 5 10:30 10:50 109 0.121 0.117 0.004 Y 6 11:02 11:22 108 0.122 0.118 0.004 Y 7 11:33 11:53 108 0.124 0.119 0.005 Y 8 12:05 12:25 108 0.124 0.119 0.005 Y 9 12:37 12:57 110 0.121 0.119 0.002 Y 10 13:10 13:30 109 0.121 0.119 0.002

Averages 109 0.122 0.118 0.005

Standard Deviation 0.002 Confidence Coefficient 0.001 Relative Accuracy 4.82

Bias Test Pass/Fail FAIL Bias Adjustment Factor 1.039

1/23/2023 NOx lb/mmBtu

Relative Accuracy Calculations and Results Relative Accuracy Test Audit

GSA: Central Heating & Refrigeration Plant Unit Boiler 1

Start Stop Steam CO PPM Use Run Time Time Flow RM CEMS Difference N 1 8:15 8:35 111 1.800 2.300 -0.500 Y 2 8:47 9:07 110 1.700 2.000 -0.300 Y 3 9:25 9:45 110 2.800 3.100 -0.300 Y 4 9:58 10:18 110 1.900 2.200 -0.300 Y 5 10:30 10:50 109 1.800 1.800 0.000 Y 6 11:02 11:22 108 1.800 1.900 -0.100 Y 7 11:33 11:53 108 2.000 2.200 -0.200 Y 8 12:05 12:25 108 1.200 1.200 0.000 Y 9 12:37 12:57 110 1.600 1.900 -0.300 Y 10 13:10 13:30 109 2.100 2.300 -0.200

Averages 109 1.878 2.067 -0.189

Standard Deviation 0.127 Confidence Coefficient 0.098 Relative Accuracy 0.287

Relative Accuracy = Absolute Difference + Confidence Coefficient

1/23/2023

CO PPM

Relative Accuracy Calculations and Results Relative Accuracy Test Audit

Start Stop Steam O2 Percent Use Run Time Time Flow RM CEMS Difference

Y 1 8:15 8:35 111 7.300 7.000 0.300 N 2 8:47 9:07 110 7.700 7.300 0.400 Y 3 9:25 9:45 110 7.600 7.300 0.300 Y 4 9:58 10:18 110 7.700 7.400 0.300 Y 5 10:30 10:50 109 7.600 7.400 0.200 Y 6 11:02 11:22 108 7.700 7.500 0.200 Y 7 11:33 11:53 108 7.800 7.500 0.300 Y 8 12:05 12:25 108 7.800 7.500 0.300 Y 9 12:37 12:57 110 7.500 7.400 0.100 Y 10 13:10 13:30 109 7.500 7.300 0.200

Averages 109 7.611 7.367 0.244

Standard Deviation 0.073 Confidence Coefficient 0.056 Relative Accuracy 3.95

1/23/2023 O2 Percent

Relative Accuracy Calculations and Results Relative Accuracy Test Audit

Moisture Calculations (Runs 1 - 6) Moisture Calculations (Runs 7 - 10)

Client: GSA Site: Central Heating & Refrigeration Plant

Date: 01/23/23 Unit Number: Boiler 1

Run: 1 2 3

Total Impinger Content: 55.40 55.40 54.30 Volume Metered: 22.405 22.405 22.159

Meter Temperature: 79.00 79.00 86.00 Delta H: 1.700 1.700 1.700

Barometric Pressure: 29.80 29.80 29.80 Meter Correction Factor: 0.985 0.985 0.985

Volume Measured (DSCF): 21.61 21.61 21.10 Water Volume (SCF): 2.61 2.61 2.56

% Moisture in Flue Gas: 10.8 10.8 10.8

Run: 4 5 6

Total Impinger Content: 54.30 59.00 59.00 Volume Metered: 22.159 22.439 22.439

Meter Temperature: 86.00 88.00 88.00 Delta H: 1.700 1.700 1.700

Barometric Pressure: 29.80 29.80 29.80 Meter Correction Factor: 0.985 0.985 0.985

Volume Measured (DSCF): 21.10 21.29 21.29 Water Volume (SCF): 2.56 2.78 2.78

% Moisture in Flue Gas: 10.8 11.6 11.6

Grace Consulting, Inc.

Moisture Calculations (Runs 7 - 10)

Client: GSA Site: Central Heating & Refrigeration Plant

Date: 01/23/23 Unit Number: Boiler 1

Run: 7 8 9

Total Impinger Content: 55.10 55.10 59.30 Volume Metered: 22.426 22.426 22.417

Meter Temperature: 87.00 87.00 87.00 Delta H: 1.700 1.700 1.700

Barometric Pressure: 29.80 29.80 29.80 Meter Correction Factor: 0.985 0.985 0.985

Volume Measured (DSCF): 21.32 21.32 21.31 Water Volume (SCF): 2.60 2.60 2.80

% Moisture in Flue Gas: 10.9 10.9 11.6

Run: 10

Total Impinger Content: 59.30 Volume Metered: 22.417

Meter Temperature: 87.00 Delta H: 1.700

Barometric Pressure: 29.80 Meter Correction Factor: 0.985

Volume Measured (DSCF): 21.31 Water Volume (SCF): 2.80

% Moisture in Flue Gas: 11.6

Date: 1/23/2023 Pollutant: NOx

Monitor Span: 229.90

Run Number

Average Measured

Value

Initial Zero Gas Bias

Final Zero Gas Bias

Zero Gas Drift

Initial Upscale Gas Bias

Final Upscale Gas Bias

Upscale Gas Drift

Calibration Gas

Percent Moisture

Corrected Value, Dry

Basis

Corrected Value, Wet

Basis 1 66.5 0.22 0.26 0.02 100.61 100.72 0.05 100.30 10.8 66.2 59.1 2 66.7 0.26 0.30 0.02 100.72 100.80 0.03 100.30 10.8 66.3 59.1 3 66.3 0.30 0.34 0.02 100.80 100.90 0.04 100.30 10.8 65.8 58.7 4 66.5 0.34 0.46 0.05 100.90 101.09 0.08 100.30 10.8 65.9 58.8 5 66.6 0.46 0.51 0.02 101.09 101.17 0.03 100.30 11.6 65.9 58.3 6 66.6 0.51 0.56 0.02 101.17 101.23 0.03 100.30 11.6 65.8 58.2 7 66.6 0.56 0.49 -0.03 101.23 101.30 0.03 100.30 10.9 65.8 58.6 8 66.8 0.49 0.43 -0.03 101.30 101.11 -0.08 100.30 10.9 66.0 58.8 9 66.9 0.43 0.35 -0.03 101.11 101.15 0.02 100.30 11.6 66.2 58.5

