### STATE OF NEW HAMPSHIRE Department of Environmental Services Air Resources Division 

# Title V Operating Permit

Permit No: TV-OP-054 Date Issued: March 9, 2007; Administrative Amendment issued on D ecember 17, 2007; Minor Modification issued on January 29, 2010 This certifies that: Northeast Utilities Public Service of New Hampshire 780 North Commercial Street Manchester, NH 03101

has been granted a Title V Operating Permit for the following facility and location: Public Service of New Hampshire Newington Station 165 Gosling Road Newington, NH AFS Point Source Number – 3301500054

This Title V Operating Permit is hereby issued unde r the terms and conditions specified in the Title V Operating Permit Application filed with the New Hampshire Department of Environmental Services on July 1, 1996 under the signature of the following responsible official certifying to th e best of their knowledge that the statements and i nformation therein are true, accurate and complete.



### Responsible Official: Designated Representative: John MacDonald John MacDonald (603) 634-2236 (603) 634-2236 Alternate Designated Representative: Technical Contact: William Smagula (603) 634-28 51 Laurel Brown Authorized Account Representative: (603) 634-2331 John MacDonald (603) 634-2236 Alternate Authorized Account Representative: William Smagula (603) 634-2851 This Permit is issued by the New Hampshire Departme nt of Environmental Services, Air Resources Divisio n pursuant to its authority under New Hampshire RSA 1 25-C and in accordance with the provisions of the Code of Federal Regulations, Title 40, Part 70. This Title V Operating Permit shall expire on March 31, 2012.

SEE ATTACHED SHEETS FOR ADDITIONAL PERMIT CONDITION S

For the New Hampshire Department of Environmental S ervices, Air Resources Division

____________________________

Director, Air Resources Division

### PSNH Newington Page 2 TV-OP-054



## TABLE OF CONTENTS

ABBREVIATIONS......................................

................................................... ................................................... ... 4

FACILITY SPECIFIC TITLE V OPERATING PERMIT CONDITIO NS ................................................. .. 6

I. F ACILITY 

### D ESCRIPTION OF 

### O PERATIONS



### ................................................... ................................................... .. 6 II. P ERMITTED 

### A CTIVITIES



### ................................................... ................................................... ..................... 6 III. S IGNIFICANT 

### A CTIVITIES 

### I DENTIFICATION AND 

### S TACK 

### C RITERIA



### ................................................... ......... 6 A. Significant Activity Identification................

................................................... ........................................ 6 B. Stack Criteria .....................................

................................................... ................................................. 7 IV. I NSIGNIFICANT 

### A CTIVITIES 

### I DENTIFICATION



### ................................................... ......................................... 8 V. E XEMPT 

### A CTIVITIES 

### I DENTIFICATION



### ................................................... ................................................... 8 VI. P OLLUTION 

### C ONTROL 

### E QUIPMENT 

### /M ETHOD 

### I DENTIFICATION



### ................................................... .............. 8 VII. A LTERNATIVE 

### O PERATING 

### S CENARIOS



### ................................................... ................................................. 9 A. Trial Test Burns with Other Fuels ..................

................................................... .................................... 9 B. Fuel Blending Requirements (State Enforceable Only)

................................................... .................... 10 C. Fly Ash Reinjection ................................

................................................... ........................................... 11 D. NOx Emission Reduction Management Practices........

................................................... ..................... 11 E. Auxiliary Fuel – Toner .............................

................................................... ......................................... 12 VIII. A PPLICABLE 

### R EQUIREMENTS



### ................................................... ................................................... ........... 13 A. State-only Enforceable Operational and Emission Lim itations........................................... ................ 13 B. Federally Enforceable Operational and Emission Limi tations ............................................ ............... 13 C. Annual SO 2 

### Allowance Programs (40 CFR 72, 40 CFR 73, Env-A 61 1.08, and Env-A 2900)............ 20 D. Ozone Season NOx Budget Trading Program (Env-A 3200 ).................................................. ............. 21 E. Annual and Non-Ozone Season NOx Allowance Program ( Env-2900 and NOx RACT Order No. ARD98-001) ............................................

................................................... ................................................... ......... 24 F. Multiple Pollutant Annual Budget Trading and Bankin g Program (Env-A 2900) [State Enforceable Only] 24 G. Discrete Emission Reduction Trading Program (Env-A 3100).............................................. .............. 27 H. Monitoring/Testing Requirements....................

................................................... ................................. 28 I. Recordkeeping Requirements.........................

................................................... ................................... 44 J. Reporting Requirements.............................

................................................... ....................................... 50 IX. R EQUIREMENTS 

### C URRENTLY 

### N OT 

### A PPLICABLE



### ................................................... .................................. 57

GENERAL TITLE V OPERATING PERMIT CONDITIONS........

................................................... .......... 58

X. I SSUANCE OF A 

### T ITLE 

### V O PERATING 

### P ERMIT



### ................................................... ...................................... 58 XI. T ITLE 

### V O PERATING 

### P ERMIT 

### R ENEWAL 

### P ROCEDURES



### ................................................... ........................ 58 XII. A PPLICATION 

### S HIELD



### ................................................... ................................................... ...................... 58 XIII. P ERMIT 

### S HIELD



### ................................................... ................................................... ............................... 58 XIV. R EOPENING FOR 

### C AUSE



### ................................................... ................................................... ................... 59 XV. A DMINISTRATIVE 

### P ERMIT 

### A MENDMENTS



### ................................................... ........................................... 60 XVI. O PERATIONAL 

### F LEXIBILITY



### ................................................... ................................................... ............. 60 XVII. M INOR 

### P ERMIT 

### A MENDMENTS



### ................................................... ................................................... ........ 62 XVIII. S IGNIFICANT 

### P ERMIT 

### A MENDMENTS



### ................................................... ............................................... 62 XIX. T ITLE 

### V O PERATING 

### P ERMIT 

### S USPENSION 

### , R EVOCATION OR 

### N ULLIFICATION 

### ....................................... 63 XX. I NSPECTION AND 

### E NTRY



### ................................................... ................................................... .................. 63 XXI. C ERTIFICATIONS



### ................................................... ................................................... .............................. 63 K. Compliance Certification Report ....................

................................................... .................................. 63

### PSNH Newington Page 3 TV-OP-054

L. Certification of Accuracy Statement ................

................................................... ................................. 64 XXII. E NFORCEMENT



### ................................................... ................................................... ................................ 65 XXIII. E MISSION 

### -B ASED 

### F EE 

### R EQUIREMENTS



### ................................................... ............................................ 65 XXIV. D UTY 

### T O 

### P ROVIDE 

### I NFORMATION



### ................................................... ................................................... 66 XXV. P ROPERTY 

### R IGHTS



### ................................................... ................................................... ....................... 67 XXVI. S EVERABILITY 

### C LAUSE



### ................................................... ................................................... ................ 67 XXVII. E MERGENCY 

### C ONDITIONS



### ................................................... ................................................... ............ 67 XXVIII. P ERMIT 

### D EVIATION



### ................................................... ................................................... ................... 68

FEDERAL ACID RAIN REQUIREMENTS .....................

................................................... ........................... 69

XXIX. P HASE 

### II A CID 

### R AIN 

### P ERMIT 

### A PPLICATION



### ................................................... ..................................... 69 XXX. G ENERAL 

### A CID 

### R AIN 

### P ROVISIONS



### ................................................... .................................................. 6 9

### PSNH Newington Page 4 TV-OP-054



## ABBREVIATIONS AAL Ambient Air Limit AP-42 Compilation of Air Pollutant Emission Factors ARD Air Resources Division ASTM American Society for Testing and Materials ATS Allowance Tracking System BACT Best Available Control Technology BHP (or bhp) Brake Horse Power BTU British Thermal Units CAA Clean Air Act, 42 U.S.C. § 7401, et seq. CAM Compliance Assurance Monitoring CAS Chemical Abstracts Service CEMS Continuous Emission Monitoring System CFR Code of Federal Regulations CNG Compressed Natural Gas CO Carbon Monoxide CO 2 

### Carbon Dioxide COMS Continuous Opacity Monitoring System DER Discrete Emission Reduction Env-A New Hampshire Code of Administrative Rules – Air Resources Division Env-Wm New Hampshire Code of Administrative Rules – Waste Management Division ECS Emission Control System ERC Emission Reduction Credit ETS Emissions Tracking System FR Federal Register HAP Hazardous Air Pollutant HHV High Heat Value HCl Hydrochloric acid Hr Hour kGal 1,000 gallons kscfm 1,000 standard cubic feet per minute KVDC Kilovolt Direct Current KW Kilowatt LAER Lowest Achievable Emission Rate Lb/hr Pounds per hour LNB Low NO x 

### Burner LNG Liquid Natural Gas LPG Liquid Petroleum Gas (Propane) MACT Maximum Achievable Control Technology mg/L Milligrams per liter MMBTU (or MMBtu) Million British Thermal Units MMCF Million Cubic Feet MW Megawatt NAAQS National Ambient Air Quality Standard NATS NOx Allowance Tracking System NESHAPs National Emissions Standards for Hazardous Air Pollutants

### PSNH Newington Page 5 TV-OP-054



## ABBREVIATIONS (cont.)

NG Natural Gas NHDES (or DES) New Hampshire Department of Environm ental Services NMOC Nonmethane Organic Compound NO x 

### Oxides of Nitrogen NSPS New Source Performance Standard NSR New Source Review PCB Polychlorinated biphenyls PE Potential Emission PM Particulate Matter PM 10 

### Particulate Matter less than 10 microns diameter ppm part per million ppmv part per million by volume PSD Prevention of Significant Deterioration PSI Pounds per Square Inch PTE Potential to Emit PUC Public Utilities Commission RACT Reasonably Available Control Technology RTAP Regulated Toxic Air Pollutant SIP State Implementation Plan SO 2 

### Sulfur Dioxide T-12M Tons during any consecutive 12-month period TAP Toxic Air Pollutant TSP Total Suspended Particulate Matter TPY Tons per Year USEPA United States Environmental Protection Agency VOC Volatile Organic Compound

### PSNH Newington Page 6 TV-OP-054



## Facility Specific Title V Operating Permit Conditio ns

I. Facility Description of Operations

Newington Station (Newington) is a fossil fuel-fire d electric generating facility, owned and operated by Public Service of New Hampshire (PSNH), a subsid iary of Northeast Utilities. The facility is comprised of one utility boiler, two auxiliary boil ers, one emergency generator, two bulk oil storage tanks, and one bulk oil storage day tank. The faci lity operations also include various activities tha t are classified as insignificant or exempt activitie s.

The one utility boiler is capable of burning either natural gas or No. 6 fuel oil or crude oil; the auxiliary boilers burn No. 2 fuel oil; and the emer gency generator burns diesel.

The auxiliary boilers provide steam and building he at when the utility boiler is not operating. The utility boiler stack is equipped with a CEMS for NO x, SO 2 

### , and CO and a COMS. Newington emits NOx, SO 2 

### , CO, VOCs, PM, CO 2 

### , RTAPs, and HAPs. Newington has installed control equipment and implemented operational changes to reduce emiss ions, including electrostatic precipitators to control particulate matter, and burner modification s (also referred to as low NOx burners), overfire air, staged combustion, and water injection, to con trol NOx emissions.

Newington operates a fly ash reinjection system, as an alternative operating scenario, to capture unburned carbon and to reduce the amount of fly ash shipped off-site as solid waste.

II. Permitted Activities

In accordance with all of the applicable requiremen ts identified in this permit, the Permittee is authorized to operate the devices and or processes identified in Sections III, IV, V and VI within the terms and conditions specified in this Permit.

III. Significant Activities Identification and Stack Cri teria

A. Significant Activity Identification

The activities identified in the following table (T able 1) are subject to and regulated by this Title V Operating Permit:

Table 1 – Significant Activity Identification Emission Unit Number Description of

Emission Unit Maximum Gross Heat Input or Maximum Power Output Maximum Operating Conditions

NT1 Steam Generating Unit 1

(Combustion Engineering Model No. 8269) (Installed 1969) Tangential Firing Crude oil or No. 6 fuel oil at no more than 2.0% sulfur content by weight, No. 2 fuel oil at no more than 0.4% sulfur content by weight, or natural gas or combination thereof: 4,350 MMBtu/hr gross heat input (nameplate rating) 1 A) In accordance with New Source Review avoidance, the maximum operating rate shall not exceed 25,235,000 MMBtu total gross heat input during any consecutive 12-month period. This maximum

1 The heat input rating of 4,350 MMBtu/hr was calcul ated based upon the nameplate rating of NT1, fuel f low to the boiler, and Btu

### PSNH Newington Page 7 TV-OP-054

Table 1 – Significant Activity Identification Emission Unit Number Description of

Emission Unit Maximum Gross Heat Input or Maximum Power Output Maximum Operating Conditions

operating rate may be adjusted upon written approval from DES. B) Toner may be used as an auxiliary fuel in the boiler. The toner feed rate shall not exceed 24 tons/day. NTAB1 Auxiliary Boiler No. 1A

(Erie City Energy Division Model No. 15Mkeystone) (Installed 1969) No. 2 Fuel Oil with maximum sulfur content of 0.4% by weight: 99.4 MMBtu/hr A) Maximum fuel consumption rate of No. 2 fuel oil shall not exceed 3.57 million gallons during any consecutive 12-month period. 2 B) This fuel consumption limitation is to limit the NOx emissions to less than 50 tons during any consecutive 12-month period. NTAB2 Auxiliary Boiler No. 1B

(Erie City Energy Division, Model No. 15Mkeystone) (Installed 1969) No. 2 Fuel Oil with maximum sulfur content of 0.4% by weight: 99.4 MMBtu/hr A) Maximum fuel consumption rate of No. 2 fuel oil shall not exceed 3.57 million gallons during any consecutive 12-month period. 3 B) This fuel consumption limitation is to limit the NOx emissions to less than 50 tons during any consecutive 12-month period. NTEG1 Emergency Generator 1

Caterpillar Model # C9 Serial # - S9L01463 Installed December 2007 2.7 MMBtu/hr Diesel 4 - equivalent to 19.4 gal/hr Operating hours shall be limited to 500 hours during any consecutive 12-month period.



### B. Stack Criteria The following stacks for the above listed significa nt devices at this facility shall discharge vertically without obstruction (including rain caps ) and meet the following criteria:

analysis of the fuel. The CEMS calculates and reco rds the heat input on a minute-by-minute basis acco rding to the procedures in 40 CFR 75. The calculated heat input from the CEMS is based upon the volumetric flow of the stack gases, the CO 2 concentration, and a carbon-based F factor—a default factor provided in 40 CFR Part 75. The calculated heat input rate fro m the CEMS is not based on fuel flow, except when dual fuels are used.

2 The heating value of No. 2 fuel oil is assumed to be 140,000 BTU/gallon. The fuel consumption limits may vary based on the actual heat content of the fuel burned.

3 The heating value of No. 2 fuel oil is assumed to be 140,000 BTU/gallon. The fuel consumption limits may vary based on the actual heat content of the fuel burned.

4 The heating value of diesel is assumed to be 137,0 00 BTU/gallon. The fuel consumption limits may var y based on the actual heat content of the fuel burned.

### PSNH Newington Page 8 TV-OP-054

Table 2 – Stack Criteria Stack Number Emission

Unit Number Emission Unit

Description Minimum Stack

Height (Feet) Above Ground Level Maximum

Inside Stack Diameter (Feet) STNT1 NT1 Steam Generating Unit No. 1 410 20.75 STNTAB1 NTAB1 Auxiliary Boiler No. 1 211 3.5 STNTAB2 NTAB2 Auxiliary Boiler No. 2 211 3.5



### Changes to the state-only requirements pertaining t o stack parameters (set forth in this permit), shall be permitted only when an air quality impact analysis which meets the criteria of Env-A 606 is performed either by the facility or the New Hampshire Department of Environmental Services, Air Resources Division (if requested by f acility in writing) in accordance with the “DES-ARD Procedure for Air Quality Impact Modeling” and approved by DES. All air modeling data shall be kept on file at the facility for review by the DES upon request.

IV. Insignificant Activities Identification

All activities at this facility that meet the crite ria identified in Env-A 609.04(d), shall be conside red insignificant activities. Emissions from the insig nificant activities shall be included in the total facility emissions for the emission-based fee calcu lation described in Section XXIII. of this Permit.

V. Exempt Activities Identification

All activities identified in Env-A 609.03(c) shall be considered exempt activities and shall not be included in the total facility emissions for the em ission based fee calculation described in Section XXIII of this permit.

VI. Pollution Control Equipment/Method Identification

The devices and/or processes identified in Table 3 are considered pollution control equipment or techniques for each identified emissions unit:

Table 3 – Pollution Control Equipment Method Identi fication 5



### Pollution Control Equipment Number Description of Equipment/Method Emission Unit Number

NT1-PC1 Electrostatic Precipitator (ESP) NT1

5 Note that additional pollution control equipment/m ethod options are included in the alternative opera ting scenario section.

### PSNH Newington Page 9 TV-OP-054

VII. Alternative Operating Scenarios

While operating under an alternative operating scen ario, the Permittee shall comply with all applicable requirements specified in this permit, i ncluding, but not limited to, state and federal operational and emission limitations specified in S ection VIII.A.through G, monitoring and testing requirements specified in Section VIII. H., recordk eeping requirements specified in Section VIII. I, and reporting requirements specified in Section VII I. J. Pursuant to 40 CFR 70.6 (a)(9), the Permittee shall keep all applicable records pertain ing to the alternative operating scenario during such operation. The Permittee shall keep a record of the scenario under which it is operating.

A. Trial Test Burns with Other Fuels (Permit to Operat e No. PO-B-1030)

Prior to the use of any fuel other than fuels previ ously reviewed and approved by the DES, PSNH shall submit a proposal to the DES, which shall inc lude, but not be limited to the following:

1. Type of fuel;

2. Analysis data of the fuel proposed, which shall inc lude proximate and ultimate analysis, volatile and semi-volatile analyses (i.e., EPA Meth od 8240, 8260, 8250, or 8270) and metals analysis (i.e., Method 3050 and mercury).

