hampton lumber 368010permit

This permit is being issued in accordance with the provisions of ORS 468A.040 and

Work Practices The permittee must perform a maintenance service on the boiler at least once in every 2-year period. As a minimum, the service must include an inspection of the burners and refractory chamber, cleaning, adjustment, and repair as necessary.

ACDP	Air Contaminant Discharge Permit
ASTM	American Society for Testing and Materials
AQMA	Air Quality Maintenance Area
calendar year	The 12-month period beginning January 1^st and ending December 31^st
CFR	Code of Federal Regulations
CO	carbon monoxide
DEQ	Oregon Department of Environmental Quality
dscf	dry standard cubic foot
EPA	US Environmental Protection Agency
FCAA	Federal Clean Air Act
gal	gallon(s)
gr/dscf	grains per dry standard cubic foot
HAP	Hazardous Air Pollutant as defined by OAR 340-244-0040
I&M	inspection and maintenance
lb	pound(s)
MMBtu	million British thermal units
MMft³	million cubic feet
NA	not applicable
NESHAP	National Emissions Standards for Hazardous Air Pollutants
NO_X	nitrogen oxides
NSPS	New Source Performance Standard
NSR	New Source Review
O₂	oxygen
OAR	Oregon Administrative Rules
ORS	Oregon Revised Statutes
O&M	operation and maintenance
Pb	lead
PACT	Powder Activated Carbon Treatment
PCD	pollution control device
PM	particulate matter
PM₁₀	particulate matter less than 10 microns in size
ppm	part per million
PSD	Prevention of Significant Deterioration
PSEL	Plant Site Emission Limit
PTE	Potential to Emit
RACT	Reasonably Available Control Technology
scf	standard cubic foot
SER	Significant Emission Rate
SIC	Standard Industrial Code
SIP	State Implementation Plan
SO₂	sulfur dioxide
Special Control Area	as defined in OAR 340-204-0070
VE	visible emissions
VOC	volatile organic compound
year	A period consisting of any 12- consecutive calendar months

1

1900-00-00T00:00:00
[PTC1]
Permit Template Coordinator
First go through the document using the tab key and fill in the form fields. Some are drop down boxes and others are fill-in fields. Once you have filled in the fields, unprotect the document by clicking on the Tools menu and clicking on Unprotect Document. When the document is unprotected, you can make any other changes, such as adding or deleting a condition.

1

1900-00-00T00:00:00
[PTC2]
Permit Template Coordinator
With the document unprotected, double click on the header section to type in the Permit No. and expiration date. Except when it takes an unusually long time to issue a permit, the expiration date for a regular permit is generally 5 years from the month after the application was received. All permits expire on the 1^st day of the month. Use the format mm/dd/yy for all dates in the permit. While in the Header section highlight the # of pages field and click on the icon in the header toolbar to recalculate the # of pages.

1900-00-00T00:00:00
[PTC3]
Mark Fisher
Delete the rest of this sentence if the source is portable.

2006-02-27T15:02:00
[msf4]
Mark Fisher
Note, it is not necessary to include the phrase “installed, constructed, or modified after June 1, 1970” if the plant began operations after this date or if all of the equipments were constructed or modified after this date.

1

2006-02-27T15:02:00
[PTC5]
Permit Template Coordinator
This condition applies to all new sources and any source in a special control area other than wood fired boilers that existed prior to June 1, 1970.

2003-12-12T16:41:00
[msf6]
Mark Fisher
Note, it is not necessary to include the phrase “installed, constructed, or modified after June 1, 1970” if the plant began operations after this date or if all of the equipments were constructed or modified after this date.

1

1900-00-00T00:00:00
[PTC7]
Permit Template Coordinator
For the purposes of this condition, “fuel burning equipment” generally means boilers and not other types of equipment that burn fuel, such as direct contact dryers or gas turbines.

2003-12-12T16:42:00
[msf8]
Mark Fisher
Note, it is not necessary to include the phrase “installed, constructed, or modified after June 1, 1970” if the plant began operations after this date or if all of the equipments were constructed or modified after this date.

2003-12-12T16:37:00
[msf9]
Mark Fisher
Note that specific fugitive emission control plans are required for some sources in the Medford/Ashland AQMA, La Grande UGA, and Lakeview UGA (see OAR 340-240-0180, 0360, and 0410.

