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

# Temporary Permit

Permit No: TP

- 0008 Date Issued: March 9, 2009 Date Reissued: August 2, 2010, July 8, 2011, July 18, 2012, August 14, 2013 & September 26, 2014 Sig nificant Permit Amendment: December 4 , 2014

This certifies that:

Northeast Utilities Public Service of New Hampshire
780 North Commercial Street Manchester, NH 03101

has been granted a Temporary Permit for a

Flue Gas Desulphurization System

at the f ollowing facility and location:

Public Service of New Hampshire
Merrimack Station
97 River Rd. Bow, NH 03304

- 3314

Facility ID No: 3301300026
Application No. Date Received Purpose

FY07

- 0103 June 7, 2007 Temporary Permit TP

- 0008

10

- 0136 June 30, 2010 Re quest for the reissuance of Temporary Permit

11

- 0078 June 3, 2011 Request for the reissuance of Temporary Permit

12

- 0113 July 2, 2012 Request for the reissuance of Temporary Permit

13

- 0088

14

- 0283 June 13, 2013

July 21, 2014 Request for the reissuance o f Temporary Permit

Significant Permit Amendment which includes devices that emit air pollutants into the ambient air as set forth in the permit application referenced above which was filed with the New Hampshire Department of Environmental Services, Air Resources Division (Division) in accordance with RSA 125

- C of the New Hampshire Laws. Request for permit renewal is due to the Division at least 90 days prior to expiration of this permit and must be accompanied by the appropriate permit application form s. This permit is valid upon issuance and expires on September 30, 2015

.

________________________________ Director, Air Resources Division

## TABLE OF CONTENTS

A BBREVIATIONS

................................ ................................ ................................ ................................ ............... 3

FACILITY SPECIFIC TE MPORARY PERMIT CONDI TIONS

................................ ................................ .. 5

I. F ACILITY 

### D ESCRIPTION OF 

### O PERATIONS



### ................................ ................................ ................................ ..... 5
II. P ROJECT 

### D ESCRIPTION



### ................................ ................................ ................................ ............................... 5
III. P ERMITTED 

### A CTIVITIES



### ................................ ................................ ................................ .............................. 6
IV. S IGNIFICANT 

### A CTIVITIES 

### I DENTIFICATIO N AND 

### S TACK 

### C RITERIA



### ................................ ................................ 7
A. Significant Activity Identification

................................ ................................ ................................ ........... 7
B. Stack Criteria

................................ ................................ ................................ ................................ ......... 9
V. P OLLUTION 

### C ONTROL 

### E QUIPMENT 

### /M ETHOD 

### I DENTIFICATION



### ................................ ................................ .. 10
VI. A PPLICABLE 

### R EQUIREMENTS



### ................................ ................................ ................................ .................... 10
A. Operational and Emissio n Limitations

................................ ................................ ................................ 10

B. Initial Compliance Demonstration Requirements

................................ ................................ ................ 17
C. Monitoring/Testing Requirements

................................ ................................ ................................ ........ 22

D. Recordkeeping Requirements

................................ ................................ ................................ ............... 25

E. Reporting Requirements

................................ ................................ ................................ ....................... 27
VII. A DMINISTRATIVE 

### P ERMIT 

### A MENDMENTS



### ................................ ................................ ................................ . 29
VIII. M INOR 

### P ERMIT 

### A MENDMENTS



### ................................ ................................ ................................ ................. 29
IX. S IGNIFICANT 

### P ERMIT 

### A MENDMENTS



### ................................ ................................ ................................ ......... 30
X. E MISSION



### - B ASED 

### F EE 

### R EQUIREMENTS



### ................................ ................................ ................................ ..... 30
XI. P ERMIT 

### D EVIATION



### ................................ ................................ ................................ ................................ .. 32

### Public Service of New Hampshire Page 3
Merrimack Station Temporary Permit TP

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## ABBREVIATIONS

AAL Ambient Air Limit
AEL Alternative Emission Limit
AP

- 42 Compilat ion 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 Ac t, 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 Opac ity Monitoring System
CTM Conditional Test Method
DES New Hampshire Department of Environmental Services

DER Discrete Emission Reduction
Env

- A New Hampshire Code of Administrative Rules

– Air Resources Division
Env

- Wm New Hampshire Code of Administrative R ules

– Waste Management Division
ECS Emission Control System
ERC Emission Reduction Credit
ETS Emissions Tracking System
FGD Flue Gas Desulphurization gal/hr Gallons per hour
HAP Hazardous Air Pollutant
HHV High Heat Value
HCl Hydrochloric acid
hr Hour
ksc fm 1,000 standard cubic feet per minute
kGal 1,000 gallons
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 Achieva ble Control Technology
mmBtu Million British Thermal Units
MMCF Million Cubic Feet
MW Megawatt

### Public Service of New Hampshire Page 4
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## ABBREVIATIONS (cont.)

NAAQS National Ambient Air Quality Standard
NG Natural Gas NHDES (or DES) New Hampshire Department of Environmental Services
NMOC Non

- Meth ane Organic Compound
NO
x 

### Oxides of Nitrogen
NSPS New Source Performance Standard
NSR New Source Review

PM Particulate Matter

PM 10 

### Particulate Matter less than 10 microns diameter

ppm part per million ppmdv part per million by dry volume
PSD Prevention of S ignificant Deterioration
PSI Pounds per Square Inch

PTE Potential to Emit
RACT Reasonably Available Control Technology
RTAP Regulated Toxic Air Pollutant
SIP State Implementation Plan
SO 2 

### Sulfur Dioxide tph tons per hour
TSP Total Suspended Particulate Ma tter
TPY Tons per Year
USEPA United States Environmental Protection Agency
VOC Volatile Organic Compound

### Public Service of New Hampshire Page 5
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## Facility Specific Temporary Permit Conditions

I. Facility Description of Operations

Public Service of New Hampshire

- Merrimack Station is a fossil fuel

- fired electricity generating facility, owned and operated by Public Service of New Hampshire (PSNH), a subsidiary of Northeast Utilities. The facility is comprised of two utility boilers, two combustion turbines operating as load shaving units, an emerge ncy generator, an emergency boiler, and coal handling systems including primary and secondary coal crushers, coal piles, coal conveyor systems, and coal unloading from railcars. The facility operations also include various activities that are classified a s insignificant or exempt activities.

The two utility boilers (MK1 and MK2) primarily burn bituminous coal, the two combustion turbines primarily burn No. 1 fuel oil or JP

- 4, the emergency generator burns No. 2 fuel oil or diesel fuel, and the emergency boiler burns No. 2 fuel oil or diesel fuel. PSNH

– Merrimack Station ignites the utility boilers with No. 2 fuel oil.

Each boiler stack is equipped with continuous emissions monitoring systems (CEMS) and a continuous opacity monitoring system (COMS). P SNH

– Merrimack Station has installed control equipment and implemented operational changes to reduce emissions, including trials of low sulfur coals to control sulfur dioxide (SO 2 

### ) emissions, selective catalytic reduction (SCR) systems to control nitrogen oxide (NO
x 

### ) emissions, and electrostatic precipitators (ESP) to control particulate matter (PM) emissions. PSNH has also initiated mercury reduction trials including carbon injection and the use of low mercury coals.

PSNH

– Merrimack Station operates a fly ash reinjection system in each of the two Boilers.