3. Specification of baseline operating conditions at N ewington Station including fuel feed rate, sulfur content of fuel, ESP operating conditions, a nd emission values of opacity, SO 2 

### , NOx, particulate, and CO (if applicable);

4. A comprehensive test plan, which shall present the proposed operating conditions for the trial burn, to include but not be limited to the fo llowing:

a) Length of fuel trial;

b) New fuel rate;

c) Means of measuring new fuel feed;

d) Description of new fuel feed process;

e) New fuel preparations;

f) Percent moisture of new fuel feed;

g) Sulfur content of new fuel;

h) Time table for operation stability;

i) Existing fuel feed rate;

j) ESP operating conditions;

k) Expected emission values of opacity, SO 2 

### , NOx, TSP, and CO;

### PSNH Newington Page 10 TV-OP-054

l) The continuous tracking or operational data prior t o the fuel trial, during the fuel trial, and for a short time after the fuel trial. SO 2 

### , NOx, and opacity can be monitored using the existing CEM.

m) A compliance stack test protocol for TSP emissions using Method 1 through 4, Method 5, or a DES approved alternate, when requested by DES.

n) Operational parameters to be monitored and recorded , which shall include, but not be limited to steam flows, boiler temperatures, and ox ygen;

o) The effects of the new fuel on flyash characteristi cs and resulting effect on the ESP operation;

p) The effects of the new fuel on bottom ash character istics;

q) Specification and description of expected operation al and combustion conditions when the trial burn has reached stabilization with the n ew fuel feed; and

r) A timetable or schedule with approximate dates of t he trial test burn.

5. Based on information regarding the proposed trial f uel burn provided by PSNH, DES may request additional specific information on the prop osed trial burn operations. In addition, metal emission stack testing may be required depend ent upon DES review of the new fuel metal analysis.

6. If the new fuel is to be consumed on a regular basi s, PSNH must apply for a temporary permit. As part of the temporary permit review pro cess, DES will make a determination as to the applicability of the New Source Review and P revention of Significant Deterioration programs, and will provide an opportunity for publi c notice and comment.

7. DES shall respond within 30 days of receipt of a pr oposal with approval, conditional approval, denial, or request for additional informa tion.

8. DES Waste Management Division may have additional r equirements and concerns and shall be contacted by PSNH prior to the initiation of any trial fuel burn.

9. A summary report shall be submitted to DES within 6 0 days after the end of the trial fuel burn, which should include a summary of operational results and trends, emission values to include CEM and stack test data, if performed, and proposed future use of fuel.

B. Fuel Blending Requirements (State Enforceable Only) (Permit to Operate No. PO-B-1030)

DES grants PSNH a waiver from Env-A 1604 in order t o purchase oil containing sulfur greater than 2.0% by weight. This oil shall be used for bl ending purposes only. PSNH shall comply with the requirements listed below when purchasing oil greater than 2.0% sulfur.

1. Delivery of greater than 2.0% sulfur oil shall be t o segregated storage tanks.

### PSNH Newington Page 11 TV-OP-054

2. Greater than 2.0% sulfur oil shall be mixed with le ss than 2.0% sulfur oil in a tank in which the “sparging system” shall be in full operation to assure complete mixing of the blended oil.

3. After mixing for an appropriate amount of time to a ssure complete blending, samples from the top, middle, and bottom of the tank shall be co llected and analyzed in accordance with method ASTM D 4294. The sample results shall be av eraged to create a composite figure in accordance with PSNH procedures.

4. After sampling is complete and the test results ind icate that the tank of blended oil is less than 2.0% sulfur by weight, the oil may be transfer red to the Newington day tank.

5. PSNH shall not burn oil containing greater than 2.0 % sulfur by weight.

6. Prior to accepting any shipment of oil containing g reater than 2.0% sulfur by weight, PSNH shall contact DES by fax or telephone.

7. PSNH shall provide DES with all analytical data fro m samples collected from all blending operations that utilize greater than 2.0% sulfur by weight oil. This data shall provide DES with specific sulfur analysis information on the oi l feeding the boilers and confirm that each blend is less than or equal to 2.0% sulfur by weigh t.

C. Fly Ash Reinjection (Permit to Operate No. PO-B-103 0)

1. To capture unburned carbon in the fly ash and to re duce the amount of ash shipped off-site as solid waste, PSNH is authorized to maintain and operate the fly ash injection system.

2. The fly ash injection system is comprised of a syst em of blowers and piping that allow fly ash from the precipitator hoppers to be reinjected into the burners of the boilers.

3. To minimize PM emissions during fly ash reinjection , PSNH shall ensure that the ESP is energized before start-up of the fly ash reinjectio n system.

D. NOx Emission Reduction Management Practices (Permit to Operate No. PO-B-1030, NOx RACT Orders Nos. ARD-97-001 and ARD-98-001, and Env -A 1211)

1. To achieve the NOx emission requirements specified in this permit, PSNH is authorized to maintain and operate any or all of following equipm ent, systems and methods: the overfire air system, water injection, and the low NOx burner s.

2. The CEMS shall be used to determine the NOx emissio ns from Unit No. 1.

3. The overfire air system is comprised of ports, duct s, and dampers that allows the combustion airflow to be diverted from the top of the windbox through ports located above the top elevation of burners.

4. The water injection system is comprised of nozzles that inject water into the flame to reduce peak flame temperature.

### PSNH Newington Page 12 TV-OP-054

5. The low NOx burners are designed to create lower NO x emissions during the combustion of fuel.

6. PSNH shall maintain compliance with the NOx emissio n limitations listed in Section VIII. B, D, E, and F during the usage of any of these alt ernative NOx emission reduction methods.

7. PSNH shall record which NOx emission reduction mana gement practice is in use and when a change in scenario occurs.

8. PSNH shall maintain records according to Section VI II. I and submit reports according to Section VIII. J.

E. Auxiliary Fuel – Toner (Permit to Operate No. PO-B- 1030) (State Enforceable)

Toner may be used as an auxiliary fuel. The combus tion of the toner shall be performed under the following conditions:

1. The toner feed rate shall not exceed 24 tons/day or a rate to ensure compliance with Env-A 1400, whichever is less.

2. PSNH shall ensure compliance with all federal and s tate air quality and waste management requirements pertaining to the combustion of toner.

3. Combustion of toner shall not occur during start-up or shutdown conditions.

4. Combustion of toner shall be ceased immediately upo n indication of abnormal operating conditions or any condition that threatens complian ce with this permit or any air quality regulation or requirement.

5. The toner shall be stored in containers with proper fire precautions observed.

6. The toner shall be handled and transferred in such a manner as to minimize fugitive dust emissions.

7. PSNH shall retain on-site the following information :

a) Name and address of the company providing the toner ;

b) Amount of toner combusted; and

c) RTAP compliance demonstration.

8. When a new toner is combusted, PSNH shall notify DE S in the semi-annual reporting.

9. PSNH shall conduct an RTAP evaluation to determine compliance for each new toner and retain it along with a copy of the Material Safety Data Sheet (MSDS) on-site for inspection by DES, upon request.

### PSNH Newington Page 13 TV-OP-054

VIII. Applicable Requirements

A. State-only Enforceable Operational and Emission Lim itations

The Permittee shall be subject to the state-only op erational and emission limitations identified in Table 4 below.

Table 4 – State-Only Enforceable Operational and Em ission Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

1. Env-A 1403 All devices subject to RSA 125-I and Env-A 1400 All devices or processes subject to RSA 125-I and E nv-A 1400 shall

comply with Env-A 1400 (Regulated Toxic Air Pollutants).

2. Env-A 1403.01(d) All devices subject to RSA 125-I and Env-A 1400 Documentation for the demonstration of compliance s hall be retained at

the facility and shall be made available to DES for inspection upon request.

3. Env-A 1404.01 All devices subject to RSA 125-I and Env-A 1400 A) The owner of a new or modified device or process re quiring a permit

under this chapter shall submit an application for a temporary permit in accordance with Env-A 607.03. B) Pursuant to RSA 125-I:5,I, the owner shall not oper ate the device or process until a temporary permit is issued. 4. Env-A 1405.01 All devices subject to RSA 125-I and Env-A 1400 The owner of any device or process subject to RSA 1 25-I and Env-A

1400 shall determine compliance with the AAL by usi ng one of the methods provided in Env-A 1405. Upon request, the owner of any device or process subject to RSA 125-I and Env-A 1400 shal l provide documentation of compliance with the AAL to DES. 5. Env-A 1605.01 Sulfur Content for Gaseous Fuels 6 NT1 The sulfur content of gaseous fuels shall not e xceed 15 grains of sulfur per 100 cubic feet of gas at standard temperature a nd pressure.



### B. Federally Enforceable Operational and Emission Limi tations

1. The Permittee shall be subject to the emission limi tations summarized in Table 5 below for the listed fuel burning devices.

6 Env-A 1605 contains the most current requirement f or the sulfur content of gaseous fuels. Env-A 1605 is state enforceable only because it is not included in New Hampshire’s State Implementation Plan (SIP). 40 CFR 52.1520 contain s the New Hampshire rules that have been approved by EPA and adopted as part of the SIP. Env-A 402.03, effective on December 27 , 1990, lists the federally enforceable sulfur limit for gaseous fuels because it was adopted as part of the SIP on September 14, 1992. Upon approval by EPA and adoption into New Hampshire’s SIP, Env-A 1605 w ill supercede Env-A 402.03, which will expire.

### PSNH Newington Page 14 TV-OP-054

Table 5 – Summary of Emission Limitations Item No. Pollutant NT1 NTAB1 NTAB2

1. SO 2 Emissions Cap for Schiller Station, Merrimack Station and Newington Station combined 55,150 tons per

calendar year NA NA

2. NOx 0.35 lb/MMBtu based on a 24-hour calendar day average with oil 7 ; 0.25 lb/MMBtu based on a 24-hour calendar day average with oil/gas 0.20 lb/MMBtu

based on a 24-hour calendar day average; 50 tons per consecutive 12-month period 0.20 lb/MMBtu

based on a 24-hour calendar day average; 50 tons per consecutive 12-month period

3. CO 0.231 lb/MMBtu based on a 24-hour calendar day average; 2915 tons per consecutive 12-month period NA NA

4. TSP 0.22 lb/MMBtu 0.41 lb/MMBtu 0.41 lb/MMBtu 5. Opacity 40% for any continuous 6- minute period 40% for any

continuous 6- minute period 40% for any

continuous 6- minute period



### 2. The Permittee shall be subject to the federally enf orceable operational and emission limitations identified in Table 6 below:

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

1. Env-A 1211.03(c)(3)(c) NOx RACT for Utility Boilers NT1 A) When firing oil, the Permittee shall be limited to 0.35 lb NOx/MMBtu, based on a 24-hour calendar day average 8

. B) When firing gas or any combination of oil and gas, the Permittee shall be limited to 0.25 lb NOx/MMBtu heat input based on a 24-hour calendar day average. C) If both a combination of gas and oil and exclusivel y oil are burned for separate periods within the same 24-hour calendar d ay, the applicable emission limit shall be a prorated value using the emission limits specified in Conditions B and C above and the actua l hour that each

7 Note that 0.35 lb/MMBtu based on a 24-hour calenda r day average is equivalent to 4,416.1 tons per consecutive 12-month period based on an annual heat input of 25,235,000 MMBtu and 0.35 lb/MMBtu.

8 Note that 0.35 lb/MMBtu based on a 24-hour calenda r day average is equivalent to 4,416.1 tons per consecutive 12-month period based on an annual heat input of 25,235,000 MMBtu and 0.35 lb/MMBtu

### PSNH Newington Page 15 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

fuel type is burned as indicated in the following e quation:

o og o og 

### t

t MMBtu

lb t MMBtu lb t

= AEL + + )

/ 35.0 * ( ) / 25.0 * (

Where: AEL=allowable NOx emission limit (in lb/MMBtu)

t og =Number of hours within 24-hour calendar day when b urning any combination of gas and oil

t o =Number of hours within 24-hour calendar day when b urning exclusively oil 2. State Permit toOperate No. PO-B1030 and Env-A 1604.01(c)(2) Fuel Specifications for No. 6 Fuel Oil and Crude Oil NT1 The sulfur content of No. 6 fuel oil and crude oil shall not exceed 2.00 percent sulfur by weight.

3. State Permits toOperate Nos. POB-1030, PO-B1031, PO-B-1032 and Env-A 1604.01(a) Fuel Specifications for No. 2 Fuel Oil NT1,

NTAB1, NTAB2 The sulfur content of No. 2 fuel oil shall not exce ed 0.40 percent by weight.

4. 40 CFR 52.1520 9

Sulfur Content for Gaseous Fuels NT1,

NTAB1, NTAB2 The sulfur content of gaseous fuels shall not excee d 5 grains of sulfur per

100 cubic feet of gas at standard temperature and p ressure.

5. State Permit toOperate No. PO-B1030 NT1 PSNH shall use No. 2 fuel oil or natural gas to start-up the boiler.

6. State Permit toOperate No. PO-B1030 Maximum Gross Heat Input NT1 A) The maximum operating rate of this electric generat ing unit is limited to 4,350 MMBtu/hr (nameplate rating) 10 gross heat input of crude oil or No. 6 fuel oil at not more than 2.0% sulfur content by weight, No. 2 fuel oil at not more than 0.4% sulfur content by weight or natural gas or any combination thereof.

9 40 CFR 52.1520 contains the New Hampshire rules th at have been approved by EPA and adopted as part of the State Implementation Plan (SIP). Env-A 402.03, effective on December 27 , 1990, contained the sulfur limit for gaseous fuel s was adopted as part of the SIP on September 14, 1992. Env-A 402.03 and is still c onsidered to be federally enforceable until such ti me as the SIP is amended and approved by the EPA. This requirement will expire at such time that Env-A 1605, the amended rule cont aining the sulfur content limit for gaseous fuels, is approved by EPA and adopted a s part of the SIP.

10 The heat input rating of 4,350 MMBtu/hr was calcul ated based upon the nameplate rating of NT1, fuel f low to the boiler, and Btu analysis of the fuel. The CEMS calculates and reco rds the heat input on a minute-by-minute basis acco rding to the procedures in 40 CFR 75. The calculated heat input from the CEMS is based upon the volumetric flow of the stack gases, the CO 2 concentration, and a carbon-based F factor—a default factor provided in 40 CFR Part 75. The calculated heat input rate fro m the CEMS is not based on fuel flow.

### PSNH Newington Page 16 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

B) In accordance with NSR avoidance for CO, the maximu m operating rate shall not exceed 25,235,000 MMBtu total gross heat input during any consecutive 12-month period. Upon written approval from DES, PSNH may adjust the maximum operating rate provided that PSNH would not exceed the emission limitations established in the permit. 7. State Permit toOperate No. PO-B1030 and Env-A 404.01 State Acid Deposition Control Program NT1 The total SO 2 emissions from Newington Station’s Unit No. 1 (NT1 ), Schiller Station, and Merrimack Station shall not e xceed 55,150 tons per calendar year.

8. State Permits toOperate Nos. POB-1030 and Env-A 2002.01 and 2002.04 (b) Visible Emission Standard for Fuel Burning Devices NT1 During normal operation, the average opacity s hall not exceed 40 percent for any continuous 6-minute period. The 6-minute t ime blocks shall be established to provide for ten 6-minute blocks per calendar hour. The first 6-minute time block in any calendar hour in excess of the opacity standard will not be considered an excess emission. Any sub sequent time block in the same calendar hour in exceedance of the opacity standard shall be considered an excess emission. To be considered an excess emission, the subsequent time block in the same calendar hour in excess of the opacity standard does not have to be consecutive in occurre nce with the first exceedance. The average opacity may exceed 40 pe rcent for a nonoverlapping set or sets of time up to 60 minutes in any 8-hour period during startup, shutdown, malfunction, soot blowing, grate cleaning, and cleaning of fires. 9. State Permits toOperate Nos. POB-1031, PO-B1032 and Env-A 2002.01 and 2002.04 (c) Visible Emission Standard for Fuel Burning Devices NTAB1,

NTAB2 The average opacity shall not exceed 40 percent for any continuous 6- minute period. The average opacity may exceed 40 p ercent for one period of 6 continuous minutes in any 60 minute period dur ing startup, shutdown, malfunction, soot blowing, grate cleaning, and clea ning of fires.

10. State Permit toOperate No. PO-B1030, and Env-A 2002.06(c)(2) Particulate Emission Standards NT1 PSNH shall not cause or allow emissions of part iculate matter in excess of the following equation at the utility boiler:

166 .0 * 880 .0 − = I E Where: E=maximum allowable particulate matter emission rat e in lb/MMBtu = 0.22 lb/MMBtu I=maximum gross heat input rate in MMBtu/hr = 4,350 MMBtu/hr

This limitation is independent of fuel type and app lies at all times, including during flyash reinjection. 11. State Permit toOperate PO-B1030 NT1 A) PSNH shall not exceed a CO emission rate of 0.231 l b/MMBtu for any 24-hour calendar day average as calculated by the C EMs. This limitation is independent of fuel type and applies at all times.