10 67.2 0.35 0.31 -0.02 101.15 101.08 -0.03 100.30 11.6 66.5 58.8

Cgas = (Cavg - Co) * Cma / (Cm - Co) Eq. 6C-1 where: Cgas = Effluent gas concentration, dry basis, ppm Cavg = Average gas concentration indicated by gas analyzer, dry basis, ppm Co = Average of initial and final system calibration bias check responses for the zero gas, ppm Cm = Average of initial and final system calibration bias check responses for the upscale calibration gas, ppm Cma = Actual concentration of the upscale calibration gas, ppm

Grace Consulting, Inc.

Sampling System Bias Check and Measured Value Correction

GSA

Central Heating & Refrigeration Plant - Unit Boiler 1

Sampling System Bias Check and Measured Value Correction

Date: 1/23/2023 Pollutant: CO

Monitor Span: 49.74

Run Number

Average Measured

Value

Initial Zero Gas Bias

Final Zero Gas Bias

Zero Gas Drift

Initial Upscale Gas Bias

Final Upscale Gas Bias

Upscale Gas Drift

Calibration Gas

Percent Moisture

Corrected Value, Dry

Basis

Corrected Value, Wet

Basis 1 2.0 -0.01 -0.04 -0.06 24.64 24.61 -0.06 24.51 10.8 2.0 1.8 2 1.9 -0.04 -0.06 -0.04 24.61 24.58 -0.06 24.51 10.8 1.9 1.7 3 3.0 -0.06 -0.08 -0.04 24.58 24.28 -0.60 24.51 10.8 3.1 2.8 4 2.0 -0.08 -0.11 -0.06 24.28 24.21 -0.14 24.51 10.8 2.1 1.9 5 1.9 -0.11 -0.07 0.08 24.21 24.27 0.12 24.51 11.6 2.0 1.8 6 1.9 -0.07 -0.02 0.10 24.27 24.38 0.22 24.51 11.6 2.0 1.8 7 2.2 -0.02 0.04 0.12 24.38 24.43 0.10 24.51 10.9 2.2 2.0 8 1.3 0.04 0.06 0.04 24.43 24.49 0.12 24.51 10.9 1.3 1.2 9 1.9 0.06 0.07 0.02 24.49 24.56 0.14 24.51 11.6 1.8 1.6

10 2.5 0.07 0.13 0.12 24.56 24.70 0.28 24.51 11.6 2.4 2.1

Cgas = (Cavg - Co) * Cma / (Cm - Co) Eq. 6C-1 where: Cgas = Effluent gas concentration, dry basis, ppm Cavg = Average gas concentration indicated by gas analyzer, dry basis, ppm Co = Average of initial and final system calibration bias check responses for the zero gas, ppm Cm = Average of initial and final system calibration bias check responses for the upscale calibration gas, ppm Cma = Actual concentration of the upscale calibration gas, ppm

Central Heating & Refrigeration Plant - Unit Boiler 1

Date: 1/23/2023 Pollutant: O2

Monitor Span: 22.16

Run Number

Average Measured

Value

Initial Zero Gas Bias

Final Zero Gas Bias

Zero Gas Drift

Initial Upscale Gas Bias

Final Upscale Gas Bias

Upscale Gas Drift

Calibration Gas

Percent Moisture

Corrected Value, Dry

Basis

Corrected Percent, Wet

Basis 1 8.3 0.04 0.06 0.09 11.02 11.05 0.14 10.96 10.8 8.2 7.3 2 8.7 0.06 0.07 0.05 11.05 11.06 0.05 10.96 10.8 8.6 7.7 3 8.6 0.07 0.08 0.05 11.06 11.08 0.09 10.96 10.8 8.5 7.6 4 8.7 0.08 0.04 -0.18 11.08 11.05 -0.14 10.96 10.8 8.6 7.7 5 8.7 0.04 0.07 0.14 11.05 11.07 0.09 10.96 11.6 8.6 7.6 6 8.8 0.07 0.06 -0.05 11.07 11.09 0.09 10.96 11.6 8.7 7.7 7 8.8 0.06 0.10 0.18 11.09 11.11 0.09 10.96 10.9 8.7 7.8 8 8.8 0.10 0.12 0.09 11.11 11.13 0.09 10.96 10.9 8.7 7.8 9 8.7 0.12 0.15 0.14 11.13 11.14 0.05 10.96 11.6 8.5 7.5

10 8.7 0.15 0.17 0.09 11.14 11.16 0.09 10.96 11.6 8.5 7.5

Cgas = (Cavg - Co) * Cma / (Cm - Co) Eq. 6C-1 where: Cgas = Effluent gas concentration, dry basis, percent Cavg = Average gas concentration indicated by gas analyzer, dry basis, percent Co = Average of initial and final system calibration bias check responses for the zero gas, percent Cm = Average of initial and final system calibration bias check responses for the upscale calibration gas, percent Cma = Actual concentration of the upscale calibration gas, percent

GSA

Central Heating & Refrigeration Plant - Unit Boiler 1

METHODS AND DISCUSSION

Test Methods used at GSA, Central Heating and Refrigeration Plant on Boiler 1

Method 4

One moisture test was performed for every two runs of the Methods 3A, 7E, and 10 testing.

