ITB-2025-01_Construction_Services_-_Natural_Gas_Distribution_Infrastructure_Project_-_Addendum_2_Attachment_3.pdf

Operations & Maintenance Manual

Prepared By:

June 2024

OPERATIONS & MAINTENANCE MANUAL June 2024

Revision: K Page ii

RECORD OF PLAN REVIEW AND REVISIONS

Revision No.

Date

Sections Revised

Remarks

Review Person(s)

A 10/13/2016 All Plan completely revised and reformatted by Payne Pipeline Services.

George D.

Rials

B 10/13/2017

1.7 8.16.1 8.21.2

8.24.2

8.32 8.33

10.0

10.1.2 10.4

Appendix A Appendix B Appendix F

Added EFV definitions.

Leak grading criteria inserted.

Statement of internal relief devices use manufacturer’s calculations for capacity of relief added.

EFV installation and notification regulation update.

Pressure testing section added.

Uprating section added.

Updated the emergency contact Added one hour notification and confirmation time limits Added statement to file any annual reports with the

PSC.

Updated contact information.

Updated contact information.

EFV customer notification example.

George D.

Rials

C 7/10/2018 2.0 8.16

10.3

System description updated.

Added details to FAC requirements for leak surveys.

Added National registry of pipeline and LNG operators update requirements.

Danny Rice

- 7/24/2018 App A Added FL PSC contact list Danny Rice

D 7/11/2019

1.7 2.0 5.11 8.8 8.9 8.15

8.17.4

8.29 8.30, 8.31, 8.32, 8.33,

8.34 9.1, 9.6

App A & B App C

Added definitions System description updated.

Updated Liaison with Public Officials section Corrected MAOP reg Updated odorization reg Added leak repair reg Added Leak surveys frequency for unprotected lines Updated welding section Revised plastic pipe rules from 11/20/2018 update.

Revised corrosion control rule per 11/20/2018 update.

Updated contact information Updated equipment list

Danny Rice

Revision: K Page iii

Person(s)

E 8/4/2020

2.0 5.1

6.1, 6.2 8.6

8.17

8.20

8.22 8.31 8.32 9.5 9.6

10.4.3 Appendix A

System description updated FAC 25-12.042 added Revised safety related conditions requirements.

Updated MAOP regulations.

Revised patrolling language Added details to FAC 25-12.040 leak survey requirements Updated FAC 25-12.045 inactive gas lines regulation Updated telemetering regulation Updated Heat Fusion Joints section Updated qualifying plastic pipe joining procedures Revised cathodic protection language Added details to FAC 25-12.054 requirements for half-cell placement, FAC 25-12.052 requirements for correction of any deficiencies Revised safety-related condition reporting Updated contact list

F 8/5/2021

1.7 2.0 3.1 8.6

8.30.3 8.31.2 8.32.1 8.33.2 8.35.2 8.36.1 9.6.2 9.14 9.19

10.1.2 10.5 10.6

Updated “incident” definition System description updated Added minimizing releases of natural gas Added footnotes to factors table Updated welding regulation Updated heat fusion regulation Updated wording Updated joining of plastic pipe regulation Updated test requirements Added notification of FPSC Updated external corrosion monitoring regulation Updated atmospheric corrosion monitoring regulation Updated record keeping requirements Updated telephonic notification requirements Updated annual report requirements Mechanical Fitting Failure Reports deleted

Revision: K Page iv

Person(s)

G 8/9/2022

2.0 7.2

8.20.1 8.33.2 8.36.1 9.6.3 9.6.4

Appendix A

Updated System Description Added language for investigation of incidents, failures, and defective materials Added language for Inactive Gas Service Lines language for specimen joints used for qualification Added language for notifying FPSC Updated language for interference bonds Added language about correcting deficiencies indicated by monitoring Updated contact list

Danny Rice

H 8/22/2022 Appendix A Removed names from contact list following FLPSC state inspection

I 5/18/2023

1.7 2.0 5.1 5.2 5.8 5.11 8.5.1 8.18 8.23

8.30.2 9.5.2 10.1.2

Added Business District Definition Updated System Description Updated Notifying Requirement Updated Communication Requirement Updated Notification Requirement Updated Liaison Requirement Updated Customer Notification Updated Reinstatement Criteria Updated Capacity of Relief Devices Criteria Updated Welder Qualification Requirements Added Amphoteric Metals Statement Updated Monetary Damage Threshold

J 6/13/2023 8.28 Updated Test Requirements for Reinstating Service Lines

K 6/10/2024 2.0

10.1.2 Appendix A

Updated System Description Updated Monetary Reporting Threshold Updated Contact Information

*Note: Provided herein is a sequential record of previous Natural Gas of Milton Plan revisions since October 2016. This manual shall be reviewed at intervals not exceeding 15 months, but at least once each calendar year.

Revision: K Page v

TABLE OF CONTENTS

1.0 INTRODUCTION AND PLAN CONTENT [192.605(A)]

1.1 Scope [192.605(a)]

1.2 General

1.3 Safety Considerations [§192.603(a) and §192.703(a)]

1.4 Roles and Responsibilities

1.5 Related Documents

1.6 References

1.7 Glossary of Terms

2.0 SYSTEM DESCRIPTION

3.0 MAINTENANCE AND NORMAL OPERATIONS [§192.605(A)]

3.1 Operating, Maintaining and Repairing the Pipeline [§192.605(b) (1)]

3.2 Controlling Corrosion [§192.605(b)(2) and Subpart I]

3.3 Availability of Construction Records, Maps, and Operating History [§192.605(b)(3)]

3.4 Gathering of Data Needed for Reporting Incidents [§192.605(b)(4)]

3.5 Starting Up and Shutting Down the Pipeline System [§192.605(b)(5)]

3.6 Compressor Stations [§192.605(b)(6) and §192.605(b)(7)]

3.7 Reviewing the Effectiveness of the O&M Procedures [§192.605(b)(8)]

3.8 Taking Precautions in Excavated Trenches to Protect Personnel [§192.605(b)(9)] .. 15

3.9 Testing and Inspecting Pipe-type or Bottle-type Holders [§192.605(b)(10)]

3.10 Responding Promptly to a Report of a Gas Odor [§192.605(b)(11)]

4.0 ABNORMAL OPERATIONS [§192.605(C)]

4.1 Responding to, Investigating, and Correcting the Cause of Abnormal Conditions [§192.605(c)(1)]

4.2 Checking Variations from Normal Operation [§192.605(c)(2)]

4.3 Notifying Responsible Personnel [§192.605(c)(3)]

5.0 EMERGENCY RESPONSE

5.1 Receiving, Identifying and Classifying Notices of Events [§192.615(a)(1)] [FAC 25- 12.041, 12.042]

5.2 Establishing and Maintaining Adequate Means of Communication with Police, Fire and Other Public Officials [§192.615(a)(2)]

