OREGON DEPARTMENT OF ENVIRONMENTAL QUALITY

OREGON TITLE V OPERATING PERMIT

Western Region

750 Front Street, Suite 120

Salem, OR 97301-1039

Telephone (503) 378-8240

Issued in accordance with the provision of

ORS 468A.040 and based on the land use compatibility findings included in the permit record.

RESPONSIBLE OFFICIALS  FACILITY CONTACT PERSON

TABLE OF CONTENTS

DEFINITIONS  3

LIST OF ABBREVIATIONS USED IN THIS PERMIT  3

PERMITTED ACTIVITIES  4

EMISSIONS UNIT (EU) AND POLLUTI0N CONTROL DEVICE (PCD) IDENTIFICATION  4

EMISSION LIMITS AND STANDARDS, TESTING, MONITORING, AND RECORDKEEPING REQUIREMENTS  5

Facility wide  5

Emissions Unit B67-EU  7

Emissions Unit B9-EU  8

Emissions Unit B10-EU  13

Emissions Unit CG1-EU  19

Emissions Unit SG2-EU  21

Emissions Unit PM5-EU  23

Emissions Unit PM6-EU  23

Emissions Unit CHS-EU  24

Emissions Unit DI-EU  25

Emissions Units CSP-EU, HFSP-EU, MH-EU, TMP-EU, UPR-EU, and WWT-EU  26

Insignificant Activities  26

PLANT SITE EMISSION LIMITS  27

GENERAL TESTING REQUIREMENTS  34

GENERAL MONITORING REQUIREMENTS  35

GENERAL RECORDKEEPING REQUIREMENTS  35

REPORTING REQUIREMENTS  36

NON-APPLICABLE REQUIREMENTS  39

GENERAL CONDITIONS  40

DEFINITIONS

“Annual” means any 12 consecutive month period.

“Daily” means SP Newsprint accounting day.

“Month“, for the purposes of compliance with the requirements of this permit, includes either a calendar month or one SP Newsprint accounting period.

LIST OF ABBREVIATIONS THAT MAY BE USED IN THIS PERMIT

PERMITTED ACTIVITIES

1.  Until such time as this permit expires or is modified or revoked, the permittee is allowed to discharge air contaminants from those processes and activities directly related to or associated with air contaminant source(s) in accordance with the requirements, limitations, and conditions of this permit. [OAR 340-218-0010 and 340-218-0120(2)]

2.  All conditions in this permit are federally enforceable and state enforceable except as noted below:

2.a.  Conditions 5, 6, 7, 8, G4, and G8 (specifically, OAR 340-248-0005 through 340-248-0180) are only enforceable by the state. [OAR 340-218-0060]

2.b.  The total reduced sulfur (TRS) PSEL in Condition 94 is currently enforceable by the state only but will become federally enforceable upon the EPA approval of proposed revisions to the Oregon Plan for the Control of Designated Pollutants from Existing Facilities (Section 111(d) Plan).

2.d.  Attachment 1 of this permit provides a cross-reference for SIP and Title V program rules that have been renumbered in the current Oregon Administrative Rules.
[OAR 340-218-0060 and 340-218-0070]

EMISSIONS UNIT (EU) AND POLLUTION CONTROL DEVICE (PCD) IDENTIFICATION

3.  The emissions units regulated by this permit are the following [OAR 340-218-0040(3)]:

Table 1    Emissions Units and Control Devices

EMISSION LIMITS AND STANDARDS, TESTING, MONITORING, AND RECORDKEEPING REQUIREMENTS

Table 2    Summary of Facility wide emission limits and standards

Fugitive Emissions

Applicable Requirement: The permittee must not allow or permit any materials to be handled, transported, or stored; or a building, its appurtenances, or a road to be used, constructed, altered, repaired or demolished; or any equipment to be operated, without taking reasonable precautions to prevent particulate matter from becoming airborne. [OAR 340-208-0210(2)] Such reasonable precautions shall include, but are not limited to the following:

Storing collected material 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.

The permittee must maintain and comply with a Fugitive Emissions Reduction Plan that will result in controlling and reducing the amount of fugitive dust emission generated on the plant site. The permittee must review and update, as needed, the Fugitive Emissions Reduction Plan at least once each calendar year. If an updated plan results, a copy of the plan shall be submitted to the Department’s Salem Regional Office with an explanation of the changes made.

 Nuisance Conditions

5.  Applicable Requirement:  The permittee must not cause or allow air contaminants from any source subject to regulation by the Department to cause a nuisance. Nuisance conditions will be verified by Department personnel in accordance with OAR 340-208-0310. [OAR 340-208-0300] This condition is only enforceable by the State.

6.  Applicable Requirement:  The permittee must not cause or permit the emission of 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 when notified by the Department that the deposition exists and must be controlled. [OAR 340-208-0450] This condition is only enforceable by the State.

7.  Monitoring and Recordkeeping Requirements:  The permittee must maintain a record of all complaints received by plant personnel that specifically refer to fugitive emissions, air quality nuisance emissions, or particulate matter fallout. A plant representative shall promptly investigate the complaint and shall provide an initial response to the complainant by the end of the following business day, if possible, and attempt to resolve the complaint within five business days. The record shall include documentation of: complaint description; the permittee’s actions to investigate and determine complaint validity; dates received and resolved; and corrective actions taken. This condition is only enforceable by the state. [OAR 340-218-0050(3)(a)]

8.  Monitoring Requirement: The permittee must maintain a telephone number capable of receiving complaints 24 hours per day and must publish the telephone number in the local newspaper annually by June 1 each year or maintain a web site that includes complaint contact information. The telephone number(s) must also be prominently displayed by the main entrance to the plant such that the public can read the sign from the public street. This condition is only enforceable by the state.
[OAR 340-218-0050(3)(a)]

Fuel Oil Sulfur Content and Used Oil Requirements

9.  Applicable Requirement:  The permittee must not burn any used oil that does not meet the definition of used oil in OAR 340-111-0020(2)(c) and 40 CFR 279.1. [OAR 340-111-0020(2)(c)]

10.  Applicable Requirement:  The permittee must not use any ASTM Grade 1 distillate fuel oil containing more than 0.3% sulfur by weight. [OAR 340-228-0110(1)]

11.  Applicable Requirement:  The permittee must not use any ASTM Grade 2 distillate fuel oil containing more than 0.5% sulfur by weight. [OAR 340-228-0110(2)]

12.  Applicable Requirement:  The permittee must not use any residual fuel oil or used oils containing more than 1.75% sulfur by weight. [OAR 340-228-0100]

13.  Monitoring and Recordkeeping Requirements:  The permittee shall monitor and maintain records of the sulfur content of oil (used, residual, ASTM Grade 1, or ASTM Grade 2) combusted by:

13.a.  Obtaining a sulfur analysis certificate from the vendor; or

13.b.  During any month when oil is delivered, analyzing or having analyzed by a contract laboratory a sample of the fuel oil in the fuel storage tank.

13.c.  Conducting an annual composite of representative samples of each batch of used oil generated on site.

13.d.  Liquid fuels shall be analyzed using ASTM D129-64, D1552-83, D4057-81, or equivalent, or as otherwise approved by the Department.

Table 3    Summary of Requirements for Emissions Unit B67-EU

 [Boilers #6 and # 7]

B67 Visible Emissions

14.  Applicable Requirement:  The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit B67-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit B67-EU is Modified EPA Method 9.

15.  B67 Particulate Matter

16.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.2 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit B67-EU. [OAR 340-228-0210(1)(a)] The reference test method for measuring particulate matter emissions from emissions unit B67-EU is Oregon Method 5 unless otherwise approved in a test plan.

18.  B67 Fuel Restriction

19.  Applicable Requirement: Only natural gas fuel may be combusted in emissions unit B67-EU.
[OAR 340-218-0080(8)]

20.  Monitoring Requirement: The permittee must maintain records of the types of fuels combusted in emissions unit B67-EU on an annual basis.

Table 4    Summary of Requirements for Emissions Unit B9-EU

[Boiler # 9 and Hog Fuel Dryer]

B9 Visible Emissions

25.  Applicable Requirement:  The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit B9-EU which is equal to or greater than 20% opacity, excluding uncombined water.
[OAR 340-208-0110]

26.  Monitoring Requirement:  At least once per calendar quarter, the permittee must conduct a Modified Method 9 visible emissions test on emissions unit B9-EU. This requirement is waived for a given period when the boiler is fired on natural gas or is not operated 100% of the time during that period.

26.a.  The Modified Method 9 test method may be waived provided the permittee conducts a six (6) minute visible emissions survey on the device at the compliance demonstration point using EPA Method 22 and visible emissions, excluding water vapor, are not detected for more than 5% (18 seconds) of the survey time.