Method 3A

O2 concentrations were determined with 10 Method 3A test runs on the Normal load. GCI used a monitor range of 0-22.16% for O2.

Method 7E

NOx emissions were determined with 10 Method 7E test runs on the Normal load.

GCI used a monitor span of 229.9 ppm for NOx.

Method 10

CO emissions were determined with 10 Method 10 test runs on the Normal load.

GCI used a monitor span of 49.74 ppm for NOx.

All gaseous sampling was performed at 16.7, 50.0, and 83.3 percent of the measurement line.

Discussion

Environmental conditions did not adversely affect the test results.

Testing was completed by following GCI’s Internal Site Specific Test Plan #23-011 with no deviations.

APPENDIX

SAMPLE CALCULATIONS

Central Heating and Refrigeration Plant Boiler 1

01-23-23 Run 1

METHOD 7E (NOx) CALCULATION (O2 Based) lb/dscf = 1.194 x 10-7 x PPM

7.06E-06 = 1.194 x 10-7 x 59.1 lb/mmBtu = lb/dscf x f-factor x 20.9

(20.9 (1−𝐵𝑤𝑎) − %𝑂2)

0.120 = 7.06E-06 x 10610 x 20.9

(20.9 (1−.027) − 7.3)

Bwa = 0.027 – moisture fraction for ambient air

*Sample calculations use rounded numbers and computer printouts carry all decimal places.

The following is used to convert ppm dry to ppm wet.

ppm dry x

%1 moisture = ppm wet

Calculate the arithmetic mean of the differences, d, of a data set as follows:

n li id n ld

Where:

n = Number of data points n li id = Algebraic sum of the individual differences di di = The difference between a reference method value and the corresponding continuous emissions monitoring system value (RMi-CEMi) at a given point in time i.

When calculating the arithmetic mean of the difference of a flow monitor data set, be sure to correct the monitor measurements for moisture if applicable.

Calculate the standard deviation, Sd, of a data set as follows:

n n d d

S n li i n li i d

Calculate the confidence coefficient (one-tailed), CC, of a data set as follows:

StCC d 0.975=

Where:

t0.975 = t value (see Table 7-1).

TABLE 7-1 T-VALUES

n-1 t0.975 n-1 t0.975 n-1 t0.975

1 12.706 12 2.179 23 2.069 2 4.303 13 2.160 24 2.064 3 3.182 14 2.145 25 2.060 4 2.776 15 2.131 26 2.056 5 2.571 16 2.120 27 2.052 6 2.447 17 2.110 28 2.048 7 2.365 18 2.101 29 2.045 8 2.306 19 2.093 30 2.042 9 2.262 20 2.086 40 2.021 10 2.228 21 2.080 60 2.000 11 2.201 22 2.074 >60 1.960

The following equation is used to calculate the relative accuracy of a data set:

100×

RM

ccd

RA

RM = Arithmetic mean of the reference method values.

d = The absolute value of the mean difference between the reference method values and the corresponding continuous emissions monitoring system values.

cc = The absolute value of the confidence coefficient.

BIAS ADJUSTMENT CALCULATION

CEM

BAF +=1

TEST DATA SHEETS

GSA DATE 01/23/23

Central Heating and Refrigeration Plant OPERATOR Kurt Kinter

23-011

Boiler 1 METER NO

DAILY FIELD BALANCE

CHECK

500.0

29.80 METER CORR. 0.985 DELTA H@ 1.662

1-2 Sample Point Delta H Probe Set Pt. Imp. Temp Meter Out Vac Press. Initial Dry Gas Volume 6.827

8:15 5 1.7 250 40 77 3 10.55

8:45 10 1.7 250 41 78 3 14.28

3441.8 15 1.7 250 43 78 3 17.96

3497.2 20 1.7 250 45 79 3 21.82

.003@15 25 1.7 250 46 80 3 25.56

.002@10 30 1.7 250 47 81 3 29.232

1.7 250 44 79 3 22.405

3-4 Sample Point Delta H Probe Set Pt. Imp. Temp Meter Out Vac Press. Initial Dry Gas Volume 30.214

9:25 5 1.7 250 54 84 3 33.96

9:55 10 1.7 250 51 85 3 37.70

3497.2 15 1.7 250 50 86 3 41.45

3551.5 20 1.7 250 48 87 3 45.21

.004@15 25 1.7 250 49 88 3 48.94

.002@12 30 1.7 250 51 88 3 52.373

1.7 250 51 86 3 22.159

5-6 Sample Point Delta H Probe Set Pt. Imp. Temp Meter Out Vac Press. Initial Dry Gas Volume 53.478

10:30 5 1.7 250 55 87 3 57.23

11:00 10 1.7 250 51 87 3 60.95

3438.3 15 1.7 250 52 87 3 64.72

3497.3 20 1.7 250 53 88 3 68.44

.005@15 25 1.7 250 54 89 3 72.20

.004@10 30 1.7 250 55 89 3 75.917

1.7 250 53 88 3 22.439

Grace Consulting, Inc.