### PSNH Newington Page 17 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

B) PSNH shall not exceed an annual CO emission rate of 2,915 tons per consecutive 12-month period based upon 0.231 lb/MMB tu and the New Source Review limited maximum annual operating rate of 25,235,000 MMBtu/year. As long as the daily and annual CO emi ssion rates are not exceeded, the maximum annual operating rate is not a permit limitation. 12. State Permit toOperate No. PO-B1030 ESP Operating Requirements NT1 A) PSNH shall maintain and operate the ESP system for the control of particulate matter, in accordance with the manufact urer’s recommendations. B) The ESP unit shall be operational at all times that the facility is in operation above 120 MW on any combination of oil an d oil/gas. The ESP will not normally be energized when the unit is burning 100 percent natural gas. C) The inlet temperature of the ESP as measured at the outlet of the boiler shall not exceed 785 ° F. D) The secondary voltage of the transformer rectifier sets (TR sets) is automatically controlled to operate between a maxim um of 45 KVDC and a minimum of 7500 VDC based on the dust loading rate, spark rate, and opacity. E) PSNH shall optimize the ESP based on the opacity ba seline for high load service. F) PSNH shall track the fields out of service. G) PSNH shall continuously operate and maintain the ES P system to minimize particulate matter emissions, to meet perm it conditions, and to maintain compliance with Env-A 2000. The operation and maintenance shall include the normal procedures for scheduled c hecking and cleaning of the hoppers and transport lines. All m aintenance procedures performed and corrective actions taken on the ESP s ystem shall be recorded. The records shall be maintained at the f acility and shall be made available for review at the request of the DES . All deviations from the operation criteria described above and the corrective actions taken shall be recorded in the work management syst em or logbook. 13. State Permit toOperate PO-B1030 New Source Review Avoidance NT1 A) PSNH avoided NSR when adding the natural gas firing capabilities on the basis that the emissions would not increase. B) If an emissions increase occurs in the maximum 24-h our calendar day average emission rate (calculated in lb/MMBtu) of a ny pollutant as determined in accordance with 40 CFR 60.14 and by D ES when burning natural gas, then the natural gas conversio n shall be subject to NSPS. C) If an emissions increase occurs in the actual annua l emissions of any pollutant as determined in accordance with 40 CFR 5 1.165, 40 CFR 52.21 or by DES, then the natural gas conversion sh all be subject to NSR. D) PSNH shall not exceed the 24-hour calendar day aver age emission rates of CO (0.231 lb/MMBtu) and NOx (0.25 lb/MMBtu for o il/gas and 0.35 for oil) as specified above. The maximum annu al operating rate of 25,235,000 MMBtu/year was used to calculate the app licable CO emission permit limits, which will be enforced thro ugh the annual CO

### PSNH Newington Page 18 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

emission limit by DES to protect the annual baselin e emission limits for CO. The maximum annual operating rate referred to herein may be adjusted by PSNH provided that the resulting emissi ons will not contribute significantly to or cause a violation of any applicable NAAQS, or a violation of any applicable PSD increme nt, or a violation of the NH State Implementation Plan, or a violation of any condition contained in a permit issued pursuant to regulation s approved or promulgated under the CAA. Regardless of the maxim um annual operating rate, the emission limitations establishe d in this permit shall not be exceeded. E) Any adjustments, requested by PSNH, to the maximum NOx and CO emission limits and the maximum operating rate refe rred to herein will be made only after DES’ review of applicable suppor ting data. Any adjustments made shall not result in an increase of emissions. Adjustments shall not be made until PSNH has receiv ed written approval from DES. 14. State Permit toOperate PO-B1030 NT1 PSNH shall follow standard operating procedures for cold boiler start-up and boiler repair practices to ensure compliance wi th opacity standards.

15. 40 CFR 72, 73, and 77 Acid Rain Provisions NT1 PSNH shall comply with the applicable Federal A cid Rain Program provisions.

16. Env-A 1211.12 NOx RACT for Auxiliary Boilers NTAB1,

NTAB2 A) Each auxiliary boiler shall be limited to a NOx RAC T emission limit of

0.20 lb/MMBtu based on a 24-hour calendar day avera ge, regardless of the type of fuel burned. B) The emissions from all auxiliary boilers shall be i ncluded in the calculation of both the actual and theoretical pote ntial emissions from the stationary source. 17. State Permits toOperate Nos. POB-1031, PO-B1032 Maximum Fuel Consumption NTAB1,

NTAB2 A) Maximum fuel consumption rate of No. 2 fuel oil for each device shall not exceed 3.57 million gallons during any consecut ive 12-month period. 11 B) This fuel consumption limitation is to limit the NO x emissions to less than 50 tons during any consecutive 12-month period

. 18. Env-A 2002.06 (c)(2) Particulate Emission Standards NTAB1,

NTAB2 PSNH shall not cause or allow emissions of particul ate matter in excess of

the following equation at each of the auxiliary boi lers:

166 .0 * 880 .0 − = I E Where: E=maximum allowable particulate matter emission rat e in lb/MMBtu = 0.41 lb/MMBtu I=maximum gross heat input rate in MMBtu/hr = 99.4 MMBtu/hr 19. Env-A 1211.01(j)(1) & 40 CFR 60.4211(e) NTEG1 Emergency Generators The emergency generator shall be limited to the fol lowing in any consecutive 12-month period:

a. 100 hours for readiness testing and maintenance che cks; and

11 The heating value of No. 2 fuel oil is assumed to be 140,000 BTU/gallon. The fuel consumption limits may vary based on the actual heat content of the fuel burned.

### PSNH Newington Page 19 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

b. 500 hours of emergency operation. 20. Env-A 2002.02 and 2002.04(c) Visible Emission Standard for Fuel Burning Devices NTEG1 The average opacity shall not exceed 20 perce nt for any continuous 6- minute period. The average opacity may exceed 20 p ercent for one period of 6 continuous minutes in any 60 minute period dur ing startup, shutdown and malfunction.

21. Env-A 2002.08 Particulate Emission Rate NTEG1 The particulate matter emissions from fuel bu rning devices installed on or after January 1, 1985 shall not exceed 0.3 lb/MMBtu

. 12

22. Env-A 1002 Fugitive Dust Facility wide The Permittee shall take precautions, such as wetting, covering, shielding or vacuuming, to prevent, abate, and control fugitive dust emissions during any activity, which might create fugitive dust. Such activities include bulk hauling activities, including the transportation an d transfer of mineral material over public roads and maintenance activiti es, including sweeping, vacuuming, or other activity involved with the upke ep of roads or parking lots. 23. 40 CFR 68 and 1990 CAA Section 112(r)(1) Accidental Release Program Requirements Facility wide The Permittee maintains no quantities of regulated substances above the threshold quantities established by the EPA under 4 0 CFR 68.130. Administrative controls will be established by the Permittee in order to ensure that inventories of regulated substances are maintained below the specified threshold quantities. The facility is su bject to the Purpose and General Duty clause of the 1990 Clean Air Act, Sect ion 112(r)(1). General Duty includes the following responsibilities: (A) Identify potential hazards that may result from suc h releases using appropriate hazard assessment techniques; (B) Design and maintain a safe facility; (C) Take steps necessary to prevent releases; and (D) Minimize the consequences of accidental releases th at do occur. If, in the future, the Permittee wishes to store qu antities of regulated substances above the threshold levels, a risk manag ement plan shall be submitted to the Part 68 implementing agency prior to exceeding threshold quantity levels in a timely manner. 24. 40 CFR 61 Subpart M, Env-A504.01(e) and EnvA 1800 Asbestos Management and Control Facility wide PSNH shall comply with the asbestos r equirements of Env-A 1800 and 40 CFR 61.145 during demolition and/or renovation.

25. 40 CFR 60.4207 (NSPS Subpart IIII) NTEG1 Maximum Sulfur Content Allowable in Liquid Fuels

a. The sulfur content of diesel fuel burned in the eme rgency generator shall not exceed 500 ppm (0.05 percent sulfur by we ight); and b. After October 1, 2010, the sulfur content of diesel fuel burned in the emergency generator shall not exceed 15 ppm (0.0015 percent sulfur by weight).

12 PSNH shall demonstrate compliance with this requir ement by using an EPA-approved emission factor and EPA/DES approved heat input content (Btu/gallon). This calculation shall be maintained on file at the facility.

### PSNH Newington Page 20 TV-OP-054

Table 6 – Federally Enforceable Operational and Emi ssion Limitations Item No. Regulatory Cite Applicable Emission Unit Applicable Requirement

26. Env-A 1211.02(o) NTEG1 Emergency Generator The emergency generator shall only operate:

a. As a mechanical or electrical power source when the primary power source for the Facility has been lost during an eme rgency such as a power outage; or b. During normal maintenance and testing as recommende d by the manufacturer.



### C. Annual SO 2 

### Allowance Programs (40 CFR 72, 40 CFR 73, Env-A 61 1.07, and Env-A 2900)

1. SO 2 

### Allowance Allocation

a) In accordance with 40 CFR Part 73, SO 2 

### allowances pursuant to the Federal Acid Rain Program for this facility are allocated as indicate d in the following table:



### Table 7 – SO 2 

### Allowance Allocation (tons) 2003 2004 2005 2006 2007 2008 2009 2010 NT1 11,660 11,660 11,660 11,660 11,660 11,660 11,660 10,613

b) Pursuant to Env-A 2906.02 [State enforceable only], Allocation of SO 2 

### Allowances , for 2007 and subsequent years, PSNH’s Schiller, Merrima ck and Newington (NT1) Stations shall transfer the SO 2 

### Allowances allocated pursuant to the Federal Acid Rain Program to DES, and DES shall transfer SO 2 

### allowances (7,289 tons) calculated pursuant to Env -A 2900 plus any potential bonus allowances calculated pursuant to Env-A 2906.07, Bonus Allocation of SO 2 

### Allowances back to PSNH’s Schiller, Merrimack, and Newington stations. The amount of SO 2 

### Allowances allocated to PSNH Newington shall be determined according the methodology in Env-A 2906. 05, Allowance Allocation Methodology

.

2. Compliance

a) Pursuant to 40 CFR 73.35, the Permittee shall compl y with the SO 2 

### emission limitation requirements.

b) At the end of each calendar year, the Permittee sha ll hold sufficient SO 2 

### allowances equivalent to the SO 2 

### emissions during that calendar year.

### PSNH Newington Page 21 TV-OP-054

3. General Provisions

Pursuant to Env-A 611.07 and Env-A 2900, SO 2 

### allowances lawfully held or acquired by the Permittee shall be governed by the following:

a) Emissions from the affected units shall not exceed any SO 2 

### allowances held by the affected unit;

b) The number of SO 2 

### allowances held by the Permittee shall not be limit ed;

c) The Permittee shall not use SO 2 

### allowances to avoid compliance with any other applicable requirement of either state or federal r ules or of the provisions of the Clean Air Act; and

d) Any SO 2 

### allowances held by the Permittee shall be accounted for according to the procedures established in the applicable provisions of 40 CFR 72, 40 CFR 73, and 40 CFR 76.

4. Excess Emissions

Pursuant to 40 CFR 72.9(e), if the Permittee has ex cess emissions, the Permittee shall submit a proposed offset plan as required under 40 CFR 77 and pay the penalty and any interest without demand pursuant to 40 CFR 77. Additional p enalties may apply pursuant to Env-A 2900. See Condition VIII. F.8.

5. Allowance Transfer

The Permittee shall transfer allowances according t o the procedures in 40 CFR 73.50.



### D. Ozone Season NOx Budget Trading Program (Env-A 3200 )

1. NOx Allowance Allocation

a) Pursuant to Env-A 3207.03, Allocation of Allowances, the amount of NOx allowances allocated to PSNH shall be as set forth in the Tabl e 8 below for the 2003, 2004, and 2005 control periods (ozone seasons of May 1 through Sep tember 30):

### PSNH Newington Page 22 TV-OP-054

Table 8 – NOx Allowance Allocation for the

Ozone Season (tons) Emission Unit 2003 2004 2005

NT1 579 507 434

2. The NOx allowances shall be allocated to PSNH for t he 2006 control period (ozone season) and subsequent control periods according to the met hodology in Env-A 3207.04, Future Allowance Allocation Methodology

.

3. Ozone Season NOx Emissions Cap

a) Pursuant to Env-A 3200, PSNH shall not emit NOx emi ssions during any control period in excess of the amount of NOx allowances held in P SNH’s NATS compliance account for that control period as of the allowance transfe r deadline of November 30.

b) Pursuant to Env-A 3200, PSNH may obtain additional NOx allowances to comply with the NOx Budget Program.

4. Allowance Transfer and Use

a) Pursuant to Env-A 3209.01, Marketable Emissions Authorization , an allowance shall be a marketable emissions authorization that may be boug ht, sold, or traded at any time during any year, not just the current year.

b) Pursuant to Env-A 3209.02, Limited Authorization, an allowance shall only be used for compliance with the NOx Budget Program in a designa ted compliance year by being in a compliance account as of the allowance transfer dea dline of November 30, or by being transferred into the compliance account by an allow ance transfer submitted by the allowance transfer deadline.

c) PSNH shall comply with the NOx allowance transfer a nd use provisions pursuant to EnvA 3209, Allowance Transfer and Use

. d) Pursuant to Env-A 3209.09, Price Disclosure, subject to a claim of confidentiality in accordance with Env-A 103, PSNH shall make availabl e to any person, all information regarding transaction cost and allowance price.

5. Allowance Banking

a) Pursuant to Env-A 3210.01, Retention of Unused Allowances, the banking of allowances shall be permitted to allow the retention of unused allowances from one year to a future year in either a compliance account, an overdraft a ccount, or a general account.

b) Pursuant to Env-A 3210.02, Account Designation, unless otherwise permitted pursuant to Env-A 3210.04, Early Reduction Allowances, unused allowances as of the end of the allowance transfer deadline shall be retained in th e compliance, overdraft, or general account and designated as banked allowances after t he NATS administrator has made all

### PSNH Newington Page 23 TV-OP-054

deductions for a given control period from the comp liance account or overdraft account pursuant to Env-A 3215, End-of-Season Reconciliation.

c) PSNH shall comply with the NOx allowance banking pr ovisions pursuant to Env-A 3210, Allowance Banking

.

6. End-of-Season Reconciliation

a) Pursuant to Env-A 3206.01, Limited Authorization , PSNH shall, no later than November 30 of each calendar year, hold respective a quantit y of NOx allowances in PSNH Newington’s current year NATS account that is equal to or greater than the total NOx emitted from PSNH Newington during the period May 1 through September 30 of the subject year.

b) PSNH shall determine compliance and reconcile allow ances by November 30 of each year for the control period of that year pursuant t o Env-A 3215.

7. Authorized Account Representative (Env-A 3211.04)

a) Only the AAR or alternate AAR shall request transfe rs of allowances in a NATS account.

b) The AAR or alternate AAR shall be responsible for a ll transactions and reports submitted to the NATS.

c) The alternative AAR shall have the same authority a s the primary representative, however, all correspondence from the NATS administr ator shall be directed to the primary AAR.

d) Pursuant to Env-A 3211.05 (f), PSNH shall replace a n AAR by submitting a revised Account Certificate of Representation to the NATS a dministrator along with the information contained in Env-A 3211.05(b) and (c) a nd the name of the AAR who is being replaced.

8. Conversion of Allowances to DERs

Pursuant to Env-A 3207.05, PSNH Newington may conve rt unused allowances to DERs in accordance with Env-A 3206.02(e) for use as NSR off sets during the ozone season and the procedures for DER generation pursuant to Env-A 310 3. Upon conversion, PSNH Newington shall surrender those converted allowance s as if they had been used for actual emissions. Under no other circumstances shall unus ed allowances be converted to, or used as, DERs or ERCs.

9. Prohibition on Property Rights (Env-A 3207.07)

a) Neither an allowance nor any future allocations, wh ich are subject to modification by DES, shall constitute a security or other form of p roperty.

b) An allowance shall not be used prior to the control period for which the allowance is allocated.

### PSNH Newington Page 24 TV-OP-054

10. Excess Emissions and Enforcement Provisions (Env-A 3217)

a) If emissions exceed the allowances held by PSNH New ington by the allowance transfer deadline (November 30), the NATS administrator shal l automatically deduct three tons of allowances from the next control period for every t on of excess emissions from PSNH Newington compliance account or overdraft account.

b) In accordance with RSA 125-J:4-a, for purposes of e nforcement of the NOx Budget Program, in determining the number of days of viola tion, any excess emissions for the control period shall presume that each day in the c ontrol period of 153 days, constitutes a day in violation unless PSNH Newington can demonstr ate, through use of verifiable emissions data that a lesser number of days should be considered. In addition, each ton of excess emissions shall constitute a separate violat ion.



### E. Non-Ozone Season NOx Allowance Program ( NOx RACT O rder No. ARD-98-001)

Pursuant to NOx RACT Order No. ARD-98-001, PSNH’s S chiller, Merrimack, and Newington stations shall comply with a NOx emissions cap of 8 208 tons for the non-ozone season beginning on October 1 and ending on April 30. Ozone season DERs and non-ozone season DERS may be used to comply with this non-ozone season limit. P reviously generated (1995 through 1998) DERs may be used to comply with this emissions cap. DERs may be generated from PSNH’s Newington and Schiller Stations, in accordance with the protocols submitted by PSNH to comply with this emissions cap.



### F. Multiple Pollutant Annual Budget Trading and Bankin g Program (Env-A 2900) [State Enforceable Only]

1. SO 2 

### Allowance Allocation

Pursuant to Env-A 2900, Multiple Pollutant Annual Budget Trading and Bankin g Program

, and subsequent revisions, DES shall allocate SO 2 

### Allowances to PSNH Newington according to the methodology in Env-A 2906.05, Allowance Allocation Methodology for 2007 and subsequent years.

2. NOx Allowance Allocation

a) Pursuant to Env-A 2900, Multiple Pollutant Annual Budget Trading and Bankin g Program , and subsequent revisions, DES shall allocate NOx Allowances to PSNH Newington according to the methodology in Env-A 290 6.05, Allowance Allocation Methodology for 2007 and subsequent years.

b) Pursuant to Env-A 2900, Multiple Pollutant Annual Budget Trading and Bankin g Program , and subsequent revisions, for 2007 and subsequent years, DES shall calculate the difference between the annual NOx budget (no mo re than 3,644 tons) and the ozone season NOx allowances allocated pursuant to Env-A 3 200.

### PSNH Newington Page 25 TV-OP-054

c) Pursuant to Env-A 2900, Multiple Pollutant Annual Budget Trading and Bankin g Program , and subsequent revisions, for 2007 and subsequent years, DES shall allocate annual NOx allowances equivalent to the difference between the annual NOx budget and the ozone season NOx allowances to PSNH’s Schiller, Merrimack, and Newington stations.

3. CO 2 

### Allowance Allocation

Pursuant to Env-A 2900, Multiple Pollutant Annual Budget Trading and Bankin g Program

, and subsequent revisions, DES shall allocate CO 2 

### Allowances to PSNH Newington according to the methodology in Env-A 2906.05, Allowance Allocation Methodology for 2007 and subsequent years.

