REGIONAL HAZE 

SOURCE PERFORMANCE REPORT 

For 

HELCO UNITS H-5 AND H-6 

Two COMBUSTION ENGINEERING MODEL VU-60 

OIL-FIRED BOILERS - 14.1 MW AND 23 MW 

In service at the 

KANOELEHUA-HILL GENERATING STATION 

Located in 

HILO, HAWAII COUNTY, HAWAII 

Prepared for the 

HAWAII ELECTRIC LIGHT COMPANY, INC. 

Test Completion Date: August 28th, 20 10 

Report Submittal Date: October 2oth, 20 1 0 
TABLE OF CONTENTS 

INTRODUCTION 

Table 1 : Background Data 

SUMMARY OF RESULTS 

Table 2: Executive Summary 

Table 3: Unit H-5 Results 

Table 4: Unit H-6 Results 

PROCESS DESCRIPTION 

ANALYTICAL TECHNIQUES 

Table 5: Analytical Instrumentation 

Figure 1 : Instrumental Sample System Diagram 

Figure 2: PM Sample System Diagram 

QUALITY ASSURANCE ACTIVITIES 

APPENDICES: 

A. Field Data Sheets 

B. Example Calculations 

C. Particulate Matter Laboratory Results 

D. Quality Assurance Activities 

E. Calibration Certifications 

F. Logged Data Records 

G. Operational Data 

H. Fuel Analysis Results 

I. Visible Emissions Observation Forms 
Source performance testing was conducted on two oil-fired boilers used to generate 

electrical power while firing 2% sulfur industrial fuel oil. These boilers, designated as Units H-5 

and H-6, are in service at the Kanoelehua-Hill Generating Station (HGS) in Hilo, Hawaii. The 

Hawaii Electric Light Company (HELCO) owns and operates this facility. The Hawaiian 

Electric Company, Inc (HECO) coordinated the testing for this emissions project. TRC - Air 

Measurements, Gainesville Office (TRC) conducted these tests on August 26" through 28~, 

2010. 

The purpose of this testing was to conduct testing in advance to meet the requirements for 

regional haze emissions testing. These sources operate according to requirements set forth by the 

Hawaii Department of Health (HDOH) Covered Source Permit No. 0234-01-C. The testing was 

conducted on each unit while operating at full load. The tests followed the procedures set forth 

in the Code of Federal Regulations, Title 40, Part 60 (40 CFR 60), Appendix A, Methods 1, 2, 

3A, 4,5,6C, 7E, 9, 10, 19,25A ,202, and The US EPA Other Test Method (0TM)-027. 

Exhaust emissions were analyzed from the boiler stacks for oxides of nitrogen (NOx), 

sulfur dioxide (SO*), carbon monoxide (CO), total hydrocarbon compounds (THC) as volatile 

organic compounds (VOC), oxygen (02), and carbon dioxide (CO*) using continuous 

instrumental monitors. Particulate matter (PM) samples for total particulate, PMlo, and PM2.5, 

including condensable particulate, were collected isokinetically fiom the boiler stack using a 

combined hotlcold manual sampling train. Visible emissions tests were also conducted during 

these tests. HECO Environmental Chemistry Laboratory of Honolulu, Hawaii analyzed fuel 

samples for total sulfur content, per the American Society of Testing and Materials (ASTM) 

Method D4294 and gross heating value per ASTM Method D240. Table 1 provides background 

data pertinent to these tests. 

This test report has been reviewed and approved for submittal to HDOH by the following 

representative: 

/ 

TRC - ~llffbheasurements 
TABLE 1 

BACKGROUND DATA 

Test Coordinator: 

Testing Organization: 

Test Participants: 

Test Dates: 

Facility Location: 

Hawaii Electric Light Company, Inc. 

P.O. Box 1027 

Hilo, Hawaii 96721 -1027 

Attn: Bob Moskwa, Staff Engineer 

(808) 969-0423 Phone 

(808) 969-0425 Facsimile 

Email: robert.moskwa~,helcohi.com 

Hawaii Electric Light Company, Inc. 

P.O. Box 2750 

Honolulu, Hawaii 96840 

Attn: Steve Ward, Sr. Environmental Scientist 

(808) 543-4535 Phone 

(808) 543-0425 Facsimile 

Email: stephen.ward@,heco.com 

TRC - Air Measurements, Gainesville Office 

6322 NW 1 8th venue, Suite 170 

Gainesville, Florida 32653 

Attention: Leonard Brenner, 

Manager, Air Measurements 

(352) 378-0332 Phone 

(352) 378-0354 Facsimile 

Email: 1brenner~trcsolutions.com 

Hawaii Electric Light Company, Inc. 