RM 4 Moisture Field Data Sheet

CLIENT

PLANT NAME

PROJECT ID

Initial Weight

Final Weight

Initial Leak Check

OHM21

Final Leak Check

Average

LOCATION

BAROMETRIC

PRESSURE

Run Number

Start Time

Stop Time

Final Leak Check

Average

Run Number

Start Time

Stop Time

Run Number

Start Time

Stop Time

Initial Weight

Final Weight

Initial Leak Check

Initial Weight

Final Weight

Initial Leak Check

Final Leak Check

Average mailto:.003@15 mailto:.002@10 mailto:.004@15 mailto:.002@12 mailto:.005@15 mailto:.004@10

7-8 Sample Point Delta H Probe Set Pt. Imp. Temp Meter Out Vac Press. Initial Dry Gas Volume 77.121

11:33 5 1.7 250 53 87 3 80.82

12:03 10 1.7 250 52 87 3 84.61

3497.3 15 1.7 250 51 87 3 88.35

3552.4 20 1.7 250 52 87 3 92.11

.004@15 25 1.7 250 54 87 3 95.82

.003@10 30 1.7 250 55 87 3 99.547

1.7 250 53 87 3 22.426

9-10 Sample Point Delta H Probe Set Pt. Imp. Temp Meter Out Vac Press. Initial Dry Gas Volume 101.172

12:37 5 1.8 250 58 86 3 104.91

13:07 10 1.8 250 55 86 3 108.65

3552.4 15 1.8 250 56 87 3 112.39

3611.7 20 1.8 250 57 87 3 116.14

.001@15 25 1.8 250 58 87 3 119.86

.002@8 30 1.8 250 60 88 3 123.589

1.8 250 57 87 3 22.417

Run Number

Start Time

Stop Time

Initial Weight

Final Weight

Initial Leak Check

Initial Weight

Final Weight

Initial Leak Check

Final Leak Check

Average

Final Leak Check

Average

Run Number

Start Time

Stop Time mailto:.004@15 mailto:.003@10 mailto:.001@15 mailto:.002@8

Time O2% NOx PPM CO PPM

8:15 8.2 66.3 1.7 8:16 8.3 66.5 1.9 8:17 8.2 66.4 1.9 8:18 8.1 66.8 2.0 8:19 8.2 66.7 1.9 8:20 8.3 66.5 1.9 8:21 8.4 66.5 1.9 8:22 8.3 66.4 1.9 8:23 8.3 66.5 1.9 8:24 8.2 66.5 2.0 8:25 8.3 67.0 2.0 8:26 8.2 66.3 2.0 8:27 8.3 66.3 2.1 8:28 8.3 66.2 2.1 8:29 8.3 66.9 2.1 8:30 8.3 66.6 2.1 8:31 8.3 67.0 2.2 8:32 8.4 66.5 2.2 8:33 8.3 66.0 2.3 8:34 8.3 66.0 2.3 8:35 8.2 66.7 2.4

Average 8.3 66.5 2.0

Client: GSA Plant: Central Heating & Refrigeration Plant

Project #: 23-011 Unit: Boiler 1

Test Date: 1/23/2023 Operator: St. Teague

Run 1

8:47 8.7 66.4 1.4 8:48 8.6 66.8 1.4 8:49 8.6 67.2 1.5 8:50 8.7 66.8 1.6 8:51 8.7 66.5 1.6 8:52 8.7 66.8 1.7 8:53 8.6 67.1 1.7 8:54 8.7 67.0 1.7 8:55 8.7 67.0 1.7 8:56 8.7 67.0 1.8 8:57 8.7 66.8 1.8 8:58 8.7 66.5 1.9 8:59 8.7 66.5 2.0 9:00 8.7 66.6 2.1 9:01 8.7 66.8 2.2 9:02 8.7 66.6 2.3 9:03 8.7 66.4 2.2 9:04 8.7 66.4 2.1 9:05 8.6 66.4 2.1 9:06 8.7 67.0 2.1 9:07 8.7 66.8 2.2

Average 8.7 66.7 1.9

Run 2

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

Test Date: 1/23/2023 Operator: St. Teague

9:25 8.7 66.0 3.0 9:26 8.6 66.5 3.0 9:27 8.6 66.2 3.0 9:28 8.6 66.6 3.1 9:29 8.7 66.7 3.0 9:30 8.6 66.6 3.0 9:31 8.6 66.5 3.0 9:32 8.7 66.2 3.0 9:33 8.7 66.0 3.0 9:34 8.7 66.0 3.1 9:35 8.6 65.5 3.1 9:36 8.7 66.6 3.1 9:37 8.7 66.6 3.1 9:38 8.6 66.6 3.1 9:39 8.6 66.3 3.0 9:40 8.6 66.4 2.9 9:41 8.6 66.3 2.9 9:42 8.8 66.3 2.8 9:43 8.7 66.4 2.8 9:44 8.7 66.0 2.8 9:45 8.7 66.1 2.8

Average 8.6 66.3 3.0

Run 3

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

Test Date: 1/23/2023 Operator: St. Teague

9:58 8.7 66.1 2.3 9:59 8.7 66.4 2.4

10:00 8.6 67.2 2.3 10:01 8.7 66.7 2.3 10:02 8.6 66.1 2.2 10:03 8.7 66.5 2.2 10:04 8.7 66.5 2.1 10:05 8.6 66.5 2.1 10:06 8.6 66.8 2.1 10:07 8.7 66.8 2.0 10:08 8.7 66.6 2.0 10:09 8.7 66.0 2.0 10:10 8.7 66.0 1.9 10:11 8.7 66.8 1.9 10:12 8.7 66.7 1.8 10:13 8.7 66.6 1.8 10:14 8.8 66.7 1.8 10:15 8.7 66.7 1.8 10:16 8.7 66.3 1.9 10:17 8.7 66.1 1.9 10:18 8.7 66.6 1.8

Average 8.7 66.5 2.0

Run 4

Test Date: 1/23/2023 Operator: St. Teague

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

10:30 8.7 66.8 1.8 10:31 8.7 66.5 1.8 10:32 8.7 66.8 1.8 10:33 8.7 66.8 1.8 10:34 8.7 66.6 1.9 10:35 8.7 66.5 1.9 10:36 8.7 66.4 2.0 10:37 8.7 66.7 1.7 10:38 8.7 66.5 1.9 10:39 8.8 66.5 1.8 10:40 8.6 67.0 1.8 10:41 8.7 66.4 1.8 10:42 8.8 66.1 1.9 10:43 8.7 66.7 1.9 10:44 8.7 66.6 1.9 10:45 8.7 66.6 1.9 10:46 8.8 66.5 1.9 10:47 8.8 66.2 1.8 10:48 8.7 66.7 1.8 10:49 8.8 67.1 1.8 10:50 8.7 67.2 1.9