1

1900-00-00T00:00:00
[PTC10]
Permit Template Coordinator
As an option the permit writer can include the following: Reasonable precautions may include, but are not limited to the following {Refer to OAR 340-208-0210(2) for a list of reasonable precautions or include others that may be more appropriate for the specific source.}

1900-00-00T00:00:00
[PTC11]
Mark Fisher
The PSEL should be set at the sources PTE or the generic PSEL level, whichever is greater. The PSEL is a PTE limit so a separate synthetic minor limit is not necessary for sources that want to avoid Title V permitting, NSR, or PSEL increases that would trigger an air quality analysis.

2006-03-29T15:34:00
[PTC12]
Mark Fisher
If there are only a few parameters, you could list them here and delete condition 14. Condition 14 is provided so that the table of information can be modified to fit specific sources and there is more room from margin to margin without interfering with the info-mapping format in this condition.

1900-00-00T00:00:00
[PTC13]
Mark Fisher
Copy the appropriate office from the following table and paste it in this cell and then delete the table.

1900-00-00T00:00:00
[PTC14]
Mark Fisher
Copy the appropriate office from the following table and paste it in this cell and then delete the table.

Table 1 Code	Source Description	SIC
Part B, No. 62	Sawmills and/or Planing Mills 25,000 or more bd.ft./maximum 8 hr. finished product	2421
Part C, No. 3	Sources electing to maintain the source’s baseline emission rate, or netting basis

1.1. Visible Emissions	Emissions from any air contaminant source must not equal or exceed 20% opacity for a period aggregating more than 3 minutes in any one hour.
Particulate Matter Emissions	The permittee must comply with the following particulate matter emission limits, as applicable:
	a. Particulate matter emissions from any fuel burning equipment must not exceed 0.1 grains per standard cubic foot, corrected to 12% CO₂ or 50% excess air.
	b. Particulate matter emissions from any air contaminant source other than fuel burning equipment and fugitive emission sources must not exceed 0.1 grains per standard cubic foot.
1.2. Fugitive Emissions	The permittee must take reasonable precautions to prevent fugitive dust emissions by:
	a. Treating vehicular traffic areas of the plant site under the control of the permittee.
	b. Operating all air contaminant-generating processes so that fugitive type dust associated with the operation will be adequately controlled at all times.
	c. Storing collected materials from air pollution control equipment in a covered container or other method equally effective in preventing the material from becoming airborne during storage and transfer.
1.3. Particulate Matter Fallout	The permittee must not cause or permit the emission of any particulate matter larger than 250 microns in size at sufficient duration or quantity, as to create an observable deposition upon the real property of another person. The Department will verify that the deposition exists and will notify the permittee that the deposition must be controlled.
1.4. Nuisance and Odors	The permittee must not cause or allow air contaminants from any source to cause a nuisance. Nuisance conditions will be verified by Department personnel.
1.5. Fuels and Fuel Sulfur Content	The permittee must not use any fuel other than natural gas, propane, butane, ASTM grade fuel oils, or on-specification used oil.
	a. Fuel oil must not contain more than 0.5% sulfur by weight for ASTM Grade 2 distillate oil; b. The permittee is allowed to use on-specification used oil as fuel which contains no more than 0.5% sulfur by weight. The permittee must obtain analyses from the marketer or, if generated on site, have the used oil analyzed if the oil is to be burned in the boiler, so that it can be demonstrated that each shipment of oil does not exceed the used oil specifications contained in 40 CFR Part 279.11, Table 1.

