This document discusses the design and construction of new pipelines for compliance, integrity, and corrosion prevention. It covers safety statistics from 2017-2020 showing zero recordable incidents. The agenda discusses jurisdictional analysis to determine pipeline regulations, high consequence area analysis, emergency flow restriction devices, geohazard analysis, leak detection capability analysis, AC interference modeling, cathodic protection design, risk analysis, and installation and commissioning of cathodic protection and AC mitigation systems.

1. August 2021
COMPLIANCE, INTEGRITY & CORROSION
Design & Construction of New Pipelines

2. SAFETY STATISTICS
2017 2018 2019 2020
Recordable Incidents 0 0 0 0
Lost Workday Case Rate 0.0 0.0 0.0 0.0
Lost Time Rate 0.0 0.0 0.0 0.0
EMR 0.75 0.7 0.72 0.7
Total Man-hours Worked 951,357 1,300,032 2,206,852 1,629,894
Preventative and Active Case Management
 Lost Workday Case Rate of Zero
 DART Rate of Zero
 Lost Time Rate (LTR) of Zero
Zero OSHA: Recordable Incidents

3. Agenda
FIRST THINGS FIRST
 Jurisdictional analysis
 High consequence area (HCA) analysis
 Emergency flow restriction device (EFRD) analysis
 Geohazard analysis
 Leak detection capability analysis
 AC interference modeling & mitigation design
 Cathodic protection (CP) design
 Risk analysis
 Cathodic protection & AC mitigation system installation
 Cathodic protection & AC mitigation system commissioning

4. What’s in and What’s Out – 49 CFR Part 192, Gas
JURISDICTIONAL ANALYSIS
Transmission pipeline – B31.8 & 192
Gathering pipeline – it depends
 Class location unit
• 660’ buffer either side of center
• Continuous sliding mile
 Class 1 – B31.8
• Contains ≤ 10 habitable buildings
 Class 2, 3, 4 – B31.8 & 192

5. What’s in and What’s Out – PHMSA “Mega Rule”
JURISDICTIONAL ANALYSIS
Mega rule part 1 – effective july 1, 2020
 New requirements for gas & liquid transmission
 Class 1 design safety factor increased from 1.1 to 1.25
• Applies to type A and type B gas gathering
 Proscribes TVC record requirements to support MAOP / MOP
• Construction inspection and turn-over packages are critical
Mega rule parts 2 & 3 – effective 2020 / 2021?
 Eliminates class 1 gathering “loop hole”
 In/out function of pressure and diameter
• ≥ 30% smys? And
• ≥ 10”, 12”, 16”?

6. What’s in and What’s Out – 49 CFR Part 195, Liquid
JURISDICTIONAL ANALYSIS
Transmission Pipeline – B31.4 & 195
Gathering Pipeline – It Depends
 ≥ 10” Gathering – B31.4 & 195
 8” Gathering (MOP > 20% SMYS)
• ≤ ¼ Mile from Unusually Sensitive
Area (USA) – B31.4 & 195 (No IMP)
• > ¼ Mile from USA – B31.4
 8” Gathering (MOP ≤ 20% SMYS) – B31.4
 ≤ 6” Gathering – B31.4

7. 49 CFR Part 192, Gas
HCA ANALYSIS – IM RULE
Design & Construction Impact
 Pressure Safety Factor Class
Location Dependent
 Need Class Location
to Calculate MAOP

8. 49 CFR Part 195, Liquid
HCA ANALYSIS – IM RULE CONT.
Directly or Indirectly Impact an HCA?
 ½ mile buffer either side of center
 Subject to integrity management rule
HCA Locations Proscribed by PHMSA
 USA’s
 DW’s – Drinking water sources
 HPA’s – Incorporated areas (USCB)
 OPA’s – “Named places” (USCB)
Design & Construction Impact
• Pipe routing. Avoid HCA’s if practical