5.3 Prompt and Effective Response to Each Type of Emergency [§192.615(a)(3)]

5.4 Availability of Personnel, Equipment, Tools and Materials [§192.615(a)(4)]

5.5 Priority of Actions [§192.615(a)(5)]

5.6 Emergency Shutdown and Pressure Reduction [§192.615(a)(6)]

5.7 Making Safe Any Actual or Potential Hazard [§192.615(a)(7)]

Revision: K Page vi

5.8 Notifying Appropriate Fire, Police and Other Public Officials [§192.615(a)(8)]

5.9 Safely Restore Any Service Outage [§192.615(a)(9)]

5.10 Emergency Response Training and Review

5.11 Liaison with Public Officials [§192.615(C)]

6.0 SAFETY-RELATED CONDITION REPORTS [§192.605(D) AND §191.23]

6.1 Guidelines Identifying a Safety Related Conditions

6.2 Conditions That Do Not Need to be Reported

6.3 Deadline for Filing Safety Related Conditions Reports [§192.605 (d)]

7.0 SURVEILLANCE AND ACCIDENT INVESTIGATION [§192.605(E), §192.613]

7.1 Continuing Surveillance [§192.605(e) and §192.613]

7.2 Investigation of Incidents, Failures and Defective Materials [§192.605(e), §192.615(a)(10), and §192.617]

8.0 MISCELLANEOUS GENERAL PROCEDURES

8.1 Change in Class Location: Required Study [§192.609]

8.2 Change in Class Location: Confirm or Revise MAOP [§192.611]

8.3 Damage Prevention Program [§192.614]

8.4 Limiting Use of Pipeline Casings [FAC 25-12.029]

8.5 Public Education [§192.616]

8.6 Maximum Allowable Operating Pressure: Steel or Plastic Pipelines [§192.619, §192.621, §192.623, §192.625]

8.7 Alternative MAOP for Certain Steel Pipelines [§192.620]

8.8 MAOP: High/Low Pressure Systems

8.9 Odorization of Gas [§192.625] [FAC 25-12.055]

8.10 Tapping Pipelines Under Pressure [§192.627]

8.11 Purging of Pipelines [§192.629]

8.12 Control Room Management [§192.631]

8.13 Line Markers – Mains [§192.707]

8.14 General Requirements for Pipeline Repairs [§192.703]

8.15 Leak Repair [§192.720]

8.16 Patrolling [§192.721]

8.17 Leakage Survey [§192.723] [FAC 25-12.040]

8.18 Test Requirements for Reinstating Service Lines [§192.725]

8.19 Abandonment or Deactivation of Facilities [§192.727]

8.20 Gas Service [FAC 25-12.043-046]

8.21 Pressure Limiting and Regulating Stations – Inspection [§192.739]

8.22 Telemetering [§192.741]

8.23 Pressure Limiting and Regulating Stations: Capacity of Relief Devices [§192.743] . 57

8.24 Valve Maintenance [§192.747]

8.25 Vault Inspection [§192.749]

Revision: K Page vii

8.26 Excess Flow Valves

8.27 Prevention of Accidental Ignition [§192.751]

8.28 Caulked Bell and Spigot Joints [§192.753]

8.29 Protecting Cast Iron Pipelines [§192.755]

8.30 Welding of Steel in Pipeline [§192 Subpart E]

8.31 Joining of Plastic Pipe [§192.281]

8.32 Qualifying Joining Procedures for Plastic Pipe [§192.283]

8.33 Qualifying Personnel for Joining Plastic Pipe [§192.285]

8.34 Inspection of Plastic Pipe Joints [§192.287]

8.35 Test Requirements [§192 Subpart J]

8.36 Uprating [§192 Subpart K]

8.37 New, Reconstructed, or Converted Facilities [FAC 25-12.008]

8.38 Marking of Materials and Facility Identification [FAC 25-12.028] [FAC25-12.050] .. 79

9.0 CORROSION CONTROL [§192 SUBPART I] [§192.453]

9.1 External Corrosion Control - Buried or Submerged Pipelines Installed After July 31, 1971 [§192.455]

9.2 External Corrosion Control - Buried or Submerged Pipelines Installed Before August 1, 1971 [§192.457]

9.3 External Corrosion Control - Examination of Buried Pipe When Exposed [§192.459]

9.4 External Corrosion Control - Protective Coating [§192.461]

9.5 External Corrosion Control - Cathodic Protection [§192.463] [FAC 25-12.052-.054]

9.6 External Corrosion Control - Monitoring [§192.465]

9.7 External Corrosion Control - Electrical Isolation [§192.467]

9.8 External Corrosion Control - Test Stations [§192.469]

9.9 External Corrosion Control - Test Leads [§192.471]

9.10 External Corrosion Control - Interference Currents [§192.473]

9.11 Internal Corrosion Control - General [§192.475]

9.12 Internal Corrosion Control - Monitoring [§192.477]

9.13 Atmospheric Corrosion Control - General [§192.479]

9.14 Atmospheric Corrosion Control - Monitoring [§192.481]

9.15 Remedial Measures - General [§192.483]

9.16 Remedial Measures – Distribution Lines other than Cast or Ductile Iron [§192.487]

9.17 Remedial Measures - Cast or Ductile Iron [§192.489]

9.18 Remedial Measures - Direct Assessment [§192.490]

9.19 Corrosion Control Records [§192.491]

Revision: K Page viii

10.0 REPORTING PROCEDURES

10.1 Incident Reporting Procedures [§191.5, §191.7, §191.15]

10.2 Incident Reporting - Names and Telephone Numbers [§191.5, §191.7, §191.15]

10.3 National Registry Operators [§191.22]

10.4 Reporting Safety-Related Conditions [§191.23, §191.25]

10.5 Annual Report Procedures [§191.11, FAC 25-12.085]

10.6 Records

LIST OF APPENDICES

Appendix A Emergency Notification Appendix B Forms Appendix C List of Available Equipment, Tools, and Materials Appendix D MAOP’s for High Pressure Distribution Lines Appendix E Pressure Test Criteria Appendix F EFV Customer Notification

Revision: K Page ix

DOT Regulation Cross-Reference List Adopted from PHMSA Form 2 Standard Inspection Report of a Gas Distribution Operator (Rev. June 29, 2015).