Average 8.7 66.6 1.9

Run 5

Test Date: 1/23/2023 Operator: St. Teague

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1

11:02 8.7 66.6 1.8 11:03 8.7 66.8 1.8 11:04 8.8 66.3 1.8 11:05 8.8 66.3 1.8 11:06 8.8 66.7 1.8 11:07 8.8 66.7 1.8 11:08 8.8 66.3 1.8 11:09 8.8 66.6 1.9 11:10 8.9 66.6 1.9 11:11 8.8 66.7 1.9 11:12 8.8 66.5 1.9 11:13 8.8 66.6 2.0 11:14 8.8 67.0 2.0 11:15 8.8 66.3 2.0 11:16 8.8 66.7 2.1 11:17 8.8 66.8 2.0 11:18 8.8 66.7 2.0 11:19 8.8 66.7 2.0 11:20 8.9 66.6 2.0 11:21 8.8 66.7 1.9 11:22 8.8 67.0 1.9

Average 8.8 66.6 1.9

Run 6

Test Date: 1/23/2023 Operator: St. Teague

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1

11:33 8.8 66.6 2.1 11:34 8.9 66.5 2.1 11:35 8.8 66.8 2.0 11:36 8.9 66.5 2.0 11:37 8.8 66.9 2.0 11:38 8.8 66.7 2.0 11:39 8.8 66.8 2.1 11:40 8.8 66.5 2.1 11:41 8.8 67.0 2.1 11:42 8.9 66.6 2.1 11:43 8.9 66.0 2.1 11:44 8.8 66.3 2.2 11:45 8.8 66.1 2.3 11:46 8.8 66.5 2.3 11:47 8.8 67.0 2.3 11:48 8.8 66.9 2.2 11:49 8.8 66.9 2.3 11:50 8.9 66.7 2.3 11:51 8.9 66.7 2.4 11:52 8.8 66.4 2.4 11:53 8.8 66.7 2.4

Average 8.8 66.6 2.2

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

Test Date: 1/23/2023 Operator: St. Teague

Run 7

12:05 8.9 66.8 1.2 12:06 8.8 67.2 1.2 12:07 8.8 67.1 1.2 12:08 8.8 66.5 1.3 12:09 8.9 66.8 1.3 12:10 8.8 66.9 1.3 12:11 8.9 66.9 1.3 12:12 8.8 67.0 1.2 12:13 8.8 66.9 1.2 12:14 8.8 66.8 1.2 12:15 8.8 66.8 1.3 12:16 8.8 67.1 1.3 12:17 8.9 66.7 1.3 12:18 8.9 66.7 1.3 12:19 8.9 66.7 1.3 12:20 8.8 67.0 1.3 12:21 8.9 66.8 1.3 12:22 8.9 66.6 1.3 12:23 8.9 66.6 1.4 12:24 8.8 66.5 1.4 12:25 8.9 66.6 1.4

Average 8.8 66.8 1.3

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

Test Date: 1/23/2023 Operator: St. Teague

Run 8

12:37 8.8 66.7 2.0 12:38 8.8 66.8 2.0 12:39 8.9 66.5 1.9 12:40 8.8 66.0 1.9 12:41 8.8 66.9 1.9 12:42 8.7 67.0 1.9 12:43 8.7 67.0 2.0 12:44 8.6 67.1 2.0 12:45 8.7 67.3 2.0 12:46 8.7 67.0 2.0 12:47 8.6 67.5 2.0 12:48 8.7 67.2 1.9 12:49 8.6 66.5 1.9 12:50 8.7 66.3 1.9 12:51 8.7 67.0 1.9 12:52 8.7 66.9 1.9 12:53 8.6 66.8 2.0 12:54 8.7 67.3 1.9 12:55 8.7 67.1 1.9 12:56 8.7 67.0 2.0 12:57 8.7 67.2 1.9

Average 8.7 66.9 1.9

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1 Project #: 23-011

Test Date: 1/23/2023 Operator: St. Teague

Run 9

13:10 8.7 66.8 2.4 13:11 8.6 66.8 2.3 13:12 8.6 67.2 2.4 13:13 8.6 67.2 2.4 13:14 8.6 67.0 2.4 13:15 8.7 67.3 2.5 13:16 8.7 67.3 2.5 13:17 8.6 67.2 2.5 13:18 8.7 67.2 2.5 13:19 8.7 67.0 2.5 13:20 8.6 67.2 2.5 13:21 8.7 67.3 2.5 13:22 8.6 67.2 2.5 13:23 8.7 67.5 2.5 13:24 8.6 67.3 2.5 13:25 8.7 67.4 2.5 13:26 8.7 67.7 2.5 13:27 8.8 67.4 2.5 13:28 8.7 66.9 2.5 13:29 8.7 66.9 2.5 13:30 8.7 67.0 2.5

Average 8.7 67.2 2.5

Run 10

Test Date: 1/23/2023 Operator: St. Teague

Client: GSA Plant: Central Heating & Refrigeration Plant

Unit: Boiler 1

GCI CALIBRATION DATA

Client GSA Test Date 1/23/2023 Plant Name Central Heating and Refrigeration Plant Project # 23-011 Source Identification Boiler 1 Operator St. Teague

Calibration Data For Cylinder Cylinder Analyzer Absolute Difference Sampling Runs: 1-10 Number Value Response Difference % of Span Gas Type: NOx % or PPM % or PPM Span: 229.9

Zero Gas CC151572 0.00 0.19 0.19 0.083

NO2 to NO Converter Check EB0120492 45.59 44.16 1.43 96.86% PASS

Mid-Range Gas XC026911B 100.30 100.51 0.21 0.091

High-Range Gas XC030336B 229.90 230.09 0.19 0.083

Run #: 1 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.22 0.01 0.26 0.03 0.02