2.1. Applicability	Federal requirements apply to boilers for which construction, modification, or reconstruction is commenced after June 9, 1989 and that have a maximum design heat input capacity of 100 million Btu per hour (Btu/hr) or less, but greater than or equal to 10 million Btu/hr. These requirements are in addition to requirements listed elsewhere in the permit. The full text of the federal standards are found in 40 CFR 60, Subpart Dc.
Definitions	a. *Construction* means fabrication, erection, or installation of an affected facility. b. *Modification* means any physical change in, or change in the method of operation of, an existing facility which increases the amount of any air pollutant (to which a standard applies) emitted into the atmosphere by that facility or which results in the emission of any air pollutant (to which a standard applies) into the atmosphere not previously emitted.
Visible emissions limit	If oil is burned in the boiler and the heat input is greater than 30 million Btu/hr, visible emissions must not exceed 20% opacity as a 6-minute average, except for one 6-minute period per hour of not more than 27% opacity.
2.2. Visible emissions monitoring	If residual oil is burned in the boiler and the heat input is greater than 30 million Btu/hr. visible emissions must be monitored with a continuous opacity monitoring system (COMS) installed, operated, and maintained in accordance with 40 CFR § 60.13.
2.3. Sulfur limits	The sulfur content of fuel oil burned in the boiler must not exceed 0.5% by weight.
2.4. Fuel sulfur monitoring	Unless an approved alternate monitoring frequency is obtained from the EPA Administrator, the permittee must record and maintain records of the amounts of each fuel combusted during each day in each subject boiler. a. If oil is burned, the permittee must maintain records of the sulfur content of the fuel oil by either obtaining fuel supplier certifications or sampling and analyzing the fuel oil in accordance with ASTM procedures. b. If relying on fuel samples for demonstrating compliance with the fuel sulfur contents limits, a sample must be collected an analyzed after each shipment of fuel is added to the storage tank.
2.5. NSPS boiler reporting requirement	Unless an approved alternate monitoring frequency is obtained from the EPA administrator, the permittee must submit semi-annual reports for periods during which oil was burned that include the following information: a. The calendar dates covered in the reporting period; b. Each 30-day average sulfur content (weight percent), calculated during the reporting period, ending with the last 30-day period in the quarter, including: i. reasons for any noncompliance with the emission standards; and ii. a description of corrective actions taken. c. If fuel supplier certifications are used to demonstrate compliance, records of fuel supplier certifications that include: i. For distillate oil: • The name of the oil supplier; and • A statement from the oil supplier that the oil complies with the specifications under the definition of distillate oil in 40 CFR § 61.41.c ii. For residual oil: • The name of the oil supplier; • The location of the oil when the sample was drawn for analysis to determine the sulfur content of the oil, specifically including whether the oil was sampled as delivered to the facility, or whether the sample was drawn from oil in storage at the oil supplier’s or oil refiner’s facility, or other location; • The sulfur content of the oil from which the shipment came (or of the shipment itself); and, • The method used to determine the sulfur content of the oil. Note: If using ASTM grade 3, include the most relevant information depending on whether the blend exhibits the characteristics of a distillate or residual oil. d. If residual oil is burned in the boiler and the heat input is greater than 30 million Btu/hr, the semi-annual report must include a summary of any excess visible emissions recorded by the COMS. e. The initial semi-annual report must be postmarked by the 30^th day of the third month following the actual date of startup. Each subsequent semi-annual report must be postmarked by the 30^th day following the end of the reporting period.
2.6. Recordkeeping	The permittee must maintain on-site, records of the amount and types of fuels burned each day for a period of at least two (2) years.

Pollutant	Limit	Units
PM	36	tons per year
PM₁₀	20	tons per year
NO_X	39	tons per year
SO₂	39	tons per year
CO	99	tons per year
VOC	96	tons per year

6.1. Operation and Maintenance	The permittee must maintain the following records related to the operation and maintenance of the plant and associated air contaminant control devices:
	a. Process/production records shown in Condition 12.
	b. Fuel supplier certifications with each delivery of fuel. Fuel supplier certifications must include the following. i. The name of the oil supplier; and, ii. A statement from the oil supplier that the oil complies with the specification under the definition of distillate oil in 40 CFR Part 60.41.c.
	c. If used oil is used, the permittee must obtain analyses from the marketer or, if generated on site, have the used oil analyzed if the oil is to be burned in the boiler, so that it can be demonstrated that each shipment of oil does not exceed the used oil specifications contained in 40 CFR Part 279.11, Table 1.
6.2. Excess Emissions	The permittee must maintain records of excess emissions as defined in OAR 340-214-0300 through 340-214-0340 (recorded on occurrence). Typically, excess emissions are caused by process upsets, startups, shutdowns, or scheduled maintenance. In many cases, excess emissions are evident when visible emissions are greater than 20% opacity for 3 minutes or more in any 60-minute period. If there is an ongoing excess emission caused by an upset or breakdown, the permittee must cease operation of the equipment or facility no later than 48 hours after the beginning of the excess emissions, unless continued operation is approved by the Department in accordance with OAR 340-214-0330(4).
6.3. Complaint Log	The permittee must maintain a log of all written complaints and complaints received via telephone that specifically refer to air pollution concerns associated with the permitted facility. The log must include a record of the permittee’s actions to investigate the validity of each complaint and a record of actions taken for complaint resolution.
6.4. Retention of Records	Unless otherwise specified, all records must be maintained on site for a period of two (2) years and made available to the Department upon request.