26.c.  If the observer is unable to conduct the tests and/or surveys due to darkness or visual interference caused by other visible emission sources or due to adverse weather conditions such as fog, heavy rain, or snow, the observer shall note such conditions on the observation form and make at least three attempts to conduct the tests and/or surveys at approximately 2-hour intervals throughout the day during daylight hours.

26.h.  Should a test exceed the applicable standard, corrective action will be taken to bring the source into compliance with the applicable requirement; and the monitoring frequency shall be daily for at least 10 consecutive business days. If the results of the daily tests are all less than the applicable standard, the test frequency maybe the same as before the exceedance occurred.

Recordkeeping: The permittee shall maintain records of all visible emissions tests and surveys, including date, time, observer, observations, results, types of fuels being burned, and any corrective actions taken. If a test is waived for a given period, so state on the record.

B9 Particulate Matter

27.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit B9-EU. [OAR 340-228-0210(1)(b)]

28.  Testing Requirements:  B9-EU must be tested at least once prior to December 1, 2011 for particulate matter (PM) emissions while burning the normal mix of solid fuels. However, no testing is required if Boiler # 9 is operated less than 120 consecutive days during the permit period. If the operational requirement for testing is met after December 1, 2011, then the required testing must be conducted within 90 days of meeting the operational requirement. The particulate matter test results must be reported as grains/dscf corrected to 12% CO₂, pounds per hour, and pounds per 1000 pounds steam.

28.a.  Test Methods:

28.a.i.  EPA Methods 1 through 4.

28.a.ii.  Oregon Method 5 shall be use to measure PM emissions.

28.a.vii.  Visible emissions shall be measured concurrently with each PM test run
using EPA Method 9.

28.b.  Process and control device information to be collected and reported during each test run include:

28.b.i.  Steaming rate.

28.b.ii.  Types and amounts of fuels combusted (dry weight basis for solid fuels). The amount of fuel combusted may be an estimated number based on the heat input values of the fuels being combusted.

28.b.iii.  Hogged fuel characteristics including moisture content and approximate percentage of wood and bark.

28.b.iv.  B9-EU opacity, exhaust temperature levels, residual oxygen levels, and flue gas flow rates.

28.b.v.  Boiler # 9 Wet Scrubber liquid flow rates and differential pressures.

29.  Monitoring Requirement: At least once per calendar year the permittee must perform a physical inspection of the Boiler # 9 Multiclone for wear, plugging, abrasion, and integrity.

29.a.  Recordkeeping: The permittee shall maintain records of the multiclone inspections including dates, systems and items inspected, findings, and repair activities.

30.  Monitoring Requirement: At least once per calendar year the permittee shall perform a physical inspection of the Boiler # 9 Wet Scrubber for corrosion, wear, plugging, abrasion, and integrity.

30.a.  Recordkeeping: The permittee shall maintain records of the wet scrubber inspections including dates, systems and items inspected, findings, and repair activities.

31.  Monitoring Requirement:  The permittee must operate, maintain, and record the output of a continuous residual oxygen monitor in accordance with the manufacturer’s written instructions when emissions unit B9-EU is in operation. The permittee shall operate and maintain an audible alarm that sounds instantaneously when the residual oxygen level is outside the normal operating range established in Condition 24.a.

31.a.  The permittee shall initiate corrective action within one hour to return to highest and best practicable treatment and control if the residual oxygen level is less the operating value of 3.0% (hourly average basis) except during startups or shutdowns.

31.a.i.  Recordkeeping: The permittee shall maintain records of residual oxygen excursions including date, value, cause, and corrective actions taken.

31.b.  A residual oxygen excursion is not necessarily a violation of the emission standards for B9-EU.

31.c.  Real time data shall be displayed at least once per minute.

31.c.i.  Recordkeeping: Arithmetic 1-hour averages of the data shall be recorded at the end of each hour.

32.  Monitoring Requirement:  The permittee must operate, maintain, and record the output of a continuous differential pressure monitor for the Boiler # 9 Wet Scrubber in accordance with the manufacturer’s written instructions when emissions unit B9-EU is in operation. The permittee shall operate and maintain an audible and/or visual alarm system that activates instantaneously when the differential pressure is less the normal value established in Condition 25.a. [40 CFR Part 64]

33.a.  The permittee shall initiate corrective action within one hour to return to highest and best practicable treatment and control if the differential pressure is less then the normal operating value of 7.0 inches of water (hourly average basis) except when B9-EU is operating at less than 25,000 pounds steam per hour, then no corrective action is required.

33.a.i.  Recordkeeping: The permittee shall maintain records of differential pressure excursions including date, value, cause, and corrective actions taken.

33.b.  A differential pressure excursion is not necessarily a violation of the particulate matter emission standards for the B9-EU.

33.c.  Real time data shall be available for display at least once per minute.

33.c.i.  Recordkeeping: Arithmetic 1-hour averages of the data shall be recorded at the end of each hour.

34.  Monitoring Requirement: The permittee shall operate, maintain, and record the output of a continuous liquid flow rate monitor for the Boiler # 9 Wet Scrubber in accordance with the manufacturer’s written instructions when emissions unit B9-EU is in operation. The permittee shall operate and maintain an audible and/or visual alarm that activates instantaneously when the liquid flow rate level is less the normal operating value established in Condition 26.a. [40 CFR Part 64]

34.a.  The permittee shall initiate corrective action within one hour to return to highest and best practicable treatment and control if the liquid flow rate is less than the normal operating value of 35.0 gallons per minute (hourly average basis) except during startups or shutdowns.

34.a.i.  Recordkeeping: The permittee shall maintain records of liquid flow rate excursions including date, value, cause, and corrective actions taken.

34.b.  A liquid flow rate excursion is not necessarily a violation of the emission standards for B9-EU.

34.c.  Real time data shall be available for display at least once per minute.

34.c.i.  Recordkeeping: Arithmetic averages of the data shall be recorded at the end of each hour.

35.  Monitoring Requirement:  The permittee may re-determine the action levels for residual oxygen, differential pressure, and/or the liquid flow rate by submitting results from a Department approved source test, supplemented as necessary by engineering assessments and manufacturer’s recommendations, that demonstrate the emissions unit can operate in compliance with the applicable standards within the new proposed action level(s).

B9

SO₂

36.  Applicable Requirement: Emissions of sulfur dioxide from Boiler # 9 must not exceed 1.2 pounds per million Btu heat input, 3-hour average, when solid fuel is burned. [OAR 340-228-0200(2)(b)] The reference test method for measuring SO₂ emissions from emissions unit B10-EU is EPA Methods 6 or 6C unless otherwise approved in the test plan.

B9 37.c.viii.  Sludge Drying

38.  Applicable Requirement: Emissions to the atmosphere from device HFD when processing wastewater treatment plant sludge shall not exceed 3200 grams of mercury per 24-hour period.
[40 CFR 61.52(b)]

39.  Testing Requirements: If the permittee does change the operation of device HFD and mercury emission are estimated to exceed 1,600 grams per 24-hour period, the following sludge test shall be performed within 90 days of the change and annually thereafter. [40 CFR 61.55(a)]

39.a.  A total of three composite samples shall be obtained within an operational period of 24 hours. When the 24-hour operation period is not continuous, the total sampling period shall not exceed 72 hours after the first grab sample is obtained. [40 CFR 61.54(c)(1)]

39.c.  The maximum 24-hour period sludge drying rate shall be determined by use of a flow rate measurement device that can measure the mass rate of sludge charged to the dryer with an accuracy of + 5 percent over its operating range. Other methods of measuring sludge mass charging rates may be used if they have received prior approval of the Department.
[40 CFR 61.54(c)(2)]

39.d.  The sampling, handling, preparation, and analysis of sludge samples shall be accomplished in accordance with EPA Method 105 (Determination of Mercury in Wastewater Treatment Plant Sewage Sludges) in Appendix B of 40 CFR Part 61. [40 CFR 61.54(c)(3)]

39.e.  The mercury emissions shall be determined by use of the following equation:

E_Hg = M x Q x F_sm(avg) / 1,000
where
E_Hg = mercury emissions, g/day
M = mercury concentration of sludge on a dry solids basis, mg/g
Q = sludge charging rate, kg/day
F_sm = weight fraction of solids in the collected sludge after mixing
1,000 = conversion factor, kg mg/g²

39.f.  Recordkeeping: Records of sludge sampling, charging rate determination and other data needed to determine mercury content of wastewater treatment plant sludge shall be retained at the source and made available for inspection by the Department for a minimum of two years.[40 CFR 61.54(g)]

40.  Applicable Requirement: No changes in the operation of the Hog Fuel Dryer shall be made which would potentially increase emissions above the level determined by the most recent sludge test, until the new emission level has been estimated by calculation and the results reported to the Department. [40 CFR 61.54(e)]

42.  Monitoring Requirement: The permittee must estimate the mercury emissions from the Hog Fuel Dryer prior to any change in operations that could be reasonably anticipated to increase mercury emissions above the level determined by the most recent sampling. The estimated emission rate must be reported to the Department and EPA prior to performing the change in operations. [40 CFR 61.54(e)]

B9 Fuels

Miscellaneous Fuels

43.  Applicable Requirement:  The amount of miscellaneous fuels that may be burned in Boiler # 9 must not exceed 30% of the total heat input value of the fuel stream to Boiler # 9 on an annual basis.
[OAR 340-218-0080(8)]

44.  Monitoring and Recordkeeping:  The permittee must maintain records demonstrating that the total heat input value of the miscellaneous fuels burned in Boiler # 9 does not exceed 30% of the total heat input value of the fuels used by Boiler # 9 on an annual basis. The records must be updated by the end of the following month for each period.

