AQ_F_0800107_20101229_PRMT_PmtRvw

NORTH CAROLINA DIVISION OF Region: Washington Regional Office
AIR QUALITY County: Bertie
Air Permit Review NC Facility ID: 0800107
Inspector's Name:
Permit Issue Date: December 29,2010 Date of Last Inspection:
Compliance Code:
Facility Data Permit Applicability(this application only)
Applicant(Facility's Name): W E Partners II,LLC SIP: 2D(.0202, .0504, .0515, .0516, .0521, .0524,
.0535, .0540, .0611, .1100,and 1806)and 2Q
Facility Address: (.0315 and.0711)
W E Partners II,LLC NSPS: Subpart Dc
3539 Governors Road NESHAP: N/A
Lewiston Woodville,NC 27849 PSD:N/A
PSD Avoidance:
SIC: 4961 /Steam Supply NC Toxics: Acrolein,As,Benzene,Be,Cd,Cl2,
NAICS: 22133/Steam and Air-Conditioning Supply Formaldehyde,HCI,Mn
112(r): N/A
Facility Classification: Before: Greenfield After: Synthetic Minor Other: Session Law 2007-397, Senate Bill 3 (S133)
Fee Classification: Before: Greenfield After: Synthetic Minor Determination of non-solid waste under CISWI
Contact Data Application Data
Facility Contact Authorized Contact Technical Contact Application Number: 0800107.10A
Garald Cottrell Garald Cottrell Garald Cottrell Date Received: 10/05/2010
Manager Manager Manager Application Type: Greenfield Facility
[phone] [phone] [phone] Application Schedule: State
1836 Eastchester Drive, 1836 Eastchester Drive, 1836 Eastchester Drive, Existing Permit Data
Ste 108 Ste 108 Ste 108 Existing Permit Number: Greenfield
High Point,NC 27265 High Point,NC 27265 High Point,NC 27265 Existing Permit Issue Date: N/A
Existing Permit Expiration Date:N/A
Review Engineer: Betsy Huddleston Comments/Recommendations:
Issue 10126R00
Review Engineer's Signature: Date:
Permit Issue Date: December 29,2010
/✓�' Permit Expiration Date:November 30,2015
1. Purpose of Application
A greenfield synthetic minor application was received on October 5, 2010 from W.E. Partners II,
LLC. This company is a wholly owned subsidiary of Wellons Energy Solutions, LLC. The
company wishes to construct a biomass cogeneration facility in Lewiston Woodville, Bertie
County, adjacent to the Perdue Grain and Oilseed, LLC, chicken processing and rendering
facilities. W.E. Partners 11 plans to supply steam to Perdue and provide electricity to Dominion
Power. It is my understanding that the company will be leasing the property from Perdue.
The proposed facility will consist of three 20,700 pound per hour (600 hp) green wood-fired
boilers and a steam turbine generator. The boilers each fire 29.4 MMBtu/hour. Each boiler is
proposed to have a multi-cyclone for particulate control. There will also be a 430 tons capacity
fuel bunker with a maximum fill rate of 100 tons/hour.

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2. Application Chronology
Application received (includes toxics model, 10/05/2010
CISWI determination request and BACT
analysis submittal)
Acknowledgment letter sent 10/11/2010
Modeling, CISWI and BACT sent to RCO 10/08/2010
Modeling review completed 11/01/2010
Additional Information Request-toxics modeling 11/17/2010
Toxics modeling resubmitted 12/01/2010
Modeling review completed 12/16/2010
Permit draft submitted for review 12/23/2010
PAM/Facilities/Fees/Programs/Actions to be completed 01/06/2010
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3. Regulatory Review/Permit Stipulation Review
This is a Greenfield facility. The following equipment is added to the permit.
Emission Emission Source Control Control System
Source ID Description System ID Description
ESB-1 (NSPS) Non-solid waste,green wood- MC-1 T multi-cyclone
fired boiler(29.4 million Btu per F
tubes,each 9 inches in diameter)
hour maximum heat input)
ESB-2(NSPS) Non-solid waste,green wood- MC-2 multi-cyclone
fired boiler(29.4 million Btu per (18 tubes,each 9 inches in diameter)
hour maximum heat input)
ESB-3 (NSPS) Non-solid waste,green wood- MC-3 F multi-cyclone
fired boiler(29.4 million Btu per F (18 tubes,each 9 inches in
hour maximum heat input) diameter)
SB-1 lGreen wood fuel storage bunker I N/A N/A
The application was not sealed by a professional engineer for the multi-clones because the
Washington Regional Office accepted that they were designed"as an integral part of the
process" (2Q.0112(c)(1)). The boilers and multi-clones come as a package unit constructed by
Wellons.
The permiee met the zoning notification requirements. There is no zoning in the county, so a
notice was placed in the Bertie Ledger newspaper on July 21, 2010. Photographs were provided
of a sign that was placed roadside notifying intent to construct.
2D.0202 "Registration of Air Pollution Sources"
This rule requires registration(permitting) of emissions sources. This rule makes provision for
the requirement to submit an emission inventory with each permit renewal application.

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2D .0504 "Particulates from Wood Burning Indirect Heat Exchangers,"
The allowable emissions of particulate (PM) from the wood boilers are calculated by the
equation
E= 1.1698 Q -0.2210
Where E=allowable emission limit for particulate matter in lb/million Btu
Q =Maximum heat input in million Btu/hour.
The total of maximum heat inputs of all wood burning indirect heat exchangers at the facility
must be used to determine the allowable emission limit for each boiler. Therefore, a total of 88.2
MMBtu/hour is applied to calculate each limit. Each boiler has a limit of 0.43 lb
P
articulate/MMBtu.
The boilers will use mixed green bark and green wood fuel. The AP-42 factor(with mechanical
control) for mixed bark and wet fuel is 0.35 lb/MMBtu. The bark factor is 0.54 lb/MMBtu and
the wet wood factor is 0.22 lb/MMBtu.
The particulate factor provided in this application is the same factor in the W.E. Partners I
application(4600106.10A, Cofield, Hertford County, Permit 10064R00). Wellons Energy
Solutions provided 0.38 lb/MMBtu as a vendor factor. Wellons Energy Solutions also provided
some particulate testing summaries for five other facilities with Wellons wood boilers and multi-
clones. The highest test result was 0.3 lb/MMBtu. Those boilers were larger than 29.4
MMBtu/hr. Most of the tests were performed prior to 1990, with one done in 2002. The test
summaries are provided as an attachment to the file copy of this review.
A particulate stack test requirement will be included in the permit to confirm the vendor factor.
2D .0515 "Particulates from Miscellaneous Industrial Processes"
This rule applies to the fuel bunker. According to the application the maximum truck fill rate for
the bunker is 100 tons/hour. The unloading rate is 12 tons/hour.
The equation to calculate the emission limit for filling is E= 55.0(P)o.11_ 40
The equation to calculate the unloading emission limit is E = 4.10(P)0.67
E=the maximum allowable emission rate for particulate matter in lbs/hour(calculated to three
significant figures for process rates greater than 30 tons/hour)
P =the process rate in tons/hour
The filling emission limit is 51.277 lbs/hour. The unloading emission limit is 21.669 lbs/hour.
I could not find a specific particulate emission factor for truck unloading of bark and wood chip
to the bunker. There is a factor for aggregate handling and storage piles in AP-42 Section 13.2.4.
The particulate factor has to be calculated using moisture content and silt(fines) content.
Assuming most of the wood fuel will be supplied by the wood products industry, the aggregate