4. Allowance Transfer and Use

a) Pursuant to Env-A 2907.01, Marketable Emissions Authorization , an allowance shall be a marketable emissions authorization that may be boug ht, sold, or traded at any time during any year, not just the current year.

b) Pursuant to Env-A 2907.02, Limited Authorization, an allowance shall only be used for compliance with the Multiple Pollutant Annual Budge t Trading and Banking Program in a designated compliance year by being in a complian ce or overdraft account as of the allowance transfer deadline, or by being transferre d into the compliance account by an allowance transfer submitted by the allowance trans fer deadline.

c) PSNH shall comply with the allowance transfer and u se provisions pursuant to Env-A 2907, Allowance Transfer and Use, and Env-A 2909, Allowance Tracking System

. d) Pursuant to Env-A 2907.08, Price Disclosure, subject to a claim of confidentiality in accordance with Env-A 103, PSNH shall make availabl e to any person, all information regarding transaction cost and allowance price.

e) Pursuant to Env-A 2907.09, Use of Allowances by Utilities, and RSA 125-J:5, X, the use of allowances by a utility as defined in RSA 362:2, shall be subject to such additional conditions as ordered pursuant to applicable law by the PUC.

5. Allowance Banking

a) Pursuant to Env-A 2908.01, Retention of Unused Allowances, the banking of allowances shall be permitted to allow the retention of unused allowances from one year to a future year in either a compliance account, an overdraft a ccount, or a general account.

b) Pursuant to Env-A 2908.02, Account Designation, unless otherwise permitted pursuant to Env-A 2909.03, General Accounts, unused allowances as of the end of the allowance transfer deadline shall be retained in the complian ce, overdraft, or general account and designated as banked allowances after the ATS admin istrator has made all deductions for a given year from the compliance account or overdra ft account pursuant to Env-A 2913, Compliance Certification.

### PSNH Newington Page 26 TV-OP-054

c) Pursuant to Env-A 2908.03, Bonus Early Allowances , bonus early allowances shall be eligible for a one-time conversion to allowances in 2007. Bonus early allowances that are converted to allowances shall not be used as VERs, ERCs, or DERs.

6. Authorized Account Representative (Env-A 2909.04)

a) Only the AAR or alternate AAR shall request transfe rs of allowances in an ATS account.

b) The AAR or alternate AAR shall be responsible for a ll transactions and reports submitted to the ATS.

c) The alternative AAR shall have the same authority a s the primary representative, however, all correspondence from the ATS administra tor shall be directed to the primary AAR.

d) Pursuant to Env-A 2909.05 (f), PSNH shall replace a n AAR by submitting a revised Account Certificate of Representation to the ATS ad ministrator along with the information contained in Env-A 2909.05(b) and (c) a nd the name of the AAR who is being replaced.

7. End-of-Season Reconciliation

a) Pursuant to Env-A 2904.01, Limited Authorization , PSNH shall, no later than January 30 of each calendar year, hold respective quantities o f SO 2 

### , NOx, and CO 2 

### in the PSNH Newington’s respective ATS accounts equal to or gre ater than the respective total SO 2 

### , NOx, and CO 2 

### emitted from PSNH Newington during the previous yea r.

b) Pursuant to Env-A 2912.01, Determination of Compliance , monitored emissions data as reported by PSNH to the ETS administrator, and as a djusted by the administrator to be in accordance with Env-A 2910, Emissions Monitoring , combined with allowance allocations and transfers recorded in the ATS, shal l provide the basis for a determination of compliance.

c) PSNH shall determine compliance and reconcile allow ances by January 30 of each year beginning in 2008 pursuant to Env-A 2913.

d) Pursuant to Env-A 2912.02, Request for Deduction of Allowances , no later than January 30, the AAR shall request the ATS administrator to deduct previous year allowances from the compliance account or overdraft account equival ent to the number of available allowances to cover the emissions during the previo us year. The AAR shall identify the compliance account or overdraft account from which the deductions shall be made and shall identify the serial number of the allowances to be deducted. If the AAR does not specify a serial number, allowances useable for tha t compliance year shall be deducted in the order of their arrival into PSNH Newington’s ac count, with allocated allowances being deducted first, followed by the deduction of transferred allowances.

e) Pursuant to Env-A 2912.04, Procurement of Additional Allowances, if the emissions of PSNH Newington in the previous year exceed the allo wances in PSNH Newington’s compliance account and overdraft account, PSNH Newi ngton shall obtain additional

### PSNH Newington Page 27 TV-OP-054

allowances by January 30 so that the total number o f allowances in PSNH Newington’s compliance account and overdraft account, including allowance transfers properly submitted to the ATS administrator by January 30, e quals or exceeds the previous year annual emissions rounded to the nearest whole ton.

8. Excess Emissions and Enforcement Provisions (Env-A 2914)

a) If emissions exceed the allowances held by PSNH New ington by the allowance transfer deadline (January 30), the Allowance Tracking Syste m administrator shall automatically deduct three tons of allowances for every ton of ex cess emissions.

b) In accordance with RSA 125-O:7, for purposes of enf orcement of the Multiple Pollutant Annual Budget Trading and Banking Program, in deter mining the number of days of violation, any excess emissions for the year shall create a presumption that each day in the year of 365 days, constitutes a day in violatio n unless PSNH Newington can demonstrate, through use of verifiable emissions da ta that a lesser number of days should be considered. In addition, each ton of excess emi ssions shall constitute a separate violation.

9. Conversion of Allowances to DERs or VERs

a) Pursuant to Env-A 2904.01 (d), allowances shall not be considered offsets, although NOx allowances which are not used to satisfy the requir ements of Env-A 2900, and which are not banked, may be converted to non-ozone season NO x DERs in accordance with Env-A 3100.

b) Pursuant to Env-A 2904.02, Conversion of Allowances to DERs or VERs , if PSNH converts unused NOx allowances to NOx DERs in accor dance with Env-A 2904.01(d) and the procedures for DER generation pursuant to E nv-A 3103, or converts unused CO2 allowances to VERs in accordance with Env-A 3800, P SNH shall surrender those converted allowances as if they had been used for a ctual emissions.

10. Prohibition on Property Rights (Env-A 2904.04)

a) Neither an allowance nor any future allocations, wh ich are subject to modification by DES, shall constitute a security or other form of p roperty.

b) An allowance shall not be used prior to the year fo r which the allowance is allocated.



### G. Discrete Emission Reduction Trading Program (Env-A 3100)

In accordance with Env-A 3100, NOx RACT Orders Nos. ARD-97-001 and ARD-98-001, and the Notices of Simultaneous Generation and Use of D ERs originally submitted on April 10, 1998, and annually thereafter upon entry of the DER s into the registry by DES, PSNH Newington shall be allowed to bank DERs for PSNH Ne wington’s own future use.

### PSNH Newington Page 28 TV-OP-054

H. Monitoring/Testing Requirements

The Permittee is subject to the monitoring/testing requirements as contained in Table 9 below:



### Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite 1. NT1 NOx

Emissions For NT1, PSNH shall install, certify, operate

and maintain, a NOx-diluent continuous emission monitoring system (consisting of a NOx pollutant concentration monitor and an O 2 or CO 2 diluent gas monitor) with an automated data acquisition and handling system for measuring and recording NOx concentration (in ppm) averaged on an hourly and 24-hour calendar day basis, O 2 or CO 2 concentration (in percent O 2 or CO 2 ) and NOx mass emission rate (in lb/MMBtu) averaged on an hourly, 24-hour calendar day, and annual basis for each unit. PSNH shall account for total NOx emissions, both NO and NO 2 , either by monitoring for both NO and NO 2 or by monitoring for NO only and adjusting the emissions data to account for NO 2 . PSNH shall measure and record NOx emissions in lb/hr averaged for one-hour and a 24-hour calendar day, and tons/consecutive 12-month period. PSNH shall calculate hourly, quarterly, and annual NOx emission rates (in lb/mmBtu) by combining the NOx concentration (in ppm), diluent concentration (in percent CO 2 ), and percent moisture according to the procedures in 40 CFR 75 Appendix F. Continuously Env-A 808.02 (a) (new) and 40 CFR 75.10(a)(2), 75.12, and Env-A 1211.03 (f)

2. NT1 NOx Mass

Emissions For NT1, PSNH shall calculate hourly NOx

mass emissions (in lbs) by multiplying the hourly NOx emission rate (in lbs/mmBtu) by the hourly heat input rate (in mmBtu/hr) and the unit or stack operating time. PSNH shallalso calculate quarterly and cumulative yearto-date NOx mass emissions and (in tons) by summing the hourly NOx mass emissions according to the procedures in 40 CFR 75 Appendix F Section 8. Hourly, quarterly, andcumulative yearto-date 40 CFR 75.71,

and 75.72 and Env-A 3212 and Env-A 2910

3. NT1 Ozone Season

NOx Emission Rate and NOx Mass Emissions PSNH, when required, shall determine the

ozone season NOx emission rate (in lb/MMBtu) by dividing ozone season NOx mass emissions (in lbs) by heat input. PSNH shall also calculate cumulative NOx mass emissions for the ozone season (in tons) by During the ozone

season Env-A

3212.01 and 40 CFR 75.75(b) and 75.72

### PSNH Newington Page 29 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite summing the hourly NOx mass emissions according to the procedures in 40 CFR 75 Appendix F Section 8. 4. NT1, NTAB1, NTAB2 Sulfur Content

of No. 2 Fuel Oil, No. 6 Fuel Oil, and Crude Oil Fuel delivery tickets, other documentation

from the fuel supplier or testing in accordance with appropriate ASTM test methods that certify the weight-percent of sulfur for each delivery of the No. 2 fuel oil, No. 6 fuel oil, and crude oil. Each delivery of fuel Env-A 806.02

5. NT1 Sulfur Content

of Natural Gas Documentation from fuel supplier or conduct

testing to determine the sulfur content of natural gas. Upon request by DES and/or EPA Env-A 809.02

(old) and EnvA 806.03 (new) 6. NT1 SO 2 Emissions PSNH shall install, certify, operate and maintain, an SO 2 CEMS automated data acquisition and handling system for measuring and recording SO 2 concentration (in ppm) averaged on an hourly and 24-hour calendar day basis, volumetric gas flow (in scfh), and SO 2 mass emissions (in lb/hr averaged over one hour and each 24-hour calendar day, and tons/consecutive 12-month period and tons/calendar year) for each unit. PSNH shall demonstrate compliance with the State Acid Rain Program emission caps by using the CEMS data. Continuously Env-A 808.02 (a)(1) (new) and 40 CFR 75.10 (a)(1)

7. NT1 CO 2

Emissions PSNH shall install, certify, operate and

maintain, a CO 2 CEMS automated data acquisition and handling system. PSNH shall measure and record CO 2 emissions in lb/hr averaged over each 24-hour calendar day and CO 2 concentration in percent averaged over each hour and over each 24-hour calendar day. Continuously 40 CFR 75.10(a)(3), and State Permit to Operate No. PO-B-1030

8. NT1 Stack

volumetric flow rate PSNH shall install, certify, operate and

maintain, a CEMS automated data acquisition and handling system to measure and record stack volumetric flow rate (in kscfm) averaged over each hour and over each 24-hour calendar day. Continuously 40 CFR 75, Env-A 2910.02

9. NT1 Heat Input

Rate PSNH shall determine the heat input rate (in

MMBtu/hr) to each unit for every hour or part of an hour any fuel is combusted following the procedures in 40 CFR 75 Appendix F. Hourly 40 CFR 75.10(c) and Env-A 2910.02 10. NT1 Net Electrical

Output PSNH shall monitor and/or calculate net

electrical output. Annually Env-A 2910.02 and 40 CFR 75 11. NT1 Ozone Season

Heat Input To determine the number of NOx allowances

allocated, PSNH shall calculate ozone season Hourly during

ozone season Env-A

3212.01 and

### PSNH Newington Page 30 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite heat input by summing each unit’s hourly heat input determined according to the procedures in 40 CFR 75 for all hours in which the unit operated during the ozone season 40 CFR 75.75(a)

12. NT1 Operating

Hours PSNH shall maintain a log of the operating

hours of the boiler. Continuously State Permit to Operate No. PO-B-1030 13. NT1 Opacity PSNH shall install, certify, opera te and maintain, a continuous opacity monitoring system with the automated data acquisition and handling system for measuring and recording the opacity of emissions (in percent opacity) for each 6-minute period for each unit. As necessary, PSNH shall also use US EPA Method 9 to estimate opacity. Continuously 40 CFR 75.10(a)(4) and Env-A 805.02 (old) and Env-A 808.02 (a) (new) and 807.02 (new) 14. NT1 PM PSNH shall conduct stack testing using US EPA Method 1-5 or 1-4 and 17 or other method approved by DES to determine the PM emissions. PSNH shall calculate and record the PM emission rate in lb/MMBtu on a 24- hour calendar day average and tons/consecutive 12-month period using stack test results and operating hours. PSNH may use other EPA-approved emission calculating methods to calculate PM emissions. Testing at least every 5 years and/or upon request by DES and/or EPA 40 CFR 70.6

(a)(3)(i)(B)

15. NT1 CO PSNH shall install, certify, operate and maintain a CO CEMS automated data acquisition and handling system for measuring and recording CO concentration (in ppm) averaged on an hourly and 24-hour calendar day basis, volumetric gas flow (in scfh), and CO mass emissions (in lb/hr averaged over one hour and each 24-hour calendar day, and tons/consecutive 12-month period and tons/calendar year) for each unit. PSNH shall conduct RATA testing for CO annually to verify the data. Continuously 40 CFR 70.6 (a)(3)(i)(B)

16. NT1 Temperature

of the flue gas at the outlet of the boiler PSNH shall measure and record the

temperature at the outlet of the boiler to determine the inlet temperature of the ESPusing a thermocouple or other temperaturemonitoring device. Daily 40 CFR 70.6 (a)(3)(i)(B)

17. NT1 Voltage of the

TR Sets PSNH shall measure and record the secondary

voltage of the TR Sets using a voltage meter or equivalent monitoring device. Daily 40 CFR 70.6 (a)(3)(i)(B)

18. NT1 Current (in

mAmps and KW) PSNH shall measure and record the current (in

mAmps and KW) using a current meter or equivalent monitoring device. Daily 40 CFR 70.6 (a)(3)(i)(B)

19. NT1 Spark rate per PSNH shall measure and recor d the spark rate Daily 40 CFR 70.6

### PSNH Newington Page 31 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite minute per minute. (a)(3)(i)(B) 20. NTI ESP fields out

of service PSNH shall monitor and record the ESP fields

out of service. Daily 40 CFR 70.6 (a)(3)(i)(B) 21. NT1 Hours that Fly

Ash Reinjection System Blowers is in Operation PSNH shall maintain a log of the hours that the

flyash reinjection system is operated. Daily when flyash reinjection is in operation 40 CFR 70.6

(a)(3)(i)(B)

22. NT1 Toner Usage PSNH shall maintain records of the amount of toner combusted in the boiler in tons/day in order to demonstrate compliance with RSA 125-I and Env-A 1400. Daily when combusting toner 40 CFR 70.6

(a)(3)(i)(B)

23. NT1 SO 2 , NOx,

CO, PM, VOCs Emissions (tons/month and tons/ consecutive 12-month period) Pursuant to the 40 CFR 52.21 (b)(21)(v)

(dated July 1, 2002) 13 , for an electric utility steam generating unit (other than a new unit or the replacement of an existing unit), actual SO2, NOx, CO, PM, VOC emissions of the unit following the physical or operational change shall equal the representative actual annual emissions of the unit, provided PSNH maintains and submits to DES on an annual basis for a period of 5 years from the date the unit resumes regular operation, information demonstrating that the physical or operational change did not result in an emissions increase. A longer period, not to exceed 10 years, may be required by DES, if it determines such a period to be more representative of normal source post-change operations. Pursuant to 40 CFR 52.21(b)(33) (dated July 1, 2002), representative actual annual emission means the average rate, in tons per year, at which the source is projected to emit a pollutant for the two-year period after the physical change or change in the method of operation of a unit (or a different consecutive two-year period within 10 years after that change, where DES determines that such period is more representative of normal source operations), considering the effect any such change will have on increasing or decreasing the hourly emissions rate and on projected capacity utilization. In projecting future emissions, Monthly 40 CFR 70.6 (a)(3)(i)(B) and 40 CFR 52.21 (b)(21) and (33), dated July 1, 2002

13 See the letter dated March 13, 2002 from Kenneth A . Colburn, Director, Air Resources Division, DES to John M. McDonald, Vice President-Operations, PSNH concerning conditional n ew source review applicability determination concer ning modifications at Newington Station.