II. Project Description

The Owner has filed a Temporary Permit application requesting to install a wet, limestone

- based flue gas desulphurization (FGD) system to control mercury emissions from Electric Gen erating Units MK1 and MK2. The FGD system will also provide a co

- benefit by removing sulfur dioxide emissions. The application was filed in accordance with RSA 125

- O:13,I, which requires this facility to file an initial permit application by June 8, 2007 . This permit establishes limits on mercury and sulfur dioxide emissions based on the requirements of RSA 125

- O:13 and 40 CFR 51.308, respectively. This permit also contains applicable monitoring, performance testing, recordkeeping and reporting requirem ents for the purpose of ensuring that the facility can comply with the requirements of RSA 125

- O:13 and 40 CFR 51.308.

Once the FGD system is constructed and operational, initial stack testing on MK1 and MK2 will be used to (1) determine whether the faci lity complies with the applicable mercury and sulfur dioxide limits; and (2) to establish any necessary operating parameters to ensure that the mercury and sulfur dioxide limits will be met on an ongoing basis. Periodic stack testing and/or continuous emi ssion monitors will be used to verify that the parameters used to monitor and control mercury and sulfur
dioxide emissions continue to be valid.

### Public Service of New Hampshire Page 6
Merrimack Station Temporary Permit TP

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The facility currently operates under the application shield provisions of Env

- A 609.08, Application
Shield an d in accordance with permits FP

- T

- 0054 (MK1), TP

- B

- 0462 (MK2), PO

- B

- 00 34 (CT1),
PO

- B

- 00 35 (CT2), PO

- B

- 1788 (Emergency Generator), TP

- B

- 0490 (Emergency Boiler), PO

- B

- 2416 (Primary Coal Crusher) and PO

- B

- 2417 (Secondary Coal Crusher), which are currently in the process of being streamlined into a Title V Operating Permit. These previously issued permits will be referenced as “Previous Permits” throughout this document. This Temporary Permit includes new conditions associated with this project, and where nec essary, identifies conditions of the Previous Permits that will either be modified or superseded as a result of this project. All terms and conditions of the Previous Permits not specifically identified in this permit remain in effect unchanged. Upon iss uance of this permit, the Owner shall comply with all unchanged terms and conditions of the Previous Permits and all terms and conditions of this permit.

Application 14

- 0283 Significant Permit Amendment

On June 20, 2014, DES has proposed to amend Temporar y Permit TP

- 0008 because the permit did not include applicable requirements of the Code of Federal Regulations (CFR), 40 CFR Part 60 Subpart OOO, Standards of Performance for Nonmetallic Mineral Processing Plants (Subpart OOO), for the Limestone Processin g and Handling System. On July 21, 2014, PSNH has consented to the proposal to amend the permit and submitted an application. The purpose of this permitting project is to add the applicable requirements of Subpart OOO for the limestone handling and

proces sing system. The amended permit also removes permit conditions restricting the limestone processing and handling system to using only one of two wet ball mills at a time, and limiting total throughput to less than 25 t ons p er h our

.

III. Permitted Activities

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

### Public Service of New Hampshire Page 7
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IV. Significant Activities Identification and Stack Criteria

A. Significant Activity Identification The activities identified in Table 1 below are subject to and regulated by this Permit:

Table 1

- Significant Activity Identification
Emission
Unit
Number Description of

Emission Unit M aximum Gross Heat Input Rating Maximum Operating Conditions

MK1 Steam Generating

Unit 1 (Installed in 1960) Front wall firing Bituminous Coal: 1,238

MMBtu/hr a. Maximum fuel consumption rate of bituminous coal shall be limited to 48.5 tons/hr, not to exceed 425,289 tons during any consecutive 12 month period 1

. b. No. 2 fuel oil consumption shall be limited to 1,656 gallons per hour, not exceed 14.5 million gallons during any consecutive 12 month period 2

. MK2 Steam Generating

Unit 2 (Installed in 1968) Opposed wall firing Bituminous Coal: 3,473

MMBtu/hr a. Maximum fuel consumption rate of bituminous coal shall be limited to 136.2 tons/hr, not to exceed 1,193,078 tons during any consecutive 12 month period 3

. b. No. 2 fuel oil consumption shall be limite d to 1,656 gallons per hour, not exceed 14.5 million gallons during any consecutive 12 month period 4

. MKLC1 Limestone

Processing and Handling System Not Applicable See Table 1A below.

1 The heating value of bituminous coal is assumed to be 12,750 Btu/lb. The fuel consumption limits may vary based on the actual heat
content of the fuel burned.

2 No. 2 fuel oil is used to ignite individual fires before establishing the main coal fires. The heating value of No. 2 fuel oil is assumed
to be 14 0,000 Btu/gal. The fuel consumption limits may vary based on the actual heat content of the fuel burned.

3 The heating value of bituminous coal is assumed to be 12,750 Btu/lb. The fuel consumption limits may vary based on the actua l heat
content of the f

uel burned.

4 No. 2 fuel oil is used to ignite individual fires before establishing the main coal fires. The heating value of No. 2 fuel oil is assumed to be 140,000 Btu/gal. The fuel consumption limits may vary based on the actual heat content of the fu el burned.

### Public Service of New Hampshire Page 8
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Table 1A

- Limestone Processing and Handling System 5

Equipment
ID Equipment Description Year
Installed Design

Capacity Control Device

L

- 1 Limestone belt conveyor (30") to

receiving hopper 2012 200 tons per hour ( tp h ) Dust suppression enclosure

with dust suppression spray (LDS

- 1)

RS

- C Radial Stacker Conveyor C (48") to

Limestone belt conveyor L

- 2 (via

hopper) Original
1961 1400 tph Dust suppression enclosure limestone product delivered

wet

L

- 2 Limestone belt conveyor (48") to

Limestone Storage Silo 2011 1400 tph Dust suppression enclosure with dust suppress i on spr ay (LDS

- 2)

L

- 2A Limestone belt conveyor (48") to

Limestone Storage Silo 2011 1400 tph Dust suppression enclosure with dust suppress i on spray (LDS

- 2)

LSS

- 1 Limestone Storage Silo # 1 2011 7500 tons Baghouse (N011)

LSS

- 2 Limestone Storage Silo # 2 201 1 7500 tons Baghouse (N005)

L

- 3A Limestone Storage Silo unloading

conveyor, indoors (30") 2011 150 tph Dust suppression enclosure with dust suppress i on spray (LDS

- 2)

L

- 3B Limestone Storage Silo unloading

conveyor, indoors (30") 2011 150 tph Dust suppr ession enclosure with dust suppression spray (LDS

- 2)

L

- 3C Limestone belt conveyor (30") from

silo storage to conveyor L

- 4 at Transfer Tower (TT

- 1) 2011 150 tph Dust suppression enclosure and dust suppression spray Transfer Tower #1 (LDS

- 2)

RC

- 1 Lime stone Transfer Tower (TT

- 1)

Maintenance Recirculation Chute to

Dump Truck 2013 20 tph Dust suppression enclosure and dust suppression spray Transfer Tower #1 (LDS

- 2)

L

- 4 Limestone belt conveyor (30") from

silo storage via TT

- 1 to Transfer Tower (TT

- 2) 2011 150 tph Dust suppression enclosure and dust suppression spray Transfer Tower #2 (LDS

- 2)

L

- 5 Limestone belt conveyor (30") from

TT

- 2 to Day Silos 2011 150 tph Dust suppression enclosure and dust suppression spray Transfer Tower #2 (LDS

- 3)

B F

- 2 Belt Feeder (30") for emergency

limestone silo feed from truck to conveyor L

- 5 2011 50 tph Dust suppression enclosure and spray at Transfer Tower #2

(LDS

- 3)

BE

- 1 Bucket Elevator for emergency

limestone silo feed from truck to conveyor L

- 5 2011 50 tph Dust suppression enclosure and spray at Transfer Tower #2

(LDS

- 3)

5 Equipment IDs 4000A, 4000B, 4030A, 4030B, 4060A and 4060B are located inside the FGD building. Emissions from baghouses 4010A and 4010B are exhausted into the FGD building.