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factor that Weyerhaeuser New Bern (facility ID No. 2500104) calculated for its wood chip truck
unloading and chip handling seems to be the best conservative factor for the bunker emission.
Weyerhaeuser's factor was established based on green wood/bark chip use.
Filling 100 tons/hour(8.5E-4 lbs/ton)= 0.09 lbs/hour
Unloading 8 tons/hour(8.5E-4 lbs/ton)= 0.01 lbs/hour
The annual fuel bunker emissions appear to be insignificant, so I am not including a condition
for 213.0515 in the permit. I am including 2D.0515 in the rule listing in Specific Condition No.
1. The bunker will be included as a permit item just to avoid generating an insignificant list
attachment for the permit.
2D .0516 "Sulfur Dioxide Emissions from Combustion Sources"
Sulfur dioxide emissions from fuel combustion may not exceed 2.3 lbs/MMBtu heat input. This
rule states that the limit does not apply if there is a limit provided in NSPS for the source. NSPS
Subpart Dc applies to the boilers. However, Subpart Dc provides no sulfur dioxide limit for
wood combustion. This means that 213.0516 is the more restrictive rule and a permit condition
needs to be included for compliance with 213.0516.
The sulfur content of the wood is 0.06%by weight. W.E. Partners calculated sulfur dioxide
emissions using the AP-42 emission factor of 0.025 lb/MMBtu. Compliance is expected with
this rule.
2D .0521 "Control of Visible Emissions:"
This rule states that the 20% opacity limit does not apply if an affected source has an applicable
NSPS limitation. NSPS Subpart Dc applies to the boilers. However, as discussed in the NSPS
regulatory review below, there is no NSPS opacity limit for the boilers because their sizes are
less than 30 MMBtu/hour. Therefore, the limit under 2D.0521 is the more restrictive rule and
applies to the boilers. A permit condition will be written for compliance with 2D.0521.
I
The boilers and the fuel bunker must meet a limit of 20%when averaged over a six-minute
period. One exceedance in an hour is acceptable (if less than 87%)up to four times in a 24-hour
period.
2D.0524 "New Source Performance Standards," 40CFR 60,Subpart Dc
Subpart Dc applies to any steam generating unit constructed, modified, or reconstructed after
June 9, 1989, and that has a maximum design heat input capacity of 29 megawatts (MW) (100
MMBtu/hour) or less, but greater than or equal to 2.9 MW(10 MMBtu/hour). Therefore,
Subpart Dc applies to boilers ESB-I, ESB-2 and ESB-3.
The regulated pollutants are SO2 and PM. However, there are no SO2 or PM emissions
limitations provided for these boilers in the rule. 60.42c addresses emission limits for coal and
oil fired boilers, and only addresses emission limits from wood combustion in boilers equal to or
greater than 30 MMBtu/hour in size. These boilers are each 29.4 MMBtu/hour.

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With the small boiler installation,NSPS is essentially hollowed out. The PM exemptions are
stated as follows,
" 60.43c (c) On and after the date on which the initial performance test is completed or required
to be completed under §60.8, whichever date comes first, no owner or operator of an affected
facility that can combust coal, wood, or oil and has a heat input capacity of 8.7 MW (30
MMBtu/hour) or greater shall cause to be discharged into the atmosphere from that affected
facility any gases that exhibit greater than 20 percent opacity(6-minute average), except for one
6-minute period per hour of not more than 27 percent opacity."
"60.43c (e)(1) On and after the date on which the initial performance test is completed or is
required to be completed under §60.8, whichever date comes first, no owner or operator of an
affected facility that commences construction, reconstruction, or modification after February 28,
2005, and that combusts coal, oil, wood, a mixture of these fuels, or a mixture of these fuels with
any other fuels and has a heat input capacity of 8.7 MW (30 MMBtu/hour) or greater shall
cause to be discharged into the atmosphere from that affected facility any gases that contain PM
in excess of 13 ng/J)."
Other requirements for the boilers are provided in 60.48c, "Reporting and Recordkeeping
Requirements."
1. Paragraph (a) states that the facility must submit notification of the date of construction
and actual startup, as provided by Subpart A, 60.7. The notifications must include:
(a) A notification of the date construction postmarked no later than 30 days after such
date.
(b) A notification of the actual date of initial startup of an affected facility postmarked
within 15 days after such date.
(c) The design heat input capacity of the boilers and identification of the fuel to be
combusted.
2. Paragraph (g)(1) states that the facility must record and maintain records of the amount of
fuel combusted during each operating day.
3. Paragraph (i) states that all records shall be maintained for a period of two years
following the dates of record.
Notification and retention conditions will be added to the permit for 60.48c.
Subpart A, 60.11 (d) states, "At all times, including periods of startup, shutdown, and
malfunction, owners and operators shall,to the extent practicable, maintain and operate any
affected facility 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 Administrator which may include, but is not limited to, monitoring results,