### PSNH Newington Page 32 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite DES shall consider all relevant information, including but not limited to, historical operational data, the company’s own representations, filings with the State or Federal regulatory authorities, and compliance plans under Title IV of the CAA; and exclude, in calculating any increase in emissions that results from the particular physical change or change in the method of operation at an electric utility steam generating unit, that portion of the unit’s emissions following the change that could have been accommodated during the representative baseline period and is attributable to an increase in projected capacity utilization at the unit that is unrelated to the particular change, including any increased utilization due to the rate of electricity demand growth for the utility system as a whole. In order to calculate annual emissions as required pursuant to 40 CFR 52.21 (dated July 1, 2002), PSNH shall monitor emissions of SO2, NOx, CO, PM, and VOCs for a period of 5 years or more beginning in 2002. 24. NT1 Fuel Flow

MetersPeriodic Monitoring PSNH shall inspect, when NT1 is in operation,

maintain and/or repair the fuel oil flow meters as necessary to ascertain accurate operation in accordance with manufacturer’s specifications. PSNH and/or the manufacturer shall calibrate or validate accurate operation of the fuel oilflow meters during planned major turbinegenerator outages. During plannedmajor turbinegenerator outages 40 CFR 70.6

(a)(3)(i)(B)

25. NTAB1, NTAB2 NOx

Emissions (for NOx RACT) PSNH shall conduct stack testing using US

EPA Method 7E to determine the NOx emissions. PSNH shall calculate and record the NOx emission rate in lb/MMBtu on a 24-hour calendar average, lb/hr on a 24-hour calendar average, and tons/consecutive 12-month period using fuel consumption measured with fuel meters and the stack test results and operating hours or other EPA-approved methods. Every 3 years and upon written request by DES and/or EPA Env-A

1211.12 (e) and 1211.20 and Env-A 803.02 and 40 CFR 70.6 (a)(3)(i)(B)

26. NTAB1, NTAB2, NTEG1 Opacity US EPA Method 9 As necessary as determined by PSNH, DES, and/or EPA 40 CFR 70.6

(a)(3)(i)(B)

27. NTAB1, NTAB2 Sulfur Content

of Propane Fuel delivery tickets, other documentation

from the fuel supplier or testing in accordance with appropriate ASTM test methods that certify the weight-percent of sulfur for each delivery of the propane. Upon request by DES and/or EPA Env-A 809.02

(old) and EnvA 806.03 (new)

### PSNH Newington Page 33 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite 28. NTAB1, NTAB2 Operating

hours PSNH shall maintain a log of the operating

hours of each device. Monthly State Permits to OperateNos. PO-B1031 and POB-1032 and 40 CFR 70.6 (a)(3)(i)(B) 29. NTAB1, NTAB2 TSP PSNH shall conduct stack testing using US EPA Method 1-5 or 1-4 and 17 to determine the TSP emission rate in lb/MMBtu. PSNH shall calculate and record the TSP emission rate in lb/MMBtu averaged over 24-hour calendar day using fuel consumption data and EPA approved emission factors or stack test results. Stack testing upon request by DES and/or EPA 40 CFR 70.6

(a)(3)(i)(B)

30. NTAB1, NTAB2 Fuel

Consumption PSNH shall measure and record the amount of

fuel consumed using fuel flow meters and/or inventory purchase records. Monthly 40 CFR 70.6 (a)(3)(i)(B)

31. NTEG1 Operating

hours The emergency generator shall be equipped

with a non-resettable hour meter. Continuous 40 CFR 60.4209(a) 32. NTAB1, NTAB2 Fuel Flow

MetersPeriodic Monitoring PSNH shall ensure that the fuel flow metering

devices are calibrated according to manufacturer specifications or in a manner approved by the Division and at frequency consistent with manufacturer recommendations, but at a minimum every five calendar years. According to manufacturer recommendation, but at a minimum every five calendar

years 40 CFR 70.6

(a)(3)(i)(B)

33. NT1 CEM Hourly

Operating Requirements & Valid Hour of CEM Data Pursuant to Env-A 808.01 and 808.03 and 40

CFR 75.10(d), the Permittee shall ensure that the CEMS and components meet the following hourly operating requirements: A) The Permittee shall ensure that each CEM is capable of completing a minimum of one cycle of operation (sampling, analyzing, and data recording) for each successive 15-minute interval pursuant to 40 CFR 75.10(d) and pursuant to Env-A 808.03(c)(2) for each successive 5-minute period for gaseous emissions, unless a longer time period is approved in accordance with Env-A 809 Hourly 40 CFR 75.10(d) and Env-A 808.01(i) and 808.03

14 The requirements of 40 CFR 75 are less stringent t han Env-A 808. 40 CFR 75 requires hourly averages to be computed using at least one data point in each fifteen-minute quadran t of an hour, where the unit combusted fuel during that quadrant of an hour. 40 CFR 75 allows an hourly average to be computed from at least two data points separated by a minimum of 15 minutes (where the unit operates for more than one quadrant of an hour) if data are unavailable as a result of the performance of calibration, quality assurance, or preventive maintenance activities pursuant to 40 CFR 75.21 and 40 CFR Appendix B or backups of data from the data acquisition and handling system, or recertification, pursuant t o 40 CFR 75.20.

### PSNH Newington Page 34 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite B) The Permittee shall reduce all SO 2 concentrations, volumetric flow, SO 2 mass emissions, CO 2 concentration, CO 2 mass emissions (if applicable), NOx concentration, and NOx emission rate data collected by the monitors to hourly

averages. C) The Permittee shall use all valid measurements or data points collected during an hour to calculate the hourly averages. All data points collected during an hour shall be, to the extent practicable, evenly spaced over the hour. D) Failure of an SO 2 or CO 2 pollutant concentration monitor, NOx concentration monitor, flow monitor, or NOx-diluent CEMS to acquire the minimum number of data points for calculation of an hourly average shall result in the failure to obtain a valid hour of data and the loss of such component data for the entire hour. E) For a NOx-diluent monitoring system, an hourly average NOx emission rate in lb/mmBtu is valid only if the minimum number of data points is acquired by both the NOx pollutant concentration monitor and the diluent monitor (CO 2 ). F) If a valid hour of data is not obtained, the Permittee shall estimate and record emissions or flow data for the missing hour by means of the automated data acquisition and handling system, in accordance with the applicable procedure for missing data. G) Pursuant to Env-A 808.01(i), a valid hour of CEM emissions data means a minimum of 42 minutes of CEM readings taken in any calendar hour, during which the CEM is not in an out of control period and the facility is in operation. 14 H) Pursuant to Env-A 808.03(a), PSNH shall average and record the CEM data for gaseous emissions for each calendar hour. I) Pursuant to Env-A 808.03(c)(1), all CEM systems shall include a means to display instantaneous values of percent opacity and gaseous emission concentrations. 34. NT1 Stack

Volumetric PSNH shall meet the following requirements

for the stack volumetric flow measuring Continuously Env-A 808.03(d)

### PSNH Newington Page 35 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite Flow Measuring Device device:

A) All differential pressure flow monitors shall have an automatic blow-back purge system installed and in wet conditions, shall have the capability for drainage of the sensing lines; and B) The stack flow monitoring system shall have the capability for manual calibrationof the transducer while the system is online and for a zero check. 35. NT1 Minimum

Measurement Capability Requirements for CEMS The Permittee shall ensure that each CEMS is

capable of accurately measuring, recording, and reporting data, and shall not incur an exceedance of the full scale range, except as provided in 40 CFR 75 Appendix A Sections 2.1.1.5, 2.1.2.5, and 2.1.4.3. As specified by regulation 40 CFR

75.10(f)

36. NT1 COMS Hourly

Operating Requirements Pursuant to 40 CFR 75.10(d), the Permittee

shall ensure that each COMS and components meet the following hourly operating requirements: A) The Permittee shall ensure that each continuous opacity monitoring system is capable of completing a minimum of one cycle of sampling and analyzing (and recording pursuant to Env-A 808.03(c)(2) unless a longer time period is approved in accordance with Env-A 809) for each successive 10-second period and one cycle of data recording for each successive 6- minute period. B) The Permittee shall reduce all opacity data to 6-minute averages calculated in accordance with the provisions of 40 CFR 51 Appendix M, except where the SIP or operating permit requires a different averaging period, in which case the State requirement shall satisfy this Acid Rain Program requirement as shown below. C) Pursuant to Env-A 808.03(b)(1), PSNH shall average the opacity data to result in consecutive, non-overlapping 6-minute averages; and D) Pursuant to Env-A 808.03(b)(2), for units subject to the Env-A 2002.04(b) exemption, the total number of minutes in any 8-hour period where the opacity, as averaged in non-overlapping 6-minute periods, exceeds the applicable opacity standard. Sampling for successive 10- second period and recording for successive 6- minute period 40 CFR

75.10(d) and Env-A 808.03(b) and (c)

### PSNH Newington Page 36 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite E) Pursuant to Env-A 808.03(c)(1), all CEM systems shall include a means to display instantaneous values of percent opacity and gaseous emission concentrations.

37. NT1 Specific

Provisions for Monitoring SO 2 Emissions (SO 2 emissions and flow monitors) A) Pursuant to 40 CFR 75.11, the Permittee

shall meet the specific provisions for SO 2 CEMS and flow monitoring systems: PSNH shall meet the general operating requirements in 40 CFR 75.10 for an SO 2 continuous emission monitoring system and a flow monitoring system. B) During hours when the unit combusts only gaseous fuel, PSNH shall determine SO 2 emissions in accordance with 40 CFR 75.11 (e)(1), (e)(2) or (e)(3). C) Pursuant to 40 CFR 75.11 (e)(3), PSNH may determine SO 2 mass emissions using a certified SO 2 continuous monitoring system, in conjunction with a certified flow rate monitor system. However, when the unit burns any gaseous fuel that is very low sulfur fuel, as defined by 40 CFR 72.2, the SO 2 monitoring system shall be subject to the quality assurance provisions of 40 CFR 75.11 (e)(3). As specified by regulations 40 CFR 75.11

38. NT1 Specific

Provisions for Monitoring NOx Emissions A) Pursuant to 40 CFR 75.12, 75.71, and

75.72 and Env-A 3212, the Permittee shallmeet the specific provisions for NOxdiluent CEMS, including the following: 1) Meet general operating requirements in 40 CFR 75.10 for a NOx continuous emission monitoring system. The diluent gas monitor in the NOx CEMS may measure either O 2 or CO 2 concentration in the flue

gases. 2) Comply with NOx emission rate procedures contained in 40 CFR 75.12(c). B) The Permittee shall meet the annual and ozone season monitoring requirements according to 40 CFR 75.74, as applicable. Continuously 40 CFR 75.12, 75.71, and 75.72 and Env-A 3212

39. NT1 Specific

Provisions for Monitoring CO 2 Pursuant to 40 CFR 75.13, the Permittee shall

meet the specific provisions for CO 2 CEMS and flow monitoring systems. Continuously 40 CFR 75.13

### PSNH Newington Page 37 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite Emissions 40. NT1 Specific

Provisions for Monitoring Opacity Pursuant to 40 CFR 75.14, the continuous

opacity monitoring and recording system shall meet all the design, installation, equipment, and performance specifications of 40 CFR 60, Appendix B, Performance Specification 1, and all the operational and quality assurance requirements of Env-A 808 (new). Continuously 40 CFR 75.14 and Env-A 808 (new)

41. NT1 CEMS and

COMS and Alternative Monitoring Certification Pursuant to 40 CFR 75.20 and 40 CFR

75.70(d) and Env-A 3212.07 and Env-A 3212.10, the Permittee shall recertify the CEMS and COMS and alternative monitoring system whenever the Permittee makes a replacement, modification, or change to the systems or to the facility that could significantly affect the ability of the systems to accurately measure and record the requisite data. The Permittee must submit an application for recertification of the monitoring system to EPA and DES. Whenever the Permittee makes a replacement, modification, or change to the systems or to the facility that could significantly affect the ability of the systems to accurately measure and record the requisite data 40 CFR 75.20,

40 CFR 75.70(d), and 40 CFR 75 Appendix E Section 1.2 and Env-A 3212.02, 3212.06, 3212.07, 3212.09, 3212.10 and 2910.04

42. NT1 QA/QC

Requirements A) Pursuant to 40 CFR 75.21 (a)(1) and 40

CFR 75.70, the Permittee shall operate, maintain, and calibrate each CEMS according to the quality assurance and quality control procedures in 40 CFR 75 Appendix B. B) Pursuant to 40 CFR 75.21 (a)(4), PSNH is not required to perform the daily and quarterly assessments of the SO 2 monitoring system on any day or any quarter when only gaseous fuel is combusted, if the SO 2 emissions are determined in accordance with 40 CFR 75.11 (e)(1) or (e)(2). However, if any daily calibration test or linearity test is failed when the unit is combusting gaseous fuel only, the SO 2 monitoring system isout-of-control. The length of the out-ofcontrol period shall be determined according to 40 CFR 75 Appendix B Section 2.1.4 or 2.2.3. C) Pursuant to 40 CFR 75.21 (a)(5), PSNH shall perform the relative accuracy test audits of the SO 2 monitoring system only when the higher-sulfur fuel is combusted. D) Pursuant to 40 CFR 75.21(b), the Permittee shall operate, calibrate, and As specified by regulation 40 CFR 75.21

and 75.70 and 75.74

### PSNH Newington Page 38 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite maintain each COMS according to the procedures specified in the SIP, pursuant to 40 CFR 51 Appendix M. E) Pursuant to 40 CFR 75.21(c), the Permittee shall ensure that all calibration gases used to quality assure the operation of the instrumentation shall meet the definition in 40 CFR 72.2. F) Pursuant to 40 CFR 75.21(d) and (e), the Permittee shall comply with the provisions concerning consequences of audits and audit decertification. G) Within and prior to the ozone season, the Permittee shall meet the quality assurance requirements contained in 40 CFR 75.74, as applicable. 43. NT1 Reference

Test Methods for Certification and Recertification of CEMS or COMS The Permittee shall use the reference test

methods listed in 40 CFR 75.22 and included in Appendix A to 40 CFR 60 to conduct monitoring system tests for certification or recertification of CEMS and excepted monitoring systems under 40 CFR 75 Appendix E and quality assurance and quality control procedures. During certification or recertification

tests 40 CFR 75.22

44. NT1 Out-ofControl Periods A) Pursuant to 40 CFR 75.21(e)(2), whenever

a CEMS or COMS fails a quality assurance audit or any other audit, the system is out-of-control, and the Permitteeshall follow the procedures for out-ofcontrol periods in 40 CFR 75.24. B) Pursuant to Env-A 3212.10 and 2910.06, whenever any monitoring system fails to meet the quality assurance requirements of 40 CFR 75 Appendix B, PSNH shall substitute the data using the applicable procedures in 40 CFR 75, Subpart D, Appendix D or E. C) Pursuant to 75.24, if an out-of-control period occurs to a monitor or CEMS, the owner or operator shall take corrective action and repeat the tests applicable to the out of control parameter as described in 40 CFR 75 Appendix B. 1) For daily calibration error tests, an out of control period occurs when the calibration error of a pollutant concentration monitor exceeds 5.0% based upon the span value, the calibration error of a diluent gas As specified by regulation 40 CFR

75.21(e)(2) and 75.24 and Env-A 3212.10 and 2910.06 and 808.01(g)

### PSNH Newington Page 39 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite monitor exceeds 1.0% O 2 or CO 2 , or the calibration error of a flow monitor exceeds 6.0% based upon the span value, which is twice the applicable specification in 40 CFR 75 Appendix A. 2) For quarterly linearity checks, an out of control period occurs when the error in linearity at any of the three gas concentrations (low, mid-range, and high) exceeds the applicable specification in 40 CFR 75 Appendix A. 3) For relative accuracy test audits (RATAs), cylinder gas audit (CGAs), and relative accuracy audits (RAAs), an out of control period occurs when the sampling is completed and the CEMS fails the accuracy criteria until successful completion of the same audit after corrective action has occurred. D) Pursuant to Env-A 3212.10, whenever both an audit of a monitoring system and a review of the initial certification or recertification application reveal that any system or component should not have been certified or recertified because it did not meet a particular performance specification or other requirement pursuant to Env-A 800 or the applicable provisions of 40 CFR Part 75, both at the time of the initial certification or recertification application submission and at the time of the audit, the department shall issue a notice of disapproval of the certification status of such system or component. E) For the purposes of this section, an audit shall be either a field audit or an audit of any information submitted to the department or the administrator. F) The data measured and recorded by the system or component shall not be considered valid quality-assured data from the date of issuance of the notification of the disapproval of certification status until the date and time that the owner or operator completes subsequently approved initial certification or recertification tests

### PSNH Newington Page 40 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite in accordance with Env-A 3212.07(t). G) The owner or operator shall follow the initial certification or recertification procedures for each disapproved system. 45. NT1 Out of Control

Periods for Opacity Out of control period for a CEMS measuring

opacity is as follows: A) The time period beginning with the completion of the daily calibration drift check where the CD exceeds 2% opacity for 5 consecutive days, and ending with the CD check after corrective action has occurred that results in the performance specification drift limits being met; B) The time period beginning with the completion of a daily CD check preceding the daily CD check that results in the CD being greater than 5% opacity and ending with the CD check after corrective action has occurred that results in the performance specification drift limits being met; or C) The time period beginning with the completion of a quarterly opacity audit where the CEMS fails the calibration error test as specified in 40 CFR 60, Appendix B, Specification 1 and ending with successful completion of the same audit where the CEMS passes the calibration error test established after corrective action has occurred. As specified by regulation Env-A

808.01(g)(2)

46. NT1 Data

Availability and Missing Data Substitution Procedures A) The Permittee shall follow the procedures

in 40 CFR 75.30 through 75.37, 75.70(f), 75.74, and 40 CFR 75 Appendix E when a valid, quality-assured hour of data is not measured or recorded. B) Pursuant to Env-A 808.02(c)(2), PSNH shall comply with the minimum percentage data availablity requirements pursuant to Env-A 808.10(a)-(d) to meet the requirements of Env-A 3200, NOx Budget Program

. C) Pursuant to Env-A 808.10, if PSNH cannot meet the percentage data availability requirements, PSNH shall also follow the provisions of Env-A 808.10(e) – (g). D) Pursuant to 40 CFR 75.24(e), if COMS is out of control, PSNH shall follow the data availability requirements of Env-A 808.10. As specified by regulation 40 CFR 75.30

through 75.37 and 75.50(f) and 75.24(e) and 75.74 and 40 CFR 75 Appendix E Section 2.5 and Env-A 808.10 and 808.02(c)(2)

### PSNH Newington Page 41 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite 47. NT1 General CEM

Requirements A) Pursuant to 40 CFR 75.5 (b), the Permittee

must operate NT1 in compliance with the requirements of 40 CFR 75.2 through 75.75 and 40 CFR 75 Appendices A through G. B) Pursuant to 40 CFR 75.5 (d), the Permittee shall account for all emissions of SO 2 , NOx, and CO 2 in accordance with 40 CFR 75.10 through 75.19. C) Pursuant to 40 CFR 75.5 (e), the Permittee shall not disrupt the continuous emission monitoring system or other approved emission monitoring method, and thereby not monitor or record SO 2 , NOx, and CO 2 , except for periods of recertification, or periods when calibration, quality assurance, or maintenance is performed pursuant to 40 CFR 75.21 and 40 CFR 75 Appendix B. D) The CEMS shall meet the most stringent requirements of 40 CFR 75 and Env-A 808 (new). Continuously 40 CFR 75.5 and Env-A 808 (new)