45.  Tire Derived Fuel (TDF)

46.  Applicable Requirement: The amount of tire derived fuel combusted in emissions unit B9-EU must not exceed 1% by weight (as received) of the total solid fuel stream on an annual basis. [06/13/95 ACDP Addendum No. 2, condition 4]

Monitoring Requirement: The permittee must maintain records demonstrating that the amount of tire derived fuel combusted in emissions unit B9-EU does not exceed the limit established in Condition 35. The calculations and comparison to the TDF limit in Condition 35 must be performed by the end of the following month for each annual period.

Table 5    Summary of Requirements for Emissions Unit B10-EU

[Boiler # 10]

B10 Visible Emissions

47.  Applicable Requirement: The permittee shall not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit B10-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110]

48.  Applicable Requirement: The permittee shall not cause or allow the emissions of any air contaminant into the atmosphere from emissions unit B10-EU which is equal to or greater than 10% opacity as a 6-minute average, excluding uncombined water. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1]

49.  Monitoring and Recordkeeping Requirement:  The permittee shall continuously monitor opacity from emissions unit B10-EU by operating and maintaining a Continuous Opacity Monitoring System (COMS) in accordance with the latest Department approved SP Newsprint Quality Assurance Plan and the Department’s Continuous Monitoring Manual whenever B10-EU is operating.

50.  A minimum of 4 opacity readings per minute shall be taken at equal intervals.

52.  The individual opacity reading that equal or exceed 20% shall be recorded and compared to the visible emissions standards of Condition 37.

54.  The average opacity for each 6-minute block must be determined from the individual reading and compared to the visible emission standards of Condition 38.

55.a.  The permittee must operate and maintain an audible alarm that sounds when the opacity reaches 10% instantaneously. The permittee must take corrective action when the average opacity is equal to or greater than 7.5% for a 6-minute period. [40 CFR Part 64]

55.a.i.  Recordkeeping:  Records of opacity excursions and corrective actions taken must be maintained.

55.a.ii.  An opacity excursion is not necessarily a violation of the applicable visible emission or particulate emission standards for B10-EU.

B10 Particulate Matter

56.  Applicable Requirement:  The permittee shall not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit B10-EU. [OAR 340-228-0210(1)(b)]

57.  Applicable Requirement:  The permittee shall not cause or allow the emission of particulate matter in excess of 0.04 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit B10-EU. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1]

58.  Applicable Requirement:  The permittee shall not cause or allow the emission of particulate matter in excess of 86.5 pounds per hour, daily average, from emissions unit B10-EU. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1]

59.  Testing Requirements Boiler # 10 must be tested at least once prior to December 1, 2011 for particulate matter (PM) emissions while burning the “normal” mixture of solid fuels. If dried biosolids are being used as part of the normal solid fuel mixture, at least one test for NO_x emissions and one test for SO₂ emissions must be conducted for emission factor verification purposes prior to December 1, 2011. However, no testing is required if Boiler # 10 is operated less than 120 consecutive days during the permit period. If the operational requirement for testing is met after December 1, 2011, then the required testing must be conducted within 90 days of meeting the operational requirement. Particulate matter test results must be reported as grains/dscf corrected to 12% CO₂, pounds per hour, and pounds per 1000 pounds steam produced. NO_x and SO₂ test results must be reported as pounds/BDT biosolids burned, pounds/hour, and pounds/1000 pounds steam produced.

60.a.  Test Methods:

60.a.i.  EPA Methods 1 through 4 must be used.

60.a.ii.  EPA Method 5 must be used to measure PM emissions to demonstrate compliance with the particulate matter emissions limits contained in Conditions 41 and 42.

60.a.iv.  ODEQ Method 5 must be used to measure PM emissions to demonstrate compliance with the particulate emission limits contained in Condition 40.

60.a.vi.  EPA Methods 7 or 7E must be used to measure NO_x emissions unless otherwise approved in the test plan.

60.a.vii.  EPA Methods 6 or 6C must be used to measure SO₂ emissions unless otherwise approved in the test plan.

60.b.  Process and control device information to be collected and reported during each test run include:

60.b.i.  Steaming rate (pounds/hour).

60.b.iii.  Hog fuel usage and fuel characteristics including moisture content and approximate percentage of wood and bark.

60.b.iv.  Types and amounts of fuels combusted (dry weight basis for solid fuels). The amount of fuel combusted may be an estimated number based on the heat input values of the fuels being combusted.

60.b.v.  Maximum 6-minute block opacity during each particulate matter test run.

Boiler exhaust temperature levels, residual oxygen levels, and flue gas flow rates (dscfm).

60.b.viii.  ESP voltages and currents (minimum of 4 readings per run separated by at least 15 minutes) during each particulate matter test run.

61.  Monitoring Requirement: The permittee must continuously monitor visible emissions from emissions unit B10-EU in accordance with the requirements of Condition 39.

62.  Monitoring Requirement:  The permittee must operate, maintain, and record the output of a continuous residual oxygen monitor in accordance with the manufacturer’s written instructions when emissions unit B10-EU is in operation. The permittee shall operate and maintain an audible alarm that sounds instantaneously when the residual oxygen level is outside the normal operating range established in Condition 45.a.

62.a.  The permittee must initiate corrective action within one hour to return to highest and best practicable treatment and control if the residual oxygen level is less the operating value of 3.0% (hourly average basis) except during startups or shutdowns.

62.a.i.  Recordkeeping: The permittee must maintain records of residual oxygen excursions including date, value, cause, and corrective actions taken.

62.b.  A residual oxygen excursion is not necessarily a violation of the emission standards for B10-EU.

62.c.  Real time data shall be displayed at least once per minute.

62.c.i.  Recordkeeping: Arithmetic averages of the data shall be recorded at the end of each hour.

63.  Monitoring Requirement:  At least once per calendar year the permittee shall perform a physical inspection of the Boiler #10 Multiclone for wear, plugging, abrasion, and integrity.

63.a.  Recordkeeping:  The permittee shall maintain records of the multiclone inspections including dates, systems and items inspected, findings, and repair activities.

64.  Monitoring Requirement:  At least once per calendar year the permittee shall perform a physical inspection of the Boiler #10 ESP for wear, plugging, abrasion, and integrity.

65.a.  Recordkeeping:  The permittee shall maintain records of the ESP inspections including dates, systems and items inspected, findings, and repair activities.

B10 SO₂

66.  Applicable Requirement: The permittee shall not cause or allow the emission into the atmosphere of sulfur dioxide in excess of 0.8 pounds per million Btu heat input, 3-hour average, from emissions unit B10-EU when liquid fuel is burned. [OAR 340-228-0200(2)(a)]

67.  Monitoring Requirement: To demonstrate compliance with the emission standards contained in Condition 48, the following material balance equation will be used to determine SO₂ emissions from B10-EU each day when liquid fuels are burned:

E = [2 x S x (d/H) x O] + (I x F)

Where,

E = emission rate of sulfur dioxide, (lb/million Btu)

S = oil sulfur content, weight fraction (wt./wt.)

d = density of oil (lb/gal)

H = heating value of oil (million Btu/gal)

O = fraction of heat input from oil, daily basis

I = SO₂ emissions from solid fuels (lb/million Btu)

F = fraction of heat input from solid fuel(s), daily basis

The above calculation and comparison with the standard must be performed within 30 days of the given day.

Recordkeeping: The permittee must maintain records of the above calculations and comparison to the SO₂ standard.

70.  Applicable Requirement:  The permittee must not cause or allow the emission into the atmosphere of sulfur dioxide in excess of 1.2 pounds per million Btu heat input, 3-hour average, from emissions unit B10-EU when solid fuel is burned. [OAR 340-228-0200(2)(b)] The reference test method for measuring SO₂ emissions from emissions unit B10-EU is EPA Methods 6 or 6C unless otherwise approved in the test plan.

71.  B10 CO PSD Limit

73.  Applicable Requirement:  The permittee shall not cause or allow the emission of carbon monoxide in excess of 220 pounds per hour, daily average, from emissions unit B10-EU. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1] The reference test method for measuring CO emissions from emissions unit B10-EU is EPA Method 10 unless otherwise approved in the test plan.