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opacity observations, review of operating and maintenance procedures, and inspection of the
source." This requirement will be covered within General Condition No. 6 in the permit.
Subpart A, 60.11 (b) states, "Any owner or operator subject to the provisions of this part shall
maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the
operation of an affected facility; any malfunction of the air pollution control equipment; or any
periods during which a continuous monitoring system or monitoring device is inoperative." This
requirement will be addressed in the control device I&M permit conditions and the 2D.0535
condition.
2D .0535 "Excessive Emissions Reporting and Malfunctions:"
NSPS Subpart A has general requirements for excess emissions recordkeeping for the NSPS Dc
boilers. However, 2D.0535 provides requirements for reporting. Therefore, there will be a
2D.0535 permit condition for the boilers.
The permit condition requires the facility to report excessive emissions that require more than
four hours to repair. Any excess emissions that do not occur during start-up or shut-down are
considered a violation of the applicable standard unless the facility demonstrates to the Director
that the excess emissions are the result of a malfunction.
2D.0540 "Particulates from Fugitive Dust Emission Sources"
This rule requires the facility to prevent fugitive dust emissions from causing or contributing to
substantive complaints or excess visible emissions beyond the property boundary. Fugitive dust
is particulate from processes that do not pass through a stack or vent. Examples of fugitive dust
are unloading areas, stockpiles, parking lots, and facility haul roads. If substantive complaints or
excessive fugitive dust emissions are observed beyond the property boundaries for six minutes in
any one hour(using Reference Method 22 in 40 CFR, Appendix A), the facility may be required
to submit a fugitive dust plan as described in 2D .0540(f).
A fugitive dust condition is auto-generated by IBEAM into the permit. Some fugitive dust may
be generated by fuel trucks, so the condition is needed.
2D.0605 "General Recordkeeping and Reporting Requirements"
This rule requires that a permitted facility keep records of all compliance related activities. This
includes test data, malfunction records, and monitoring data. The rule gives the state authority to
request information from the permit holder if a violation is suspected. This rule also establishes
the requirement to keep all records for a minimum of two years.
2D .0611 "Monitoring Emissions from Other Sources:"
This regulation allows DAQ to include Inspection and Maintenance requirements for the multi-
cyclones. I&M requirements for annual internal inspection, monthly external inspection, and
SSM (startup, shutdown and malfunction) logbooks will be added to the permit.

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2D .1806 - "Control and Prohibition of Odorous Emissions"
This rule requires the facility to implement management practices sufficient to prevent
objectionable odors from the facility to move beyond the facility property boundaries. It requires
maximum feasible controls be determined(under 2D .1807) and implemented if objectionable
odors are noted. As a precautionary measure, a condition for odor will be added to the permit.
2Q .0315 "Synthetic Minor Facilities"
Potential uncontrolled emissions of PMIo,NOx and CO from the boilers are greater than 100
tons/year. Therefore 15A NCAC 2Q .0500, Title V Procedures,applies to W.E. Partners 11.
To avoid Title V permitting the company has requested a 58,000 tons/yr facility-wide fuel
combustion limit (65.6%of potential). Under this limit, W.E. Partners II calculates the
maximum actual facility-wide CO emission at 96.41 tons/yr. PMIo emissions are calculated at
88.71 tons/year(with multi-cyclone control). The actual maximum NOx emission would be 76.3
tons/yr.
The CO factor provided in this application is the same as given in the W.E. Partners I application
(4600106.10A, Cofield, Hertford County, Permit 10064R00). Wellons Energy Solutions
provided 0.38 lb/MMBtu as a vendor factor. This factor is significantly less than the AP-42
factor of 0.60 lb/MMBtu. Wellons Energy Solutions provided some CO testing summaries for
five other facilities with larger Wellons wood boilers and multi-clones. The highest test result
was 0.255 lb/MMBtu. Most of the tests were performed prior to 1990, with one done in 2002.
The test summaries are provided as an attachment to the file copy of this review.
The permittee has based the fuel combustion limit on PM emissions instead of PMIo. Wellons
Energy Solutions provided an after control emission factor of 0.38 lb/MMBtu for PM. The PMIo
emission is 92% of the PM emission. PM testing results were also given for the same five
facilities discussed above. The highest test result was 0.3 lb/MMBtu.
The average fuel Btu content reported in the application is 4375 Btu/lb with 45%wood moisture
content. In my experience the heat value of green (50%moisture)wood is usually analyzed
between 4200-4300 Btu/lb. General rule of thumb has been to use 4500 Btu/lb for green wood
when no test value is available. At 4500 Btu/lb the PM and CO emissions from 58,000 tons of
wood are 99.2 tons each.
The permittee provided a vendor NOx factor of 0.295, which is greater than the AP-42 factor of
0.22 lb/MMBtu.
Because W.E. Partners is applying vendor factors, the facility will be required to perform CO
(Method 10) and PM (Method 5)testing for one of the boilers within 180 days of facility start-
up.
The 58,000 tons per year green wood combustion limit is acceptable for demonstrating synthetic
minor status, as long as the stack tests results are equal or below the factors for CO and PM in
this application.

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On 11/10/2010 I discussed options of how to construct the synthetic minor permit conditions
with Garald Cottrell. We determined that at some later date W.E. Partners II may wish to
explore modification of the 58,000 tons per year fuel limit. They would base a new fuel limit on
the CO and PM stack tests results. The synthetic minor condition can be written to track fuel
usage and calculate monthly emissions using the stack test factors. The permit condition would
require keeping up with fuel use every month and calculating rolling 12-month emissions for CO
and PM (and maybe NOx if the new fuel limit jacks it up significantly). In addition, the toxics
modeling would require revision, and likely require stack height adjustments to accommodate
additional arsenic emissions. Arsenic may prove to be the primary limiting factor for fuel
combustion.
2Q.0705 "Existing Facilities and SIC Calls," 2Q.0711 "Emission Rates Requiring a
Permit," and 2D.1100 "Control of Toxic Air Pollutants"
According to 2Q.0706(c), "Notwithstanding 2Q .0702(a)(18), on and after July 10, 2010, an
evaluation of a modification to a combustion source shall also include emissions from all
permitted combustion sources as defined in 02Q .0703. A permit application filed pursuant to
Subparagraph(b)(2) of this Rule shall include an evaluation for all toxic air pollutants identified
by the Director as causing an acceptable ambient level in 15A NCAC 02D .1104 to be
exceeded." This application for the new boilers constitutes a modification.
I ran the DAQ emissions spreadsheet(attached to the file copy of this review) for toxics
emissions from the boilers. The data matches that in the application.
W.E. Partners II submitted toxics modeling with the application. Tom Anderson with AQAB
completed the review and approved the modeling results. However, from reading Tom's review,
I realized that the facility modeled each boiler firing 19,3338 tons/year fuel. I explained to Mr.
Cottrell with Wellons that modeling individual sources will limit the fuel on each boiler to
19,333. As a result of the conversation, Wellons Energy Solutions re-submitted their modeling
on December 1, 2010. This modeling was performed for a representative stack, no control for
the toxics emissions, 88.2 MMBtu/hr total heat input from the boilers and a maximum fuel usage
of 58,000 tons per year across all of the boilers. Tom Anderson completed review and approved
the results on December 16, 2010. A copy of his review is attached to the file copy of this permit
review(k:\bertie\00107\20101216 Toxics Modeling Review.doc).
A permit condition will be added for the following toxics under 2D.I 100.
Toxic Air Pollutant Facility-Wide Emission
Limit
Acrolein(107-02-8) 0.4 lbs/hour
Arsenic&Compounds(total mass of elemental AS,arsine and all inorganic 11.2 lbs/year
compounds)(ASC(7778394))
Benzene(7143-2) 12,132 lbs/year
Beryllium Metal(unreacted)(Component of BEC)(7440-41-7) 10.6 lb/year
Cadmium Metal,elemental,unreacted(Component of CDC)(7440-43-9) 1 lbs/year
Chlorine(7782-50-5) 1.7 lbs/day