Bob Moskwa, Staff Engineer 

Steve Ward, Sr. Environmental Scientist 

Gary Akimseu 

TRC - Air Measurements 

Leonard Brenner, Manager - Air Measurements 

Roger Osier, Environmental Scientist 

Richard Hyre, Associate Project Manager 

Richard Stallings, Senior Project Manager 

August 261h through 281h, 201 0. 

The Kanoelehua-Hill Generating Station is located in Hilo, 

Hawaii. 
Process Description: 

Regulatory Application: 

Emission Sampling Points: 

Test Methods: 

Unit H-5 is a 14.1-MW Combustion Engineering Model 

VU-60 oil-fired boiler used to produce steam for generation 

of electrical power distributed on the local grid. The boiler 

is fired with industrial fuel oil that has a sulfur content not to 

exceed 2.0%. 

Unit H-6 is a 23-MW Combustion Engineering Model VU60 oil-fired boiler used to produce steam for generation of 

electrical power distributed on the local grid. The boiler is 

fired with industrial fuel oil that has a sulfur content not to 

exceed 2.0%. 

Hawaii Department of Health Covered Source Permit No. 

0234-0 l -C regulates the operation of these sources. 

The Unit 5 stack was a 130 ft tall stack with an approximate 

1.2 degree taper. The stack inside diameter was 55 inches at 

the test ports elevation. The two test ports were located 

approximately 64' downstream from where the top of the 

duct entered from the side and approximately 25' upstream 

of the stack outlet. Flow rate calculations for the tapered 

stack followed EPA guidelines. 

The Unit 6 test location was in a horizontal duct with a 

rectangular cross-section measuring 53.5-inches deep by 

101.5-inches high. The five vertical test ports were located 

21'2" downstream from a bend and 54" upstream from the 

vertical stack. 

EPA Method 1 was used to select particulate matter (PM) 

sampling point locations. 

EPA Method 2 was used to measure stack gas differential 

pressures, i.e., velocity measurements. These measurements 

were used for verification of sampling isokinetics, 

calculation of stack gas flow rates, and determination of 

mass pollutant emission rates. 

EPA Method 3A was used to determine oxygen (02) and 

carbon dioxide (CO2) concentrations. 

EPA Method 4 was used for determination of stack gas 

moisture content. 

EPA Methods 5 and 202 were used for determination of 

total PM (filterable and condensable) concentrations. 
Test Methods (Continued): EPA Method 6C was used for determination of sulfur 

dioxide (SO2) concentrations 

EPA Method 7E was used for determination of nitrogen 

oxides (NOx) concentrations 

EPA Method 9 was used to determine opacity using visible 

emissions (VE) measurements by a certified observer. 

EPA Method 10 was used for determination of carbon 

monoxide (CO) concentrations. 

EPA Method 19 was used for determination of pollutant 

emission rates using published fuel factors. 

EPA Method 25A was used for determination of total 

hydrocarbon compound (THC) concentrations used to report 

volatile organic compound (VOC) concentrations. 

other Test Method (OTM) 027 and EPA Method 202 were 

used for determination of PM25 and PMlo concentrations 

(filterable and condensable). 

American Society of Testing and Materials (ASTM) Method 

D4294 was used to determine sulfur content in the fuel oil 

by x-ray diffraction. 

ASTM Method D240 was used to determine the heating 

value of the fuel oil by bomb calorimeter. 
SUMMARY OF RESULTS 

The Hawaii Electric Light Company, Inc. (HELCO) owns and operates the KanoelehuaHill Generating Station (HGS) in Hilo, Hawaii. Among the units at this facility, two oil-fired 

boilers are used to produce steam for generation of electrical power while firing industrial fuel 

oil that has a sulfur content not to exceed 2.0%. The boilers as designated as Units H-5 and H-6. 

Stack emissions from Units H-5 and H-6 are the subject of this report. 

Table 2 provides the Executive Summary of the Units H-5 and H-6 regional haze 

emissions test results. The emissions test results are an average of the three test runs at the full 

load for each boiler. NOx, CO, VOC, and SO2 emissions concentrations are reported in units of 

parts per million by volume (ppmv) on a dry basis corrected to 3% excess 02. Concentrations of 

PM were reported in terms of grains of particulate per dry standard cubic foot (grtdscf) corrected 

to 12% excess CO2. Emission rates for NOx, SO2, CO, VOC, and PM are reported in terms of 

pounds per million British thermal units of fuel burned (IbstMMBtu) and pounds per hour 

(Ibsthr). Fuel sulfur content is reported on a percent weight basis (% wt). 