9. 49 CFR Part 195, Liquid Only
EFRD ANALYSIS – IM RULE
How Much of a Spill is Too Much?
 Regulation not proscriptive
 ANPRM – 40 minutes
Design & Construction Impacts
 Leak Detection Method
• What type, frequency, capability?
(time)
 Valve Locations
• How many / where? (drain down)
 Remote Operation & Control?
◦ Where and when? (time)

10. 49 CFR Part 195
GEOHAZARD
 Topography and Geology
 Geological Hazards
• Earthquake Induced Hazards
• Mass Wasting
• Flooding and High Groundwater
• Stream Channel Migration and Avulsion
Hazards
• Surface Erosion
• Karst Topography

11. 49 CFR Part 195, Liquid Only
LDCA ANALYSIS – IM RULE
How Quickly Can a Leak Be Identified?
 Leak Detection Techniques?
• Credit for Multiples
 Pipeline and Product Type?
 Proximity to HCA’s?
Design & Construction Impacts
 Swiftness of LDS
 Response Personnel Locations
 Risk Assessment Results

12. Pipeline Threat & Personnel Safety Hazard
AC INTERFERENCE
High Voltage (≥ 69 kV) Power Lines That
Cross or Parallel Pipelines
 Digital Simulation of Induced AC Voltage
and Current on Pipeline
 Design Mitigation to Eliminate Corrosion
& Safety Hazard
 Design & Construction Impacts
• Get started early
◦ Months to obtain power line
data
• Minimize crossings & parallelism
• Cross @ 90o angle

13. Pipeline Corrosion Protection & Monitoring System
CP DESIGN
Monitoring System
 Test Stations
• Casings, road crossings, fence lines
• Potential monitoring & AC interference areas
Cathodic Protection System
 Impressed Current, Deep Anode Beds
Design & Construction Impacts
 Cathodic Protection Rectifier Requires AC Power
 Insulated flange kits at all UG/AG pipeline
transitions and tie-ins (Facilities, LACTS, etc…)

14. Parking Lot
CP DESIGN
Design & Construction Impacts
 Electrical isolation at all power system
grounds (Remote control valves, pumps,
meters, instrumentation, pipe supports)

15. Parking Lot cont.
CP DESIGN CONT.
Design & Construction Impacts
 Electrical isolation at instrument tubing and electrical conduit

16. How Much is Too Much? – Integrity Management Program
RISK ANALYSIS – IM RULE
Design & Construction Impacts
 Design Drives Risk
• Pipe wall (Barrier)
• Routing (Mitigator)
◦ Receptors
◦ Third party damage
◦ Geohazards
• Corrosion Protection
(Mitigator)
• Security (Mitigator)

17. Coordinate with Pipeline Installation
CP INSTALLATION
One Year Post Operation to Complete

18. Coordinate with Pipeline Installation cont.
CP INSTALLATION CONT.
One Year Post Operation to Complete

19. Coordinate with Pipeline Installation
AC MITIGATION INSTALLATION
Temporary Mitigation System During
Construction?
 Personnel Shock Protection During
Stringing and Lowering In
Install mitigation system simultaneously with pipeline

20. Baseline Survey
CP COMMISSIONING
 Prior to the Application of
Cathodic Protection
 Permanent Record of
Pipeline Native Potentials
 Identify Areas of Stray
Current Interference
(Corrosion)

21. On/Off Survey
CP COMMISSIONING CONT.
 Demonstrates Compliance
with Cathodic Protection
Criterion
 Identifies Any Areas
of Inadequate Protection
/Non-Compliance

22. DCVG Survey
CP COMMISSIONING CONT.
 Identifies Location and Severity of Pipeline Coating Defects
 Post Backfill QC Check of Pipeline Contractor (Warranty Work)

23. D: C:
Vice President, Asset Integrity & Corrosion
Audubon Companies
blouque@auduboncompanies.com
918.514.5879
BRYAN LOUQUE
913.221.3446
auduboncompanies.com