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Toxic Air Pollutant Facility-Wide Emission
Limit
Formaldehyde(50-00-0) 10.4 lb/hour
Hydrogen chloride(hydrochloric acid)(7647-01-0) 1.7 lb//hour
Manganese&compounds(MNC) 3.4 lbs/day
The condition will limit fuel combustion to 58,000 tons per year.
A permit condition will be added for toxics that were under their TPERs in 2Q.0711.
Chronic ( Acute
Carcinogens Acute Systemic
Pollutant (Ib/yr) Toxicants Toxicants(Ib/hr) Irritants
(lb/day) (lb/hr)
Acetaldehyde(75-07-0) 6.8
Benzo(a)pyrene(Component of
83329/POMTV&56553/7PAH) 2.2
(50-32-8)
CFC-I I (Trichlorofluoromethane) 140
(75-69-4) �—
Carbon tetrachloride(56-23-5) 460 ^�
Chlorobenzene(108-90-7) 146
chloroform(67-66-3) 290
Chromium(VI)Soluble Chromate
Compounds(Component of CRC) 0.013
(SOICR6)
DEHP(Di 2-ethylhexyl)phthalate) 0.63
(
117-81-7
�Ethylene dichloride(1,2- _F 260
dichloroethane)(107-06-2)
Hexachlorodibenzo-p-dioxin 0.0051
1,2,3,6,7,8 (57653-85-7)
iMEK(methyl ethyl ketone,2- 78 22.4
butanone)(78-93-3)
Mercury,vapor(Component of
0.013
�HGQ(7439-97-6) F I
Methyl chloroform(71-55-6) �^ 250 64
Methylene chloride(75-09-2) 1600 r0.39
�Nickel metal(Component of NIC) 0.13
(7440-02-0)
1PCB (polychlorinated biphenyls) 5.6
(1336-36-3)
Pentachlorophenol(87-86-5) 0.063 0.0064 (�
�Perch loroethyle 13000
(tetrachloroethylene)(127-18-4)
Phenol(108-95-2) I 0.24 �—

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Chronic Acute
Carcinogens Acute Systemic
Pollutant i Toxicants Irritants
(lb/yr) (lb/day) Toxicants(lb/hr) (lb/hr)
Styrene(100-42-5) 2.7 �-
TCE(trichloroethylene)(79-01-6) 1 4000 —1
Tetrach 1 orod i benzo-p-dioxin,
2,3,7,8-(Component of CLDC& 0.0002
83329/POMTV)(1746-01-6)
[Toluene(108-88-3) 98 14.4
Vinyl chloride(75-01-4) 26 [—
Xylene(mixed isomers)(1330-20-7) 57 F16.4
BACT Determination for Boilers ESB-1 and ESB-2
General Assembly of North Carolina, Session Law 2007-397,Senate Bill 3 (SB3)
The Renewable Energy and Energy Efficiency Portfolio Standard (REPS) requires 3% of North
Carolina retail sales for each electric public utility to come from renewable energy resources for
calendar year 2012. One of the ways to meet this requirement is to purchase electric power from
a new renewable energy facility. W.E. Partners II plans to serve as such a facility.
Senate Law 2007-397, Senate Bill 3 (S133) (62-133.7(g))requires biomass combustion processes
at a new renewable energy facility to meet BACT (a copy of S133 is attached to the file copy of
this review). The BACT analysis is performed in the same manner as required by PSD. Raleigh
Permits Section has established that BACT analysis has to be done for PM, PMIo,NOx, S02,
CO, VOC and mercury(August 27, 2010 memo from Sheila Holman).
W.E. Partners II submitted a BACT analysis on October 5, 2010. W.E. Partners has
recommended that multi-cyclones serve as BACT for particulate control. The proposed BACT
for NOx is staged combustion and good combustion practices, and BACT for SO 2 is
uncontrolled emission. The recommended BACT for CO and VOC is proper boiler design and
good combustion practices. The BACT proposed for mercury is use of low-mercury biomass
fuel.
In order to issue this permit in a timely manner, a placeholder condition will be added to the
permit to explain that WE. Partners II is a renewable energy facility under REPS and that a
BACT analysis has been submitted to DAQ. An electronic copy and hard copy of the BACT
analysis were forwarded to Jeff Twisdale, Raleigh Permits Section. Jeff confirmed receipt on
November 10, 2010. Once the BACT determination review is completed, DAQ will open the
permit administratively at a later date and construct conditions for BACT.
New Source Performance Standard (NSPS) for Commercial and Industrial Solid Waste
Incineration (CISWI)
The DAQ has begun to compare renewable fuels to the definition of"solid waste" under Section 129
of the Clean Air Act(CAA). DAQ is requiring applicants to submit information about their fuel so
that a determination can be made as to whether the Solid Waste Disposal Act applies. If a fuel is
determined to be a solid waste,the New Source Performance Standard (NSPS) for commercial and

Page I 1
industrial solid waste incineration (CISWI)units would also apply. DAQ's determination is based on
the North Carolina Attorney General's Office September 28, 2009 memorandum to Keith Overcash.
On October 5, 2010, W.E. Partners II submitted a CISWI determination request. The request
provided the information recommended by the 9/28/2009 memo. I have sent the request to
Raleigh Permits Section for review and response. A letter from DAQ has not yet been issued to
the permittee. I have been previously told by RCO (John Evans for the W.E.Partners I permit
10064R00)that it's fine to issue the permit without the final letter. I am to include "non-solid
waste" in the descriptors for the boilers in the permit.
4. NESHAPS, PSD, Attainment Status, 112r
a. NESHAPS -No NESHAP Subpart is currently applicable to this facility. The
proposed Boiler MACT, once promulgated, will apply to this facility as an area
source.
b. PSD—PM and PMIo potential emissions are the greatest from this facility. The
vendor supplied factors in the application result in a PM facility-wide
uncontrolled potential of 734 tpy and a PMIo potential of 587tpy. While the
synthetic minor conditions limit the facility to a PSD minor status, I will add a
PSD avoidance condition to the permit for PM.
Bertie County is triggered for increment tracking for PM,PMIo, S02, and NOx
(NO2). The maximum lb/hr increases contributed by this facility will be provided
in the cover letter to the permit.
PM- 33.5lbs/hr
PMIo- 30.8lbs/hr
S02 - 2.2 lbs/hr
NOx- 26.5lbs/hr
C. Attainment Status -This facility is in an attainment area.
d. 112r-The facility will not handle, store, or use any I I2R pollutants in enough
quantity to be subject to this regulation.
5. Facility Emissions Review
The facility has set a limit that boilers will not burn more than 58,000 tons of fuel per rolling 12-
month year. Fuel moisture content is expected to be approximately 45%. Average fuel heat
content is expected to be 4375 Btu/lb.