### Public Service of New Hampshire Page 9
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Table 1A

- Limestone Processing and Handling System 5

Equipment
ID Equipment Description Year
Installed Design

Capacity Control Device

4000A Limestone Day Silo A 2011 300 tons Baghouse (4010A)

4000B Limestone Day Silo B 2011 300 tons Baghouse (4010B)

4030A Limestone Feeder A 2011 18.5 tph N/A

- Water injection

4030B Limestone Feeder B 2011 18.5 tph N/A

- Water injection

4060A Ball Mill A 2011 18.5 tph N/A

- Water injection

4060B Ball Mill B 2011 18.5 tph N/A

- Water injection



### B. Stack Criteria

The following devices at the Facility shall have exhaust stacks that di scharge vertically, without obstruction, and meet the criteria in Table 2:

Table 2

- Stack Criteria
Stack
Number Emission

Unit
Number Emission Unit

Description Minimum Stack

Height (Feet) Above
Ground Level Maximum Inside

Stack Diameter (Feet)
STMK2 (By pass Stack) MK1 Steam Generating Unit

No. 1 317 14.5

STMK3 MK1

and/or
MK2 with
MK2

- PC7 Steam Generating Units

No. 1 and/or No. 2 with FGD System 445 21.5



### 1. The Owner may change the stack criteria described in Table 2 with notification to DES provided that :

i. An air quality impact analysis is performed either by the facility or DES (if requested by the facility in writing) in accordance with Env

- A 606 and the “Guidance and Procedure for Performing Air Quality Impact Modeling in New Hampshire,” and
ii. The analysi s demonstrates that emissions from the modified stack will continue to comply with all applicable emission limitations and ambient air limits.

2. All air modeling data and analyses shall be kept on file for review by DES upon request.

### Public Service of New Hampshire Page 10
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V. Pollution Control Equ ipment/Method Identification

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

Table 3

- Pollution Control Equipment/Method Identification
Pollution
Control Equipment
Number Description of Equipment/Method Emission Unit
Number Controlled

MK1

- PC1 Electrostatic Precipitator (ESP) #1 on MK1 MK1
MK1

- PC2 ESP #2 on MK1 MK1
MK1

- PC3 Selective Catalytic Reduction (SCR) deNO

x System MK1
MK2

- PC4 ESP #1 on MK2 MK2
MK2

- PC5 ESP #2 on MK2 MK2
MK2

- PC6 SCR deNO

x System MK2
MK2

- PC7 Flue Gas Desulphurization (FGD) System MK1 and MK2



### VI. Applicable Requirements

A. Operational and Emission Limitations The Owner shall be subject to the operational and emission limitations identified in Table 4
b elow.

Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

1. 1 Env

- A 1403 Devices subject to RSA
125

- I and Env

- A 1400 Devices or processes, subject to RSA 125

- I and Env

- A 1400, shall compl y with Env

- A 1400 (Regulated Toxic Air Pollutants).
2. 2 Env

- A 1403.01(d) Devices subject to RSA

125

- I and Env

- A 1400 Documentation for the demonstration of compliance shall be retained and shall be made available to DES for inspection upon request.
3. 3 E nv

- A 1404.01 Devices subject to RSA
125

- I and Env

- A 1400 a. The Owner of a new or modified device or process requiring 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, t he owner shall not operate the device or process until a temporary permit is issued.
4. 4 Env

- A 1405.01 Devices subject to RSA
125

- I and Env

- A 1400 The Owner of any device or process that emits an RTAP shall determine compliance with the AAL by using one of the methods provided in Env

- A 1405. Upon request, the Owner of any device or process that emits an RTAP shall provide documentation of compliance with the AAL to DES.
5. Env

- A 1002.04 Fugitive Dust MKLC1 The Owner shall prevent, abate, and control fugitiv e dust emissions using best management practices 6

.

6 To comply with this provision, PSNH

– Merrimack Station shall us e Best Management Practices to manage and minimize fugitive dust, as established in the PSNH Merrimack Station Environmental Management System Plan for Fugitive Emissions.

### Public Service of New Hampshire Page 11
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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

6. 40 CFR
51.30 8(e)(1) MK2 a. Beginning on July 1, 2013, when MK2

- PC7 (FGD system) is in operation, SO 2 emissions shall be controlled to 10 percent
of the uncontrolled SO 2 emission rate (90 percent SO 2

rem oval) . Compliance with this percent reduction shall be
determined on a cal endar month average by compari ng the
SO 2 emission rates as measured by CEMS on the inlet and outlet of the FGD system.
b. The Owner shall submit a report no later than December 31,
201 4 that includes the calendar month average SO 2 emission rates at the inlet and outlet of the FGD and the corresponding calendar month average emissions reductions during the preceding 12 month s of operation, excluding the initial startup and commissioning period and any periods when the FGD system is not operating. DES will use this data to
establish the maximum sustainable rate of SO 2 emissions
reductions for MK2. The maximum sustainable rate is the highest rate of reductions that can be achieved 100 per cent of
the time.

c. DES shall establish the maximum sustainable rate of SO 2 emissions reductions based on a statistical analysis of the data submitted to DES pursuant to paragraph b. above. This established rate shall be incorporated as a permit condition
f or MK2. Under no circumstances shall the SO 2 removal efficiency for MK2 be less than 90 percent.

7. 40 CFR
51.30 8(e)(1) MK2 Beginning on July 1, 2013, the Owner shall not operate MK2
unless MK2

- PC7 is in operation.
8. 40 CFR 51.308 Regional Haze
Plan MK1 a. Beginning on July 1, 2013, when MK2

- PC7 (FGD system) is
in operation, SO 2 emissions shall be controlled to 10 percent
of the uncontrolled SO 2 emission rate (90 percent SO 2 removal) . Compliance with this percent reduction shall be
determined on a cal enda r month average by compari ng the
SO 2 emission rates as measured by CEMS on the inlet and outlet of the FGD system.
b. The Owner shall submit a report no later than December 31,
2014 that includes the calendar month average SO 2 emission
rates at the inlet and outlet of the FGD and the corresponding calendar month average emissions reductions during the preceding 12 month s of operation, excluding the initial startup and commissioning period and any periods when the FGD system is not operating. DES will use this data to
establish the maximum sustainable rate of SO 2 emissions
reductions for MK1. The maximum sustainable rate is the highest rate of reductions that can be achieved 100 percent of
the time.

c. DES shall establish the maximum sustainable rate of S O 2 emissions reductions based on a statistical analysis of the data submitted to DES pursuant to paragraph b. above. This established rate shall be incorporated as a permit condition

### Public Service of New Hampshire Page 12
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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

for MK1. Under no circumstances shall the SO 2 removal efficiency for MK 1 be less than 90 percent.
9. 40 CFR 51.308 MK1 Beginning on July 1, 2013, the Owner shall not operate MK1 through STMK2 (bypass stack) if MK2

- PC7 is capable of stable operation.
10. 40 CFR 51.308 MK1 Beginning on July 1, 2013, the Owner shall not operate MK1 through STMK2 (bypass stack) for more than 840 hours in any
consecutive 12

- month period.
11. Env

- A 1606.01(a)(1) MK1 & MK2 For coal burning devices placed in operation before April 15, 1970, the sulfur content of the coal shall not exceed 2.8 pounds per mil lion BTU gross heat content at any time.
12. Env