49 CFR PART 191&192

Operations & Maintenance

Description Section Procedures - Reporting 1 191.5(b)

191.7(a) 191.7(d)

Immediate Reporting: Incidents Is there a process to immediately report incidents to the National Response Center? 10.1.2

2 191.9(a) Incident Reports Does the process require preparation and filing of an incident report as soon as practicable but no later than 30 days after discovery of a reportable incident?

10.1.4

3 191.9(b) Supplemental Incident Reports Does the process require preparation and filing of supplemental incident reports? 10.1.6

4 191.22(a) 191.22(c) 191.22(d)

National Registry of Pipeline and LNG Operators (OPID) Does the process require the obtaining, and appropriate control, of Operator Identification Numbers (OPIDs)?

10.3

5 192.605(a) 191.23(a) 191.23(b) 191.25(a) 191.25(b) 191.25(c)

Safety Related Condition Reports Do the procedures require reporting of safety-related conditions?

6.0 10.4

6 192.605(d) Safety Related Conditions Does the process include instructions enabling personnel who perform operation and maintenance activities to recognize conditions that may potentially be safety-related conditions?

6.0

Procedures - Customer and EFV Installation 1 192.13(c)

192.16(a) 192.16(b) 192.16(c) 192.16(d)

Customer Notification Is a customer notification process in place that satisfies the requirements of 192.16? 8.5.1

2 192.383(b) 192.381(a) 192.381(b) 192.381(c) 192.381(d) 192.381(e) 192.383(a) 192.383(c)

EFV Installation Is there an adequate excess flow valve (EFV) installation and performance program in place? 8.26

Revision: K Page x

Description Section Procedures – Normal Operating and Maintenance 1 192.605(a) Normal Maintenance and Operations Does the process include a requirement to review the manual at intervals not exceeding 15 months, but at least once each calendar year?

1.1

2 192.605(a) 192.605(b)(3)

Normal Operations and Maintenance Procedures - History Does the process include requirements for making construction records, maps and operating history available to appropriate operating personnel?

3.3

3 192.605(a) 192.605(b)(5)

Normal Operations and Maintenance Procedures Does the process include procedures for starting up and shutting down any part of the pipeline in a manner to assure operation with the MAOP limits, plus the build-up allowed for operation of pressure-limiting and control devices?

3.5

4 192.605(a) 192.605(b)(8)

Normal Operations and Maintenance Procedures - Review Does the process include requirements for periodically reviewing the work done by operator personnel to determine the effectiveness, and adequacy of the procedures used in normal operations and maintenance and modifying the procedures when deficiencies are found?

3.7

5 192.605(b)(9) 192.713(b)

Safety While Making Repairs Does the process ensure that repairs are made in a safe manner and are made so as to prevent damage to persons and property?

3.8 8.14

6 192.605(a) 192.605(b)(10)

Holders Does the process include systematic and routine testing and inspection of pipe-type or bottle-type holders?

3.9 N/A

7 192.605(a) 192.605(b)(11)

Gas Odor Response Does the process require prompt response to the report of a gas odor inside or near a building?

3.10 5.3.5

8 192.723(b)(1) 192.721(b)(1) 192.723(a) 192.613

Business District Definition Do the procedures define a “Business District”? 1.7

Procedures – Change in Class Location 1 192.605(b)(1)

192.609(a) 192.609(b) 192.609(c) 192.609(d) 192.609(e) 192.609(f)

Change in Class Location Required Study Does the process include a requirement that the operator conduct a study whenever an increase in population density indicates a change in the class location of a pipeline segment operating at a hoop stress that is more than 40% SMYS?

8.1

2 192.605(b)(1) 192.611(a) 192.611(b) 192.611(c) 192.611(d)

Change in Class Location Confirmation or Revision of MAOP Does the process include a requirement that the MAOP of a pipeline segment be confirmed or revised within 24 months whenever the hoop stress corresponding to the established MAOP is determined not to be commensurate with the existing class location?

8.2

Revision: K Page xi

Description Section

Procedures – Continuing Surveillance 1 192.605©

192.613(a) 192.613(b) 192.703(b) 192.703(c)

Continuing Surveillance Does the process include procedures for performing continuing surveillance of pipeline facilities, and also for reconditioning, phasing out, or reducing the MAOP in a pipeline segment that is determined to be in unsatisfactory condition but on which no immediate hazard exists?

7.1

Procedures – Damage Prevention Program 1 192.614(a) Damage Prevention Program Is a damage prevention program approved and in place? 8.3

2 192.614(b) Participation in Qualified One Call Systems Does the process require participation in qualified one-call systems? 8.3

3 192.614(c)(5) Construction Marking Does the process require marking proposed excavation sites to the Common Ground Alliance’s (CGA) Best Practices or the use of more stringent and accurate requirements?

8.3.3

4 192.614(c)(1) Documented Damage Prevention Program – TPD Does the process specify how reports of Third-Party Activity and names of associated contractors or excavators are input back into the mail-outs and communications with excavators along the system?

8.3.2(1)

5 192.614(c)(3) Documented Damage Prevention – TPD/One Call Does the process specify how reports of TPD are checked against One-Call tickets? 8.3.2(4)

Procedures – Emergency 1 192.615(a)(1) Receiving Notices Does the emergency plan include procedures for receiving, identifying, and classifying notices of events which need immediate response?