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Pollutant Factor (lb/MMBtu) Actual Maximum Potential Uncontrolled
Emissions (after Emissions (tpy)
control) (t 8760 hrs w/no fuel limit
PM 0.38 (vendor factor after 96.4 734 a
control
PMIo 0.34 (factor after control) 88.7 587 a
SO2 0.025 (AP-42) 6.3 9.7
NOx 0.295 (vendor factor) 75.9 114.0
CO 0.38 vendor factor c 96.4 146.8
VOC 0.017 (AP-42) 4.3 6.6
a The application states that the multi-cyclones have an 80% efficiency for PM and 77% for
PMIo. Back calculate the hourly emission without control and apply 8760 hours of operation.
The DAQ spreadsheet calculates a much lower potential PM emission of 222.9 tpy and PMIo
emission of 199.7 tpy.
b AP-42 Table 1.6-5 states that PMIo is 92%of total PM emitted from multi-clone control.
The vendor NOx factor is slightly higher than the AP-42 factor of 0.22 lb/MMBtu.
Bunker capacity is 430 tons. According to the application the fuel bunker fill rate is 100
tons/hour and the unloading maximum rate is 12 tons/hour. The closest factor I could find for
truck chip loading/unloading is the AP-42 factor for aggregate handling. Both Weyerhaeuser
and Domtar use this factor for their chip handling, conveying, drops and storage piles (see
213.0515 discussion earlier in this review). Assuming that they won't fill more than capacity in a
day, the potential emission would be about 0.06 ton PM/yr.
The bunker emissions are considered insignificant for permitting. To save from having to add an
insignificant source page to the permit, I am adding it to the permit item list.
6. Conclusions, Comments and Recommendations
a. I have added a requirement to stack test one of the boilers for PM and CO. They
are applying vendor factors against the 100 tpy synthetic minor permit limits.
b. A condition is added to acknowledge that the Permittee has submitted a BACT
analysis to satisfy SB3. The condition also states that DAQ will open the permit
once BACT is determined. I have reminded Garald Cottrell that BACT may
change control device requirements.
C. Raleigh Permits Section will later issue a CISWI determination and perform a
BACT review.
d. I recommend that the Division of Air Quality issue Permit No. 10064R00 to
W. E. Partners II, LLC.
(k:\bertie\00107\20101223r00.doc)

WOODWASTE COMBU )N EMISSIONS CALCULATOR REVISIOt NPUT SCREEN
Instructions: Enter emission source/facility data on the"INPUT"tab/screen. The air emission results and summary of input
�.� data are viewed/printed on the"OUTPUT"tab/screen. The different tabs are on the bottom of this screen.
1•
This spreadsheet is for your use only and should be used with caution.DENR does not guarantee the accuracy of the
�� �� information contained. This spreadsheet is subject to continual revision and updating. It is your responsibility to be aware
NCDENRof the most current information available. DENR is not responsible for errors or omissions that may be contained herein.
Directions:Enter and select information in the boxes in the column on the right:
FIELDS SELECTIONS
COMPANY NAME: WE Partners II
FACILITY ID NUMBER: 800107
PERMIT NUMBER 10126ROO
FACILITY CITY: Lewiston Woodville
FACILITY COUNTY: Bertie
SPREADSHEET PREPARED BY: Betsy Huddleston
EMISSION SOURCE ID NO.: ESB-1 to ESB-3
MAXIMUM HEAT INPUT(MILLION BTU PER HOUR): 88.20 MMBTU/HR
TYPE OF BOILER: srOKER
TYPE OF FUEL: BARK AND WET WOOD
FUEL HEATING VALUE
FUEL HEATING VALUE(BTU/LB): 4375 BTU/LB 8.75 MM BTU/TON
DEFAULT IS AS FOLLOWS(not used for Greenhouse Gas calcs--See below for GHG de.
8000 BTU/LB DRY WOOD
4500 BTU/LB WET WOOD
(TYPE OVER NUMBER AT ABOVE RIGHT IF YOU HAVE SITE SPECIFIC DATA)
OTHER SOURCE-SPECIFIC DATA
ACTUAL YEARLY FUEL USAGE(TONS PER YEAR): 58,000.00 TPY
CALCULATED POTENTIAL YEARLY USAGE(TONS PER YEAR) 88,300.80 TPY
REQUESTED ANNUAL LIMITATION(TONS PER YEAR) 58,000.00 TPY
(TYPEOVER IF NECESSARY-DEFAULT IS POTENTIAL)
TYPE OF PARTICULATE CONTROL: MECHANICAL COLLECTOR(NO REINJECTION)
NOX CONTROL IF PRESENT(DEFAULT IS ZERO) 0 %
SITE SPECIFIC STACK TEST DATA FOR PARTICULATE: 0 LB/MMBTU
(IF AVAILABLE:OUTLET FILTERABLE PARTICULATE ONLY)
(LEAVE AS ZERO IF NO DATA AVAILABLE)
ADDITIONAL INFORMATION FOR GREENHOUSE GAS(GHG)EMISSIONS
ENTER CALCULATION TIER
from EPA Mandatory Reporting Rule(MRR)Subpart C- TIER 1: DEFAULT HIGH HEAT VALUE AND DEFAULT EF
www.epa.gov/climatechange/emissions/ghgrulemaking.html
NOTE. EF is"Emission Factor"
SINCE TIER 3 IS NOT BEING USED 0.500 (decimal fraction)
DO NOT ENTER FUEL CARBON CONTENT
HIGH HEAT VALUE(HHV)FOR GHGs
FOR TIER 1 and TIER 3,the FUEL HEATING VALUE entered above is overriden with the EPA DEFAULT: 15.38 MMBTU/TON
This default HHV is from EPA's MRR,Table C-1,"Wood and Wood Residuals"
FOR TIER 2,the FUEL HEATING VALUE entered above is used. The value entered must be the annual average HHV of the fuel
determined using procedures in the EPA MRR(see 98.33(a)(2))
NOTE: Using Tier 1,therefore the EPA default HHV will be used for all GHG calculations(CO2, CH4 and N20)