48. NT1 CEMS

Performance and Audit Requirements The Permittee shall ensure that each CEMS

meets the following requirements: A) Each CEMS meets equipment, installation, and performance specifications in 40 CFR 75 Appendix A; B) Each CEMS is maintained according to the quality assurance and quality control procedures in 40 CFR 75 Appendix B; and C) Each CEMS shall record SO 2 and NOx emissions in the appropriate units of

measurement. D) PSNH shall comply with the most stringent CEM audit requirements contained in 40 CFR 75 and Env-A 808.07, General Audit Requirements , EnvA 808.08, Audit Requirements for Gaseous CEM Systems , and Env-A 808.09, Audit Requirements for Opacity CEM Systems

. As specified by regulation 40 CFR

75.10(b) and Env-A 808.07, 808.08, and 808.09 and 40 CFR 75 Appendices A and B

49. NT1 NOx Mass

Emissions – General Provisions Pursuant to Env-A 3200, NOx Budget

Program, PSNH shall comply with the provisions of 40 CFR 75 Subparts A, C, D, E, F, and G and Appendices A through G applicable to NOx concentration, flow rate, NOx emission rate and heat input, as set forth and referenced in Subpart H. As specified by regulation Env-3212.01

and 40 CFR 75.70(a)

50. NT1 NOx Mass PSNH is prohibited from the follow ing: Continuously 40 CFR

### PSNH Newington Page 42 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite EmissionsProvisionsProhibitions A) Using alternative monitoring system,

reference method, or any other alternative for the required CEMS without approval through petition process in 40 CFR 75.70(h). B) Discharging or allowing discharge of NOx emissions without accounting for all emissions in accordance with the provisions of Subpart H, except as provided in 40 CFR 75.74. C) Disrupting the CEMS or any other approved emission monitoring method, and thereby avoid monitoring and recording NOx mass emissions, except for periods of re-certification or periods when calibration, quality assurance testing, or maintenance is performed in accordance with the provisions of 40 CFR 75 Subpart H applicable to the monitoring systems under 40 CFR 75.71, except as provided in 40 CFR 75.74. D) Retiring or permanently discontinuing the use of the CEMS, or any other approved emission monitoring system except under one of the following circumstances: 1) During a period that the unit is covered by a retired unit exemption that is in effect under the State or federal NOx mass emission reduction program that adopts the requirements of Subpart H; 2) The owner or operator is monitoring NOx emissions from the affected unit with another certified monitoring system approved, in accordance with the provisions of 40 CFR 75.70(d); or 3) The designated representative submits notification of the date of certification testing of a replacement monitoring system in accordance with 40 CFR 75.61. 75.70(c)

51. NT1 NOx Mass

Emissions – Petitions for Alternatives PSNH may submit a petition to DES and EPA

requesting an alternative to any requirement of 40 CFR 75 Subpart H. Such a petition shall meet the requirements of 40 CFR 75.66 and any additional requirements established by Env-A 3200 or other applicable state or Federal NOx mass emission reduction programs that adopt the requirements of 40 Not applicable 40 CFR 75.70(h) and 40 CFR 75 Subpart E and 40 CFR 75 Appendix E and Env-A 3212.09

### PSNH Newington Page 43 TV-OP-054

Table 9 – Monitoring/Testing Requirements Item No. Device Parameter Method of Compliance Frequency of Method Regulatory

Cite CFR 75 Subpart H. 52. NT1 NOx Mass

Emissions – NOx Emission Rate and Heat Input –Oil/Gas Non-Peaking Units For an affected unit that qualifies as a nonpeaking gas-fired or non-peaking oil-fired unit, PSNH shall either: A) Meet the requirements of 40 CFR 75.71(a) and (b); or B) Meet the general operating requirements in 40 CFR 75.10 for NOx diluent continuous emission monitoring system, except as provided in accordance with 40 CFR 75 Subpart E, and use the procedures specified in 40 CFR 75 Appendix D for determining hourly heat input. The heat input apportionment provisions in Section 2.1.2 of 40 CFR 75 Appendix D shall not be used to meet the NOx mass reporting provisions of 40 CFR 75 Subpart H. As specified by regulation 40 CFR

75.71(c)

53. NT1 NOx Mass

Emissions – Annual Monitoring PSNH shall meet the requirements of 40 CFR

75 Subpart H during the entire calendar year. During the calendar year 40 CFR

75.74(a) and (b)

54. NT1 Valid

Averaging Periods for Gaseous and Opacity CEMS The number of hours of valid CEM and COM

data required for determining a valid averaging period for the different emission standard periods shall be: A) For a 3-hour emission standard period, 2 hours of valid data; B) For a 4-hour emission standard period, 3 hours of valid data; C) For an 8-hour emission standard period, 6 hours of valid data; D) For a 12-hour emission standard period, 9 hours of valid data, and E) For a 24-hour emission standard period, 18 hours of valid data. As specified by regulation Env-A 808.14

and 805.09 (old)

55. Facility wide Inventories of

Regulated Substances PSNH shall monitor the quantity of regulated

substances to ensure that facility is in compliance with the requirements of 40 CFR 68. Continuously 40 CFR 68 and 1990 CAA Section 112(r)(1)

### PSNH Newington Page 44 TV-OP-054

I. Recordkeeping Requirements

The Permittee is subject to the Recordkeeping requi rements as contained in Table 10 below:



### Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

1. Liquid Fuel Utilization Records: The Permittee shall maintain the following monthly records, or records for an alternative period as approved by DES in accordance with Env-A 912, of the liquid fuel characteristics and utilization: A) Fuel consumption (monthly and 12-month rolling average); B) Fuel type; C) Viscosity (based on generally accepted values); D) Sulfur content as percent sulfur by weight of fuel; E) BTU content per gallon of fuel; and F) Hours of operation of each fuel combustion device while operating with each type of liquid fuel, so the distribution of fuel among each combustion device can be estimated. Monthly or an alternative period as approved by DES in accordance with Env-A 912 and for fuel consumption, monthly and 12- month rolling

average NT1, NTAB1,

NTAB2, NTEG1 Env-A 901.03(a)(1)

and (c) (old) and Env-A 903.03(a)(3) and (b) (new)

2. Gaseous Fuel Utilization Records: The Permittee shall maintain the following monthly records, or records for an alternative period as approved by DES in accordance with Env-A 912, of the fuel characteristics and utilization: A) Fuel consumption (monthly and 12-month rolling average); B) Fuel type; C) Sulfur content as percent sulfur by weight of fuel or in grains per 100 cubic feet of fuel (as tested upon request by DES and/or EPA); D) Hours of operation of each fuel combustion device while operating with each type of gaseous fuel, so the distribution of fuel among each combustion device can be estimated. Monthly or an alternative period as approved by DES in accordance with Env-A 912 and for fuel consumption, monthly and 12- month rolling

average NT1, NTAB1,

NTAB2 Env-A

903.03(a)(4) (new)

3. Monitoring Plan and QA/QC Plan: A) The Permittee shall prepare and maintain a monitoring plan for the CEMS and COMS, Whenever a change occurs that could affect monitoring NT1 40 CFR 75.53 (a), (b), (e), and (f) and Env-A 808.06 and

15 On April 23, 1999 DES promulgated new Env-A 900 rules to streamline the recordkeeping and reporting requirement sections of the New Hampshire Code of Administrative Rules. Until such time that the new Env-A 900 rules are approved and adopted into the State Implementation Plan (SIP) by EPA, all Title V permi ts will be incorporating the old Env-A 900 rules (w hich became effective on November 11, 1992), unless the new Env-A 900 rules are more stringent. These recordkeeping and report ing requirements shall fall under the Permit Shield provisions as contained in Section XIII of this permit.

### PSNH Newington Page 45 TV-OP-054

Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

which contains sufficient information to demonstrate that all unit SO 2 emissions, NOx emissions, CO 2 emissions and opacity are monitored and reported. B) The Permitte shall prepare and maintain monitoring plans for other approved monitoring methods, which contain sufficient information to demonstrate that all unit NOx emissions are monitored and reported. C) The Permittee shall update the monitoring plan whenever the Permittee makes a replacement, modification or change that could affect the CEMS or COMS or other approved monitoring method. D) The Permittee shall review the QA/QC plan and all data generated by its implementation at least once each year. E) The Permittee shall revise or update the QA/QC plan, as necessary, based on the results of the annual review by conducting the following: 1) Documenting any changes made to the CEM or the monitoring method or changes to any information provided in the monitoring plan; 2) Including a schedule of, and describing, all maintenance activities that are required by the CEM manufacturer or that might have an effect on the operation of the system; 3) Describing how the audits and testing required by this part will be performed; and 4) Including examples of the reports that will be used to document the audits and tests required by this part; 5) Make the revised QA/QC plan available for on-site review by the division at any time; and 6) Within 30 days of completion of the annual QA/QC plan review, certify in writing that the owner or operator will continue to implement the source’s existing QA/QC plan or submit in writing any changes to the plan and the reasons for each change. F) The QA/QC plan shall be considered an update to the CEM monitoring plan method or annually, whichever is more frequent 3212.13 and 2910.09

### PSNH Newington Page 46 TV-OP-054

Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

required by Env-A 808.04. G) Pursuant to Env-A 3212.13(a) and Env-A 2910.09, the unit subject to acid rain emission limitations (NT1) shall comply with the requirements of 40 CFR 75.62, except the monitoring plan shall also include all of the information required by 40 CFR 75, Subpart H. 4. CEM, COMS and Other Approved Monitoring Methods Recordkeeping Requirements: A) The Permittee shall record and maintain the information required pursuant to 40 CFR 75.57, 75.58, 75.59, and 75.73(b), which includes the certification, quality assurance, and quality control records. B) The Permittee shall record and maintain CEMS and COMS records according to the most stringent requirements of Env-A 808 and 40 CFR 75. As specified by regulation NT1 40 CFR 75.57, 75.58,75.59, and 75.73 and Env-A 3212 and Env-A 903.04 (a) (new) and Env-A 800 and 40 CFR 75

5. General NOx Recordkeeping Requirements: The Permittee shall record and maintain the following information for fuel burning devices: A) Facility information, including the following: 1) Source name; 2) Source identification; 3) Physical address; and 4) Mailing address. B) Identification of fuel burning devices; C) Operating schedule for each fuel burning device identified in Condition B) above: 1) Days per calendar week during the normal operating schedule; 2) Hours per day during the normal operating schedule and for a typical ozone season day; and 3) Hours per year during the normal operating schedule. D) Type and amount of fuel burned for each fuel-burning device during normal operating conditions and for a typical ozone season day, if different from normal operating conditions, on an hourly basis in mmBtu/hr. E) Theoretical potential NOx emissions for the calculation year for each fuel burning device: 1) Annual emissions, in tons per year; and 2) Typical ozone season day emissions, in Annually and as applicable NT1, NTAB1,

NTAB2, NTEG1 Env-A 901.08 (c)

(1)–(5) (old) and Env-A 905.02 (new)

### PSNH Newington Page 47 TV-OP-054

Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

pounds per day. F) Actual NOx emissions for each fuel burning device: 1) Annual emissions, in tons per year; and 2) Typical ozone season day emissions, in pounds per day. G) Emission factors and the origin of the emission factors used to calculate the NOx emissions. 6. Sulfur Analysis Records for Fuel Oil: PSNH shall maintain delivery tickets from each fuel oil supplier for each shipment of fuel oil received. The delivery tickets shall be in a form suitable for inspection and available to the DES and/or EPA upon request. Each delivery ticket shall indicate the following: A) The name of the fuel supplier; B) The address of the fuel supplier; C) The telephone number of the fuel supplier; D) The type of fuel delivered; E) The quantity of fuel oil delivered; F) The date of delivery; and G) The maximum percent sulfur by weight of the fuel oil delivered. If the delivery tickets do not contain sulfur content of fuel delivered, the Permittee shall provide other documentation from the fuel supplier with the above information or perform testing in accordance with appropriate ASTM test methods to determine compliance with the sulfur content limitation provisions in Env-A 1604 for liquid fuels. For each delivery of fuel oil NT1, NTAB1,

NTAB2, NTEG1 Env-A 806.05

(new) and 40 CFR 70.6(a)(3)

7. Delivery Ticket for Propane: PSNH shall maintain delivery tickets from each propane supplier for each shipment of propane received. The delivery tickets shall be in a form suitable for inspection and available to the DES and/or EPA upon request. Each delivery ticket shall indicate the following: A) The name of the fuel supplier; B) The address of the fuel supplier; C) The telephone number of the fuel supplier; D) The type of fuel delivered; E) The quantity of propane delivered; F) The date of delivery. For each delivery of

propane NTAB1,

NTAB2 Env-A 806.05

(new) and 40 CFR 70.6(a)(3)

8. Natural Gas Utilization Records: PSNH shall maintain billing tickets for each natural gas supplier. The billing tickets shall be in a form Monthly NT1 State Permit toOperate No. PO-B1030

### PSNH Newington Page 48 TV-OP-054

Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

suitable for inspection and available to the DES and/or EPA upon request. Each billing ticket shall indicate the following: A) The name of the fuel supplier; B) The address of the fuel supplier; C) The telephone number of the fuel supplier; and D) The quantity of natural gas used. 9. Emergency Generator Operating Records: PSNH shall record and maintain monthly and annual records of the operating hours of the emergency generator. Monthly NTEG1 TP-B-0536

10. Auxiliary Boiler Operating Records: PSNH shall record and maintain monthly and consecutive 12-month records of the operating hours of each auxiliary boiler Monthly NTAB1, NTAB2 State Permit to

Operate No. PO-B1031 and PO-B1032 11. Multipollutant Budget and Trading Program Recordingkeeping Requirements: PSNH shall comply with the recordkeeping requirements of the multipollutant budget and trading program. As required by RSA 125-O and Env-A 2900 NT1 Env-A 2900

12. Certificate of Representation: The Permittee shall complete and retain a certificate of representation for a designated representative or an alternate designated representative including the elements pursuant to 40 CFR 72.24, Certificate of representation

. Maintain at the facility at all times NT1 40 CFR 72.24

13. Record Retention: The Permittee shall retain the records required by this permit on file for a minimum of 5 years except the certificate of representation for the designated representatives shall be kept beyond the 5-year period. 16 Retain for a minimum of 5 years or as specified Facility wide Env-A 902.01 (a) (new), Env-A 3213, 40 CFR 70.6 (a)(3)(ii)(B), and 40 CFR 72.9 (f)

14. Regulated Toxic Air Pollutant Records: The Permittee shall maintain records in accordance with the applicable method used to demonstrate compliance pursuant to Env-A 1405. Maintain at facility at all times All devices

subject to RSA 125-I and Env-A 1400 Env-A 902.01 (c)

(new) State Enforceable Only

15. Representative Actual Annual Emissions Test Recordkeeping Requirements: PSNH shall maintain records of SO 2 , NOx, CO, PM, and VOCs emissions in tons/month and tons per consecutive 12-month period for NT1. Monthly NT1 40 CFR 52.21(b)(21) and (33), dated July 1, 2002 and 40 CFR 70.6(a)(3)(ii) and Env-A 906 16. Monitoring Records : The Permittee shall maintain records of monitoring results as specified in Table 9 of this Permit including the Maintain as required in Table 9 As specified for

each monitoring record 40 CFR

70.6(a)(3)(ii)

16 Note that record retention for five years is more stringent than the three year record retention requ ired in some sections of 40 CFR 75.

### PSNH Newington Page 49 TV-OP-054

Table 10 – Applicable Recordkeeping Requirements 15



### Item No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

following: A) Visible emission/opacity test results for NT1, NTAB1, NTAB2, and NTEG; B) NOx, SO 2 , CO 2 , continuous emissions monitoring data for NT1; C) Stack volumetric flow rate for NT1; D) Heat input rate for NT1; E) PM emissions (in lb/MMBtu over a 24- hour calendar day, tons per 12-month period) for NT1, NTAB1, and NTAB2; F) Toner usage in tons/day for NT1; G) Voltage of the transformer rectifier sets (TR Sets) for NT1-PC1; H) Temperature of flue gas at the outlet of the boiler (in degrees F) for NT-PC1; I) Current to ESP for NT1-PC1; J) Spark Rate in ESP for NT1-PC1; K) Fields out of service in ESP for NT1-PC1; L) Hours of operation of the flyash reinjection system for NT1; M) NOx, SO 2 , CO, and VOC emissions for the auxiliary boilers for NTAB1 and NTAB2; N) Net electrical output (MWh) for NT1; O) Flow metering calibrations for NT1, NTAB1, and NTAB2; and P) Quantities of regulated substances above the thresholds established by EPA under 40 CFR 68.130 facilitywide. 17. Operating Scenario Records: PSNH shall maintain a record of the scenarios under which it is operating. PSNH shall specify whether operation is under normal conditions or an alternative operating scenario listed in Section VII. PSNH shall specify which alternative operating scenario is in use. Whenever operation method changes from normal operation to a specific alternative operating scenario Facility wide 40 CFR 70.6 (a)(9)

18. NSPS Recordkeeping Requirements for Internal Combustion Engines Maintain documentation from the engine manufacturer certifying that the engine complies with the applicable emissions standards stated in 40 CFR 60 Subpart IIII. Maintain Up-toDate Data NTEG1 40 CFR 60.4211 (NSPS Subpart IIII)

### PSNH Newington Page 50 TV-OP-054

J. Reporting Requirements

The Permittee is subject to the federally enforceab le reporting requirements identified in Table 11 below:



### Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite 1. NOx Reporting Requirements: The Permittee shall submit reports of the NOx records kept pursuant to the Section VIII. I. Table 9, Applicabl e Recordkeeping Requirements. Annually (no later than April 15 th

of the following year) NT1, NTAB1, NTAB2, NTEG1 Env-A 901.09

(old) and Env-A 909.03 (new)

2. State Acid Deposition Control Program Reporting Requirements: The Permittee shall submit an annual report of the fuel utilization information pursuant to Env-A 903.03 and Section VIII. I. Table 10, Applicable Recordkeeping Requirements. Annually (no later than April 15 th

of the following year) NT1 Env-A 907.02 (new)