- A 1606.01(a)(2) MK1 & MK2 For coal burning devices placed in operation before April 15, 1970, the sulfur content of the coal shall not exceed 2.0 pounds per million BTU gross heat content averaged over any

con secutive 3

- month period.
13. RSA 125

- O:13,
II Affected Sources as defined

in RSA 125

- O:12 Beginning on July 1, 2013, total mercury emissions from the affected sources shall be at least 80 percent less on an annual basis than the baseline mercury input, as d efined in RSA 125

- O:12, III.
14. RSA 125

- O:13,
III MK1 & MK2 Prior to July 1, 2013, the Owner shall test and implement, as practicable, mercury reduction control technologies or methods to achieve early reductions in mercury emissions below the
baseline merc ury emissions. The Owner shall report the results of any testing to DES and shall submit a plan for DES approval before commencing implementation.
15. RSA 125

- O:13

- V MK1 & MK2 a. Mercury reductions (achieved through the operation of the FGD system) greater tha n 80 percent shall be sustained insofar as the proven operational capability of the system, as installed, allows.
b. DES, in consultation with the Owner, shall determine the maximum sustainable rate of mercury emissions reductions and incorporate such rate a s a permit condition for MK1 and MK2. This requirement in no way affects the ability of the
Owner to earn over

- compliance credits consistent with RSA
125

- O:16, II.
16. RSA 125

- O:13,
VI MK1 & MK2 The purchase of mercury emissions allowances or credits from

an y established emissions allowance or credit program shall not be allowed for compliance with the mercury reduction requirements of this permit or the requirements of RSA
125:O:13.
17. RSA 125

- O:13,
VII MK1 & MK2 If the mercury reduction requirement in Item 13 above is not achieved in any year after the July 1, 2013 implementation date, and after full operation of the FGD technology, then the Owner may utilize early emissions reduction credits or over

- compliance credits, or both, to make up any shortfall, and thereby be in compliance.

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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

18. RSA 125

- O:13,
VIII MK1 & MK2 If the mercury reduction requirement in Item 13 above is not achieved by the Owner in any year after the July 1, 2013 implementation date despite the Owner's installation and full operation of FGD technology, consistent with good operational practice, and the owner's exhaustion of any available early
emissions reduction or over

- compliance credits, then the owner
shall be deemed in violation of this section unless it submits a plan to DES, within 30 days of such noncompliance, and subsequently obtains approval of that plan for achieving compliance within one year from the date of such noncompliance. DES may impose conditions for approval of such plan.
19. RSA 125

- O:17 MK1 & MK2 Variances from mercury e missions reduction requirements:

a. The Owner may request a variance from the mercury emissions reduction requirements of this permit and RSA
125

- O:13, by submitting a written request to DES. The request shall provide sufficient information concerning the

con ditions or special circumstances on which the variance request is based to demonstrate to the satisfaction of DES that variance from the applicable requirements is necessary.
b. Where an alternative schedule is sought, the Owner shall submit a proposed sched ule which demonstrates reasonable further progress and contains a date for final compliance as soon as practicable. If DES deems such a delay is reasonable under the cited circumstances, it shall grant the requested variance.

c. Where an alternative reduction requirement is sought, the Owner shall submit information to substantiate an energy supply crisis, a major fuel disruption, an unanticipated or unavoidable disruption in the operations of the affected sources, or technological or economic infeasibility. D ES, after consultation with the New Hampshire Public Utilities Commission, shall grant or deny the requested variance. If requested by the Owner, DES shall provide the owner with an opportunity for a hearing on the request.
20. RSA 125

- O:16,
I MK1 & MK2 Econ omic Performance Incentives/Generation and Use of Early
Emissions Reduction Credits:

a. DES shall issue to the Owner early emissions reduction
credits in the form of credits or fractions thereof for each pound of mercury or fraction thereof reduced below the baseline mercury emissions, on an annual basis, in the period prior to July 1, 2013.

b. Ratios of early reductions credits to pounds of mercury
reduced shall be as follows:

i. 1.5 credits per pound reduced prior to July 1, 2008;
ii. 1.25 credits per pound for red uctions between July 1, 2008 and December 31, 2010; and

### Public Service of New Hampshire Page 14
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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

iii. 1.1 credits per pound for reductions between January 1, 2011 and July 1, 2013.

c. Reductions shall be calculated based upon the results of stack tests conducted, measurement by continuous emission
moni toring, or other methodology approved by DES to confirm emissions during the time of operation of mercury reduction technology.

d. Early emissions reduction credits may be banked by the Owner or utilized after July 1, 2013 to meet the reduction requirement o f RSA 125

- O:13, II as allowed under RSA
125

- O:13, VII.

e. Early emissions reduction credits are not sellable or
transferable to non

- affected sources; however, upon the July 1, 2013 compliance date, the Owner may request a one

- for

one conversion of early emis sions reduction credits to over

compliance credits.

f. Should a federal rule applicable to mercury emissions at one
or more of the affected sources be enacted with an implementation date prior to July 1, 2013, then early reduction credits may only be earned for emissions reductions that exceed the level required by the federal rule of the affected sources in aggregate or the baseline mercury emissions level, whichever is lower, at the same ratios listed in subparagraph (b) above.

g. Early emissions reduction cre dits shall not be used for compliance with the requirement of RSA 125

- O:13, II prior to the installation of FGD technology, and shall not be used as a means to delay the installation of the FGD technology.

21. RSA 125

- O:16,
II MK1 & MK2 Economic Performance Incentives/ Use of Over

- Compliance
Credits:

a. DES shall issue to the Owner over

- compliance credits in the form of credits or fractions thereof for each pound of mercury or fraction thereof reduced in excess of the emissions reduction requirement of RSA 125

- O :13, II, on an annual basis, following the compliance date of July 1, 2013.

b. The ratios of over

- compliance credits to excess pounds of mercury reduced shall be as follows:

i. 0.5 credits per pound reduced for reductions between 80 and 85 percent;
ii. 1 credit p er pound reduced for reductions between 85 and 90 percent reduction; and
iii. 1.5 credits per pound reduced for reductions of 90 percent or greater.

c. Over

- compliance credits may be banked for future use. The requirements of RSA 125

- O:13, V shall not alter the

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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

emissions levels at which over

- compliance credits are
earned.

d. Should a federal rule applicable to mercury emissions at one or more of the affected sources be enacted, then over

compliance credits may only be earned for emissions
reductions that exceed the level required by the federal rule of the affected sources in aggregate or the requirement of
RSA 125

- O:13, II, whichever is lower, at the same ratios listed in subparagraph (b) above.

e. At the request of the Owner, over

- compliance credits may
be surrendered by the owner to the department and SO 2 allowances shall be transferred to the owner at a rate of 55
tons SO 2 allowances for every one over

- compliance credit. Transfer shall be limited to a maximum of 20,000 total tons
SO 2 allowances transferred in a given year, defined as the
sum of all SO 2 allowances received by the affected sources
under RSA 125

- O:4, IV(a)(2) and IV(a)(3), and under this subparagraph. SO 2 allowances shall be credited to the affected sources' accounts in the following year in
accordance w ith RSA 125

- O:4, IV(a)(4).