Annual Period	The annual plant site emissions limits apply to any 12-consecutive calendar month period.

7.1. Excess Emissions	The permittee must notify the Department of excess emissions events if the excess emission is of a nature that could endanger public health.
	Such notice must be provided as soon as possible, but never more than one hour after becoming aware of the problem. Notice must be made to the regional office identified in Condition 8.3 by e-mail, telephone, facsimile, or in person.
	a. If the excess emissions occur during non-business hours, the permittee must notify the Department by calling the Oregon Emergency Response System (OERS). The current number is 1-800-452-0311.
	b. The permittee must also submit follow-up reports when required by the Department.
7.2. Annual Report	For each year this permit is in effect, the permittee must submit to the Department by February 15^th two (2) copies of the following information for the previous calendar year:
	a. A summary of annual and consecutive 12-month emission totals pollutant emissions determined each month in accordance with Condition 5.0 and comparison to the PSEL.
	b. Annual process or production parameters as shown in Condition 12.
	c. Annual fuel(s) combusted, by fuel type (cubic/ft/year or gallons/year).
	d. Records of all planned and unplanned excess emissions events.
	e. Summary of complaints relating to air quality received by permittee during the year.
	f. List permanent changes made in plant process, production levels, and pollution control equipment which affected air contaminant emissions.
	g. List major maintenance performed on pollution control equipment.
7.3. Notice of Change of Ownership or Company Name	The permittee must notify the Department in writing using a Departmental “Permit Application Form” within 60 days after the following:
	a. Legal change of the name of the company as registered with the Corporations Division of the State of Oregon; or
	b. Sale or exchange of the activity or facility.
7.4. Construction or Modification Notices	The permittee must notify the Department in writing using a Departmental “Notice of Construction Form,” or “Permit Application Form,” and obtain approval in accordance with OAR 340-210-0205 through 340-210-0250 before:
	a. Constructing, installing, or establishing a new stationary source that will cause an increase in any regulated pollutant emissions;
	b. Making any physical change or change in operation of an existing stationary source that will cause an increase, on an hourly basis at full production, in any regulated pollutant emissions; or
	c. Constructing or modifying any air pollution control equipment.
7.5. Where to Send Reports and Notices	The reports, with the permit number prominently displayed, must be sent to the Permit Coordinator for the region where the source is located as identified in Condition 8.3.

8.1. Permit Renewal Application	The completed application package for renewal of this permit is due on September 1, 2012 Two (2) copies of the application must be submitted to the DEQ Permit Coordinator listed in Condition 8.3.
Permit Modifications	Application for a modification of this permit must be submitted not less than 60 days prior to the source modification. A special activity fee must be submitted with an application for the permit modification. The fees and two (2) copies of the application must be submitted to the Business Office of the Department.
8.2. Permit Coordinator Address	All reports, notices, and applications should be directed to the Permit Coordinator as follows: Department of Environmental Quality Western Region 750 Front Street NE, Suite 120 Salem, OR 97301-1039 Telephone: (503) 378-5305
8.3. Department Contacts	Information about air quality permits and the Department’s regulations may be obtained from the DEQ web page at www.deq.state.or.us. All inquiries about this permit should be directed to the Salem regional office as follows: Department of Environmental Quality Salem Office 750 Front Street NE, Suite 120 Salem, OR 97301-1039 Telephone: (503) 378-8240

9.1. Annual Compliance Fee	The Annual Fee specified in OAR 340-216-0020, Table 2, Part 2 for a Standard ACDP is due on December 1 of each year this permit is in effect. An invoice indicating the amount, as determined by Department regulations, will be mailed prior to the above date.
Change of Ownership or Company Name Fee	The non-technical permit modification fee specified in OAR 340-216-0020, Table 2, Part 3(a) is due with an application for changing the ownership or the name of the company.
9.2. Special Activity Fees	The special activity fees specified in OAR 340-216-0020, Table 2, Part 3 (b through i) are due with an application to modify the permit.
9.3. Where to Submit Fees	Fees must be submitted to: Department of Environmental Quality Business Office 811 SW Sixth Avenue Portland, Oregon 97204-1390