Upscale Gas 100.51 100.61 0.04 100.72 0.09 0.05

Run #: 2 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.26 0.03 0.30 0.05 0.02

Upscale Gas 100.51 100.72 0.09 100.80 0.13 0.03

Run #: 3 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.30 0.05 0.34 0.07 0.02

Upscale Gas 100.51 100.80 0.13 100.90 0.17 0.04

Run #: 4 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.34 0.07 0.46 0.12 0.05

Upscale Gas 100.51 100.90 0.17 101.09 0.25 0.08

Source Identification Boiler 1 Operator St. Teague

Run #: 5 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.46 0.12 0.51 0.14 0.02 Upscale Gas 100.51 101.09 0.25 101.17 0.29 0.03

Run #: 6 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.51 0.14 0.56 0.16 0.02 Upscale Gas 100.51 101.17 0.29 101.23 0.31 0.03

Run #: 7 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.56 0.16 0.49 0.13 -0.03 Upscale Gas 100.51 101.23 0.31 101.30 0.34 0.03

Run #: 8 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.49 0.13 0.43 0.10 -0.03 Upscale Gas 100.51 101.30 0.34 101.11 0.26 -0.08

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100 Span

Source Identification Boiler 1 Operator St. Teague

Run #: 9 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.43 0.10 0.35 0.07 -0.03

Upscale Gas 100.51 101.11 0.26 101.15 0.28 0.02

Run #: 10 Initial Values Final Values Gas Type: NOx Analyzer System System System System Span: 229.9 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.19 0.35 0.07 0.31 0.05 -0.02

Upscale Gas 100.51 101.15 0.28 101.08 0.25 -0.03

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100

Source Identification Boiler 1 Operator St. Teague

Calibration Data For Cylinder Cylinder Analyzer Absolute Difference Sampling Runs: 1-10 Number Value Response Difference % of Span Gas Type: CO % or PPM % or PPM Span: 49.74

Zero Gas CC151572 0.00 0.02 0.02 0.040

Mid-Range Gas XC004907B 24.51 24.60 0.09 0.181 High-Range Gas CC46579 49.74 49.83 0.09 0.181

Run #: 1 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.01 -0.06 -0.04 -0.12 -0.06

Upscale Gas 24.60 24.64 0.08 24.61 0.02 -0.06

Run #: 2 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.04 -0.12 -0.06 -0.16 -0.04

Upscale Gas 24.60 24.61 0.02 24.58 -0.04 -0.06

Run #: 3 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.06 -0.16 -0.08 -0.20 -0.04

Upscale Gas 24.60 24.58 -0.04 24.28 -0.64 -0.60

Run #: 4 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.08 -0.20 -0.11 -0.26 -0.06

Upscale Gas 24.60 24.28 -0.64 24.21 -0.78 -0.14

Source Identification Boiler 1 Operator St. Teague

Run #: 5 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.11 -0.26 -0.07 -0.18 0.08

Upscale Gas 24.60 24.21 -0.78 24.27 -0.66 0.12

Run #: 6 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.07 -0.18 -0.02 -0.08 0.10

Upscale Gas 24.60 24.27 -0.66 24.38 -0.44 0.22

Run #: 7 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 -0.02 -0.08 0.04 0.04 0.12

Upscale Gas 24.60 24.38 -0.44 24.43 -0.34 0.10

Run #: 8 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 0.04 0.04 0.06 0.08 0.04

Upscale Gas 24.60 24.43 -0.34 24.49 -0.22 0.12

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100

Source Identification Boiler 1 Operator St. Teague

Run #: 9 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 0.06 0.08 0.07 0.10 0.02 Upscale Gas 24.60 24.49 -0.22 24.56 -0.08 0.14

Run #: 10 Initial Values Final Values Gas Type: CO Analyzer System System System System Span: 49.74 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.02 0.07 0.10 0.13 0.22 0.12 Upscale Gas 24.60 24.56 -0.08 24.70 0.20 0.28

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100

Source Identification Boiler 1 Operator St. Teague

Calibration Data For Cylinder Cylinder Analyzer Absolute Difference Sampling Runs: 1-10 Number Value Response Difference % of Span Gas Type: O2 % or PPM % or PPM Span: 22.16

Zero Gas XC026911B 0.00 0.03 0.03 0.135

Mid-Range Gas CC151572 10.96 10.98 0.02 0.090

High-Range Gas CC434256 22.16 22.17 0.01 0.045

Run #: 1 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.04 0.05 0.06 0.14 0.09

Upscale Gas 10.98 11.02 0.18 11.05 0.32 0.14

Run #: 2 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.06 0.14 0.07 0.18 0.05

Upscale Gas 10.98 11.05 0.32 11.06 0.36 0.05

Run #: 3 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.07 0.18 0.08 0.23 0.05

Upscale Gas 10.98 11.06 0.36 11.08 0.45 0.09

Run #: 4 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.08 0.23 0.04 0.05 -0.18

Upscale Gas 10.98 11.08 0.45 11.05 0.32 -0.14

Source Identification Boiler 1 Operator St. Teague

Run #: 5 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.04 0.05 0.07 0.18 0.14

Upscale Gas 10.98 11.05 0.32 11.07 0.41 0.09

Run #: 6 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.07 0.18 0.06 0.14 -0.05

Upscale Gas 10.98 11.07 0.41 11.09 0.50 0.09

Run #: 7 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.06 0.14 0.10 0.32 0.18

Upscale Gas 10.98 11.09 0.50 11.11 0.59 0.09

Run #: 8 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.10 0.32 0.12 0.41 0.09

Upscale Gas 10.98 11.11 0.59 11.13 0.68 0.09

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100

Source Identification Boiler 1 Operator St. Teague

Run #: 9 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.12 0.41 0.15 0.54 0.14