22. 40 CFR 60.672(b) (Subpart OOO) MKLC1

Transfer points from :

 RS

- C to L

- 2

 L

- 1 to L

- 2

 L

- 2 to L

- 2A

 BF

- 2 to BE

- 1

 BE

- 1 to L

- 5 NSPS for Nonmetallic Mineral Processing Plants

- Standard for Particulate matter

a. Fugitive emissions from affected facilities other than crushers that are not enclosed in a building : The average opacity from any transfer point on a belt

conv eyor or from any other affected facility installed after April 22, 2008, shall not exceed 7 percent 7

. 40 CFR 60.672(b)

&
40 CFR 60.672(e) MKLC1

 Transfer point from
L

- 3C to L

- 4 located inside
the transfer tower TT

- 1

 Transfer point from
L

- 4 to L

- 5 loc ated inside
the transfer tower TT

- 2

 Transfer points located inside the silo building:

 Limestone silo LSS

- 1 to
L

- 3A or L

- 3B

 Limestone silo LSS

- 2

to L

- 3A or L

- 3B b. Fugitive emissions from affected facilities other than
crushers that are enclosed in a building : If any transfer point on a conveyor belt or any other affected facility is enclosed in a building, then each enclosed
af fected facility must comply with the emission limit
identified in Item 22.a or the building enclosing the affected facilities must comply with the following emission limits:

i. Fugitive emissions from the building openings (except
for vents 8 ) must not exceed 7 percent opacity; and

ii. Vents in the building must meet the particulate matter emission limit of 0.014 gr/dscf.

7 Compliance with visible emission limitations shall be determined using 40 CFR 60, Appendix A, Method 9 as des cribed in Table 5,

Item 6.

8 Per 40 CFR 60.671, Vent means an opening through which there is mechanically induced air flow for the purpose of exhausting from a building air carrying particulate matter emissions from one or more affected facilities.

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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

 L

- 3A to L

- 3C & L

- 3B
to L

- 3C

 Transfer points located
inside t he F G D building:

 Day silo A to b elt
feeder A

 Day silo B to belt
feeder B.

40 CFR 60.672(b) MKLC1 (Ball Mills

-

4060A & 4060B) c. Fugitive emissions from crushers that are enclosed in a building : The opacity of fugit ive emissions from each crusher shall
not exceed 12% or the building enclosing the affected facilities must comply with the emission limits identified in
Item 22.b.i. and ii.

40 CFR 60.672(f) MKLC1 (LSS1 & LSS2) d. Emissions from a baghouse that controls in dividual, enclosed storage bins : The opacity of emissions from any baghouse that controls emissions from an individual, enclosed storage bin shall not
exceed 7%.

40 CFR 60.672(e) & (f) MKLC1 (4000A & 4000B) e. The opacity of emissions from any baghouse tha t controls emissions from an individual, enclosed storage bin shall not exceed 7% or the building enclosing the affected facilities must comply with the emission limits identified in Item
22.b.i. and ii.

23. 40 CFR 60.672(d) MKLC1 Truck dumping of nonmet allic materials into any screening operation, feed hopper, or crusher is exempt from the requirements of Subpart OOO.

24. 40 CFR 60.670(d) MKL C 1 NSPS for Nonmetallic Mineral Processing Plants

- Equipment Replacement

The Owner or Operator shall be allowed to replace a component of the facility with new equipment of equal or smaller capacity, having the same function as the existing equipment by complying with the reporting requirements of Table 8, Item 7, provided there is no increase in the amount of emiss ions . The Owner or Operator may implement the equipment replacement immediately upon filing the report.
25

. 40 CFR 60.11(d) & (g) Subpart A MKLC1 NSPS General Provisions

a. At all times, including periods of startup, shutdown, and malfunction, owners an d operators shall, to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whethe r acceptable operating and maintenance procedures are being
used will be based on information available to the

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Table 4

- Operational and Emission Limitations
Item
No. Regulatory

Cite Applicable Emission Unit Applicable Requirement

Administrator which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source;
b. For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in this part, nothing in this part shall preclude the use, including the exclusiv e use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed.



### B. Initial Compliance Demonstration Req uirements The Owner shall demonstrate initial compliance with the emission limitations specified in Table 4 for the parameters contained in Table 5 below, within 60 days after achieving stable FGD operation with both MK1 and MK2 exhausting through stack ST MK3. The Owner shall perform the initial compliance demonstration requirements listed in Table 5 below. In addition, the Owner shall perform all monitoring and testing requirements in Table 6 to ensure compliance with emissions and operating limitations contained in Table 4.

Table 5: Initial Compliance Demonstration Requirements

Item
No. Applicable

Emission
Unit Parameter Method of Compliance Frequency
of Method Regulatory

Basis

1. MK1 & MK2
with MK2

- PC7 Performance

tests for

mercury a. The Owner shall co nduct initial

performance tests for mercury to demonstrate compliance with the respective mercury emissions limitation in Table 4, Item 13

. b. Testing shall be conducted and the results reported in accordance with 40 CFR 60, Sections 60.8(a), (b), (d), (e), and (f), and Appendix A. The following test methods or DES approved alternatives shall be used for the pollutants specified:
i. Method 1 or 2 to determine exit velocity of stack gases;
ii. Method 3 or 3A to determine carbon dioxide, oxygen, excess air, and
mol ecular weight (dry basis) of stack

gases; iii. Method 4 to determine moisture content (volume fraction of water vapor) of stack gases;
iv. For mercury, in accordance with the mercury monitoring requirement of
RSA 125

- O:15 and Table 6, Item 3 of W ithin 60 days after achieving
stable FGD operation
with both
MK1 and
MK2 exhausting through stack
STMK3 Env

- A 802 &

40 CFR 60.8 (a), (b), (d)

- (f)

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Table 5: Initial Compliance Demonstration Requirements

Item
No. Applicable

Emission
Unit Parameter Method of Compliance Frequency
of Method Regulatory

Basis

this permit.
2. MK1 & MK2 Performance

Test for SO 2 a. The Owner shall conduct an initial

performance test for SO 2 to demonstr ate compliance with the respective SO 2 emissions limitation in Table 4, Item s 6
and 8

. b. Testing shall be conducted and the results reported in accordance with 40 CFR 60, Sections 60.8(a), (b), (d), (e), and (f), and Appendix A. The following test methods

o r D ES approved alternatives shall be used for the pollutants specified:
i. Use of certified CEMS monitors. With the use of CEMS monitors, compliance will be determined based on a monthly average of CEMS data. Within 60 days after achieving
stable FGD operation
with both
MK1 and
MK2 exhausting through stack
STMK3 Env

- A 802 &

40 CFR 60.8 (a), (b), (d)

- (f)

3. MK1, MK2 &

MKLC1 General Stack

Testing Requirements Compliance testing shall be planned and carried

out in accordance with the following schedule:

a. At the request of DES, submit to DES a pretest protocol at least 30 days prior to the commencement of testing which includes the following information:
i. Calibration methods and sample data sheets;
ii. Descriptions of the test methods to be used;
iii. Pre

- test prepa ration procedures;
iv. Sample collection and analysis procedures;

v. Process data to be collected; and
vi. Complete test program description.
b. At the request of DES, participate in a pretest conference with a DES representative at least 15 days prior to the
test date.

c. Emission testing shall be carried out under the observation of a DES representative.
d. Within 60 days after completion of testing or within 15 days of receipt of test report, submit a copy of the test report to DES. Initial performance
test and subsequent

t esting Env

- A

802.03, 802.04,
802.05 &
802.11

4. MK1, MK2 &
MKLC1 General Stack

Testing Requirements Operating Conditions During a Stack

Emissions Test A compliance test shall be conducted under one of the following operating conditions:

a. Between 90 and 10 0 % of maximum operating capacity; Initial performance
test and subsequent

tests Env

- A

802.10

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Table 5: Initial Compliance Demonstration Requirements

Item
No. Applicable

Emission
Unit Parameter Method of Compliance Frequency
of Method Regulatory

Basis

b. A production rate at which maximum emissions occur; or

c. At such operating conditions agreed upon during a pre

- test meeting conducted pursuant to Env

- A 802.05.
5. MKLC1 General Stack Testing Requirements Visible Emissions Testing Pursuant to

