1. ECDA Process for Cased Gas Transmission Pipelines
Charlie Hall
Manager, Special Projects
Mears, CPG

2. Objectives
Review the ECDA Process From a Technical and Regulatory Perspective
Review On-Going Validation Efforts and our Casing Test Facility

3. Technical Basis of the ECDA Process for Cased Pipelines
Fundamentally the ECDA process seeks to determine if a corrosive situation potentially exists in the casing.
Anode
Cathode
Metallic Path
Electrolytic Path
If the coating is free of holidays, an external corrosion cell cannot occur (absent disbonded coating issues).
If a holiday is present, the highest risk of external corrosion occurs when the holiday is in contact with electrolyte.

4. Technical Basis of the ECDA Process for Cased Pipelines
If electrolyte is in contact with the holiday and the casing, indirect inspection tools can detect the holiday. Additionally, the holiday would be in the CP circuit and may be receiving adequate CP.
If the casing is metallically shorted, the holiday will likely not receive any available CP. Available CP will seek the path of lowest resistance, which most likely is the metallic contact.
These same principles apply to buried un-cased piping.

5. Technical Basis of the ECDA Process for Cased Pipelines
Situations that cause external corrosion in cased pipelines
Metallic contact between casing and pipeline
Electrolytic contact between casing and pipeline
Atmospheric Corrosion on pipeline in casing
Reference GRI-05/0200
“External Corrosion Probability Assessment for Carrier Pipes Inside Casings”
Casing Corrosion Direct Assessment – ECDA
Larry G. Rankin and Hussain M. Al Mahrous
January 2005

6. Principles of ECDA Process Development
ECDA is a structured process that is intended to improve safety by assessing and reducing the impact of external corrosion on pipeline integrity.
ECDA is a continuous improvement process targeted to identify and address locations where corrosion activity has occurred, is occurring, or may occur.

7. DOT Code Requirements for the ECDA Process
Per DOT Part , DA can be used to assess the integrity of gas transmission pipelines for the external, internal, and SCC.
Per DOT Part , DA must be performed in accordance with , , , and , and specifically ECDA in accordance with NACE RP0502.

8. Application of NACE RP 0502 to Cased Gas Transmission Pipelines
Per NACE RP0502, Table 1, Cased crossings requires a separate ECDA region.
Per NACE RP0502, Table 2, indirect testing methods are “applicable” for shorted casings.
Per NACE RP0502, Table 2, indirect testing methods for cased piping are “Not Applicable: Not applicable to this tool or not applicable without additional considerations.
The ECDA Process we have developed for Cased Piping addresses the NACE RP0502 requirement for “additional consideration” and fully complies with DOT part 192 and NACE RP0502 protocols.

9. Mears solicited a clarification to footnote #3 Table 2 from PHMSA
Quote from that clarification – one bullet second clarification include in regards to footnote #3
Answer B – is intended to assess the integrity of the pipe including cased pipelines

10. The ECDA Process for Cased Pipelines
The Cased Pipeline ECDA Process looks to find areas where corrosion may have or may be occurring, just like the ECDA process for buried uncased pipelines.
The Cased Pipeline ECDA Process uses the same 4 steps as used for buried uncased pipelines.

11. The ECDA Process for Cased Pipelines
The Cased Pipeline ECDA Process meets the same protocol requirements as for buried uncased pipelines (ie. immediate, schedule, monitored conditions, minimum excavation requirements, etc.).
The Cased Pipeline ECDA Process utilizes Guided Wave Ultrasonic Inspection as an additional Indirect Inspection Tool concurrent with ALL Direct Examinations.
The Cased Pipeline ECDA Process is being designed using the knowledge gained from the smart pig results of 1201 cased pipelines
The process is being validated both in the field and using a newly constructed Casing Test Bed

12. Pre-Assessment
Collect all required data elements (additional elements have been identified for cased pipelines)
Must be Feasible to perform ECDA on cased pipeline
Must be able to indirectly examine
Must be able to directly examine both ends (if necessary) and comply with all of the PHMSA guided wave target items
Must establish meaningful segments and regions for cased pipelines that pass the “red face test”

13. Has the ability to detect corrosion wall loss
Indirect Inspection
Indirect inspection tools can detect metallic or electrolytic shorted conditions
PCM (NACE RP 0502)
PCM with A-FRAME (NACE RP 0502)
P/S & C/S Potentials (including CIS both sides)
Internal Resistance (NACE RP 0200)
Cycling the Rectifier (NACE RP 0200)
Pipe/Cable Locator (NACE RP 0200)
Panhandle Eastern Method (AGA)
Has the ability to detect corrosion wall loss
Guided Wave (Guided Wave UT Target Items)

14. Are Tools Complimentary?
The word complementary can mean different things to different people.
Typically “complimentary” suggests something that adds value, reinforces, or supplements something else.
When someone says you and your spouse compliment one another, it suggests that the two of you are better as a whole, and you make up for each others’ strengths and weaknesses.