Upscale Gas 10.98 11.13 0.68 11.14 0.72 0.05

Run #: 10 Initial Values Final Values Gas Type: O2 Analyzer System System System System Span: 22.16 Response Response Cal. Bias Response Cal. Bias Drift

% of Span % of Span % of Span

Zero Gas 0.03 0.15 0.54 0.17 0.63 0.09

Upscale Gas 10.98 11.14 0.72 11.16 0.81 0.09

System Calibration Bias = System Cal. Response - Analyzer Cal. Response X 100 Span

Drift = Final System Cal. Response - Initial System Cal. Response X 100

CALIBRATION AND GAS CERTIFICATION SHEETS

Date:

Model: 30.3 (in Hg)

Serial: 14.29 (in Hg)

Temp Temp K' Orifice Actual

Initial Final Orifice Coefficient Vacuum Initial Final Average

(deg F) (deg F) Serial # (see above) (in Hg) (deg F) (deg F) (deg F)

0.68 22.0 791.600 802.070 10.470 70 71 CS-48 0.3580 18 70 70 70

1.1 16.4 802.200 812.382 10.182 71 72 CS-55 0.4687 17 70 71 70.5

1.8 14.7 812.500 824.028 11.528 72 73 CS-63 0.5921 16 71 71 71

3.4 11.5 824.100 836.585 12.485 73 75 CS-73 0.8245 15 71 71 71

0.000

DRY GAS

METER ORIFICE

Vm(std) Vcr(std) Value Variation

(cu ft) (cu ft) Value Variation (in H20) (in H20)

10.566 10.366 0.981 -0.004 1.723 0.061

10.267 10.112 0.985 -0.00013 1.628 -0.034

11.622 11.445 0.985 -0.00029 1.670 0.008

12.600 12.468 0.990 0.00445 1.627 -0.035

Average: 0.985 Average: 1.662 individual values from the average is +-0.2.

Signature: Date:

Important: For valid test results, the Actual Vacuum should be 1 to 2 in. Hg greater than the Theoretical Critical Vacuum shown above.

Grace Consulting, Inc.

EPA Method 5

522 Series Meter Box Calibration Calibration Orifice Method

English Meter Box Units, English K' Factor

12/19/2022

Apex Barometric Pressure:

Oh M21 Theoretical Critical Vacuum:

Important: The Critical Orifice Coefficient, K', must be entered in English units, (ft)^3*(deg R)^0.5/((in.Hg)*(min)).

DRY GAS METER READINGS Critical Orifice Readings

D H (in

H 2 O) Time (min)

Initial

Volume

(cu ft)

Final

Volume

(cu ft)

Total

Volume

(cu ft)

AMBIENT TEMPERATURE

Davee Moody 12/19/2022

CORRECTED VOLUME DRY GAS METER ORIFICE

CALIBRATION CALIBRATION FACTOR Orifice for Calc.

FACTOR Y DH 2.804965416

Note: For Calibration Factor Y, the ratio of the reading of the calibration meter to the dry gas meter, acceptable tolerance of individual values from the average is +-0.02.

For Orifice Calibration Factor dH@, the orifice differential pressure in inches of H20 that equates to 0.75 cfm of air at 68 F and 29.92 inches of Hg, acceptable tolerance of

6.1364.17

D m b mstdm t

H P

VV

( )stdm stdcr

V

V Y =( )

460+ amb b stdcr t

P

KV

q

75.

ø ö ç ç è æ D=D stdcrV

HH

q mailto:dH@ mailto:dH@

CERTIFICATE OF ANALYSIS

Grade of Product: EPA PROTOCOL STANDARD

Part Number: E02AI99E15W0005 Reference Number: 54-402462757-1 Cylinder Number: EB0120492 Cylinder Volume: 146.0 CF Laboratory: 124 - Chicago (SAP) - IL Cylinder Pressure: 2015 PSIG PGVP Number: B12022 Valve Outlet: 660 Gas Code: NO2,BALA Certification Date: Jun 20, 2022

Expiration Date: Jun 20, 2025

Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA 600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a mole/mole basis unless otherwise noted.

Do Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.

ANALYTICAL RESULTS

Component Requested Actual Protocol Total Relative Assay

Concentration Concentration Method Uncertainty Dates

NITROGEN DIOXIDE 45.00 PPM 45.59 PPM G1 +/- 2% NIST Traceable 06/13/2022, 06/20/2022 AIR Balance

CALIBRATION STANDARDS

Type Lot ID Cylinder No Concentration Uncertainty Expiration Date

GMIS 401648671106 CC507727 56.79 PPM NITROGEN DIOXIDE/NITROGEN +/- 1.4% Feb 02, 2025 PRM 12397 D887665 74.2 PPM NITROGEN DIOXIDE/AIR +/- 1.3% Feb 02, 2022 The SRM, PRM or RGM noted above is only in reference to the GMIS used in the assay and not part of the analysis.

ANALYTICAL EQUIPMENT

Instrument/Make/Model Analytical Principle Last Multipoint Calibration

MKS FTIR NO2 017707558 FTIR Jun 20, 2022

Triad Data Available Upon Request

Airgas Specialty Gases Airgas USA LLC 12722 S. Wentworth Ave.

Chicago, IL 60628 Airgas.com

Signature on file

Approved for Release Page 1 of 1

Part Number: E02NI99E15A3615 Reference Number: 32-402562179-1 Cylinder Number: XC026911B Cylinder Volume: 144.0 CF Laboratory: 112 - Troy-32 (SAP) - MI Cylinder Pressure: 2015 PSIG PGVP Number: B62022 Valve Outlet: 660 Gas Code: NO,NOX,BALN Certification Date: Oct 31, 2022

Expiration Date: Oct 31, 2030

Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA 600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a mole/mole basis unless otherwise noted. The results relate only to the items tested. The report shall not be reproduced except in full without approval of the laboratory. Do

Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.