40 CFR 60 Subpart OOO The Owner or Operator shall notify the
D epartment at least 30 days prior to conducting
the required performance testing by providing the following:

a. The name, mailing address, telephone
number and contact information of the
owner of the non

- metall ic processing plant;
b. The address of the physical location where
the non

- metallic processing plant will be operated; and

c. For each piece of equipment, including bu t not limited to grinding mills, bucket elevators, loading stations and conveyors that is a component of the non

- metallic processing plant, the following
information:
i. A description of the equipment;
ii. The manufacturer of the equipment;
iii. The serial number of t he equipment;
and
iv. The maximum throughput of the equipment

. Initial performance

test Env

- A

802.12

6

. MKLC1 Particulate
matter & Opacity a. Affected facilities enclosed in a building:

The Owner or Operator shall determine compliance with the PM standards fo r any affected facility that is enclosed in a building as follows:
i. Except as specified in 40 CFR 60.675(e)(3) and (4), EPA Methods 5
or 17 shall be used to determine the particulate matter concentration from each building vent. The sample volume
shall be a t least 1.70 dscm (60 dscf)

. For Method 5 , if the gas stream being sampled is at ambient temperature, the sampling probe and filter may be operated without heaters. If the gas Initial performance
test within
180 days
after the
issuance of signif icant
amendment 40 CFR

60.675

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Table 5: Initial Compliance Demonstration Requirements

Item
No. Applicable

Emission
Unit Parameter Method of Compliance Frequency
of Method Regulatory

Basis

stream is above ambient temperature, the sampling probe and filter may be operat ed at a temperature high enough, but no higher than 121 °C (250 °F), to prevent water condensation on the
filter.
ii. To demonstrate compliance with the fugitive emission limits for buildings specified in Table 4, Item 22.b.i , the
Owner or O perator must condu c t an initial Method 9 performance test according to Item 6 .b below and
40 CFR 60.11.
iii. Performance tests must be conducted
while all affected facilities inside the building are operating.
MKLC1 Opacity b. Procedures for determining compliance with opacity standard: In determining compliance with the opacity standard in Table 4, Item 2 2 , the Owner or Operator shall use Method 9 and the procedures in
40 CFR 60.11 , with the following
additions:
i. The minimum distance between the
observer and the emission source shall be 4.57 meters (15 feet).
ii. The observer shall, when possible, select a position that minimizes interference from other fugitive emission sources (e.g., r oad dust). The required observer positio n relative to the sun (Method 9 , Section 2.1) must
be followed.
iii. For affected facilities using wet dust suppression for particulate matter control, a visible mist is sometimes generated by the spray. The water mist

mu st not be confused with particulate
matter emissions and is not to be
considered a visible emission. When a water mist of this nature is present, the
observation of emissions is to be made at a point in the plume where the mist is no longer visible.

c. When d etermining compliance with the fugitive emissions standard for any

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Table 5: Initial Compliance Demonstration Requirements

Item
No. Applicable

Emission
Unit Parameter Method of Compliance Frequency
of Method Regulatory

Basis

affected facility described under 40 CFR 60.672(b) or §60.672(e)(1), the duration of
the Method 9 observations must be 30 minutes (five 6

- minute averages). Compliance with the applicable fu gitive
emission limits in Table 4, Item 2 2 must be based on the average of the five 6

- minute averages.
MKLC1 Opacity d. Baghouses that control emissions from individual storage bins: In determining compliance with the opacity of stack emissions from any baghouse that controls emissions only from an individual enclosed storage bin under 40 CFR 60.672(f), using Method 9, the duration of
the Method 9 observations shall be 1 hour (ten 6

- minute averages). The duration of the Method 9 observations may be reduce d to the duration the affected facility operates (but not less than 30 minutes) for baghouses that control storage bins that operate for less than 1 hour at a time.
MKLC 1 PM &

Opacity e. Alternatives: For the above required

performance tests, t he Owner or Operator may use the alternative methods and procedures specified in 40 CFR 60.675(e).

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C. Monitoring/Testing Requirements

The Owner is subject to the monitoring/testing requirements as contained in Table 6 below:

Table 6

– Monitoring/Testing Requireme nts
Item
No. Device Parameter Method of Compliance Frequency
of Method Regulatory

Cite
1. MK1 & MK2 Continuous
Emissions Monitoring Systems Site

- Specific Monitoring Plan

- Continuous

Emissions Monitoring Systems

a. The Owner shall submit a CEMS monitoring pla n describing the proposed systems. The monitoring plan shall contain the information required under Env

- A 808.04(c) and address all applicable monitoring requirements of Env

- A 808, 40 CFR Part 60, and 40 CFR Part 75.

b. The CEMS monitoring plan in item a a bove, shall at a minimum, address the following operating scenarios:

i. CEMS monitoring for units MK1 and
MK2 when both units MK1 and MK2 are operating and emissions are discharged through the common exhaust stack STMK3;

ii. CEMS monitoring for compliance with
th e SO 2 limitation specified in Table 4,
Item 6 and 8 ;

iii. Monitoring for unit MK1 when emissions are discharged through stack STMK2 (bypass stack). At least 90 days prior to
the
installation of
the CEM
system Env

- A

808.04(a)

2. MK1 & MK2 Continuous
Emissions
Mon itoring Systems Quality Assurance/Quality Control Plan

Requirements The Owner of a source required by this part to install, operate, and maintain an opacity or gaseous
CEMS shall:

a. Prepare a quality assurance/quality control (QA/QC) plan, which shall contai n written procedures for implementation of its QA/QC program for each CEMS;

b. File the QA/QC plan with DES no later than the time specified in Env

- A 808.05(e) after the initial startup of each CEMS;

c. Review the QA/QC plan and all data generated by its implem entation at least once each year;

d. Revise or update the QA/QC plan, as necessary, based on the results of the annual As specified
within regulation Env

- A 808.06

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Table 6

– Monitoring/Testing Requireme nts
Item
No. Device Parameter Method of Compliance Frequency
of Method Regulatory

Cite review, by:

ii. Documenting any changes made to the CEMS or changes to any information provided in the monitoring plan;

iii. Including a schedul e of, and describing,
all maintenance activities that are required by the CEMS manufacturer or that might have an effect on the operation of the system;

iiii. Describing how the audits and testing required by this part will be performed;
and

iiv. Including examp les of the reports that
will be used to document the audits and tests required by this part;

e. Make the revised QA/QC plan available for review by DES at any time; and

f. Within 30 days of completion of the annual QA/QC plan review, certify in writing that
th e Owner 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;

g. Revision of the QA/QC plan is required if the results of emission report reviews, inspections, audits, review of the QA/QC plan, or any other information available to DES show that the plan does not meet the criteria specified in 40 CFR 60, Appendix F, Procedure 1, section 3; and

h. The QA/QC plan shall be considered an update to the CEMS monitoring plan required by Env

- A 808.04.
3. MK1 & MK2 Mercury
Emissions Monitoring of Mercury Emissions

a. Prior to the availability and operation of CEMS, and subsequent to the baseline emissions testing under RSA 125

- O:14, II,
stack tests o r another methodology approved by DES shall be conducted twice per year to determine mercury emissions levels from the
affected sources.

b. Any stack tests performed shall employ a federally recognized and approved methodology, proposed by the Owner and empl oying a test protocol approved by DES. Twice per year or until a

mercury CEM S is in operation and approved by
DES RSA 125

-

O:15

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Table 6

– Monitoring/Testing Requireme nts
Item
No. Device Parameter Method of Compliance Frequency
of Method Regulatory

Cite

c. When a federal performance specification takes effect and a mercury CEMS capable of meeting the federal specifications becomes available, a mercury CEMS, approved by DES, shall be installed on STMK3 as deemed appropr iate by DES.