WOODWASTE COMBUSTION EMISSIONS ULATOR REVISION 12/1/2010-OUTPUT SCREEN
Instructions: Enter emission source/fac....r-ta on the"INPUT'tab/screen. The air emission results and summary of
PIMAinput data are viewed/printed on the"OUTPUT'tab/screen. The different tabs are on the bottom of this screen.
This spreadsheet is for your use only and should be used with caution.DENR does not guarantee the accuracy of the
Information contained. This spreadsheet is subject to continual revision and updating. It is your responsibility to be aware
NCDENRof the most current information available. DEN is not responsible for errors or omissions that maybe contained herein.
S URCE/FACILITY/USER INPUT SUMMARY(FROM INPUTSCREEN)
COMPANY: WE Partners 11 FACILITY ID NO.: 800107
PERMIT NUMBER: 10126R00
EMISSION SOURCE DESCRIPTION: 88.2 MMBTU/HR BARK AND WET WOOD FIRED BOILER FACILITY CITY: Lewiston Woodville
EMISSION SOURCE ID NO.: ESB-1 to ESB-3 FACILITY COUNTY: Bettie
PARTICULATE CONTROL DEVICE: MECHANICAL COLLECTOR(NO REINJECTION) POLLUTANT CONTROL EFF.
SPREADSHEET PREPARED BY: FM
FUEL HEAT VALUE: 4375 BTU/LB NOX 0
ACTUAL FUEL THROUGHPUT: HHV Used for GHGs MMBTU/TON: 15.38 PM CALC'D AS 36.4%
POTENTIAL FUEL THROUGHPUT: BOILER TYPE: STOKER PM10 CALC'D AS 34.8%
REQUESTED MAX.FUEL THRPT: NO STACK TEST DATA USED PM2.5 CALC'D AS 53.7%
METHOD USED TO COMPUTE ACTUAL GHG EMISSIONS: TIER 1: DEFAULT HIGH HEAT VALUE AND DEFAULT EF
CARBON CONTENT USED FOR GHGS(AS A FRACTION): CARBON CONTENT NOT USED FOR CALCULATION TIER CHOSEN
CRITERIA AIR POLLUTANT EMISSIONS INFORMATION
ACTUAL EMISSIONS POTENTIAL EMSSIONS EMISSION FACTOR
Os CONTROLS I LIAMTs) (BEFORE CONTROLS I VATS) (AMR CaFrrn I oars) Ib/mmBtu
AIR POLLUTANT EMITTED Ib/hr ton Ib/hr tons ib/hr tons uncontrolled controlled
PARTICULATE MATTER PM 32.37 93.13 50.89 222.90 32.37 93.13 0.577 0.367
PARTICULATE MATTER<10 MICRONS(PM1o) 29.72 85.51 45.60 109.73 29.72 85.51 0.517 0.337
PARTICULATE MATTER<2.5 MICRONS(PM25) 18.26 52.53 39.43 172.68 18.26 52.53 0.447 0.207
SULFUR DIOXIDE S02 2.21 6.34 2.21 9.66 2.21 6.34 0.025 0.025
NITROGEN OXIDES NOx 19.40 55.83 19.40 84.99 19.40 55.83 0.220 0.220
CARBON MONOXIDE CO 52.92 152.25 52.92 231,79 52.92 152.25 0.600 0.600
VOLATILE ORGANIC COMPOUNDS VOC 1.50 4.31 1.50 6 57 1.50 4.31 0.017 0.017
LEAD 4.2E-03 1.2E-02 4.2E-03 1.9E-02 4.2E-03 1.2E-02 4.BE-OS 4.8E-05
TOXIC/HAZARDOUS AIR POLLUTANT EMISSIONS INFORMATION
ACTUAL EMISSIONS POTENTIAL EMSSIONS EMISSION FACTOR
CAS (n RCONTROLS I S) (WFOREC00rTROLS1-1TS) VK RCIXJTROL'-S) IblmmBlu
TOXIC I HAZARDOUS AIR POLLUTANT NUMBER Iblhr 1W ib/hr Ib/r Ibfnr lbtyr uncontrolled/controlled
Acetaldehyde H) 75070 7.32E-02 421.225 7.32E-02 641.285 7.32E-02 421.225 8.30E-04 8.30E-04
Aceto henone H 98862 2.82E-07 1.62E-03 2.82E-07 2.47E-03 2.82E-07 1.62E-03 3.20E-09 3.20E-09
Acrolein H 107028 3.53E-01 2030.000 3.53E-01 3090.528 3.53E-01 2030.000 4.00E-03 4.00E-03
Antimony&Compounds H SBC 6.97E-04 4.009 6.97E-04 6.104 6.97E-04 4.009 7.90E-06 7.90E-06
Arsenic&Compounds H ASC 1.94E-03 11.165 1.94E-03 16.998 1.94E-03 11.165 2.20E-05 2.20E-05
Benzene(TH) 71432 1 3.70E-01 2131,500 3.70E-01 3245.054 3.70E-01 2131.500 4.20E-03 4.20E-03
Benzo(a)pyrane M 50328 2.29E-04 1.320 2.29E-04 2.009 2.29E-04 1.320 2.60E-06 2.80E-06
Beryllium metal(un-reacted)(Also Include In SEC)(T/H 7440417 9.70E-05 0.558 9.70E-05 0.850 9.70E-05 0.558 1.10E-06 1.10E-06
Cadmium Metal(elemental un-reacted)-(Add w/CDC)(r" 7440439 3.62E-04 2.081 3.62E-04 3.168 3.62E-04 2.081 4.10E-06 4.10E-06
Carbon tetrachloride H 56235 3.97E-03 22.838 3.97E-03 34.768 3.97E-03 22.838 4.50E-05 4.50E-05
Chlorine(T 7782505 6.97E-02 400.925 6.97E-02 610.379 6.97E-02 400.925 7.90E-04 7.90E-04
Chlorobenzene H) 108907 2.91E-03 16.748 2.91E-03 25.497 2.91E-03 16.748 3.30E-05 3.30E-05
Chloroform 67663 2.47E-03 14.210 2.47E-03 21.634 2.47E-03 14.210 2.80E-05 2.80E-05
Chromium-other com s(H)add w/chrom acid to get CRC 1.54E-03 8.881 1.54E-03 13.521 1.54E-03 8.881 1.75E-05 1.75E-05