B10 NO_x PSD Limit

74.  Applicable Requirement:  The permittee shall not cause or allow the emission of nitrogen oxides in excess of 769 pounds per hour, daily average, from emissions unit B10-EU. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1] The reference test method for measuring NO_x emissions from emissions unit B10-EU is EPA Methods 7 or 7E unless otherwise approved in the test plan.

B10 VOC PSD Limit

75.  Applicable Requirement:  The permittee shall not cause or allow the emission of volatile organic compounds in excess of 220 pounds per hour, daily average, from emissions unit B10-EU. [2/05/80 EPA PSD Permit: PSD-X80-03, Condition 1] The reference test method for measuring VOC emissions from emissions unit B10-EU is EPA Method 25A unless otherwise approved in the test plan.

B10 Fuel Restrictions

79.  Applicable Requirement:  The amount of fiber based fuel (FBF) combusted must not exceed 13.7% by weight (as received) of the total solid fuel feed stream combusted in emissions unit B10-EU on annual basis. [06/13/95 ACDP Addendum # 2, Condition 4]

80.  Applicable Requirement:  The amount creosote treated wood fuel (CTWF) combusted must not exceed 50% by weight (as received) of the total solid fuel feed stream combusted in emissions unit B10-EU on a annual basis. [06/13/95 ACDP Addendum No. 2, Condition 4]

81.  Applicable Requirement: The amount of miscellaneous solid fuels that may be burned in emissions unit B10-EU must not exceed 30% of the total heat input value of the fuel stream to emissions unit B10-EU on an annual basis. [OAR 340-218-0080(8)]

81.a.  Monitoring Requirement: The permittee must maintain records demonstrating that the amounts of FBF, CTWF, and miscellaneous fuels combusted in B10-EU on an annual basis are in compliance with the usage limits stated in Conditions 54, 55, and 56 for each fuel. The demonstrations and recordkeeping must be performed by the end of the following month for each annual period.

Table 6    Summary of Requirements for Emissions Units CG1-EU

[Cogeneration System #1]

CG1-EU

40 CFR Part 60 Subpart A--General Provisions

Applicable Requirement: The permittee must maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operations of emissions unit CG1-EU; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b)]

89.  Applicable Requirement: At all times, including periods of startup, shutdown, and malfunction, the permittee must, to the extent practicable, maintain and operate the emissions unit CG1-EU 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 use will be based on information available to the Department which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. [40 CFR 60.11(d)]

90.  Applicable Requirement: The permittee must not build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in gases discharged to the atmosphere from emissions unit CG1-EU. [40 CFR 60.12]

CG1-EU Visible Emissions

94.  Applicable Requirement:  The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit CG1-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit CG1-EU is Modified EPA Method 9.

95.  CG1-EU Particulate Matter

96.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit CG1-EU. [OAR 340-228-0210(1)(b)] The reference test method for measuring PM emissions from emissions unit CG1-EU is Oregon Method 5 unless otherwise approved in a test plan.

97.  HRSG1 NO_x

98.  Applicable Requirement:  The permittee must not cause to be discharged into the atmosphere from emissions device HRSG1 any gases that contain nitrogen oxides in excess of 0.20 pounds per million Btu heat input. [40 CFR 60.44b(a)(4)(i)] The reference test method for measuring NO_x emissions from emissions device HRSG1 is EPA Method 7 or 7E unless otherwise approved in a test plan.

99.  CTG1 NO_X

101.  Applicable Requirement:  The permittee must not cause to be discharged into the atmosphere from emissions device CTG1 any gases that contain nitrogen oxides in excess of the following:
[40 CFR 60.332(a)(1) and 40 CFR 60.332(a)(3)]

STD = 75*(14.4/Y) + F

where

STD = allowable NO_x emissions (ppmv @ 15% O₂ dry basis)

Y = manufacturer’s rated heat rate at manufacturer’s rated load (kilojoules per watt hour) or, actual measured heat rate based on lower heating value of fuel as measured at actual peak load for the facility. The value of Y shall not exceed 14.4 kilojoules per watt hour.

F = NO_x emission allowance for fuel-bound nitrogen and is calculated using the following table:

103.  Monitoring Requirement: The permittee must operate a continuous monitoring system to monitor and record the fuel consumption and the ratio of water to fuel being fired in CTG1. This system shall be accurate to within + 5 percent. [40 CFR 60.334(a)]

104.  Monitoring Requirement: The permittee must establish water to fuel ratio action levels for CTG1 based on performance test results. The action levels determined will be included with the performance test reports submitted to the Department. [40 CFR Part 64]

104.a.  If an action level excursion occurs, the permittee shall initiate corrective action promptly to return the water injection system back to highest and best control.

104.b.  Recordkeeping: The permittee shall maintain records of action level excursions and corrective actions taken.

104.c.  An action level excursion is not necessarily a violation of the nitrogen oxides emission standards for emissions unit CG1-EU.

106.  CTG1 SO₂

107.  Applicable Requirement:  The permittee must comply with one or the other of the following conditions: [40 CFR 60.333]

108.  The permittee must not cause to be discharged into the atmosphere from CTG1 any gases which contain sulfur dioxide in excess of 0.015 percent by volume (150 ppm) at 15% oxygen and on a dry basis. [40 CFR 60.333(a)] The reference test method for measuring sulfur dioxide emissions from CTG1 is EPA Method 6 unless otherwise approved in a test plan.

110.  The permittee must not burn in CTG1 any fuel which contains sulfur in excess of 0.8 percent by weight. [40 CFR 60.333(b)]

111.  Monitoring Requirement: To demonstrate compliance with the requirements of Condition 67.b,  the permittee must monitor the sulfur content of the fuel being combusted in CTG1 on a semi-annual basis. [40 CFR 60.334(b) and EPA Region 10 Waiver dated 8/23/02]

Table 7    Summary of Requirements for Emissions Units SG2-EU

[Steam Generator Unit #2]

SG2-EU 40 CFR Part 60 Subpart A--General Provisions

113.  Applicable Requirement: The permittee must maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operations of emissions unit SG2-EU; any malfunction of the air pollution control equipment; or any periods during which a continuous monitoring system or monitoring device is inoperative. [40 CFR 60.7(b)]

114.  Applicable Requirement: At all times, including periods of startup, shutdown, and malfunction, the permittee must, to the extent practicable, maintain and operate the emissions unit SG2-EU 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 use will be based on information available to the Department which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. [40 CFR 60.11(d)]

115.  Applicable Requirement: The permittee must not build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in gases discharged to the atmosphere from emissions unit SG2-EU. [40 CFR 60.12]

SG2 Visible Emissions

116.  Applicable Requirement: The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit SG2-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit SG2-EU is Modified EPA Method 9.

SG2 Particulate Matter

117.  Applicable Requirement: The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot, corrected to 12% CO₂ or 50% excess air, from emissions unit SG2-EU. [OAR 340-228-0210(1)(b)] The reference test method for measuring PM emissions from emissions unit SG2-EU is Oregon Method 5 unless otherwise approved in a test plan.

SG2 NO_x

118.  Applicable Requirement: The permittee must not cause to be discharged into the atmosphere from emissions unit SG2-EU any gases that contain nitrogen oxides in excess of 0.20 pounds per million Btu heat input. [40 CFR 60.44b(a)(4)(i)] The reference test method for measuring NO_x emissions from emissions unit SG2-EU is EPA Method 7 or 7E unless otherwise approved in a test plan.

Table 8    Summary of Requirements for Emissions Unit PM5-EU

[Paper Machine # 5]

PM5-EU Visible Emissions

120.  Applicable Requirement: The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit PM5-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit PM5-EU is Modified EPA Method 9.

121.  PM5-EU Particulate Matter

122.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.2 grains per dry standard cubic foot from emissions unit PM5-EU. [OAR 340-226-0210(1)(a)] The reference test method for measuring PM emissions from emissions unit PM5-EU is Oregon Method 5 unless otherwise approved by a test plan.

123.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in any one hour from emissions unit PM5-EU in excess of the amount shown in Table 1, OAR 340-226-0320, for the process weight allocated to that process. [OAR 340-226-0310] The reference test method for measuring PM emissions from emissions unit PM5-EU is Oregon Method 5 unless otherwise approved by a test plan.

124.  PM5-EU PM and VE Monitoring

Monitoring Requirement: The permittee must investigate, resolve, and record air quality related complaints involving emissions unit PM5-EU in accordance with Condition 7.

Table 9    Summary of Requirements for Emissions Unit PM6-EU

[Paper Machine # 6]

PM6-EU Visible Emissions

125.  Applicable Requirement: The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit PM6-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit PM6-EU is Modified EPA Method 9.