4. MK1 & MK2 Stack flow,
NO

x , SO 2 , and CO 2 (or
O 2 ), opacity The new stack ( STMK3 from the FGD) serving

units MK1 and MK2 shall be equipped with flow
monito ring, NO

x , SO 2 , and CO 2 or O 2 CEMS and a continuous opacity monitor (COMS) 9 . The
CEMS and COMS shall meet 40 CFR 75 requirements. Continuously Env

- A 808.02(a) (new) and 40
CFR 75 §75.10(a)(2), §75.12, and
Env

- A 1211.03(f)
5. MK2

- PC7 FGD Operating
Parameters a. The Owner shall continuously monitor the

scrubber liquor pH and FGD absorber exit gas temperature. b. The Owner shall calibrate or validate the accurate operation of the instruments measuring the parameters a minimum of once annually in accordance with

man ufacturer’s recommended procedures or alternative procedures as approved by DES.
All records of the calibrations or validations shall be kept and made available upon request. Continuously RSA 125

- C:6,
XI

6. MK2

- PC7 FGD Data Acquisition System The Owner sh all have a data acquisition system

for the FGD absorber exit gas temperature and scrubber liquor pH monitors, which calculates and monitors hourly averages and daily

averages. Continuously RSA 125

- C:6,
XI

7. MK1 & MK2 Sulfur Test
Method for
Coal The owne r or operator shall use Method ASTM

D 4239

- 00 to determine the sulfur content of coal in pounds of sulfur per million BTU gross
heat content. Each shipment of
coal Env

- A 806.04

8. MKLC1 Transfer points
from :

 RS

- C to L

- 2

 L

- 1 to L

- 2

 L

- 2 to L

- 2A

 BF

- 2 to BE

- 1

 BE

- 1 to L

- 5 Visible

emissions testing The Owner or Operator shall conduct emissions

testing to evaluate compliance with the visible
emission limitations in Table 4

, I tem 22.a

. Testing shall be conducted in accordance with
Table 5

, I tems 4, 5 a nd 6

. Withi n 5 years from the previous performance

test 40 CFR

60. 675 &
Table 3 of Subpart OOO

9. MKLC1 ( 4000A, 4000B, Visible

emissions a. The owner or operator of any affected

facility for which construction, Quarterly (if
the affected 40 CFR

9 Due to excessive moisture in the flue gas exiting the FGD system, the COMS will be installed prior to the stack.

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Table 6

– Monitoring/Testing Requireme nts
Item
No. Device Parameter Method of Compliance Frequency
of Method Regulatory

Cite LSS1 & LSS2) modification, or reconstruction commenced

on or after April 22, 2008, that uses a baghouse to control emissions must conduct quarterly 30

- minute visible emissions inspections using EPA Method 22

.
b. The Method 22 test shall be conducted while the baghouse is operating. The test is
successful if no visible emissions are
observed.

c. If any visible emissions are observed, the owner or operator of the affected facility
must initiate corrective action within 24 hours to return the baghouse to normal operation. The owner or operator must
record each Method 22 test , including the date and any corrective actions taken, in the logbook required under Table 7, Item 7

. facility is operated during the
calendar quarter) 60.674(c)



### D. Recordkeeping Requirements The Owner is subject to the Re cordkeeping requirements as contained in Table 7 below:

Table 7

– Applicable Recordkeeping Requirements
Item
No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

1. Record Retention and Availability

The Owner s hall keep the required records on
file. These records shall be available for review by DES upon request. Retain for a minimum of 5 years Emissions Units specified in
Table 1 and
Pollution
Control Equipment specified in
Table 3 Env

- A 902

2. General Recordk eeping Requirements for

Process Operations
The Owner shall k eep monthly records of t he quantity of limestone used as documented by limestone delivery records

. Monthly MKLC1
MK2

- PC7 Env

- A 903.02

3. The Owner shall maintain the standard

operating and maintenance procedures for the air pollution control equipment in a convenient location (e.g., control room/technical library) and make them readily available to DES upon request. Maintain at facility

a t all times MK2

- PC7 Env

- A 90 6.01

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Table 7

– Applicable Recordkeeping Requirements
Item
No. Recordkeeping Requirement Frequency of Recordkeeping Applicable

Emission Unit Regulatory Cite

4. CEMS and Other Approved Monitoring

Methods Recordkeeping Requirements

a. The Owner shall record and maintain the information pursuant to 40 CFR Part 75, which includes the certification, quality assurance, and quality contro l records.
b. The Owner shall record and maintain CEMS records according to the most stringent requirements of Env

- A 808 and 40
CFR Part 75. As specified by regulation MK1, MK2,

MK2

- PC7 Env

- A 903.04

Env

- A 808
40 CFR Part 75

5. The Owner shall record the hours of operation

of MK1 and MK2 as follows:

a. Total hours of MK1 and MK2 each ; and
b. Total hours of MK1 when discharging through STMK2 (bypass stack)

. Monthly MK1 and MK2 Env

- A 906

6. The owner or operator shall maintain the

following sulfur analysis records:

a. Records showing the maximum weight percentage sulfur and quantity of each fuel delivery shipment received; and
b. Records showing either:
1. T he analytical method used and the specified fuel analysis results of the shipment or consignment from which
the sh ipment came; or 2. Delivery records sufficient to allow for traceability of the analytical results corresponding to each shipment received by the stationary source, showing: i. The date of delivery; ii. The quantity of de livery; iii. The type of fuel;
iv. The maximum weight percentage sulfur; and

v. The name, address, and telephone number of the company making the delivery. Each shipment of
coal MK1 & MK2 Env

- A 806.05

7. The Owner or Operator must record each

period ic inspection required under Table 6,
Item 9 , including dates and any corrective actions taken, in a logbook (in written or electronic format). The owner or operator must keep the logbook onsite and make hard or electronic copies (whichever is requested) o f the logbook available to DES/EPA upon request. Maintain on a
continuous basis MKLC1 40 CFR 60.676(b)

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E. Reporting Requirements The Owner is subject to the reporting requirements identified in Table 8 below:

Table 8

– Applicable Reporting Requirements
It em No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory Cite

1. Performance Test Reports The Owner shall submit a report to DES documenting the results of the compliance stack emission test. The compliance stack emission t est 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 Owner to be collected;

e. All test results;
f. A desc ription 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 repo rt, including sample calculations for each equation used. No later than 60 days after a performance test MK1, MK2 &

MK2

- PC7 Env

- A 802.11

2. Quarterly Reports
The Owner shall submit to DES no later than 30 calendar days after the end of the calendar

qu arter, the informat ion required in Table 7, Item
4. Quarterly

– 30 calendar days after
the end of the calendar quarter MK1, MK2,

MK2

- PC7 40 CFR 75,

Env

- A 808.11

3. Semi

- annual Report The Owner shall submit to DES the following
information on a semi

- annual basis:

a. Hours of operation of MK1 and MK2 as required in Table 7, Item 5; and
b. Limestone records as required in Table 7,
Item 2. Semi

- annual MK1, MK2,
MKLC1 Env

- A 910

4. Annual Emissions Compliance Report for Mercury The Owner shall submit to DES a report of annual mercury emissions from the affected sources to demonstrate compliance with Item 13 of Table 4. This report shall include all references and methodologies used to calculate the total mercury
emissions from the affected sources. Annually by April
15 th of each calendar year Affected

Sources as
defined in RSA
125

- O:12 Env

- A 910

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Table 8

– Applicable Reporting Requirements
It em No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory Cite