Chromic acid )Add as comp.of wICR6 and CRC IH 7738945 3.09E-04 1.776 3.09E-04 2.704 3.09E-04 1.776 3.50E-08 3.50E-06
Cobalt compounds( CDC 5.73E-04 3.299 5.73E-04 5.022 5.73E-04 3.299 6.50E-06 6.50E-06
Dinkro henot,2,4- 51285 1.59E-05 9.14E-02 1.59E-05 0.139 1.59E-05 0.091 1.80E-07 1.80E-07
Di 2-eth he hthalate DEHP 117817 4.15E-06 2.39E-02 4.15E-06 3.63E-02 4.15E-06 2.39E-02 4.70E-08 4,70E-08
Ethyl benzene(H) 100414 2.73E-03 15.733 2.73E-03 23.952 2.73E-03 15.733 3.10E-05 3.10E-05
Ethylene dichloride 1,2-dichloroethane 107062 2.56E-03 14.718 2.56E-03 22.406 2.56E-03 14.718 2.90E-05 2.90E-05
Formaldehyde H) 50000 3.88E-01 2233.000 3.88E-01 3399.581 3.88E-01 2233.000 4.40E-03 4.40E-03
Hezachlorodibenzo- iorin 1,2,3,6,7,8 57653857 2.80E-09 1.61E-05 2.80E-09 2.46E-05 2.80E-09 1.61E-05 3.18E-11 3.18E-11
Hydrogen chloride(hydrochloric a 7647010 1.68E+00 9642.500 1.68E+00 14680.008 1.68E+00 9642.500 1.90E-02 1.90E-02
Lead and Lead compounds PBC 4.23E-03 24.360 4.23E-03 37.086 4.23E-03 24.360 4.80E-05 4.80E-05
Manganese&com unds MNC 1.41E-01 812.0D0 1.41E-01 1236.211 1.41E-01 812.000 1.60E-03 1.60E-03
Mercury,vapor Include in Mercu &Com s M 7439976 3.09E-04 1.776 3.09E-04 2.704 3.09E-04 1.776 3.50E-06 3.50E-06
Metho bromide(H)(bromomethane) 74839 1.32E-03 7.613 1.32E-03 11.589 1.32E-03 7.613 1.50E-05 1.50E-05
Methyl chloride H)chloromethane 74873 2.03E-03 11.673 2.03E-03 17.771 2.03E-03 11.673 2.30E-05 2.30E-05
Methyl chloroform 1,1,1 trichloroethane 71556 2.73E-03 15.733 2.73E-03 23.952 2.73E-03 15.733 3.10E-05 3.10E-05
Methyl ethyl ketone M 78933 4.76E-04 2.741 4.76E-04 4.172 4.76E-04 2.741 5.40E-Olt 5.40E-06
Methylene chloride H dichloromethane K7723140
2.56E-02 147.175 2.56E-02 224.063 2.56E-02 147.175 2.90E-04 2.90E-04
Naphthalene H 8.56E-03 49.228 8.56E-03 74.945 8.56E-03 49.228 9.70E-05 9.70E-05
Nickel metal(Component of Nickel&Compounds)(T/H 2 91 E-03 16.748 2.91 E-03 25.497 2.91 E-03 16.748 3.30E-05 3.30E-05
Nitro phenol,4-H 9.70E-06 5.58E-02 9.70E-06 8.50E-02 9.70E-06 5.58E-02 1.10E-07 1.10E-07
Pentachloro enol H 4.50E-06 2.59E-02 4.50E-06 3.94E-02 4.50E-06 2.59E-02 5.10E-08 5.10E-08
Perchloroelh lens tetrachloroeth ene 3.35E-03 19.285 3.35E-03 29.360 3.35E-03 19.285 3.80E-05 3.80E-05
Phenol H 4.50E-03 25.883 4.50E-03 39.404 4.50E-03 25.883 5.10E-05 5.10E-05
Phosphorus Metal,Yellow or White 2.38E-03 13.703 2.38E-03 20.861 2.38E-03 13.703 2.70E-05 2.70E-05
Polychlorinated biphen s 1336363 7.19E-07 4.14E-03 7.19E-07 6.30E-03 7.19E-07 4.14E-03 8.15E-09 8.15E-M
PoI c clic Organic Matter H PoMTV 1.10E-02 63.438 1.10E-02 96.579 1.10E-02 63.438 1.25E-04 1.25E-04
Pro naldeh a(H) 123386 5.38E-03 30.958 5.38E-03 47.131 5.38E-03 30.958 6.10E-05 6.10E-05
Pro ene dichloride 1,2dichloro o ne 78875 2.91E-03 16.748 2.91E-03 25.497 2.91E-03 16.748 3.30E-05 3.30E-05
Selenium compounds H SEC 2.47E-04 1.421 2.47E-04 2.163 2.47E-04 1.421 2.80E-06 2.80E-06
Styrene H 100425 1.68E-01 964.250 1.68E-01 1468.001 1.68E-01 964.250 1.90E-03 1.90E-03
Tetmchlorodibenzo- iman,2,3,7,8- 1746016 7.59E-10 4.36E-06 7.59E-10 6.64E-06 7.59E-10 4.36E-06 8.60E-12 8.80E-12
Toluene H 108883 8.11E-02 466.900 8.11E-02 710.821 8.11E-02 466.900 9.20E-04 9.20E-04
Trichloroeth lens H 79018 2.65E-03 15.225 2.65E-03 23.179 2.65E-03 15.225 3.00E-05 3.00E-05
Trichlorofluoromethane CFC 111 75694 3.62E-03 20.808 3.62E-03 31.678 3.62E-03 20.808 4.10E-05 4.10E-05
Trichloro enol,2,4,6 88062 1.94E-06 1.12E-02 1.94E-06 1.70E-02 1.94E-06 1.12E-02 2.20E-M 2.20E-08
Vinyl chloride H 75014 1.59E-03 9.135 1.59E-03 13.907 1.59E-03 9.135 1.80E-05 1.80E-05
X lene 1330207 2.21 E-03 12.688 2.21 E-03 19.316 2.21 E-03 12.688 2.50E-05 2.50E-05
H hest HAP(Hydrogen chloride h rochloric acid) H 7647010 1.68E+00 9642.500 1.68E+00 14680.0 1.68E+00 9642.5 1.90E-02 1.90E-02
Total HAPs NA 13.42E+00 1.97E+04 3.42E+00 I 3.00E+04 3.42E+00 1.97E+04 3.88E-02 3.88E-02