PM6-EU Particulate Matter

126.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot from emissions unit PM6-EU. [OAR 340-226-0210(1)(b)] The reference test method for measuring PM emissions from emissions unit PM6-EU is Oregon Method 5 unless otherwise approved by a test plan.

127.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in any one hour from emissions unit PM6-EU in excess of the amount shown in Table 1, OAR 340-226-0320, for the process weight allocated to that process. [OAR 340-226-0310] The reference test method for measuring PM emissions from emissions unit PM6-EU is Oregon Method 5 unless otherwise approved by a test plan.

128.  PM6-EU PM and VE Monitoring

129.  Monitoring Requirement: The permittee must investigate, resolve, and record air quality related complaints involving emissions unit PM6-EU in accordance with Condition 7.

Table 10    Summary of Requirements for Emissions Unit CHS-EU

[Pneumatic Chip Handling System]

CHS-EU Visible Emissions

132.  Applicable Requirement:  The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit CHS-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit CHS-EU is Modified EPA Method 9.

CHS-EU Particulate Matter

133.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot from emissions unit CHS-EU. [OAR 340-226-0210(1)(b)] The reference test method for measuring PM emissions from emissions unit CHS-EU is Oregon Method 5 unless otherwise approved by a test plan.

134.  Applicable Requirement:  The permittee must not cause or allow the emission of particulate matter in any one hour from emissions unit CHS-EU in excess of the amount shown in Table 1, OAR 340-226-0320, for the process weight allocated to that process. [OAR 340-226-0310] The reference test method for measuring PM emissions from emissions unit CHS-EU is Oregon Method 5 unless otherwise approved by a test plan

135.  CHS-EU PM and VE Monitoring

136.  Monitoring Requirement:  At least once each calendar month, the permittee must conduct an external inspection of emissions unit CHS-EU and its associated duct work for structural integrity, corrosion, and air leaks and must take corrective actions as needed to maintain the system in proper condition.

136.a.  Recordkeeping:  The permittee must maintain records of the inspections including date, findings, and corrective actions taken.

Table 11  Summary of Requirements for Emissions Units DI-EU

[Deink Plant]

DI-EU Visible Emissions

137.  Applicable Requirement: The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions unit DI-EU which is equal to or greater than 20% opacity, excluding uncombined water.
[OAR 340-208-0110] The reference test method for measuring visible emissions from emissions unit B67-EU is Modified EPA Method 9.

138.  DI-EU Particulate Matter

139.  Applicable Requirement: The permittee must not cause or allow the emission of particulate matter in excess of 0.1 grains per dry standard cubic foot from emissions unit DI-EU. [OAR 340-226-0210(1)(b)] The reference test method for measuring particulate matter emissions from emissions unit DI-EU is Oregon Method 5 unless otherwise approved in the test plan.

140.  DI-EU PM and VE Monitoring

141.  Monitoring Requirement: The permittee must investigate, resolve, and record air quality related complaints involving emissions unit DI-EU in accordance with Condition 7.

Table 12  Summary of Requirements for Emissions Units CSP-EU, HFSP-EU, MH-EU, TMP-EU, UPR-EU, WWT-EU

[Chip Storage Pile]

[Hogged Fuel Storage Pile]

[Raw Material & Fuel Receiving and Distribution]

[Thermal Mechanical Pulping]

[Unpaved Roads]

[Wastewater Treatment System]

142.  Applicable Requirement: The permittee must not cause or allow the emissions of any air contaminant into the atmosphere for a period or periods aggregating more than three minutes in any one hour from emissions units CSP-EU, HFSP-EU, MH-EU, UPR-EU, TMP-EU, and WWT-EU which is equal to or greater than 20% opacity, excluding uncombined water. [OAR 340-208-0110] The reference test method for measuring visible emissions from these emissions units is Modified EPA Method 9.

143.  Monitoring Requirement:  The permittee must investigate, resolve, and record air quality related complaints involving these emissions units in accordance with Condition 7.

Insignificant Activities Emission Limits and Standards

146.  The Department acknowledges that insignificant emissions units (IEUs) identified by rule as either categorically insignificant activities or aggregate insignificant emissions [OAR 340-200-0020] exist at facilities required to obtain an Oregon Title V Operating Permit. IEUs must comply with all applicable requirements. In general, the requirements that could apply to IEUs are incorporated as follows:

146.a.  OAR 340-208-0110 (20% opacity)

146.b.  OAR 340-228-0210 (0.1 gr/dscf corrected to 12% CO₂ or 50% excess air for fuel burning equipment)

146.c.  OAR 340-226-0210 (0.1 gr/dscf for non-fugitive, non-fuel burning equipment)

146.d.  OAR 340-226-0310 (process weight limit for non-fugitive, non-fuel burning process equipment)

147.  Testing, Monitoring, and Recordkeeping Requirements: Unless otherwise specified in this permit or an applicable requirement, the Department is not requiring any testing, monitoring, recordkeeping, or reporting for the applicable emissions limits and standards that apply to IEUs. However, if testing were performed for compliance purposes, the permittee would be required to use the test methods identified in the definitions of “opacity” and “particulate matter” in OAR 340-208-0010 and perform the testing in accordance with the Department’s Source Sampling Manual.

PLANT SITE EMISSION LIMITS

150.a.  The permittee may only use Unassigned Emissions after any necessary construction (OAR 340-218-0190) and permit revision applications (OAR 340-218-0120 through 340-218-0180) have been approved by the Department.

150.c.  In accordance with OAR 340-222-0045(5), the unassigned emissions for PM and PM₁₀ must be established again and reduced upon the following permit renewal to no more than significant emission rate for each pollutant.

150.e.  Emission reduction credits are available for external offsets until May 14, 2017 in accordance with OAR 340-268-0030. Emission reduction credits may be used for internal use only after any necessary construction (OAR 340-218-0190) and permit revision applications (OAR 340-218-0120 through 340-218-0180) have been approved by the Department. If the credits are not used for external offsets or for internal use by May 14, 2017, the credits will revert to being unassigned emissions in accordance with OAR 340-268-0030(4)(b). At the next renewal unassigned emissions will be reduced such that they do not exceed the significant emission rate consistent with the requirements of OAR 340-222-0045(5). NOTE: These credits are the result of the permanent removal the #2 Combustion Turbine Generator from service on May 14, 2007. (Stack Parameters: Height = 150 feet, Diameter = 11.5 feet, Stack Gas Flow Rate = 345,000 acfm, Stack Gas Temperature = 309ºF)

PSEL MONITORING

The permittee must determine compliance with the Plant Site Emission Limits established in Condition 94 of this permit by conducting monitoring in accordance with following procedures, test methods, and frequencies: [OAR 340-222-0080]

Process Parameters

The permittee must maintain records of the following process parameters:

Table 13.  Process Parameters

Emission Calculations

Emission calculations must be performed each month for the preceding 12 consecutive calendar months using Equation 1 to demonstrate compliance with the plant site emissions limits established in Condition 94.

E = [S(P_eu x EF_eu)/2000] + E_MA + AI EQUATION 1

Where:

E = pollutant emissions (tons/year)

P_eu = process parameters identified in Condition 96.a.

EF_eu = emission factor identified for each emissions unit and pollutant in Condition 96.c.

E_MA = VOC emissions emitted by emissions unit MA-EU as calculated in Condition 96.d.

AI = Aggregate Insignificant Emissions = 1 ton for PM, PM₁₀, and VOC

158.a.  Emissions calculations and comparisons to the PSEL for each 12-month period must be performed by the last day of the following month.

158.c.  Compliance with the PSEL must be determined using the calculations contained in Condition 96.b using the monitored parameters recorded during the reporting period and the emission factors contained in Condition 96.c, unless the permittee elects to pay emission fees based on actual emissions using a verified emission factor determined in accordance with OAR 340-220-0170. If the permittee is paying on actual emissions based on a verified emission factor, the verified emission factor must be used for determining compliance with the PSEL in accordance with Condition 99.

158.e.  The first 12 consecutive month period for PSEL compliance monitoring begins on the first day of the month in which the permit is issued.

Emission Factors

The emission factors for calculating pollutant emissions are as follows:

Table 14.  Emission Factors

The SO₂ emission factor for emissions unit B10-EU when burning distillate or used oil shall be determined using the following equation:

EF_SO2 = 142 x S

Where,

EF_SO2 = emission factor for calculating emissions of sulfur dioxide emissions from
emissions unit B10-EU when burning oil (lb/Mgal)

S = sulfur content of oil [e.g., 0.05% sulfur content = 0.05]

The emission factors listed in Condition 96.c are not enforceable limits unless otherwise specified in this permit.

VOC Emission Calculations for MA-EU

The VOC emissions from emissions unit MA-EU are determined using Equation 2.