5. Quarterly Coal Report
The Owner shall submit to DES no later than 30 calendar days after the end of the calendar quarter, the informat ion required in Table 7, Item
6. Sub mittal of the “Monthly Report of Cost and Quality of Fuel for Electric Plants,” will satisfy the requirements of this condition. Quarterly

– 30 calendar days after
the end of the calendar quarter MK1 & MK2 Env

- A 910.01

6. NSPS Subpart OOO Test Reports

a. No later than 60 days after the particulate
matter and visible emissions testing is performed, file with the department a summary report of the results of the visible emissions testing that includes the following:

i. The emission points that were observed
and wh ere visible emissions were assessed;

ii. The rate of processing of material through
the non

- metallic mineral processing plant during the test;

iii. An indication of whether each emission point passed or failed the visible emissions test;

iv. The name of the person that performed the visible emissions testing, and the date the person was most recently certified to perform US EPA Test Method 9 prior to the date of the test; and

v. A copy of the Method 9 certification for the person(s) that performed the vis i ble
emissions te st; and

b. Retain the data sheets completed during the visible emissions testing by the US EPA
Method 9

- certified observer at the facility and
make such data sheets available to the department upon request. No later than 60 days after a performance test MKLC1 Env

- A 802.12 & 40 CFR 60.676(f)

7. NSPS for Nonmetallic Mineral Processing Plants

- Equipment Replacement Reporting Requirements

Each Owner or Operator seeking to comply with Table 4, Item 2 4 shall submit to the Division the following information about the existing facility component being replaced and the replacement piece of equipment.

a. For a conveyor belt:
i. The width of the existing belt being As necessary MKLC1 40 CFR 60.676(a)

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Table 8

– Applicable Reporting Requirements
It em No. Reporting Requirement Frequency of Reporting Applicable

Emission Unit Regulatory Cite

replaced; and
ii. The width of the replacement conveyor
belt.
b. For a storage bin:
i. The rated capacity in tons of the existing storage bin being replaced; and
ii. The rated capacity in tons of the replacement storage bin.

c. For a grinding mill or bucket elevator : i. The rated capacity in tons per hour of the existing facility being replaced; and
ii. The rated capacity in tons per hou r of the replacement equipment

.



### VII. Administrative Permit Amendments

A. Pursuant to Env

- A 612.01, the Owner may implement the changes addressed in the request for an administrative permit amendment as defined in Part Env

- A 100 immediately upon submittal of the request.

B. Pursuant to Env

- A 612.01, the Director shall take final action on a request for an administrative permit amendment in accordance with the provisions of Env

- A 612.01(b) and (c).

VIII. Minor Permit Amendments

A. Pursuant to Env

- A 612.03, the owner or operator of a source or device shall submit to the department a request for a minor permit amendment for any proposed change to an existing permit condition which will not result in an increase in the amount of a specific air pollutant currently emitted by the source or device and will not result in the emission of any regulated air pollutant or regulated toxic air pollutant currently not emitted by the source or device.

B. The request for a minor permit amendment shall:
1. Be in t he form of a letter to the department;
2. Describe the proposed change; and
3. Describe any new applicable requirements that will apply if the change occurs.

C. The department shall take final action on a request for a minor permit amendment within 90 days
of rece ipt of such a request.

D. The owner or operator may implement the proposed change immediately upon filing a request for minor permit amendment with the department.

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IX. Significant Permit Amendments

A. Pursuant to Env

- A 612.04, the owner or operator shall submit a n application to the department for a significant permit amendment for any proposed change to the physical structure or operation of the source or device covered by the temporary permit which increases the amount of a specific air pollutant currently emitt ed by such source or device or which results in the emission of any regulated air pollutant currently not emitted by such source or device.

B. A request for a significant permit amendment shall include the following:

1. A complete application form, as describe d in Env

- A 1703 through Env

- A 1708, as applicable and provided by the department, containing all pertinent information with regard to the amendment including, if applicable, the information specified in Env

- A 1709.

2. The fee(s) specified in Env

- A 702 throug h Env

- A 705, as applicable.

3. A description of:

a. The proposed change;
b. The emissions resulting from the change; and

c. Any new applicable requirements that will apply if the change occurs: and

4. Where air pollution dispersion modeling is required for a source or device pursuant to Env

- A 606.02, the information required pursuant to Env

- A 606.03.

C. The department shall take final action on a request for a significant permit amendment within 90 days of receipt of such a request, provided that the public notice and hea ring procedures specified
in Env

- A 621 have been satisfied.

D. The owner or operator shall not implement the proposed change until the department issued the amended permit.

X. Emission

- Based Fee Requirements

A. The Owner shall pay an emission

- based fee quarterly f or this facility as calculated each calendar year pursuant to Env

- A 705.03.

B. The Owner shall determine the total actual annual emissions from the facility to be included in
the emission

- based multiplier specified in Env

- A 705.03(a) for each calendar year i n accordance with the methods specified in Env

- A 616.

C. The Owner shall calculate the annual emission

- based fee for each calendar year in accordance with the procedures specified in Env

- A 705.03 and the following equation:

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Where:

FEE = The annual emission

- based fee for each calendar year as specified in Env

- A 705.
E = The emission

- based multiplier is based on the calculation of total annual

emissions as specified in Env

- A 705.02 and the provisions 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 calculated in Env

- A 705.03(c).
ISF = The Inventory Stabilization Factor as specified in Env

- A 705.03(d).
D. The Owner shall contact the DES eac h calendar year for the value of the Inventory Stabilization
Factor.

E. The Owner shall contact the DES each calendar year for the value of the Consumer Price Index Multiplier.

F. The Owner shall submit, to the DES, payment of the emission

- based fee and a sum mary of the calculations referenced in Sections X.B. and C. of this Permit for each calendar year. The total
emission

- based fee shall be paid in four equal installments on a quarterly basis. The quarterly payments shall be made in accordance with Env

- A 7 05.04 on the 15 th 

### day of the following
months:

1. July of the year to which the fee applies (e.g., January, February, March 2007 emission fees are due July 15, 2007);

2. October of the year to which the fee applies (e.g., April, May, June 2007 emission fees ar e due on October 15, 2007).

3. January of the following year (e.g., July, August, September 2007 emission fees are due on January 15, 2008);

4. April of the following year (e.g., October, November, December 2007 emission fees are due on April 15, 2008).

The Ow ner shall pay any remaining balance of the total annual emission

- based fee no later than April 15 th 

### of the following year.

The emission

- based fee and summary of the calculations shall be submitted to the following
address:

New Hampshire Department of E nvironmental Services
Air Resources Division
29 Hazen Drive
P.O. Box 95 Concord, NH 03302

- 0095 ATTN.: Emissions Inventory

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G. The DES shall notify the Owner of any under payments or over payments of the annual emission

based fee in accordance with Env

- A 705.0 5.

XI. Permit Deviation

In accordance with 40 CFR 70.6(a)(3)(iii)(B), the Owner 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 devi ation. This 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 preventative measures taken.

Within 10 days of disco very of the permit deviation, the Owner shall submit a written report including the above information as well as the following: preventive measures taken to prevent future occurrences; date and time the permitted device returned to normal operation; speci fic device, process or air pollution control equipment that contributed to the permit deviation; type and quantity of excess emissions emitted to the atmosphere due to permit deviation; and an explanation of the calculation or estimation used to quantify e xcess emissions.

Said Permit deviation shall also be submitted in writing to the DES in the semi

- annual summary report of monitoring and testing requirements due July 31st and January 31st of each calendar year. Deviations are instances where any Permi t condition is violated and has not already been reported as an emergency pursuant to 40 CFR 70.6(g).

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