3. CEMS Recertification Notifications and Reports: A) The Permittee shall notify EPA and DES by telephone or in writing and not later than 21 days prior to the first scheduled day of full recertification testing and at least 7 calendar days prior to the first scheduled day of partial recertification testing (when all of the tests are not required). In emergency situations when equipment fails with lost data, the Permittee may provide notice within 2 business days following the date when testing is scheduled. If the testing is rescheduled, the Permittee may notify DES and EPA by telephone or other means within 2 business days prior to the scheduled test date or the revised test date, whichever is earlier. B) Within 45 calendar days after completing all recertification tests, the Permittee shall submit to EPA and DES the electronic and hardcopy information contained in 40 CFR 75.63. C) Pursuant to Env-A 3212.14 and Env-A 2910.10, PSNH shall submit an application to DES within 45 days after completing all initial certification or recertification tests including the information required under 40 CFR 75, Subpart H. D) Pursuant to Env-A 2910.07, PSNH shall also submit written notification required pursuant to 40 CFR 75.61 to the ATS administrator. 7 days prior to partial recertification, 21 days prior to full recertification, and 45 days after all recertification tests NT1 40 CFR 75.61 (a)(1), 75.70, 75.63, and 75.73(d) and Env-A 3212 and 2910

4. Relative Accuracy Test Audit (RATA) 21 calendar days NT1 40 CFR 75.61

### PSNH Newington Page 51 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite Notification and Reports: A) The Permittee shall submit written notice to EPA and DES no later than 21 calendar days prior to the first scheduled day of testing. 17 If the testing is rescheduled, the Permittee may notify DES and EPA by telephone or other means no later than 24-hours in advance of the new testing date. DES shall require rescheduling of the RATA if staff necessary to observe the RATA are not available. B) If requested, the Permittee shall submit the quality assurance RATA reports to EPA and DES by the later of 45 days after completing a quality assurance RATA or 15 days of receiving the request. C) Pursuant to Env-A 808.07(b), PSNH shall submit to DES a written report summarizing the testing within 30 days of the completion of the test. D) Pursuant to Env-A 2910.07, PSNH shall also submit written notification required pursuant to 40 CFR 75.61 to the ATS administrator. prior to RATA (a)(5) and 75.73(d) and Env-A 3212.11 and 2910 and 808.05 and 808.07(c) and (d)

5. Performance Specification Testing Reports: A) DES shall be notified of the date or dates of the performance specification testing at least 30 days prior to the scheduled dates. B) PSNH shall submit to DES a written report summarizing the testing within 30 days of the completion of the test. 30-day notice to DES prior to test; test report to DES 30 days after the

test NT1 Env-A 808.05

6. General Audit Notification Requirements: PSNH shall notify DES at least 2 weeks prior to any planned audit or test procedure except for RATAs, where PSNH shall provide at least 30 days notice prior to the performance of the RATA. 2 weeks prior to any planned audit or test procedure and at least 30 days prior to the RATA. NT1 Env-A 808.07(c) and (e)

7. Monitoring and QA/QC Plan Submittals: The Permittee shall submit to EPA and DES a complete, electronic, up-to-date monitoring plan at the time of recertification application submission and in each electronic quarterly report, and whenever an update of the electronic monitoring plan information is required. In the recertification application, in each electronic quarterly report, and whenever an update of the electronic monitoring plan information is required NT1 40 CFR 75.62 and 75.73(d) and (e) and Env-A 808.04, 808.06, 3212 and 2910

8. Quarterly Reports: A) The Permittee shall submit to DES and EPA in 30 calendar days after the end of the NT1 40 CFR 75.64, 40 CFR 75.73(f), 40

17 Note that pursuant to Env-A 808.07, PSNH shall not ify DES at least 30 days prior to the performance o f the RATA. This requirement is less stringent than the requirement of 40 CFR 75.

### PSNH Newington Page 52 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite electronic format or other format as approved by DES and/or EPA 30 calendar days after the end of the calendar quarter the information contained in 40 CFR 75.64(a), 40 CFR 75.73(f), 40 CFR 75.74, Env-A 2912, Env-A 3212, Env-A 3214, Env-A 808.11(new), and Env-A 808.13 (new) and the following information: 1) Written report of opacity, SO 2 , NOx, and CO 2 emissions as calculated by the CEMS. 2) The 24-hour averages of the following shall be reported, whether or not an excess emission has occurred:

a. SO 2 lb/MMBtu, SO 2 ppm, and SO 2 lb/hr; b. NOx lb/MMBtu, NOx ppm, and NOx lb/hr;

c. Percent CO 2 and CO 2 lb/hr as measured by continuous monitor/recorder; d. Stack volumetric flowrate (in kscfm);

e. Load (in MW); f. Steam flow (in klbs/hr);

g. Heat input (MMBtu/hr); and h. Opacity (in percent). 3) Excess emission data recorded by the CEM system, including the following:

a. The date and time of the beginning and ending of each of excess emissions; b. The magnitude of each excess emission;

c. The specific cause of the excess emission; and d. The corrective action taken. 4) If no excess emissions have occurred, a statement to that effect; 5) For gaseous emission monitoring systems, the daily averages of the measurements made and emissions rates calculated. 6) A statement as to whether the CEM system was inoperative, repaired, or adjusted during the reporting period; 7) If the CEM system was inoperative, repaired, or adjusted during the reporting period, the following information:

a. The date and time of the beginning and ending of each period when the calendar quarter CFR 75.57(f), 40CFR 75.74, EnvA 2910, Env-A 2911, Env-A 3212, Env-A 3214, Env-A 808.11(new), Env-A 808.13 (new), and State Permit to Operate No. PO-B-1030

### PSNH Newington Page 53 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite CEM was inoperative; b. The reason why the CEM was not operating;

c. The corrective action taken; and d. The percent data availability calculated in accordance with Env-A 808.10 for each flow, diluent, or pollutant analyzer in the CEM system; 8) The date and time beginning and ending each period when the source of emissions which the CEM system is monitoring was not operating; 9) When calibration gas is used, the following information:

a. The calibration gas concentration; b. If a gas bottle was changed during the quarter: i) The date of the calibration gas bottle change; ii) The gas bottle concentration before the change; and iii) The gas bottle concentration after the change; and

c. The expiration date for all calibration gas bottles used. 10) Excess emissions of SO 2 shall be defined as an annual SO 2 emission, which exceeds the state acid rain emission limitation, as calculated from CEM data. B) The designated representative shall affirm that the component/system identification codes and formulas in the quarterly electronic reports represent current operating conditions. C) The designated representative shall submit a certification in support of each quarterly emissions monitoring report based on reasonable inquiry of those persons with primary responsibility for ensuring that all of the unit's emissions are correctly and fully monitored. D) The certification shall indicate whether the monitoring data submitted were recorded in accordance with the applicable requirements of this part including the quality control and quality assurance procedures and specifications of 40 CFR 75, and any such requirements, procedures and specifications of an applicable excepted or approved alternative monitoring method.

### PSNH Newington Page 54 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite E) For a unit with add-on emission controls, the designated representative shall also include a certification, for all hours where data are substituted following the provisions of 40 CFR 75.34(a)(1), that the add-on emission controls were operating within the range of parameters listed in the monitoring plan and that the substitute values recorded during the quarter do not systematically underestimate SO 2 or NOx emissions, pursuant to 40 CFR 75.34. F) For a unit that is reporting on a control period basis, the designated representative shall also include a certification that the NOx emission rate and NOx concentration values substituted for missing data under 40 CFR 75 Subpart D are calculated using only values from a control period and do not systematically underestimate NOx emissions. G) Pursuant to Env-A 3212.15(e) and Env-A 2910.11(a)(3), the quarterly reports shall be submitted in the manner specified in 40 CFR 75, Subpart H and 40 CFR 75.64. H) Pursuant to Env-A 3212.15(f) and Env-A 2910.11(a)(4), for NT1 the quarterly reports shall include all of the data and information required in 40 CFR Subpart H and 40 CFR Subpart G. I) Pursuant to Env-A 3214.01 and Env-A 2911.01, PSNH shall also submit emissions and operations information in electronic format as part of the quarterly reports. J) Pursuant to Env-A 3214.02, PSNH shall also submit to the NETS administrator in the quarterly reports, NOx emissions in lb/hr for every hour during the control period and cumulative quarterly and seasonal NOx emission data in pounds. K) Pursuant to Env-A 2911.02, PSNH shall also submit to the ETS administrator in the quarterly reports, SO 2 , NOx and CO 2 emissions in lb/hr for every hour during the year and cumulative quarterly and annual SO 2 , NOx and CO 2 emissions data in pounds. 9. Offset Plans for Excess SO 2 Emissions : The Permittee shall submit an offset plan no later than 60 days after the end of any calendar year during which a unit has excess SO 2 emissions. The offset plan shall contain the information pursuant to 40 60 days after the end of any calendar

year NT1 40 CFR 77.3

### PSNH Newington Page 55 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite CFR 77.3. 10. Quarterly Audit Reports: Pursuant to Env-A 808.07 (new), the Permittee shall submit to DES, a written summary report of the results of all required audits that were performed in that quarter

, in accordance with the following: A) For gaseous CEM audits, the report format shall conform to that presented in 40 CFR 60, Appendix F, Procedure 1, Section 7; and B) For opacity CEM audits, the report format shall conform to that presented in EPA-600/8- 87-025, April 1992, “Technical Assistance Document: Performance Audit Procedures for Opacity Monitors.” Quarterly, no later than 30 calendar days after the end of the quarter for which reporting is required NT1 Env-A 808.07 (new)

11. Quarterly Fuel Data Reports: The Permittee shall submit the fuel data listed in Table 10 above summarized on a monthly basis and for the previous 3 quarters in addition to the current reporting quarter. The Permittee shall submit monthly fuel usage information, including fuel type and the sulfur content by device. Quarterly, no later than 30 calendar days after the end of the quarter for which reporting is required NT1, NTAB1,

NTAB2 Env-A 910 and

State Permits toOperate Nos. POB-1030, PO-B1031, and PO-B1032

12. Annual Fuel Data Reports: The Permittee shall submit quarterly fuel usage information for the emergency generator on a calendar year basis. Annually (no later than April 15 th

of the following year) NTEG1 Env-A 910

13. Performance Test Reports : The Permittee shall submit a report to DES documenting the results of the compliance stack emission test. The compliance stack emission test report shall contain the following information: A) All the information required for the pre-test protocol as described in Env-A 802.04; B) All test data; C) All calibration data; D) Process data agreed by DES and the Permittee to be collected; E) All test results; F) A description of any discrepancies or problems that occurred during testing or sample analysis; G) An explanation of how discrepancies or problems were treated and their effect on the final results; and H) A list and description of all equations used in the test report, including sample calculations for each equation used. No later than 60 days after a performance test Facility wide Env-A 802.11 (new)

14. Net Electrical Output Reporting – T he Permittee shall report monthly data 18 of the net electrical Annually (no later than April 15 th

of NT1 Env-A 2906.05(g) and

18 Copies of the Forms EIA-906 and EIA-920 are suffic ient.

### PSNH Newington Page 56 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite output of each affected source for the calendar year and the ozone season to DES. the following year) 3207.04(k)

15. Regulated Toxic Air Pollutant Reports: The Permittee shall report actual emissions speciated by individual regulated toxic air pollutants, including a breakdown of VOC emission compounds. Annually (no later than April 15 th

of the following year) Facility wide Env-A 907.01 (new) State Enforceable Only

16. Representative Actual Annual Emissions Test Emissions Reporting Requirements: PSNH shall submit to DES annually SO 2 , NOx, CO, PM, and VOCs emissions in tons/month and consecutive 12-month period for NT1. Annually (no later than April 15 th

of the following year) NT1 40 CFR 52.21(b)(21) and (33), dated July 1, 2002 and Env-A 910 (new) 17. Semi-Annual Permit Deviation/Monitoring Reports: The Permittee shall submit a permit deviation/monitoring report of the data specified i n Table 9 of this Permit every 6 months. All required reports must be certified by a responsible official consistent with 40 CFR 70.5(d). The report shall contain a summary of the following information, unless this information was provided (or will be provided) to DES pursuant to another requirement: A) Visible emission/opacity test results for NT1, NTAB1, NTAB2, and NTEG; B) Summary showing monthly average sulfur content of the liquid and gaseous fuels from testing and/or delivery ticket and/or other documentation certifications for liquid and gaseous fuel sulfur content for NT1, NTAB1, and NTAB2; C) NOx, SO 2 , CO 2 , continuous emissions monitoring data for NT1; D) PM emissions (in lb/MMBtu over a 24-hour calendar day, tons per 12-month period) for NT1, NTAB1, and NTAB2; E) Toner usage in tons/day and an indication of the combustion of any new toners for NT1; F) Hours of operation without the flyash reinjection system for NT1; G) NOx, SO 2 , CO, and VOC emissions for the auxiliary boilers (NTAB1, NTAB2) and emergency generator (NTEG); H) Net electrical output (MWh) for NT1; I) Operating hours for the emergency generator (NTEG); and J) All instances of deviations from Permit requirements. Semiannually (by July 31 st and January 31 st

of each calendar year) Facility wide 40 CFR 70.6(a)(3)(iii)(A) and Env-A 911.05

18. Notification of Removal of Overfire Air: PSNH shall notify DES in writing within 30 calendar Within 30 calendar days of removal NT1 Env-A 910 (new)

### PSNH Newington Page 57 TV-OP-054

Table 11 – Applicable Reporting Requirements Item No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory

Cite days of removing the overfire air capabilities. 19. Prompt Reporting of Permit Deviations: The Permittee shall promptly report deviations from permit requirements by phone, fax or e-mail in accordance with Section XXVIII of this permit and Env-A 911 (new). Within 24 hours of discovery of

occurrence Facility wide Env-A 911 (new) and 40 CFR 70.6 (a)(3)(iii)(B)

20. Certification by a Responsible Official: Any report or compliance certification submitted to the DES and/or EPA shall contain certification by a responsible official of truth, accuracy, and completeness as outlined in Section XXI.B of this permit. With each submittal Facility wide 40 CFR 70.5 (d)

21. Certification by the Designated Representative or the Alternate Designated Representative: Any document submitted under the Acid Rain program shall be signed and certified by the designated representative or the alternate designated representative and include the statements pursuant to 40 CFR 72.21 (a)(1) and (2). With each submittal NT1 40 CFR 72.21

22. Emissions Reporting and Emissions Fees: The Permittee shall submit reports of actual emissions of all significant and insignificant activities and payment of emission-based fees in accordance with Env-A 700 and Section XXIII of this permit. Quarterly payment on the 15 th

day of the 2 nd quarter after actual emissions occurred; Reporting annually by April 15 th of the following year Facility wide Env-907.01 (new) and Env-A 705.03 and 705.04

23. Annual Acid Rain Compliance Certification Report: The Permittee shall submit an annual compliance certification report containing all the information required in 40 CFR 72.90(b) Annually, within 60 days after the end of the calendar year NT1 40 CFR 72.90

24. Multipollutant Budget and Trading Program Annual Compliance Certification : The Permittee shall submit an annual compliance certification for the prior year containing the information listed in Env-A 2913



### . By January 30 of each year, beginning in 2007 NT1 Env-A 2913

25. NOx Budget Program Compliance Certification : For each control period (May 1 to September 30 of each year), the Permittee shall submit an annual compliance certification containing the information listed in Env-A 3216. By November 30 of each year NT1 Env-A 3216

26. Annual Title V Compliance Certification: The Permittee shall submit an annual compliance certification in accordance with Section XXI of this permit. Annually (no later than April 15 th of the following year) Facility wide 40 CFR 70.6(c)(1)



### IX. Requirements Currently Not Applicable

The Permittee did not identify any requirements tha t are not applicable to the facility.

### PSNH Newington Page 58 TV-OP-054



## General Title V Operating Permit Conditions

X. Issuance of a Title V Operating Permit

This Permit is issued in accordance with the provis ions of Part Env-A 609. In accordance with 40 CFR 70.6(a)(2), this Permit shall expire on the dat e specified on the cover page of this Permit, which shall not be later than the date five (5) years aft er issuance of this Permit.

Permit expiration terminates the Permittee's right to operate the Permittee's emission units, control equipment or associated equipment covered by this p ermit, unless a timely and complete renewal application is submitted at least 6 months before t he expiration date.



### XI. Title V Operating Permit Renewal Procedures

Pursuant to Env-A 609.07(b), an application for ren ewal of this Permit shall be considered timely if it is submitted to the Director at least six months prior to the designated expiration date of this Permit.



### XII. Application Shield

Pursuant to Env-A 609.08, if an applicant submits a timely and complete application for the issuance or renewal of a Permit, the failure to have a Permi t shall not be considered a violation of this part until the Director takes final action on the applic ation.



### XIII. Permit Shield

A. Pursuant to Env-A 609.09(a), a permit shield shall provide that:

1. For any applicable requirement or any state requ irement found in the New Hampshire Rules Governing the Control of Air Pollution specifically included in this Permit, compliance with the conditions of this Permit shall be deemed compl iance with said applicable requirement or said state requirement as of the date of permit iss uance; and

2. For any potential applicable requirement or any potential state requirement found in the New Hampshire Rules Governing the Control of Air Pollut ion specifically identified in this Title V Operating Permit Section IX as not applicable to the stationary source or area source, the Permittee need not comply with the specifically ide ntified federal or state requirements.



### B. The permit shield identified in Section XIII.A. of this Permit shall apply only to those conditions incorporated into this Permit in accordance with th e provisions of Env-A 609.09(b). It shall not apply to certain conditions as specified in Env-A 6 09.09(c) that may be incorporated into this Permit following permit issuance by DES.

### PSNH Newington Page 59 TV-OP-054

C. If a Title V Operating Permit and amendments theret o issued by the DES does not expressly include or exclude an applicable requirement or a s tate requirement found in the NH Rules Governing the Control of Air Pollution, that applic able requirement or state requirement shall not be covered by the permit shield and the Permittee s hall comply with the provisions of said requirement to the extent that it applies to the Pe rmittee.



### D. If the DES determines that this Title V Operating P ermit was issued based upon inaccurate or incomplete information provided by the applicant or Permittee, any permit shield provisions in said Title V Operating Permit shall be void as to t he portions of said Title V Operating Permit which are affected, directly or indirectly, by the inaccurate or incomplete information.