5.1

2 192.615(a) 192.615(a)(2)

Emergency Response Communication Does the emergency plan include procedures for establishing and maintaining adequate means of communication with appropriate fire, police, and other public officials?

5.2

3 192.615(a) 192.615(a)(3) 192.615(a)(11 )192.615(b)(1

Emergency Response Does the emergency plan include procedures for making a prompt and effective response to a notice of each type of emergency, including gas detected inside or near a building, a fire or explosion near or directly involving a pipeline facility, or a natural disaster?

5.3

4 192.615(a) 192.615(a)(4)

Emergency Response Does the process include procedures for ensuring the availability of personnel, equipment, tools, and materials as needed at the scene of an emergency?

5.4

5 192.615(a) 192.615(a)(5)

Emergency Response - Actions Does the emergency plan include procedures for taking actions directed toward protecting people first and then property?

5.5

6 192.615(a) 192.615(a)(6)

Emergency Response Does the emergency plan include procedures for the emergency shutdown or pressure reduction in any section of pipeline system necessary to minimize hazards to life or property?

5.6

7 192.605(a) 192.615(a)(7)

Emergency Response - Hazards Does the emergency plan include procedures for making safe any actual or potential hazard to life or property?

5.7

Revision: K Page xii

Description Section 8 192.615(a)

192.615(a)(8) Public Official Notification Does the emergency plan include procedures for notifying appropriate public officials of gas pipeline emergencies and coordinating with them both planned responses and actual responses during an emergency?

5.8

9 192.615(a) 192.615(a)(9)

Service Outage Restoration Does the emergency plan include procedures for safely restoring any service outage? 5.9

10 192.615(a) 192.615(a)(10

Incident Investigation Actions Does the process include procedures for beginning action under §192.617, if applicable, as soon after the end of the emergency as possible?

7.2

11 192.615(b)(2) Emergency Response Training Does the process include training of the appropriate operating personnel to assure they are knowledgeable of the emergency procedures and verifying that the training is effective?

5.10

12 192.615(b)(3) Emergency Response Performance Does the process include detailed steps for reviewing employee activities to determine whether the procedures were effectively followed in each emergency?

5.10

13 192.615(c) 192.615(c)(1) 192.615(c)(2) 192.615(c)(3) 192.615(c)(4)

Liaison with Public Officials Does the process include steps for establishing and maintaining liaison with appropriate fire, police and other public officials and utility owners?

5.11

Procedures – Public Awareness Program 1 192.616(j)

192.616(h) Master Meter and Petroleum Gas Systems Does the master meter or petroleum gas system operator's process meet the requirements of 192.616(j)?

N/A

Procedures – Failure Investigation 1 192.617 Incident Investigation Does the process include procedures for analyzing accidents and failures, including the selection of samples of the failed facility or equipment for laboratory examination, where appropriate, for the purpose of determining the causes of the failure and minimizing the possibility of recurrence?

7.2

Procedures – MAOP 1 192.605(b)(1)

192.619(a) 192.619(b) 192.621(a) 192.621(b) 192.623(a) 192.623(b)

Maximum Allowable Operating Pressure Determination Does the process include procedures for determining the maximum allowable operating pressure for a pipeline segment in accordance with 192.619?

8.6

Revision: K Page xiii

Description Section

Procedures – Pressure Test 1 192.503(a)

192.503(b);

192.503(c);

192.503(d);

192.505(a);

192.505(b);

192.505(c);

192.505(d);

192.505(e);

192.507(a);

192.507(b);

192.507(c)

Test Acceptance Criteria and Procedures Were test acceptance criteria and procedures sufficient to assure the basis for an acceptable pressure test?

8.35

App. E

Procedures – Odorization of Gas 1 192.605(b)(1)

192.625(a);

192.625(b);

192.625(c);

192.625(d);

192.625(e);

192.625(f)

Odorization of Gas Does the process ensure appropriate odorant levels are contained in its combustible gases in accordance with §192.625? 8.9

Procedures – Tapping Pipelines Under Pressure 1 192.605(b)(1)

192.627 Tapping Pipelines Under Pressure Is the process adequate for tapping pipelines under pressure? 8.10

2 192.627 192.805(b)

Qualification of Personnel Tapping Pipelines under Pressure Does the process require taps on a pipeline under pressure (hot taps) to be performed by qualified personnel?

8.10

Procedures – Pipeline Purging 1 192.605(b)(1)

192.629(a);

192.629(b)

Pipeline Purging Does the process include requirements for purging of pipelines in accordance with 192.629? 8.11

Procedures – Line Marker 1 192.707(a)

192.707(b);

192.707(c);

192.707(d);

ROW Markers Requirements Does the process adequately cover the requirements for placement of ROW markers? 8.13

Procedures – Distribution System Patrolling & Leakage Survey 1 192.721

192.721(a);

192.721(b);

192.723(a);

192.723(b)

Distribution System Leakage Surveys Does the process require distribution system patrolling and leakage surveys to be conducted?

8.17

Revision: K Page xiv

Description Section

Procedures – Test Requirements for Reinstating Service Lines 1 192.605(b)

197.725(a);

197.725(b)

Test Reinstated Service Lines Is the process adequate for the testing of disconnected service lines? 8.18

Procedures – Abandonment or Deactivation of Facilities 1 192.605(b)(1)

192.727(a);

192.727(b);

192.727(c);

192.727(d);

192.727(e);

192.727(f);

192.727(g)

Abandonment or Deactivation of Pipe and Facilities Does the process include procedures for the abandonment and deactivation of pipelines that are in accordance with 192.727?

8.19

Procedures – Pressure Limiting and Regulating Station 1 192.605(b)(1)

192.739(a);

192.739(b)

Pressure Limiting and Regulating Stations Inspection and Testing Does the process include procedures for inspecting and testing each pressure limiting station, relief device, and pressure regulating station and their equipment at intervals not exceeding 15 months, but at least once each calendar year as required?

8.21

2 192.605(b)(1) 192.741(a) 192.741(b) 192.741(c)

Pressure Telemetering or Recording Gauges Does the process require telemetering or recording gauges be utilized as required for distribution systems?