10.1. Permitted Activities	This permit allows the permittee to discharge air contaminants from processes and activities related to the air contaminant source(s) listed on the first page of this permit until this permit expires, is modified, or is revoked.
Other Regulations	In addition to the specific requirements listed in this permit, the permittee must comply with all other legal requirements enforceable by the Department.
10.2. Conflicting Conditions	In any instance in which there is an apparent conflict relative to conditions in this permit, the most stringent conditions apply.
10.3. Masking of Emissions	The permittee must not cause or permit the installation of any device or use any means designed to mask the emissions of an air contaminant that causes or is likely to cause detriment to health, safety, or welfare of any person or otherwise violate any other regulation or requirement.
10.4. Department Access	The permittee must allow the Department’s representatives access to the plant site and pertinent records at all reasonable times for the purposes of performing inspections, surveys, collecting samples, obtaining data, reviewing and copying air contaminant emissions discharge records and conducting all necessary functions related to this permit in accordance with ORS 468-095.
10.5. Permit Availability	The permittee must have a copy of the permit available at the facility at all times.
10.6. Open Burning	The permittee may not conduct any open burning except as allowed by OAR 340 Division 264.
10.7. Asbestos	The permittee must comply with the asbestos abatement requirements in OAR 340, Division 248 for all activities involving asbestos-containing materials, including, but not limit to, demolition, renovation, repair, construction, and maintenance.
10.8. Property Rights	The issuance of this permit does not convey any property rights in either real or personal property, or any exclusive privileges, nor does it authorize any injury to private property or any invasion of personal rights, nor any infringement of federal, state, or local laws or regulations.
10.9. Termination, Revocation, or Modification	The Department may modify or revoke this permit pursuant to OAR 340-216-0082 and 340-216-0084.

Boiler (natural gas fired)	PM	2.5	lbs/MMft³	BLR 1	DEQ
	PM₁₀	2.5	lbs/MMft³		DEQ
	SO₂	1.7	lbs/MMft³		DEQ
	CO	84	lbs/MMft³		DEQ
	NO_X	100	lbs/MMft³		DEQ
	VOC	5.5	lbs/MMft³		DEQ

Boiler (distillate oil fired)	PM	3.3	lbs/Mgallons	BLR1	DEQ
	PM₁₀	2.3	lbs/Mgallons		DEQ
	SO₂	71	lbs/Mgallons		DEQ
	CO	5	lbs/Mgallons		DEQ
	NO_X	20	lbs/Mgallons		DEQ
	VOC	0.2	lbs/Mgallons		DEQ
Cyclones (medium efficiency)	PM	0.5	lbs/BDT	QM2,PM1, PM2, PM3, PM5, PM7,PMC	DEQ
	PM₁₀	0.25	lbs/BDT		DEQ
Cyclone (high efficiency)	PM	0.2	lbs/BDT	FJ1	DEQ
	PM₁₀	0.16	lbs/BDT		DEQ

Cyclone (Bag House)	PM	0.001	lbs/BDT	FJ, NPC-1	DEQ
	PM₁₀	0.001	lbs/BDT		DEQ
Truck Bin Unloading	PM	0.062	lbs/BDT	truck bins	AP-42, 13.2.4, Equation 1
	PM₁₀	0.022	lbs/BDT
Dry Kilns	PM	0.02	lbs/MBF	DK 1-6	DEQ
	PM₁₀	0.02	lbs/MBF		DEQ
	VOC	0.6	lbs/MBF		DEQ
Anti-Stain Lumber Coating	VOC	2.71	lbs/gallon	ASB-1, ASB-2, ASB-3	MSDS
Finger Joint Resin	VOC	0.134	lb/lb	resin	MSDS
Finger Joint Hardener	VOC	0.148	lb/lb	hardener	MSDS
Finger Joint Catalyst	VOC	0.058	lb/lb	catalyst	MSDS

Emissions device or activity	Process or production parameter	Frequency
Boiler	natural gas (ft³)and distillate fuel use (gallons)	Monthly, Annually
Cyclones	bone dry tons	Monthly, Annually
Truck Bin Unloading	bone dry tons	Monthly, Annually
Dry Kilns	board feet	Monthly, Annually
Anti-Stain Lumber Coatings	gallons	Monthly, Annually
Finger Joint resin, hardener,catalyst	pounds	Monthly, Annually