TABLE 2 

Executive Summary 

Parameter 

Generator Output (MW) 

N& (ppmvd 9 3% excess 0,) 

Nq (IbsIMMBtu) 

NOx (Ibshr) 

Fuel Sulfur Content (Oo wt. ASTM D-4294) 

SO, (ppmvd 3 3% excess 0,) 

SO, (IbsMMBtu) 

SO2 (I bshr) 

PMT,,, (grams PMDSCF @ 12% CO, per EPA M-51202) 

PM,,,,, (IbsNMBtu) 

PMTmaI (bshr, per EPA M-51202) 

PM,, (grams PMDSCF 3 12% C0, per EPA CTM-2071202) 

PM,, (IbsNMBtu) 

PM,, (Ibshr, per EPA CTM-0271202) 

PM,, (grams PMDSCF 2 12% C0, per EPA CTM-2071202) 

PM, (IbsNMBtu) 

PM2 (Ibshr, per EPA CTM-027R02) 

VE (% opaclh.) 

CO (ppmvd @ 3% excess 0,) 

CO (IbsIMMBtu) 

CO (Ibshr) 

VOC (ppmvd 3 3% excess 0,) 

VOC (I bs/MMBtu) 

VOC (Ibshr) 

Hill Unit 5 

14.0 

376.2 

0.482 

94.7 

0.97% 

518 

0 923 

182 

0 0442 

0 0769 

15 1 

0 0285 

0 0496 

931 

00168 

0 0292 

5 49 

1 04% 

41.3 

0.0322 

6.36 

0.63 

0.00030 

0.060 

Hill Unit 6 

2 1 .2 

328.4 

0.42 1 

122 

0.78% 

401 

0.714 

208 

0 0356 

0 0599 

17.3 

0 0223 

0.0374 

11.2 

0 0184 

0 0307 

9.17 

5.00% 

1.02 

0.00079 

0.23 

0.96 

0.00043 

0.13 
Stratification within the stack was evaluated prior to testing using a three-point traverse. 

The stratification was minimal (less than 5%) for NOx, S02, and C02 emissions. All subsequent 

sampling was conducted from a single point of average emissions during each test run. Each test 

run for the gaseous parameters NOx, SO2, CO, VOC, 02, and CO2 was 60 minutes in duration. 

The total particulate matter test runs, including both filterable and condensable particulate, were 

also 60 minutes in duration. Test runs for PMlo and PM25 were conducted using a combined 

sampling train that collected both sample fractions along with the condensable particulate 

fraction. These runs were 90 minutes in duration. Moisture and velocity measurements were 

conducted in conjunction with the PM sampling. Visible emissions (VE) testing consisted of 

three 6-minute test runs, conducted three times for each boiler. Both TRC and HELCO 

personnel were used to conduct the various VE tests. Fuel samples were collected during each 

day of testing and analyzed for sulfur content and gross heating value. 

Tables 3 and 4 represent the emissions test results for the Unit H-5 and H-6 full load test 

runs, respectively. These tabular summaries contain all pertinent operational parameters, 

ambient conditions, measured emissions, corrected concentrations, and calculated emission rates. 

NOx, SO2, and CO emissions are reported in units of ppmv on a dry basis, corrected to 3% 02. 

Volatile organic compound (VOC) concentrations were determined from THC measurements 

and were determined on a ppmv, wet basis as methane, reported also on a ppmv, dry basis as 

methane, corrected to 3% 02. Concentrations of PM were determined in units of grams of 

PMIDSCF and reported in terms of grains PMIDSCF at 12% excess C02. Emission rates for 

NOx, S02, CO, PM, and VOC are reported in terms of IbsIMMBtu and Ibslhr. 

Volumetric flow and mass emission rates were determined using the EPA Method 1 

through 4 flow data from the PM test runs. EPA Method 19 was used to determine emission 

rates in units of lbs/MMBtu using published F factor fuel data and diluent 02 emissions. Mass 

emission rates for NOx, SO2, CO, and VOC were calculated using the EPA Method 51202 

sample train measured flow rates. Mass emission rates for particulates were determined using 

the measured flow from the sample train from which their respective samples were collected. 

Examples of mass emission rate calculations and other calculations necessary for the 

presentation of the test results are contained in Appendix B. 

Appendix A contains the stack diagrams, stratification test results, isokinetic calculation 

worksheets, and all field data sheets used during these tests. Appendix B contains examples of 

all calculations necessary for the reduction of the data presented in this report. Particulate matter 

results and calculation worksheets from the laboratory analysis are presented in Appendix C. 

Quality assurance activities are documented in Appendix D. Certificates of calibrations are 

contained in Appendix E of this report. Appendix F contains the records of logged data, 

displayed in one-minute intervals, used to record THC, SO2, NOx, CO, 02, and C02 

concentrations; it also includes a running and final average of the raw data. Appendix G 

contains unit operational data hand logged by plant personnel. Appendix H contains the fuel 

analyses for fuel sulfur content and gross heating value conducted by HECO Environmental 

Chemistry Laboratory. Visible emission observation forms and TRC observer certifications are 

presented in Appendix I.