8.22

3 192.605(b)(1) 192.743(a) 192.743(b) 192.743(c)

Pressure Limiting and Regulating Stations Capacity of Relief Devices Does the process include procedures for ensuring, either by testing or a review of calculations, at intervals not exceeding 15 months, but at least once each calendar year, that the capacity of each pressure relief device at pressure limiting stations and pressure regulating stations has sufficient capacity, and for installing a new or additional device if a relief device is determined to have insufficient capacity?

8.23

Procedures – Valve and Vault Maintenance 1 192.605(b)(1)

192.747(a) 192.747(b)

Valve Maintenance Distribution Lines Does the process include procedures for inspecting and partially operating each distribution system valve that might be required in an emergency at intervals not exceeding 15 months, but at least once each calendar year and for taking prompt remedial action to correct any valve found inoperable?

8.24

Procedures – Vault Inspection 1 192.605(b)(1)

192.749(a);

192.749(b);

192.749(c);

192.749(d)

Vault Inspection Does the process provide adequate direction for inspecting vaults having a volumetric internal content of 200 cubic feet (5.66 cubic meters) or more that house pressure regulating/limiting equipment and are inspections to be performed at the required interval?

8.25 N/A

Revision: K Page xv

Description Section

Procedures – Prevention of Accidental Ignition 1 192.605(b)(1)

(192.751(a);

192.751(b);

192.751(c)

Prevention of Accidental Ignition Does the manual include procedures for minimizing the danger of accidental ignition where gas constitutes a hazard of fire or explosion?

8.27

Procedures – Caulked Bell and Spigot Joints 1 192.753(a)

192.753(b) Bell and Spigot Joints Does the process require that caulked bell and spigot joints be correctly sealed? 8.28

Procedures – Protecting Cast Iron Pipe 1 192.755(a)

192.755(b) Protecting Cast-Iron Pipeline Does the process require adequate protection for segments of a buried cast-iron pipeline for which support has been disturbed?

8.29

Procedures – Welding and Weld Defect Repair/Removal 1 192.225(a)

192.225(b) Welding Procedures Does the process require welding to be performed by qualified welders using qualified welding procedures and are welding procedures and qualifying tests required to be recorded in detail?

8.30

2 192.227(a) 192.225(a);

192.225(b);

192.328(a);

192.328(b)

Qualification of Welders Does the process require welders to be qualified in accordance with API 1104 or the ASME Boiler & Pressure Vessel Code?

8.30.2 8.31

3 192.227(b) 192.225(a);

192.225(b);

192.805(b)

Qualification of Welders for Low Stress Pipe Does the process require welders who perform welding on low stress pipe on lines that operate at < 20% SMYS to be qualified under Section I of Appendix C to Part 192, and are welders who perform welding on service line connection to a main required to be qualified under Section II of Appendix C to Part 192?

8.30.2

4 192.303 192.229(a);

192.229(b);

192.229(c);

192.229(d)

Limitations on Welders Does the process require certain limitations be placed on welders? 8.30.3

5 192.303 192.231

Welding Weather Does the process require welding to be protected from weather conditions that would impair the quality of the completed weld? 8.30.4

6 192.303 192.233(a);

192.233(b);

192.233(c)

Miter joints Does the process prohibit the use of certain miter joints? 8.30.5

7 192.303 192.235

Preparation for Welding Does the process require certain preparations for welding, in accordance with §192.235? 8.30.6

8 192.303 192.241(a);

192.241(b);

192.241(c)

Inspection and Test of Welds Does the process require visual inspections of welds to be conducted by qualified inspectors? 8.30.7

Revision: K Page xvi

Description Section 9 192.303

192.245(a);

192.245(b);

192.245(c)

Repair or Removal of Weld Defects Does the process require welds that are unacceptable to be removed and/or repaired as specified by 192.245? 8.30.9

Procedures – Nondestructive Testing 1 192.243(a)

192.243(b);

192.243(c);

192.243(d);

192.243(e)

Nondestructive Test and Interpretation Procedures Is there a process for nondestructive testing and interpretation? 8.30.8

Procedures – Joining of Pipeline Materials 1 192.303

192.273(b);

192.281(a);

192.281(b);

192.281(c);

192.281(d);

192.281(e)

Plastic Pipe Joints Does the process require plastic pipe joints to be designed and installed in accordance with 192.281?

8.31

2 192.273(b) 192.283(a);

192.283(b);

192.283(c);

192.283(d)

Plastic pipe - Qualifying Joining Procedures Does the process require plastic pipe joining procedures to be qualified in accordance with §192.283, prior to making plastic pipe joints?

8.32

3 192.285(d) 192.285(a);

192.285(b);

192.285(c);

192.805

Plastic pipe - Qualifying Joining Procedures Is a process in place to ensure that personnel making joints in plastic pipelines are qualified? 8.33.1

4 192.287 192.805(h)

Qualification of Personnel Inspecting Joints in Plastic Pipelines Is a process in place to assure that persons who inspect joints in plastic pipes are qualified?

8.34

5 192.605(b)(1) 192.756

Maintenance of Equipment Used in Joining if Plastic Pipe by Heat Fusion Does the process require maintaining equipment used in joining of plastic pipe heat fusion in accordance with the manufacturer’s recommended practices or with written procedures that have been proven by test and experience to produce acceptable joints?

8.31.2

Procedures – Corrosion Control 1 192.453

192.805(b) Corrosion Control Personnel Qualification Does the process require corrosion control procedures to be carried out by, or under the direction of, qualified personnel?

9.0

2 192.605(b)(2) 192.455(a);

192.461;

192.463;

192.483(a)

New Buried Pipe Coating Does the process require that each buried or submerged pipeline installed after July 31, 1971, be protected against external corrosion with an adequate coating unless exempted by §192.455(b)?

9.1

Revision: K Page xvii

Description Section 3 192.605(b)(2)

192.452(a);

192.455(a);

192.455(b);

192.461(a)

Conversion to Service - Pipe Coating Does the process require that each buried or submerged pipeline that has been converted to gas service and was installed after July 31, 1971, be protected against external corrosion with an adequate coating unless exempted by 192.455(b)?