ANALYTICAL RESULTS

Component Requested Actual Protocol Total Relative Assay

Concentration Concentration Method Uncertainty Dates

NOX 100.0 PPM 100.3 PPM G1 +/- 1.3% NIST Traceable 10/21/2022, 10/31/2022 NITRIC OXIDE 100.0 PPM 100.3 PPM G1 +/- 1.3% NIST Traceable 10/21/2022, 10/31/2022 NITROGEN Balance

CALIBRATION STANDARDS

Type Lot ID Cylinder No Concentration Uncertainty Expiration Date

NTRM 200610-45 CC733406 98.61 PPM NITRIC OXIDE/NITROGEN +/-0.9% Oct 06, 2026 PRM 12386 D685025 9.91 PPM NITROGEN DIOXIDE/AIR +/-2.0% Feb 20, 2020 GMIS 401085385103 CC502530 14.68 PPM NITROGEN DIOXIDE/NITROGEN +/-2.1% Oct 31, 2022 GMIS 124206889138 CC323705 4.3 PPM NITROGEN DIOXIDE/NITROGEN +/-2.0% Feb 18, 2023 The SRM, NTRM, PRM, or RGM noted above is only in reference to the GMIS used in the assay and not part of the analysis.

ANALYTICAL EQUIPMENT

Instrument/Make/Model Analytical Principle Last Multipoint Calibration

E/N 54 Nicolet IS50 NO FTIR Oct 20, 2022 E/N 54 Nicolet IS50 NO2 FTIR Oct 20, 2022

Triad Data Available Upon Request

Airgas Great Lakes region Airgas USA LLC 1290 Combermere Dr.

Troy, MI 48083 Airgas.com

Signature on file

Customer: GRACE

CONSULTANTS

CONSULTING INC,

Part Number: E02NI99E15A0237 Reference Number: 32-402404828-1 Cylinder Number: XC030336B Cylinder Volume: 144.0 CF Laboratory: 112 - Troy-32 (SAP) - MI Cylinder Pressure: 2015 PSIG PGVP Number: B62022 Valve Outlet: 660 Gas Code: NO,NOX,BALN Certification Date: Apr 27, 2022

Expiration Date: Apr 27, 2030

Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA 600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a mole/mole basis unless otherwise noted.

Do Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.

ANALYTICAL RESULTS

Component Requested Actual Protocol Total Relative Assay

Concentration Concentration Method Uncertainty Dates

NOX 230.0 PPM 229.9 PPM G1 +/- 1.3% NIST Traceable 04/14/2022, 04/27/2022 NITRIC OXIDE 230.0 PPM 229.9 PPM G1 +/- 1.3% NIST Traceable 04/14/2022, 04/27/2022 NITROGEN Balance

CALIBRATION STANDARDS

Type Lot ID Cylinder No Concentration Uncertainty Expiration Date

NTRM 13010330 KAL004373 243.4 PPM NITRIC OXIDE/NITROGEN +/-0.5% May 04, 2022 PRM 12386 D685025 9.91 PPM NITROGEN DIOXIDE/AIR +/-2.0% Feb 20, 2020 GMIS 401085385103 CC502530 14.68 PPM NITROGEN DIOXIDE/NITROGEN +/-2.1% Oct 31, 2022 The SRM, PRM or RGM noted above is only in reference to the GMIS used in the assay and not part of the analysis.

ANALYTICAL EQUIPMENT

Instrument/Make/Model Analytical Principle Last Multipoint Calibration

E/N 54 Nicolet IS50 NO FTIR Mar 31, 2022 E/N 54 Nicolet IS50 NO2 FTIR Mar 31, 2022

Triad Data Available Upon Request

Airgas Great Lakes region Airgas USA LLC 1290 Combermere Dr.

Troy, MI 48083 Airgas.com

Signature on file

Customer: GRACE

CONSULTANTS

CONSULTING INC,

Part Number: E02NI99E15A02Z4 Reference Number: 32-402558666-1 Cylinder Number: XC004907B Cylinder Volume: 144.0 CF Laboratory: 112 - Troy-32 (SAP) - MI Cylinder Pressure: 2015 PSIG PGVP Number: B62022 Valve Outlet: 350 Gas Code: CO,BALN Certification Date: Oct 20, 2022

Expiration Date: Oct 20, 2030

Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA 600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a mole/mole basis unless otherwise noted. The results relate only to the items tested. The report shall not be reproduced except in full without approval of the laboratory. Do

Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.

ANALYTICAL RESULTS

Component Requested Actual Protocol Total Relative Assay

Concentration Concentration Method Uncertainty Dates

CARBON MONOXIDE 25.00 PPM 24.51 PPM G1 +/- 0.9% NIST Traceable 10/20/2022 NITROGEN Balance

CALIBRATION STANDARDS

Type Lot ID Cylinder No Concentration Uncertainty Expiration Date

NTRM 120112 KAL004165 49.24 PPM CARBON MONOXIDE/NITROGEN +/-0.6% Aug 31, 2024

ANALYTICAL EQUIPMENT

Instrument/Make/Model Analytical Principle Last Multipoint Calibration

E/N 54 NICOLET IS50 CO FTIR Oct 04, 2022

Triad Data Available Upon Request

Airgas Great Lakes region Airgas USA LLC 1290 Combermere Dr.

Troy, MI 48083 Airgas.com

Signature on file

Customer: GRACE

CONSULTANTS

CONSULTING INC

Part Number: E02NI99E15A0302 Reference Number: 32-402291962-1 Cylinder Number: CC46579 Cylinder Volume: 144.3 CF Laboratory: 112 - Troy-32 (SAP) - MI Cylinder Pressure: 2015 PSIG PGVP Number: B62021 Valve Outlet: 350 Gas Code: CO,BALN Certification Date: Dec 07, 2021

Expiration Date: Dec 07, 2029

Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA 600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical uncertainty as stated below with a confidence level of 95%.