E_MA = [å (M_x x D_x x C_x) / 2000] – [110.3 x (P/487,000)] EQUATION 2

Where,

E_MA  =  Total VOC emissions for emissions unit MA-EU (tons/year)

M  =  Material usage for the period in gallons

D  =  Material density in pounds per gallon

C  =  VOC content expressed as a decimal

X  =  Subscript X represents a specific material

P  =  Actual production level (MDT paper) for a given annual period.

110.3  =  A constant to account for the VOC emissions (tons/year) that are already accounted for in other emissions units VOC emission calculations. (e.g., the emission factor for calculating VOC emissions from emissions unit PM5-EU includes the chemicals used in that process at the time the testing was conducted to establish the factor.)

487,000  =  The production level (MDT paper/year) at which the 110.3 tons of VOC emissions were established.

The permittee must maintain records of the monthly emission calculations and comparisons to the PSEL performed for each 12-month period.

GENERAL TESTING REQUIREMENTS

Unless otherwise specified in this permit, the permittee must conduct all testing in accordance with the Department’s Source Sampling Manual. [OAR 340-212-0120

159.f.  Unless otherwise specified by a state or federal regulation, the permittee must submit a source test plan to the Department at least 30 days prior to the date of the test. The test plan must be prepared in accordance with the Source Sampling Manual and address any planned variations or alternatives to prescribed test methods. The permittee should be aware that if significant variations are requested, it may require more than 30 days for the Department to grant approval and may require EPA approval in addition to approval by the Department.

159.h.  Only regular operating staff may adjust the processes or emission control device parameters during a compliance source test and within two (2) hours prior to the tests. Any operating adjustments made during a compliance source test, which are a result of consultation during the tests with source testing personnel, equipment vendors, or consultants, may render the source test invalid.

159.j.  Unless otherwise specified by permit condition or Department approved source test plan, all compliance source tests must be performed as follows:

159.j.i.  at least 90% of the design capacity for new or modified equipment;

159.j.iii.  at least 90% of the maximum operating rate for existing equipment; or

159.j.v.  at 90 to 110% of the normal maximum operating rate for existing equipment. For purposes of this permit, the normal maximum operating rate is defined as the 90th percentile of the average hourly operating rates during a 12 month period immediately preceding the source test. Data supporting the normal maximum operating rate must be included with the source test report.

159.k.  Each source test must consist of at least three (3) test runs and the emissions results must be reported as the arithmetic average of all valid test runs. If for reasons beyond the control of the permittee a test run is invalid, the Department may accept two (2) test runs for demonstrating compliance with the emission limit or standard.

159.m.  Source test reports prepared in accordance with the Department’s Source Sampling Manual must be submitted to the Department within 60 days of completing any required source test, unless a different time period is approved in the source test plan submitted prior to the source test.

159.o.  “Modified EPA Method 9” means the minimum visible emission observation period must be six minutes, though longer periods may be required by a specific rule or permit condition. During the test period, if any one reading is equal to or equal to or greater than the visible emissions limit for the emissions unit, then the observation period must be a minimum of 60 minutes or until a violation of the emissions standard has been documented; whichever is a shorter period. Aggregate times (e.g., 3 minutes in any one hour) consist of the total duration of all readings during the observation period that are equal to or exceed the opacity percentage in the standard, whether or not the readings are consecutive. Each EPA Method 9 reading represents 15 seconds of time. [See the definition of “Opacity” in OAR 340-208-0010]

GENERAL MONITORING REQUIREMENTS

160.a.  The permittee must not knowingly render inaccurate any required monitoring device or method.
[OAR 340-218-0050(3)(a)(E)]

160.c.  Methods used to determine actual emissions for fee purposes must also be used for compliance determination and can be no less rigorous than the requirements of OAR 340-218-0080.
[OAR 340-218-0050(3)(a)(F)]

160.d.  Monitoring requirements must commence on the date of permit issuance unless otherwise specified in the permit or an applicable requirement. [OAR 340-218-0050(3)(a)(G)]

160.g.  Monitoring is not required for facility wide or specific emissions units that are not in operation during the applicable period. [OAR 340-218-0050(3)(a)(A)]

GENERAL RECORDKEEPING REQUIREMENTS

161.a.  The permittee must maintain the following general records of testing and monitoring required by this permit: [OAR 340-218-0050(3)(b)(A)]

161.a.i.  the date, place as defined in the permit, and time of sampling or measurements;

161.a.ii.  the date(s) analyses were performed;

161.a.iii.  the company or entity that performed the analyses;

161.a.iv.  the analytical techniques or methods used;

161.a.v.  the results of such analyses;

161.a.vi.  the operating conditions as existing at the time of sampling or measurement; and

161.a.vii.  the records of quality assurance for continuous monitoring systems (including but not limited to quality control activities, audits, calibration drift checks).

161.b.  Unless otherwise specified by permit condition, the permittee must make every effort to maintain 100 percent of the records required by the permit. If information is not obtained or recorded for legitimate reasons (e.g., the monitor or data acquisition system malfunctions due to a power outage), the missing record(s) shall not be considered a permit deviation provided the amount of data lost does not exceed 10% of the averaging periods in a reporting period or 10% of the total operating hours in a reporting period, if no averaging time is specified. For continuous emission and parameter monitors, missing data shall not be considered a permit deviation, provided data lost does not exceed 10% of the total time on an annual basis. Upon discovering that a required record is missing, the permittee shall document the reason for the missing record. In addition, any missing record that can be recovered from other available information shall not be considered a missing record. [OAR 340-214-0110, 340-212-0160, and 340-218-0050(3)(b)]

161.d.  Recordkeeping requirements shall commence on the date of permit issuance unless otherwise specified in the permit or an applicable requirement. [OAR 340-218-0050(3)(b)(C)]

161.e.  Unless otherwise specified, the permittee must retain records of all required monitoring data and support information for a period of at least five (5) years from the date of the monitoring sample, measurement, report, or application. Support information includes all calibration and maintenance records and all original strip-chart recordings for continuous monitoring instrumentation, and copies of all reports required by the permit. All existing records required by the previous Air Contaminant Discharge Permit shall also be retained for five (5) years. [OAR 340-218-0050(b)(B)]

161.g.  Recordkeeping is not required for facility wide or specific emissions units that are not in operation during the applicable period. [OAR 340-218-0050(3)(b)(A)]

REPORTING REQUIREMENTS

162.  The permittee must submit three (3) copies of the reports required below except as noted (such as Conditions 113.e and 114), completed on forms approved by the Department. One copy of the report shall be submitted to the EPA and two copies to the regional office. All instances of deviations from permit requirements shall be clearly identified in such reports: [OAR 340-218-0050(3)(c)(A) and 340-218-0080(6)(d)]

NSPS Semi-Annual Reports

163.a.  The permittee must submit an excess emission and monitoring systems performance report or a summary report semiannually for the emissions unit CG1-EU. [40 CFR 60.7(c) and 60.7(d)]

163.a.i.  All excess emissions and monitoring systems performance reports must be postmarked by August 15^th for the January 1 through June 30 reporting period and by March 15^th for the July 1 through December 31 reporting period. [40 CFR 63.19(d)]

163.a.ii.  The excess emissions report must include the information required by 40 CFR 60.7(c), unless the total duration of the excess emissions for the reporting period is less than 1 percent of the total operating time for the reporting period and CMS downtime for the reporting period is less than 5% of the total operating time for the reporting period, then no excess emissions report is required unless otherwise required by this permit.

163.a.iii.  The CMS summary report must contain the information and be in the format shown in figure 1 of 40 CFR 60.7, unless otherwise approved in writing by the Department.

163.a.v.  Semi-Annual Compliance Certifications

163.b.  The Semi-Annual Compliance Certification Report (Form R1002 and if applicable R1003) for the period January 1 through June 30 must be submitted by August 15, unless otherwise approved in writing by the Department. [OAR 340- 218-0050(3)(c)]

163.c.  The Semi-Annual Compliance Certification Report (Form R1002 and if applicable R1003) for the period July 1 through December 31 must be submitted by March 15, unless otherwise approved in writing by the Department. [OAR 340- 218-0050(3)(c)]

163.d.  The semi-annual compliance certification must include the following (provided that the identification of applicable information may cross-reference the permit or previous reports, as applicable): [OAR 340-218-0080(6)(c)]

163.d.i.  The identification of each term or condition of the permit that is the basis of the certification;

163.d.iii.  The identification of the method(s) or other means used by the owner or operator for determining the compliance status with each term and condition during the certification period, and whether such methods or other means provide continuous or intermittent data. Such methods and other means must include, at a minimum, the methods and means required under OAR 340-218-0050(3). If necessary, the owner or operator also shall identify any other material information that must be included in the certification to comply with section 113(c)(2) of the FCAA, which prohibits knowingly making a false certification or omitting material information;

163.d.iv.  The status of compliance with terms and conditions of the permit for the period covered by the certification, based on the method or means designated in OAR 340-218-0040(6)(c)(B). The certification shall identify each deviation and take it into account in the compliance certification. The certification must also identify as possible exceptions to compliance any periods during which compliance is required and in which an excursion or exceedance, as defined under OAR 340-200-0020, occurred; and

163.d.vi.  Such other facts as the Department may require to determine the compliance status of the source.