### E. Pursuant to Env-A 609.09(f), nothing contained in S ection XIII of this Permit shall alter or affect the ability of the DES to reopen this Permit for ca use in accordance with Env-A 609.19 or to exercise its summary abatement authority.



### F. Pursuant to Env-A 609.09(g), nothing contained in t his section or in any title V operating permit issued by the DES shall alter or affect the followi ng:

1. The ability of the DES to order abatement requiring immediate compliance with applicable requirements upon finding that there is an imminent and substantial endangerment to public health, welfare, or the environment;

2. The state of New Hampshire's ability to bring an en forcement action pursuant to RSA 125- C:15,II;

3. The provisions of section 303 of the CAA regarding emergency orders including the authority of the EPA Administrator under that section;

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

5. The applicable requirements of the acid rain progra m, consistent with section 408(a) of the CAA;

6. The ability of the DES or the EPA Administrator to obtain information about a stationary source, area source, or device from the owner or op erator pursuant to section 114 of the CAA; or

7. The ability of the DES or the EPA Administrator to enter, inspect, and/or monitor a stationary source, area source, or device.



### XIV. Reopening for Cause

The Director shall reopen and revise a Title V Oper ating Permit for cause if any of the circumstances contained in Env-A 609.19(a) exist. In all proceed ings to reopen and reissue a Title V Operating Permit, the Director shall follow the provisions sp ecified in Env-A 609.19(b) through (g).

### PSNH Newington Page 60 TV-OP-054

XV. Administrative Permit Amendments

A. Pursuant to Env-A 612.01, the Permittee may impleme nt the changes addressed in the request for an administrative permit amendment as defined in Pa rt Env-A 100 immediately upon submittal of the request.



### B. Pursuant to Env-A 612.01, the Director shall take f inal action on a request for an administrative permit amendment in accordance with the provisions of Env-A 612.01(b) and (c).



### XVI. Operational Flexibility

A. Pursuant to Env-A 612.02, the Permittee subject to and operating under this Title V Operating Permit may make changes involving trading of emissi ons, off-permit changes, and section 502(b)(10) changes at the permitted stationary sour ce or area source without filing a Title V Operating Permit application for and obtaining an a mended Title V Operating Permit, provided that all of the following conditions are met, as we ll as conditions specified in Section XVI. B through E of this permit, as applicable. DES has in cluded permit terms authorizing the generation of DERs.

1. The change is not a modification under any provi sion of Title I of the CAA;

2. The change does not cause emissions to exceed th e emissions allowable under the Title V operating permit, whether expressed therein as a ra te of emissions or in terms of total emissions;

3. The owner or operator has obtained any temporary permit required by Env-A 600;

4. The owner or operator has provided written notif ication to the director and administrator of the proposed change and such written notification i ncludes:

a) The date on which each proposed change will occur o r has occurred;

b) A description of each such change;

c) Any change in emissions that will result;

d) A request that the operational flexibility procedur es be used; and

e) The signature of the responsible official, consiste nt with Env-A 605.04;

5. The change does not exceed any emissions limitation s established under any of the following:

a) The New Hampshire Code of Administrative Rules, Env -A 100-4300;

### PSNH Newington Page 61 TV-OP-054

b) The CAA; or

c) This Title V Operating Permit; and

6. The Permittee, DES, and EPA have attached each writ ten notice required above to their copy of this Title V Operating Permit.



### B. For changes involving the trading of emissions, the Permittee must also meet the following conditions:

1. The Title V Operating Permit issued to the stationa ry source or area source already contains terms and conditions including all terms and condit ions which determine compliance required under 40 CFR 70.6(a) and (c) and which all ow for the trading of emissions increases and decreases at the permitted stationary source or area source solely for the purpose of complying with a federally-enforceable e missions cap that is established in the permit independent of otherwise applicable requirem ents;

2. The owner or operator has included in the applicati on for the Title V Operating Permit proposed replicable procedures and proposed permit terms which ensure that the emissions trades are quantifiable and federally enforceable f or changes to the Title V Operating Permit which qualify under a federally- enforceable emissi ons cap that is established in the Title V Operating Permit independent of the otherwise appli cable requirements;

3. The Director has not included in the emissions trad ing provision any devices for which emissions are not quantifiable or for which there a re no replicable procedures to enforce emissions trades; and

4. The written notification required above is made at least 7 days prior to the proposed change and includes a statement as to how any change in em issions will comply with the terms and conditions of the Title V Operating Permit.



### C. For off-permit changes, the Permittee must also mee t the following conditions:

1. Each off-permit change meets all applicable require ments and does not violate any existing permit term or condition;

2. The written notification required above is made con temporaneously with each off-permit change, except for changes that qualify as insignif icant under the provisions of Env-A 609.04;

3. The change is not subject to any requirements under Title IV of the CAA and the change is not a Title I modification;

4. The Permittee keeps a record describing the changes made at the source which result in emissions of a regulated air pollutant subject to a n applicable requirement, but not otherwise

### PSNH Newington Page 62 TV-OP-054

regulated under this Permit, and the emissions resu lting from those changes; and

5. The written notification required above includes a list of the pollutants emitted and any applicable requirement that would apply as a result of the change.



### D. For section 502(b)(10) changes, the Permittee must also meet the following conditions:

1. The written notification required above is made at least 7 days prior to the proposed change; and

2. The written notification required above includes an y permit term or condition that is no longer applicable as a result of the change.



### E. Pursuant to Env-A 612.02(f), the off-permit change and section 502(b)(10) change shall not qualify for the permit shield under Env-A 609.09.



### XVII. Minor Permit Amendments

A. Pursuant to Env-A 612.05 prior to implementing a mi nor permit modification, the Permittee shall submit a written request to the Director in accorda nce with the requirements of Env-A 612.05(b).



### B. The Director shall take final action on the minor p ermit amendment request in accordance with the provisions of Env-A 612.05(c) through (g).



### C. Pursuant to Env-A 612.05(h), the permit shield spec ified in Env-A 609.09 shall not apply to minor permit amendments under Section XVII. of this Permit.



### D. Pursuant to Env-A 612.05(a), the Permittee shall be subject to the provisions of RSA 125-C:15 if the change is made prior to the filing with the Dir ector a request for a minor permit amendment.



### XVIII. Significant Permit Amendments

A. Pursuant to Env-A 612.06, a change at the facility shall qualify as a significant permit amendment if it meets the criteria specified in Env -A 612.06(a)(1) through (5).



### B. Prior to implementing the significant permit amendm ent, the Permittee shall submit a written request to the Director which includes all the info rmation as referenced in Env-A 612.06(b) and (c) and shall be issued an amended Title V Operatin g Permit from the DES. The Permittee shall be subject to the provisions of RSA 125-C:15 if a r equest for a significant permit amendment is not filed with the Director and/or the change is ma de prior to the issuance of an amended Title V Operating Permit.



### C. The Director shall take final action on the signifi cant permit amendment in accordance with the Procedures specified in Env-A 612.06(d), (e) and (f ).

### PSNH Newington Page 63 TV-OP-054

XIX. Title V Operating Permit Suspension, Revocation or Nullification

A. Pursuant to RSA 125-C:13, the Director may suspend or revoke any final permit issued hereunder if, following a hearing, the Director det ermines that:

1. The Permittee has committed a violation of any appl icable statute or state requirement found in the New Hampshire Rules Governing the Control of Air Pollution, order or permit condition in force and applicable to it; or

2. The emissions from any device to which this Permit applies, alone or in conjunction with other sources of the same pollutants, presents an i mmediate danger to the public health.



### B. The Director shall nullify any Permit, if following a hearing in accordance with RSA 541-A:30, II, a finding is made that the Permit was issued in whole or in part based upon any information proven to be intentionally false or misleading.



### XX. Inspection and Entry

EPA and DES personnel shall be granted access to th e facility covered by this Permit, in accordance with RSA 125-C:6,VII, for the purposes of: inspecti ng the proposed or permitted site; investigating a complaint; and assuring compliance with any applica ble requirement or state requirement found in the NH Rules Governing the Control of Air Pollution and/or conditions of any Permit issued pursuant to Chapter Env-A 600.



### XXI. Certifications

A. Compliance Certification Report

In accordance with 40 CFR 70.6(c) the Responsible O fficial shall certify, for the previous calendar year, that the facility is in compliance w ith the requirements of this permit. The report shall be submitted annually, no later than April 15 th of the following year. The report shall be submitted to the DES and to the U.S. Environmental Protection Agency - New England Region



### . The report shall be submitted in compliance with th e submission requirements below.

In accordance with 40 CFR 70.6(c)(5), the report shall describe:

1. The terms and conditions of the Permit that are the basis of the certification;

2. The current compliance status of the source with re spect to the terms and conditions of this Permit, and whether compliance was continuous or in termittent during the reporting period;

3. The methods used for determining compliance, includ ing a description of the monitoring, record keeping, and reporting requirements and test methods; and

4. Any additional information required by the DES to d etermine the compliance status of the

source.

### PSNH Newington Page 64 TV-OP-054

B. Certification of Accuracy Statement

All documents submitted to the DES shall contain a certification of accuracy statement by the responsible official of truth, accuracy, and comple teness. Such certification shall be in accordance with the requirements of 40 CFR 70.5(d) and contain the following language:

"I am authorized to make this submission on behalf of the facility for which the submission is made. Based on information and belief formed after reasonable inquiry, I certify that the statem ents and information in the enclosed documents are to the best of my knowledge and belief true, accurate and complete. I am aware that there are s ignificant penalties for submitting false statements and information or omit ting required statements and information, including the possibili ty of fine or imprisonment."

All reports submitted to DES (except those submitte d as emission based fees as outlined in Section XXIII of this Permit) shall be submitted to the following address:

New Hampshire Department of Environmental Services

Air Resources Division 29 Hazen Drive P.O. Box 95 Concord, NH 03302-0095 ATTN: Section Supervisor, Compliance Bureau

All reports submitted to EPA shall be submitted to the following address:

Office of Environmental Stewardship Director Air Compliance Program United States Environmental Protection Agency

1 Congress Street Suite 1100 (SEA) Boston, MA 02114-2023 ATTN: Air Compliance Clerk

### PSNH Newington Page 65 TV-OP-054

XXII. Enforcement

Any noncompliance with a permit condition constitut es a violation of RSA 125-C:15, and, as to the conditions in this permit which are federally enfor ceable, a violation of the Clean Air Act, 42 U.S.C. Section 7401 et seq., and is grounds for enforcemen t action, for permit termination or revocation, or for denial of an operating permit renewal applicati on by the DES and/or EPA. Noncompliance may also be grounds for assessment of administrative, c ivil or criminal penalties in accordance with RSA 125-C:15 and/or the Clean Air Act. This Permit doe s not relieve the Permittee from the obligation to comply with any other provisions of RSA 125-C, the New Hampshire Rules Governing the Control of Air Pollution, or the Clean Air Act, or to obtai n any other necessary authorizations from other governmental agencies, or to comply with all other applicable Federal, State, or Local rules and regulations, not addressed in this Permit.

In accordance with 40 CFR 70.6 (a)(6)(ii) a Permitt ee shall not claim as a defense 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.



### XXIII. Emission-Based Fee Requirements

A. The Permittee shall pay an emission-based fee quart erly for this facility as calculated each calendar year pursuant to Env-A 705.03.



### B. The Permittee shall determine the total actual quar terly emissions from the facility to be included in the emission-based multiplier specified in Env-A 705.03(a) for each calendar quarter in accordance with the methods specified in Env-A 616.



### C. The Permittee shall calculate the quarterly emissio n-based fee for each calendar year in

accordance with the procedures specified in Env-A 7 05.03 and the following equation: Where:

FEE = The quarterly emission-based fee for each ca lendar quarter as specified in Env-A

705. E = The emission-based multiplier is based on the calculation of total quarterly

emissions as specified in Env-A 705.02 and the prov isions specified in Env-A 705.03(a). DPT = The dollar per ton fee the DES has specified in Env-A 705.03(b). CPIm= The Consumer Price Index Multiplier as calcu lated in Env-A 705.03(c). ISF = The Inventory Stabilization Factor as speci fied in Env-A 705.03(d).



### D. The Permittee shall contact the DES each calendar y ear for the value of the Inventory Stabilization Factor. ISF * CPIm * DPT * E = FEE

### PSNH Newington Page 66 TV-OP-054

E. The Permittee shall contact the DES each calendar y ear for the value of the Consumer Price Index Multiplier.



### F. The Permittee shall submit, to the DES, payment of the emission-based fee and a summary of the calculations referenced in Sections XXIII.B. and C of this Permit for each calendar quarter. The total emission-based fee shall be paid in four equa l installments on a quarterly basis. The quarterly payments shall be made in accordance with Env-A 705.04 on the 15 th 

### day of the following months:

1. July of the year to which the fee applies (e.g., fe es for emissions occurring during January, February, March 2007 are due July 15, 2007);

2. October of the year to which the fee applies (e.g., fees for emissions occurring during April, May, June 2007 are due on October 15, 2007);

3. January of the following year (e.g., fees for emiss ions occurring during July, August, September 2007 are due on January 15, 2008);

4. April of the following year (e.g., fees for emissio ns occurring during October, November, December 2007 are due on April 15, 2008).

The Permittee shall pay any remaining balance of th e total emission-based fee for the year no later than April 15 th 

### of the following year.

The emission-based fee and summary of the calculati ons shall be submitted to the following address:

New Hampshire Department of Environmental Services Air Resources Division 29 Hazen Drive P.O. Box 95 Concord, NH 03302-0095 ATTN.: Emissions Inventory



### G. The DES shall notify the Permittee of any under pay ments or over payments of the annual emission-based fee in accordance with Env-A 705.05.



### XXIV. Duty To Provide Information

In accordance with 40 CFR 70.6 (a)(6)(v), upon the DES's written request, the Permittee shall furnish, within a reasonable time, any information necessary for determining whether cause exists for modifying, revoking and reissuing, or terminating t he Permit, or to determine compliance with the Permit. Upon request, the Permittee shall furnish to the DES copies of records that the Permittee is required to retain by this Permit. The Permittee m ay make a claim of confidentiality as to any information submitted pursuant to this condition in accordance with Part Env-A 103 at the time such information is submitted to DES. DES shall evaluat e such requests in accordance with the provisions of Part Env-A 103.

### PSNH Newington Page 67 TV-OP-054

XXV. Property Rights

Pursuant to 40 CFR 70.6 (a)(6)(iv), this Permit doe s not convey any property rights of any sort, or any exclusive privilege.



### XXVI. Severability Clause

Pursuant to 40 CFR 70.6 (a)(5), the provisions of t his Permit are severable, and if any provision of this Permit, or the application of any provision of this Permit to any circumstances is held invalid, the application of such provision to other circumst ances, and the remainder of this Permit, shall not be affected thereby.



### XXVII. Emergency Conditions

Pursuant to 40 CFR 70.6 (g), the Permittee shall be shielded from enforcement action brought for noncompliance with technology based 19 

### emission limitations specified in this Permit as a result of an

emergency 20 

### . In order to use emergency as an affirmative defe nse to an action brought for noncompliance, the Permittee shall demonstrate the affirmative defense through properly signed, contemporaneous operating logs, or other relevant e vidence that:



### A. An emergency occurred and that the Permittee can id entify the cause(s) of the emergency;



### B. The permitted facility was at the time being proper ly operated;



### C. During the period of the emergency, the Permittee t ook all reasonable steps as expeditiously as possible, to minimize levels of emissions that exce eded the emissions standards, or other requirements in this Permit; and



### D. The Permittee submitted notice of the emergency to the DES within two (2) business days of the time when emission limitations were exceeded due to the emergency. This notice must contain a description of the emergency, any steps taken to mi tigate emission, and corrective actions taken.

19 Technology based emission limits are those establis hed on the basis of emission reductions achievable with various control measures or process changes (e.g., a new source performance standard) rather than thos e established to attain health based air quality standards.

20 An "emergency" means any situation arising from sud den and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation would require immediate corrective actio n to restore normal operation, and that causes the source to exc eed a technology based limitation under the permit, due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include nonc ompliance to the extent caused by improperly designed equipment, lack of preventative maintenance, careless or impr oper operations, operator error or decision to keep oper ating despite knowledge of any of these things.

### PSNH Newington Page 68 TV-OP-054

XXVIII. Permit Deviation

In accordance with 40 CFR 70.6(a)(3)(iii)(B), the P ermittee shall report to the DES all instances of deviations from Permit requirements, by telephone, fax, or e-mail (pdeviations@des.state.nh.us) within 24 hours of discovery of such deviation. Th is report shall include the deviation itself, including those attributable to upset conditions as defined in this Permit, the probable cause of such deviations, and any corrective actions or preventat ive measures taken.

Within 10 days of discovery of the permit deviation , the Permittee shall submit a written report including the above information as well as the foll owing: preventive measures taken to prevent future occurrences; date and time the permitted dev ice returned to normal operation; specific device, process or air pollution control equipment that con tributed to the permit deviation; type and quantity of excess emissions emitted to the atmosphere due t o permit deviation; and an explanation of the calculation or estimation used to quantify excess e missions.

Said Permit deviation shall also be submitted in wr iting to the DES in the semi-annual summary report of monitoring and testing requirements due J uly 31st and January 31st of each calendar year. Deviations are instances where any Permit condition is violated and has not already been reported as an emergency pursuant to Section XXVII of this Perm it.

Reporting a Permit deviation is not an affirmative defense for action brought for noncompliance.

### PSNH Newington Page 69 TV-OP-054



## Federal Acid Rain Requirements

XXIX. Phase II Acid Rain Permit Application

The attached Phase II Acid Rain Permit application, dated January 12, 2004, is hereby incorporated by reference into this permit. The Permittee shall comply with the requirements set forth in the Phase II Acid Rain Permit Application and this perm it.



### XXX. General Acid Rain Provisions

The Permittee shall comply with the applicable prov isions of 40 CFR 72, Permit Regulations 

### ; 40 CFR 73, Sulfur Dioxide Allowance System 

### ; 40 CFR 75, Continuous Emission Monitoring 

### ; and 40 CFR 77, Excess Emissions



### .