9.1

4 192.605(b)(2) 192.455(a);

192.457(a);

192.452(a);

192.452(b)

Cathodic Protection post July 1971 Does the process require that each buried or submerged pipeline installed after July 31, 1971, be protected against external corrosion with a cathodic protection system within 1 year after completion of construction, conversion to service, or becoming jurisdictional onshore gathering?

9.1

5 192.605(b)(2) 192.455(e)

Use of Aluminum Does the process give adequate guidance for the installation of aluminum in a submerged or buried pipeline? 9.1.4

6 192.605(b)(2) 192.457(b)

Cathodic Protection pre–August 1971 Does the process require that pipelines installed before August 1, 1971 (except for cast and ductile iron lines) which are 1) bare or ineffectively coated transmission lines or 2) bare or coated pipes in compressor, regulator or meter stations must be cathodically protected in areas where active corrosion is found in accordance with Subpart I or Part 192?

9.2.2

7 192.605(b)(2) 192.459

Examination of Exposed Portions of Buried Pipe Does the process require that exposed portions of buried pipeline must be examined for external corrosion?

9.3

8 192.605(b)(2) 192.459

Further Examination of Exposed Portions of Buried Pipe Does the process require further examination of exposed buried pipe if corrosion is found?

9.3

9 192.605(b)(2) 192.461(c) 192.461(d) 192.461(e) 192.483(a)

New Buried Pipe Coating Installation Does the process give adequate guidance for the application and inspection of protective coatings on pipe? 9.4

9 192.605(b)(2) 192.463(a);

192.463(c)

Cathodic Protection Monitoring Criteria Does the process require CP monitoring criteria to be used that is acceptable? 9.5.1

10 192.605(b)(2) 192.463(b);

192.463(c)

Cathodic Protection of Amphoteric Metals Does the process describe criteria to be used for cathodic protection of amphoteric metals (aluminum) that are included in a steel pipeline?

9.5.2

11 192.605(b)(2) (192.465(a))

Cathodic Protection Monitoring Does the process adequately describe how to monitor CP that has been applied to pipelines? 9.6

12 192.605(b)(2) (192.465(b))

Rectifiers or other Impressed Current Sources Does the process give sufficient details for making electrical checks of rectifiers or impressed current sources?

9.6.2

13 192.605(b)(2) (192.465(c))

Bonds, Diodes and Reverse Current Switches Does the process give sufficient details for making electrical checks of interference bonds, diodes, and reverse current switches?

9.6.3

14 192.605(b)(2) (192.465(d))

Correction of Corrosion Control Deficiencies Does the process require that the operator correct any identified deficiencies in corrosion control? 9.6.4

Revision: K Page xviii

Description Section 15 192.605(b)(2)

(192.465(e)) Unprotected Buried Pipelines (typically bare pipelines) Does the process give sufficient direction for the monitoring of external corrosion on buried pipelines that are not protected by cathodic protection?

9.6.5

16 192.605(b)(2) (192.467(a);

192.467(b);

192.467(c);

192.467(d);

192.467(e))

Isolation from Other Metallic Structures Does the process give adequate guidance for electrically isolating each buried or submerged pipeline from other metallic structures unless they electrically interconnect and cathodically protect the pipeline and the other structures as a single unit?

9.7

17 192.469 Test Stations Does the process contain provisions to assure that each pipeline has sufficient test stations or other contact points to determine the adequacy of cathodic protection?

9.8

18 192.605(b)(2) (192.471(a);

192.471(b);

192.471(c);

192.469)

Test Leads Installation Does the process provide adequate instructions for the installation of test leads? 9.9

19 192.605(b)(2) (192.473(a))

Interference Currents Does the operator have a program in place to minimize detrimental effects of interference currents on its pipeline system and does the process for designing and installing cathodic protection systems provide for the minimization of detrimental effects of interference currents on existing adjacent metallic structures?

9.10

20 192.605(b)(2) (192.475(a))

Internal Corrosion Does the process require that the corrosive effect of the gas on the pipeline be investigated and if determined to be corrosive, steps be taken to minimize internal corrosion?

9.11

21 192.605(b)(2) (192.475(a);

192.475(b))

Internal Corrosion in Cutout Pipe Does the process direct personnel to examine removed pipe for evidence of internal corrosion? 9.11.2

22 192.605(b)(2) (192.477)

Internal Corrosion Corrosive Gas Actions Does the process give adequate direction for actions to be taken if corrosive gas is being transported by pipeline?

9.11.1 N/A

23 192.605(b)(2) (192.479(a);

192.479(b);

192.479(c))

Atmospheric Corrosion Does the process give adequate guidance for protecting above ground pipe from atmospheric corrosion? 9.13

24 192.605(b)(2) (192.481(a);

192.481(b);

192.481(c))

Atmospheric Corrosion Monitoring Does the process give adequate instruction for the inspection of aboveground pipeline segments for atmospheric corrosion?

9.14

25 192.605(b)(2) 192.487 192.489

Evaluation of Externally Corroded Pipe Does the process provide sufficient direction for personnel to evaluate the remaining strength of externally corroded pipe?

9.6

26 192.605(b)(2) 192.487 192.489

Repair of Externally Corroded Pipe Does the process give sufficient guidance for personnel to repair or replace pipe that is externally corroded to an extent that there is not sufficient remaining strength in the pipe wall?

9.16 9.17

Revision: K Page xix

Description Section 27 192.605(b)(2)

192.487 Evaluation of Internally Corroded Pipe Does the process give sufficient guidance for personnel to evaluate the remaining strength of pipe that has been internal corroded?

9.12

28 192.605(b)(2) 192.487(a) 192.487(b) 192.489(a) 192.489(b) 192.491(c)

Repair of Internally Corroded Pipe Does the process give sufficient guidance for personnel to repair or replace pipe that has internal corroded to an extent that there is no longer sufficient remaining strength in the pipe wall?

9.16

29 192.491(c) (192.485(a);

192.485(b);

192.487(a);

192.487(b))

Repair of Corroded Pipe Does the process give sufficient guidance for personnel to repair or replace pipe that has corroded to an extent that there is no longer sufficient remaining strength in the pipe wall?