163.e.  Notwithstanding any other provision contained in any applicable requirement, the owner or operator may use monitoring as required under OAR 340-218-0050(3) and incorporated into the permit, in addition to any specified compliance methods, for the purpose of submitting compliance certifications. [OAR 340-218-0080(6)(e)]

Annual Reports

163.f.  Annual reports shall be submitted by March 15, unless otherwise approved by the Department in writing, and shall consist of the following:

163.f.i.  The Annual Report (Form R1001).

163.f.ii.  The Emission Fee Reports (Forms F1101 through F1106 as applicable). [OAR 340-220-0100]

163.f.iv.  A summary listing of excess emissions events consisting of the date, time, and the affected emissions unit for each excess emission that occurred during the prior calendar year.

163.f.vi.  A listing of projects completed, deleted, or changed in the Fugitive Emissions Reduction Plan in the past calendar year.

163.f.viii.  Other Reporting Requirements

164.  Excess Emissions Reporting: [OAR 340-214-0300 through 340-214-0360]

165.  The permittee must report all excess emissions in accordance with OAR 340-214-0300 through 340-214-0360. In summary, the permittee must immediately (i.e., as soon as possible but in no case more than one hour after a source knew or should have known of an excess emission period) notify the Department by telephone or in person of any excess emission, other than pre-approved startup, shutdown, or scheduled maintenance. Notification must, to the extent reasonably ascertainable at the time of notification, include the source name, nature of the emissions problem, name of the person making the report, name and telephone number of the contact person for further information, date and time of the onset of the upset condition, whether or not the incident was planned, the cause of the excess emission (e.g., startup, shutdown, maintenance, breakdown, or other), equipment involved in the upset, estimated type and quantity of excess emissions, estimated time of return to normal operations, efforts made to minimize emissions, and a description of remedial actions to be taken. Follow-up reporting must be made in accordance with Condition 113.e.

167.a.  In the event of any excess emissions which are of a nature that could endanger public health and occur during non-business hours, weekends, or holidays, the permittee must immediately notify the Department by calling the Oregon Emergency Response System (OERS). The current number is 1-800-452-0311.

167.b.  If startups, shutdowns, or scheduled maintenance may result in excess emissions, the permittee must submit startup, shutdown, or scheduled maintenance procedures used to minimize excess emissions to the Department for prior authorization, as required in OAR 340-214-0310 and 340-214-0320. New or modified procedures must be received by the Department in writing at least 72 hours prior to the first occurrence of the excess emission event. The permittee must abide by the approved procedures and have a copy available at all times.

167.c.  The permittee must notify the Department of planned startup/shutdown or scheduled maintenance events only if required by permit condition or if the source is located in a nonattainment area for a pollutant which may be emitted in excess of applicable standards.

167.d.  In accordance with OAR 340-214-0340 for any excess emissions event, the permittee must submit to the Department a written report of excess emissions for each calendar day of the event. The report must be submitted within 15 days of the date of the event (unless based on the severity of the event, the Department specifies a shorter time period for submittal for the report) and include the following:

167.d.i.  The date and time of the beginning of the excess emissions event and the duration or best estimate of the time until return to normal operations;

167.d.ii.  The date and time the owner or operator notified the Department of the event;

167.d.iii.  The equipment involved;

167.d.iv.  Whether the event occurred during a period of planned startup, planned shutdown, scheduled maintenance, or as a result of a breakdown, malfunction, or emergency;

167.d.v.  Steps taken to mitigate emissions and corrective actions taken, including whether the approved procedures for a planned startup, shutdown, or maintenance activity were followed;

167.d.vi.  The magnitude and duration of each occurrence of excess emissions during the course of an event and the increase over normal rates or concentrations as determined by continuous monitoring or a best estimate (supported by operating data and calculations);

167.d.vii.  The final resolution of the cause of the excess emissions; and

167.d.viii.  Where applicable, evidence supporting any claim that emissions in excess of technology-base limits were due to an emergency pursuant to OAR 340-214-0360.

167.e.  Recordkeeping: The permittee must keep an excess emissions log of all planned and unplanned excess emissions. The log must include all pertinent information as required by Condition 113.e and be kept by the permittee for five calendar years.

167.g.  168.  Permit Deviation Reporting:  The permittee must promptly report deviations from permit requirements that do not cause excess emissions, including those attributable to upset conditions, as defined in the permit, the probable cause of such deviations, and any corrective actions or preventive measures taken. “Prompt” means within 15 days of the deviation. Deviations that cause excess emissions, as specified in OAR 340-214-0300 through 340-214-0360 shall be reported in accordance with OAR 340-214-0340.
[OAR 340-218-0050(3)(c)(B)]

169.  All required reports must be certified by a responsible official consistent with OAR 340-218-0040(5);
[OAR 340-218-0050(3)(c)(D)]

170.  Reporting requirements must commence on the date of permit issuance unless otherwise specified in the permit. [OAR 340-218-0050(3)(c)(E)]

171.  Addresses of regulatory agencies are the following, unless otherwise instructed:

NON-APPLICABLE REQUIREMENTS

172.  State and Federal air quality requirements (e.g., rules and regulations) currently determined not applicable to the permittee are listed below along with the reason for the non-applicability: [OAR 340-218-0110]

Reason code definitions:

a  this pollutant is not emitted by the facility

b  the facility is not in this source category

c  the facility is not in a special control/nonattainment area

d  the facility is not in this county

e  the facility does not have this emissions unit

f  the facility does not use this fuel type

g  the rule does not apply because no changes have been made at the facility that would trigger these procedural requirements

h  this method/procedure is not used by the facility

i  this rule applies only to DEQ and regional authorities

j.  there are no emissions units with add-on control devices or the pre-controlled potential emissions are is less than 100 tons per year or the emissions units with add-on control devices and pre-controlled emissions greater than 100 tons per year are subject to emissions standards promulgated after November of 1990

GENERAL CONDITIONS

G29.  General Provision

Terms not otherwise defined in this permit have the meaning assigned to such terms in the referenced regulation.

G30.  Reference materials

Where referenced in this permit, the versions of the following materials are effective as of the dates noted unless otherwise specified in this permit:

a.  Source Sampling Manual; January 23, 1992 - State Implementation Plan Volume 3, Appendix A4;

b.  Continuous Monitoring Manual; January 23, 1992 - State Implementation Plan Volume 3, Appendix A6; and

c.  All state and federal regulations as in effect on the date of issuance of this permit.

G31.  Compliance [OAR 340-218-0040(3)(n)(C), 340-218-0050(6), and 340-218-0080(4)]

a.  The permittee must comply with all conditions of this permit. Any permit condition noncompliance constitutes a violation of the Federal Clean Air Act and/or state rules and is grounds for enforcement action; for permit termination, revocation and re-issuance, or modification; or for denial of a permit renewal application. Any noncompliance with a permit condition specifically designated as enforceable only by the state constitutes a violation of state rules only and is grounds for enforcement action; for permit termination, revocation and re-issuance, or modification; or for denial of a permit renewal application.

b.  Any schedule of compliance for applicable requirements with which the source is not in compliance at the time of permit issuance is supplemental to, and does not sanction noncompliance with the applicable requirements on which it is based.

c.  For applicable requirements that will become effective during the permit term, the source must meet such requirements on a timely basis unless a more detailed schedule is expressly required by the applicable requirement.

G32.  Masking Emissions:

The permittee must not install or use any device or other means designed to mask the emission 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. [OAR 340-208-0400] This condition is enforceable only by the State.

G33.  Credible Evidence:

Notwithstanding any other provisions contained in any applicable requirement, any credible evidence may be used for the purpose of establishing whether a person has violated or is in violation of any such applicable requirements. [OAR 340-214-0120]

G34.  Certification [OAR 340-214-0110, 340-218-0040(5), 340-218-0050(3)(c)(D), and 340-218-0080(2)]

Any document submitted to the Department or EPA pursuant to this permit must contain certification by a responsible official of truth, accuracy and completeness. All certifications must state that based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and, complete. The permittee must promptly, upon discovery, report to the Department a material error or omission in these records, reports, plans, or other documents.

G35.  Open Burning [OAR Chapter 340, Division 264]

The permittee is prohibited from conducting open burning, except as may be allowed by OAR 340-264-0020 through 340-264-0200.

G36.  Asbestos [40 CFR Part 61, Subpart M (federally enforceable), OAR Chapter 340-248-0005 through 340-248-0180 (state-only enforceable) and 340-248-0205 through 340-248-0280]

The permittee must comply with OAR Chapter 340, Division 248, and 40 CFR Part 61, Subpart M when conducting any renovation or demolition activities at the facility.