15. Are Tools Complimentary?
The IITs for Casings are complimentary.
The tools look for the same potential corrosive conditions, but they do so in slightly different manners.
This can help to account for the strengths and limitations of each tool.
This is also true for the IITs that are used to assess buried pipelines.

16. Indirect Inspection Severity Guide
CASED PIPELINE INDIRECT INSPECTION METHOD INDICATIONS & SEVERITY GUIDE
COMMON NAME OF TOOL
TYPE OF TOOL
MINOR
(NO PATH INDICATED)
MODERATE (ELECTROLYTIC PATH)
SEVERE (METALLIC CONTACT)
P/S & C/S POTENTIALS
ELECTRICAL POTENTIAL
P/S & C/S "ON" DIFFER BY MORE THAN 100 mV
P/S & C/S "ON" DIFFER BY 10 mV TO 100 mV
P/S & C/S "ON" DIFFER BY LESS THAN 10 mV
PIPE CURRENT MAPPER
AC CURRENT ATTENUATION
CURRENT LOSS ACROSS CASING < 5%
CURRENT LOSS ACROSS CASING 5%-25%
CURRENT LOSS ACROSS CASING > 25%
PCM WITH A-FRAME
AC VOLTAGE GRADIENT
NO INDICATION AT EITHER END
INDICATION < 80 dBmA
INDICATION > 80 dBmA
INTERNAL RESISTANCE
ELECTRICAL RESISTANCE
PIPE-TO-CASING RESISTANCE > 0.5 OHM
P-C RESISTANCE TO 0.5 OHM
P-C RESISTANCE < 0.01 OHM
CYCLING THE RECTIFIER
COMPARE P/S & C/S POTENTIAL SHIFTS
>100 mV DIFFERENCE C/S SHIFT < 25% P/S SHIFT
10 mV-100 mV DIFF. & C/S 25%-75% OF P/S SHIFT
< 10 mV DIFF. & C/S > 75% OF P/S SHIFT
PIPE/CABLE LOCATOR
RADIO SIGNAL
NO SIGNIFICANT SIGNAL LOSS
MODERATE SIGNAL LOSS
NEAR TOTAL SIGNAL LOSS
PANHANDLE EASTERN METHOD
REVERSE CURRENT APPLIED TO CASING
ADDITIONAL TESTING REQUIRED TO DEFINE
PIPE-TO-CASING RES < 0.01 OHM
CASING/PIPE CAPACITANCE
TINKER & RASOR MODEL CE-IT
"CLEAR" DISPLAY
NONE
"SHORTED" DISPLAY

17. Indirect Inspection Classification of Indirect Inspection Testing
Indirect Inspection Results
DE Prioritization
Any indication of a Metallic Short or Electrolytic Path
Immediate
NO indication of either a Metallic Short or Electrolytic Path
Monitored1
1For casings that were identified with some history of either a Metallic Short or Electrolytic Path but are not presently indicating the same , the DE Priority will be moved to the Immediate category and require direct examination during the first application of the ECDA process..

18. Direct Examination Must be performed per NACE RP0502.
Minimum direct examinations per NACE RP0502 protocols (ie. All immediates, 2 worst case monitored for 1st time through)
Guided Wave ultrasonic indirect inspections must be performed during all Direct Examinations. Any metallic shorts or indications of electrolytic paths must be cleared prior to inspection.

19. Direct Examination
Guided Wave must comply with all of the PHMSA Guided Wave Target Items, or exceptions documented with technical basis.

20. Post Assessment
Must comply with NACE RP0502

21. Summary of Smart Pig Results
1201 cased pipelines smart pigged from 2004 to 2006.
144 of the 1201 cased pipelines (12%) had anomalies with metal loss detected > 20%.
20 of the 144 cased pipelines with metal loss >20% (1.6 % of all cased pipelines) were found with anomalies > 80 feet from the nearest end of the casing.

22. Summary of Smart Pig Results
The lowest Pf/MAOP for any anomaly was 1.67, and the anomaly was within .1 feet of the end of the casing.
The lowest Pf/MAOP for all anomalies > 80 feet from the end of the casing was 1.79 (anomaly 27% deep, 5.3” long).
The results strongly suggest that external corrosion is not a significant threat to cased pipelines.

23. Validating the Process - Casing Test Facility

24. Validating the Process Casing Test Facility

26. Example of IIT Results on Casing Test Facility - PCM
Distance70
Clear Condition
Simulated Elect Short
Simulated Metallic Short
Actual Elect Short
100 ft
231
760
1700
482
50 ft
217
680
1550
471
0 ft
194
593
1340
395
191
218
152
149
146
104 89 80
North
South
All readings in milli-amps, out of a total of 2 amps
PCM A-Frame detected location of 20%, 50%, and 80% anomalies in shorted conditions

27. Summary
The ECDA process and the NACE RP 0502 is applicable to cased pipelines.
The process will improve the safety of cased pipelines by identifying when potential corrosive conditions occur, requiring direct examinations and remediation, in the same manner as required when applying ECDA on buried pipelines.
The process will continue to improve, as the tools and the process are continually improved.

28. Comments/Discussion
Thank You
Charlie Hall