9.16

30 192.605(b)(2) (192.489(a);

192.489(b))

Graphitization of Cast Iron and Ductile Iron Does the process give adequate guidance for remediation of graphitization of cast iron or ductile iron pipe?

9.17 N/A

31 192.605(b)(2) (192.491(a);

192.491(b);

192.491(c))

Corrosion Control Records Does the process include records requirements for the corrosion control activities listed in 192.491? 9.19

Revision: K Page 1

1.0 INTRODUCTION AND PLAN CONTENT [192.605(A)]

This Operations and Maintenance (O&M) Manual provides guidelines, procedures, and organizational responsibilities for the operations and maintenance of the City of Milton Natural Gas Pipeline System.

This plan has been organized by elements corresponding to PHMSA regulations at 49 CFR §192.605. The text of this plan comprises separate sections for:

Section 1.0 Introduction and Plan Content [192.605(a)]

Section 2.0 System Description

Section 3.0 Maintenance and Normal Operations [192.605(b)]

Section 4.0 Abnormal Operations

Section 5.0 Emergency Response

Section 6.0 Safety Related Condition Reports [192.605(d)]

Section 7.0 Surveillance and Accident Investigation [192.605(e)]

Section 8.0 Miscellaneous General Procedures [192 Subpart L & Subpart M]

Section 9.0 Corrosion Control [192 Subpart I]

Section 10.0 Reporting Procedures

1.1 Scope [192.605(a)]

Natural Gas of Milton has prepared, for each pipeline, a manual of written procedures for conducting operations and maintenance activities and for emergency response as required by Federal Pipeline Safety Regulations.

This Operations and Maintenance Manual will be reviewed at intervals not exceeding 15 months, but at least once each calendar year by appropriate operating personnel and managers. Appropriate changes will be made as necessary to ensure that the Manual is effective. These changes will be documented in the Record of Reviews and Revisions of the beginning of this plan.

Appropriate parts of this Manual shall be kept at locations where operations and maintenance activities are conducted.

Revision: K Page 2

1.2 General

The statements of policies and instructions as outlined in this Manual are to serve as guidelines for the safe operation and maintenance of natural gas distribution pipelines and related facilities. The primary objective shall be to operate and maintain Company facilities for the safety of employees, the general public, and the environment.

The policies, as stated, are the views of management and are to serve as a basis for the development of specific operation and maintenance instructions. The instructions shall cover detailed procedures of job functions as related to employees and instructions or notices to the general public as related to the use of customer-owned gas facilities.

Policies and instructions are based on rules and regulations of State or Federal regulating agencies and industry-accepted standards such as ANSI B31.8 (latest approved edition) Code for Pressure Piping - Gas Transmission and Distribution Piping Systems. Where rules and regulations of State Public Utility Commissions or Federal agencies are more stringent than the relevant ANSI standards or industry standards, the requirements of the regulatory body shall apply. In addition, it is recognized that standards, as established, are minimum requirements, and the Company, at its option, may require additional safeguards.

Instructions may be in the form of computer-based training, training schools, on-the-job training by Supervisors, Operator Qualification or a written outline of directions for the performance of assigned duties. Instructions assisting employees (those who perform operations and maintenance functions) to recognize potential safety-related pipeline conditions subject to Department of Transportation reporting requirements are contained in Section 6 of this Manual. Instructions to the general public may be in the form of notices or brochures issued as information for the proper installation and use of customer-owned facilities and equipment.

Although this manual is primarily intended for pipeline operations, there are certain administrative functions such as record keeping, contact with the public, and reporting to governmental agencies that shall be carried out by the departments to which the responsibilities are assigned.

Revision: K Page 3

Provisions of this manual must be compiled with, as appropriate to a given operating or maintenance function. This includes making available to those responsible for operations and maintenance, appropriate construction records, the maximum allowable operating pressure of each pipeline segment, and other data that affect safe operation of the pipeline system.

1.3 Safety Considerations [§192.603(a) and §192.703(a)]

1.3.1 Safety Concerns

The Department of Transportation (DOT) regulation (§192.603 and §192.703) regarding the transportation of gas by pipeline states that "No person may operate a segment of pipeline unless it is operated in accordance with this subpart (Subpart L – Operations and Subpart M - Maintenance)."

It is recognized that the requirements of Subparts L and M are minimum requirements, and the Company, at its option, may require additional safeguards [§192.603(a) and §192.703(a)].

1.3.2 Pipeline Hazards

Natural Gas of Milton pipelines transport natural gas. Inherent hazards of a release from a natural gas pipeline include:

• Flammability: Natural gas is extremely flammable, easily ignited by heat, sparks or flames. Natural gas will form explosive mixtures with air when the concentration of natural gas is between 5 to 15 percent relative to the air. Vapor may migrate to an ignition source and flashback.

• Natural Gas has no odor: Natural gas used in residential areas often contains a distinctive odorant called mercaptan so that if natural gas escapes, it can be detected. The natural gas transported in the Natural Gas of Milton pipelines contains odorant.

• Asphyxiation: Natural gas is lighter than air. Outdoors, it rises and dissipates harmlessly into the atmosphere. In confined spaces, it may displace air. A person who enters such a place where the natural gas has replaced the air may suffocate.

Revision: K Page 4

1.4 Roles and Responsibilities

The Gas Superintendent along with assigned operating staff, operators, technicians and craft or maintenance personnel, share responsibility for the safe and efficient use of pipeline facilities under their control. Those responsible for operations shall become familiar with all procedures and instructions relating to the safe operation of the pipeline and its associated facilities. The Gas Superintendent is also responsible for the operations of the facility and pipeline and has the authority to shut down the pipeline facility or any portion of the system when a leak or any other condition is of such nature that it presents an immediate hazard to persons or property.

See Appendix A for Company Personnel Contact Information.

1.5 Related Documents

The following related documents are available as references:

• Natural Gas of Milton Distribution Integrity Management Plan

• Natural Gas of Milton Operator Qualification Program

• Natural Gas of Milton Public Awareness Program

• Natural Gas of Milton O&M Procedures

1.6 References

CFR Title 49, Part 192, Transportation of Natural and Other Gas by Pipeline, Minimum Federal Standards, Subparts L and M.