G37.  Stratospheric Ozone and Climate Protection [40 CFR 82 Subpart F, OAR 340-260-0040]

The permittee must comply with the standards for recycling and emissions reduction pursuant to 40 CFR Part 82, Subpart F, Recycling and Emissions Reduction.

G38.  Permit Shield [OAR 340-218-0110]

a.  Compliance with the conditions of the permit is deemed compliance with any applicable requirements as of the date of permit issuance provided that:

i.  such applicable requirements are included and are specifically identified in the permit, or

ii.  the Department, in acting on the permit application or revision, determines in writing that other requirements specifically identified are not applicable to the source, and the permit includes the determination or a concise summary thereof.

b.  Nothing in this rule or in any federal operating permit alters or affects the following:

i.  the provisions of ORS 468.115 (enforcement in cases of emergency) and ORS 468.035 (function of department);

ii.  the liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance;

iii.  the applicable requirements of the national acid rain program, consistent with section 408(a) of the FCAA; or

iv.  the ability of the Department to obtain information from a source pursuant to ORS 468.095 (investigatory authority, entry on premises, status of records).

c.  Sources are not shielded from applicable requirements that are enacted during the permit term, unless such applicable requirements are incorporated into the permit by administrative amendment, as provided in OAR 340-218-0150(1)(h), significant permit modification, or reopening for cause by the Department.

G39.  Inspection and Entry [OAR 340-218-0080(3)]

Upon presentation of credentials and other documents as may be required by law, the permittee must allow the Department of Environmental Quality, or an authorized representative (including an authorized contractor acting as a representative of the EPA Administrator), to perform the following:

a.  enter upon the permittee's premises where an Oregon Title V Operating Permit program source is located or emissions-related activity is conducted, or where records must be kept under the conditions of the permit;

b.  have access to and copy, at reasonable times, any records that must be kept under conditions of the permit;

c.  inspect, at reasonable times, any facilities, equipment (including monitoring and air pollution control equipment), practices, or operations regulated or required under the permit; and

d.  as authorized by the FCAA or state rules, sample or monitor, at reasonable times, substances or parameters, for the purposes of assuring compliance with the permit or applicable requirements.

G40.  Fee Payment [OAR 340-220-0010, and 340-220-0030 through 340-220-0190]

The permittee must pay an annual base fee and an annual emission fee for all regulated air pollutants. For purposes of Title V fees, “regulated pollutant” means particulates, VOC, NO_X, and SO₂. The permittee must submit payment to the Department of Environmental Quality, Business Office, 811 SW 6th Avenue, Portland, OR 97204, within 30 days of the date the Department mails the fee invoice or August 1 of the year following the calendar year for which emission fees are paid, whichever is later. Disputes must be submitted in writing to the Department of Environmental Quality. Payment must be made regardless of the dispute. User-based fees will be charged for specific activities (e.g., computer modeling review, ambient monitoring review, etc.) requested by the permittee.

G41.  Off-Permit Changes to the Source [OAR 340-218-0140(2)]

a.  The permittee must monitor for, and record, any off-permit change to the source that:

i.  is not addressed or prohibited by the permit;

ii.  is not a Title I modification;

iii.  is not subject to any requirements under Title IV of the FCAA;

iv.  meets all applicable requirements;

v.  does not violate any existing permit term or condition; and

vi.  may result in emissions of regulated air pollutants subject to an applicable requirement but not otherwise regulated under this permit or may result in insignificant changes as defined in OAR 340-200-0020.

b.  A contemporaneous notification, if required under OAR 340-218-0140(2)(b), must be submitted to the Department and the EPA.

c.  The permittee must keep a record describing off-permit changes made at the facility that result in emissions of a regulated air pollutant subject to an applicable requirement, but not otherwise regulated under the permit, and the emissions resulting from those off-permit changes.

d.  The permit shield of condition G9 does not extend to off-permit changes.

G42.  Section 502(b)(10) Changes to the Source [OAR 340-218-0140(3)]

a.  The permittee must monitor for, and record, any section 502(b)(10) change to the source, which is defined as a change that would contravene an express permit term but would not:

i.  violate an applicable requirement;

ii.  contravene a federally enforceable permit term or condition that is a monitoring, recordkeeping, reporting, or compliance certification requirement; or

iii.  be a Title I modification.

b.  A minimum 7-day advance notification must be submitted to the Department and the EPA in accordance with OAR 340-218-0140(3)(b).

c.  The permit shield of condition G9 does not extend to section 502(b)(10) changes.

G43.  Administrative Amendment [OAR 340-218-0150]

Administrative amendments to this permit must be requested and granted in accordance with OAR 340-218-0150. The permittee must promptly submit an application for the following types of administrative amendments upon becoming aware of the need for one, but no later than 60 days of such event:

a.  legal change of the registered name of the company with the Corporations Division of the State of Oregon, or

b.  sale or exchange of the activity or facility.

G44.  Minor Permit Modification [OAR 340-218-0170]

The permittee must submit an application for a minor permit modification in accordance with OAR 340-218-0170.

G45.  Significant Permit Modification [OAR 340-218-0180]

The permittee must submit an application for a significant permit modification in accordance with OAR 340-218-0180

G46.  Staying Permit Conditions [OAR 340-218-0050(6)(c)]

Notwithstanding conditions G16 and G17, the filing of a request by the permittee for a permit modification, revocation and re-issuance, or termination, or of a notification of planned changes or anticipated noncompliance does not stay any permit condition.

G47.  Construction/Operation Modification [OAR 340-218-0190]

The permittee must obtain approval from the Department prior to construction or modification of any stationary source or air pollution control equipment in accordance with OAR 340-210-0200 through OAR 340-210-0250.

G48.  New Source Review Modification [OAR 340-224-0010]

The permittee may not begin construction of a major source or a major modification of any stationary source without having received an air contaminant discharge permit (ACDP) from the Department and having satisfied the requirements of OAR 340, Division 224.

G49.  Need to Halt or Reduce Activity Not a Defense [OAR 340-218-0050(6)(b)]

The need to halt or reduce activity will not be a defense. It will not be a defense for a permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit.

G50.  Duty to Provide Information [OAR 340-218-0050(6)(e) and OAR 340-214-0110]

The permittee must furnish to the Department, within a reasonable time, any information that the Department may request in writing to determine whether cause exists for modifying, revoking and reissuing, or terminating the permit, or to determine compliance with the permit. Upon request, the permittee must also furnish to the Department copies of records required to be retained by the permit or, for information claimed to be confidential, the permittee may furnish such records to the Department along with a claim of confidentiality.

G51.  Reopening for Cause [OAR 340-218-0050(6)(c) and 340-218-0200]

a.  The permit may be modified, revoked, reopened and reissued, or terminated for cause as determined by the Department.

b.  A permit must be reopened and revised under any of the circumstances listed in OAR 340-218-0200(1)(a).

c.  Proceedings to reopen and reissue a permit must follow the same procedures as apply to initial permit issuance and affect only those parts of the permit for which cause to reopen exists.

G52.  Severability Clause [OAR 340-218-0050(5)]

Upon any administrative or judicial challenge, all the emission limits, specific and general conditions, monitoring, recordkeeping, and reporting requirements of this permit, except those being challenged, remain valid and must be complied with.

G53.  Permit Renewal and Expiration [OAR 340-218-0040(1)(a)(D) and 340-218-0130]

a.  This permit expires at the end of its term, unless a timely and complete renewal application is submitted as described below. Permit expiration terminates the permittee's right to operate.

b.  Applications for renewal must be submitted at least 12 months before the expiration of this permit, unless the Department requests an earlier submittal. If more than 12 months is required to process a permit renewal application, the Department must provide no less than six (6) months for the owner or operator to prepare an application.

c.  Provided the permittee submits a timely and complete renewal application, this permit will remain in effect until final action has been taken on the renewal application to issue or deny the permit.

G54.  Permit Transference [OAR 340-218-0150(1)(d)]

The permit is not transferable to any person except as provided in OAR 340-218-0150(1)(d).

G55.  Property Rights [OAR 340-200-0020 and 340-218-0050(6)(d)]

The 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, except as provided in OAR 340-218-0110.

G56.  Permit Availability [OAR 340-200-0020 and 340-218-0120(2)]

The permittee must have available at the facility at all times a copy of the Oregon Title V Operating Permit and must provide a copy of the permit to the Department or an authorized representative upon request.

ALL INQUIRIES SHOULD BE DIRECTED TO:

DEQ-Western Region

750 Front St. NE, Suite 120

Salem, OR 97301-1039

(503) 378-8240

SP Newsprint Permit 2008

Cross-reference from New Rule Numbers to Old Rule Numbers (Effective March 24, 2003)