TOXIC AIR POLLUTANT EMISSIO DRMA77ON(FOR PERMITTING PURPOSES)
EXPECTED ACTUAL EMISSIONS AFTER CONTROLS/LIMITATIONS(FOR PERMITTING PURPOSES) EMISSION FACTOR
Ib/mmBtu
TOXIC AIR POLLUTANT CAS Num. Ib/hr lb/day Ib/yr uncontrolled controlled
Acetaldehyde H 7507D 7.32E-02 1.76E+00 421,225 8.30E-04 8.30E-04
Acrolein(TH) 107028 3.53E-01 8.47E+00 2030.000 4.00E-03 4.00E-03
Arsenic 8 Compounds(TH) ASC 1.94E-03 4.66E-02 11.165 2.20E-05 2,20E-05
Benzene(TH) 71432 3.70E-01 8.89E+00 2131.500 4.20E-03 4.20E-03
Benzo(a) rene 50328 2.29E-04 5.50E-03 1.320 2.60E-06 2.60E-06
Beryllium metal(un-reacted) Also include in BEC (TM) 7440417 9.70E-05 2.33E-03 0.558 1.10E-06 1.10E-0640)
Cadmium Metal elemental un-reacted-Add w/CDC) /H -OB 7440439 3.62E-04 8.68E-03 2.081 4.1 DE-06 4.10E ,, I !".A
Carbon tetrachloride H) 56235 3.97E-03 9.53E-02 22.838 4.50E-05 4.50E-05
Chlorine(TH) 7782505 6.97E-02 1.67E+00 400.925 7.90E-04 7,90E-04
Chlorobenzene(TH) 108907 2.91E-03 6.99E-02 16.748 3.30E-05 3.30E-05
Chloroform(TH) 67663 2.47E-03 5.93E-02 14.210 2.80E-05 2.80E-05
Di(2-eth the 1)phthalate(DEHP)(TH) 117817 4.15E-06 9.95E-05 2.39E-02 4.70E-08 4.70E-08
Ethylene dichloride(1,2-0ichloroethene)(TH) 107062 2.56E-03 6.14E-02 14.718 2.90E-05 2.90E-05
Soluble Chromate Cmpds,as Chrome(VI)(TH) SOLCR6 3.09E-04 7.41E-03 1.776 04 3.50E-06 3.50E-06
Formaldehyde(TH) 50000 3.88E-01 9.31E+00 2233+000 4.40E-03 4.40E-03
Hexachlorodibenzo- Toxin 1,2,3.6.7,8 M 57653857 2.80E-09 6.73E-08 0.000 3.18E-11 3.18E-11
Hydrogen chloride(hydrochloric acid)(TH) 7647010 1.68E+00 4.02E+01 9642.500 1.90E-02 1.90E-02
Manganese&compounds H MNC 1.41 E-01 3.39E+00 812+000 1.60E-03 1.60E-03
Mercury,vapor(Include in MercuryBCompds)(T/H) 7439976 3.09E-04 7.41 E-03 1.776 3.50E-06 3.50E-06
Methyl chloroform(TH)(1,1,1 tnchloroethane) 71556 2.73E-03 6.56E-02 15.733 3.10E-05 3.10E-05
Methyl ethyl ketone M 78933 4.76E-04 1.14E-02 2.741 5.40E-06 5.40E-06
Methylene chloride(TH)(dichloromethane) 75092 2.56E-02 6.14E-01 147.175 2.90E-04 2.90E-04
Nickel metal(Component of Nickel 8 Compounds)(TM) 7440020 2.91 E-03 6.99E-02 16.748 3,30E-05 3.30E-05
Pentachlorophenol H) 87865 4.50E-06 1.08E-04 0.026 5.10E-08 5.1 DE-08
Perchloroeth lens(tetrachloroeth ene)(TH) 127184 3.35E-03 8.04E-02 19.285 3.80E-05 3.80E-05
Phenol(TH) 108952 4.50E-03 1.08E-01 25,883 5.10E-05 5.10E-05
Polychlorinated bi henyls(TH) 1336363 7.19E-07 1.73E-05 4.14E-03 8.15E-09 8.15E-09
Styrene(TH) 100425 1.68E-01 4.02E+00 964.250 1.90E-03 1.90E-03
Tetrachlorodibenzo- Toxin,2,3,7,8-(TH) 1746016 7.59E-10 1.82E-08 4.36E-06 8.60E-12 8.60E-12
Toluene(TH) 108883 8.11 E-02 1.95E+00 466.900 9.20E-04 9.20E-04
Tnchloroeth lane H 79016 2.65E-03 6.35E-02 15.225 3.00E-05 3.00E-05
Trichloro0uoromethene(CFC 111)IT) 7s6sa 3.62E-03 8.68E-02 20.808 4.10E-05 4.10E-05
Vinyl chloride(TH) 75014 1.59E-03 3.81 E-02 9.135 1.80E-05 1.80E-05
Xylene(TH) 11330207 1 2.21E-03 5.29E-02 12.688 2.50E-05 2.50E-05
GREENHOUSE GAS EMISSIONS INFORMATION(FOR EMISSIONS INVENTORY GREENHOUSE GAS EMISSIONS-POTENTIAL TO EMIT
PURPOSES) -CONSISTENT WITH EPA MANDATORY REPORTING RULE(MRR)METHOD NOT BASED ON EPA MRR METHOD
ACTUAL EMISSIONS POTENTIAL EMISSIONS-utilize max heat POTENTIAL EMISSIONS With
EPA MRR Emission Requested Emission Limitation-
input capacity and
Factors utilize requested fuel limit and EPA
MRR Emission Factors
EPA MRR CALCULATION METHOD:TIER 1
GREENHOUSE GAS metric tons/yr, short tons/yr,
metric tons/yr CO2e short tons/yr short tons) r short tons/ r,CO2e short tons/ r CO2e
CARBON DIOXIDE(CO2)-
BIOGENIC EMISSIONS' 83,673.35 zero 92,233.97 79,887.58 zero' 52,473.81 zero'
METHANE CH4 2.85E+01 5.99E+02 3.15E+01 2.73E+01 5.72E+02 1.79E+01 3.76E+02
NITROUS OXIDE N20 3.75E+00 1.16E+03 4.13E+00 3.58E+00 1.11E+03 2.35E+00 7.28E+02
TOTAL
1,760.89 TOTAL 1,681.22 TOTAL 1,104.30
BIOGENIC CO2 has 0 CO2e NOTE:The DAQ Air Emissions Reporting Online(AERO)system requires short tons
NOTE: CO2e means CO2 equivalent The EPA MRR requires metric tons