CFR Title 49, Part 191, Transportation of Natural and Other Gas by Pipeline, Annual Reports, Incident Reports, and Safety-Related Condition Reports.

ASME/ANSI B31.8 - Latest approved edition, Gas Transmission and Distribution Piping Systems, Chapter V.

NACE SP0169-2007, Control of External Corrosion on Underground or Submerged Metallic Piping Systems

API 1104 20th Edition, Welding of Pipelines and Related Facilities, Note: Unless otherwise stated, references to API 1104 are for Edition 20.

Revision: K Page 5

NACE Standard RP0502-2002, “Pipeline External Corrosion Direct Assessment Methodology'' (2002).

ASME/ANSI B31.8 (2010) “Gas Transmission and Distribution Piping Systems”

Florida Administrative Code (FAC), Chapter 25-12, “Safety Of Gas Transportation By Pipeline”

CGA Common Ground Alliance, Best Practice Version 4.0

1.7 Glossary of Terms

Abandoned means permanently removed from service.

Administrator means the Administrator, Pipeline and Hazardous Materials Safety Administration or his or her delegate.

Annually means at intervals not exceeding 15 months, but at least once each calendar year.

Branched Service Line means a gas service line that begins at the existing service line or is installed concurrently with the primary service line but serves a separate residence.

Business District means an area marked by the distinguishing characteristics of being used in the conducting of buying and selling commodities and services, and related transactions. A “business district” would normally be associated with the assembly of people in shops, offices, and the like, and in the conduct of such businesses.

Cathodic (Corrosion) Protection means the equipment and methods used to protect underground metallic pipe is against corrosion (rusting and pitting).

Class Location Unit is an onshore area that extends 220 yards on either side of the centerline of any continuous 1-mile length of pipeline.

Commission means, unless a different intent clearly appears from the context, the Florida Public Service Commission, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850, area code (850)413-6770.

Confirmed Discovery means when it can be reasonably determined, based on information available to the operator at the time a reportable event has occurred, even if only based on a preliminary evaluation.

Customer Meter means the meter that measures the volume of gas transferred from a gas supplier to a consumer.

Distribution Line means a pipeline other than a gathering or transmission line.

Revision: K Page 6

Distribution System As used in this manual means any group of interconnected pipe and facilities operating at a hoop stress of less than 20 percent specified minimum yield strength which transports gas from a common source of supply or storage facility to a customer.

Downstream means any point in the direction of flow of a gas from the reference point.

Emergency, as used in these procedures, shall be defined as a situation in which:

(1) The continued safe operation of the gas pipeline is endangered, or

(2) A gas leak (ignited or not) is of such magnitude that major roads or highways must be closed, or

(3) A failure or malfunction of the natural gas pipeline exists that:

(i) Affects a large number of customers or imposes a danger to life and health of such magnitude that mobilization of all available emergency action forces is required, or

(ii) Necessitates immediate action to prevent or lessen property damage or save lives.

(4) A fire and/or explosion has occurred near or directly involves the natural gas pipeline, or

(5) A natural disaster has occurred.

Emergency Plan means the written procedures for responding to emergencies on the pipeline system.

Fusion means the union of two plastic surfaces that have been heated, or have had solvents applied, sufficiently to melt and fuse them together.

Gas as used herein shall mean natural, manufactured, liquefied petroleum gas with air admixture, or any similar gaseous substances, but shall not include liquefied petroleum gas in either the liquid or gaseous form except when stored or used for peak shaving or standby fuels in conjunction with an operator’s system.

Gas Meter means an instrument manufactured primarily for use in measuring, and indicating or recording the measurement of, the volume of gas that has moved through the instrument.

Gathering Line means a pipeline that transports gas from a current production facility to a transmission line or main.

Revision: K Page 7

Grade 1 Leak A gas leak, which, due to its location and/or relative magnitude, constitutes a potentially hazardous condition to persons or property and requires immediate repair or continuous action until the condition is no longer hazardous. Grade 1 leaks include, but are not limited to:

• Damage by outside sources resulting in leakage.

• Any indication on a combustible gas indicator (CGI) of gas entering a building.

• Any reading within three feet of a building wall.

• Any reading of 4% or more gas-in-air (80% LEL or more) within manholes, vaults, or catch basins.

• Escaping gas that has ignited.

• Any leak which, in the judgment of operating personnel at the scene, requires immediate action to eliminate a hazardous condition.

Grade 2 Leak A leak that does not present an immediately hazardous condition, but justifies scheduled repair based upon its potential for future hazard. Grade 2 leaks include, but are not limited to:

• Any reading in a paved or unpaved area which is more than 3 feet from, but within 30 feet of a building.

• Any reading less than 4% gas-in-air (80% LEL) in manholes, vaults, or catch basins; the reading to be taken with the structure in its normal condition as nearly as is physically possible.

• Any leak, which in the judgment of the operating personnel at the scene, requires scheduled repair.

Grade 3 Leak A leak that is not hazardous at the time of detection and can be reasonably expected to remain that way. Any leak on the Company’s Natural Gas Pipeline System, which is not classified as Grade 1 or Grade 2, shall be designated as Grade 3.

High-pressure distribution system means a distribution system in which the gas pressure in the main is higher than the pressure provided to the customer;

therefore, a pressure regulator is required on each service to control pressure to the customer.

Revision: K Page 8

Incident (Gas Pipeline) as defined at §191.3, means an event that involves a release of natural gas from a pipeline facility that results in:

(1) An event that involves a release of gas from a pipeline, or of liquefied natural gas, liquefied petroleum gas, refrigerant gas, or gas from an LNG facility, and that results in one or more of the following consequences:

• A death, or personal injury necessitating in-patient hospitalization;

• Estimated property damage of $122,000 or more, including loss to the operator and others, or both, but excluding cost of gas lost; For adjustments for inflation observed in calendar year 2021 onwards, changes to the reporting threshold will be posted on PHMSA’s website. These changes will be determined in accordance with the procedures in Part 191 Appendix A.

• Unintentional estimated gas loss of three million cubic feet or more;

(2) An event that is significant in the judgment of the operator, even though it did not meet the criteria of paragraphs (1) or (2) of this definition. This may vary from State to State.

Line section means a…