ECDA · 2016-08-04 · Slide 3 METHODOLOGY ECDA is conducted in 4 steps Step Key Actions 1...
Transcript of ECDA · 2016-08-04 · Slide 3 METHODOLOGY ECDA is conducted in 4 steps Step Key Actions 1...
ECDA
Slide 2
Contents
• Methodology
• Application
• Pre-assessment
• Indirect Inspection
• Detailed Examination
• Post-assessment
• Questions
EXTERNAL CORROSION DIRECT ASSESSMENT
Slide 3
METHODOLOGY
ECDA is conducted in 4 steps
Step Key Actions
1 Pre-assessment
● Feasibility study
● Data collection
● Identification of ECDA regions
● ECDA indirect assessment tool selection
2 Indirect Inspection
● Above ground inspections
● Identification of critical sites, i.e. those considered most likely susceptible to external corrosion
● Ranking of sites
3 Detailed Examination ● Excavation of critical sites
● Infield data collection and measurements
4 Post Assessment
● Immediate / future fitness-for-purpose assessment
● Determination of re-assessment interval
● Evaluation of ECDA effectiveness
Slide 4
• Feasibility
• Applicability of the methodology
• Data gathering
• Data
• Availability
• Input
• Definition of ECDA regions
• Parameters used to define ECDA regions are not prescribed by
NACE
• NACE define ‘data elements’ which may or may not be
considered.
• Goal orientated process that recognises common differences
METHODOLOGY: PRE-ASSESSMENT
Slide 5
• ECDA Tool Selection, how and where?
• Based on ground conditions / detection capability, and;
• Based on the results of the region definition and perceived threat, so;
• May be done on an isolated region or whole of line.
METHODOLOGY: PRE-ASSESSMENT
Slide 6
• Conducting of above ground inspections
• Interpretation of results
• Severity of results
• Identification of potential dig sites
• Refinement of potential dig sites
METHODOLOGY: INDIRECT ASSESSMENT
Slide 7
To satisfy the requirements of the pre-assessment and form the basis of the
region identification and ranking, an adaptation of the established MACAW
‘QPRAM’ threat model has been used.
QPRAM uses a tri-matrix system to and assess threats:
APPLICATION
Matrix Type Threat Mitigation Interaction
Content Mechanistic parameters
which assess the threat
severity
Survey and condition
monitoring results
Effectiveness of mitigation
activities in relation to
specific threat parameters
Examples
Pipe/coating age
Soil analyses
AC/DC interference
Casings
CIPS/CIS
DCVG
Current attenuation
Combined mitigation of
coating and CP
Slide 8
Threat Matrix Mitigation Matrix
APPLICATION
Slide 9
QPRAM Threat Algorithm
APPLICATION
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑆𝑛
1 − 1 −𝑀1𝐸1 …(1 −𝑀𝑛𝐸𝑛)
𝑃𝑜𝐹 = 𝐵𝑃𝑜𝐹 𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜𝑠
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑇ℎ𝑟𝑒𝑎𝑡 𝑃𝑎𝑟𝑎𝑚𝑒𝑡𝑒𝑟
𝐴𝑝𝑝𝑙𝑖𝑐𝑎𝑏𝑙𝑒 𝑀𝑖𝑡𝑖𝑔𝑎𝑡𝑖𝑜𝑛𝑠
Slide 10
APPLICATION
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑆𝑛
1 − 1 −𝑀1𝐸1 …(1 −𝑀𝑛𝐸𝑛)
Slide 11
APPLICATION
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑆𝑛
1 − 1 −𝑀1𝐸1 …(1 −𝑀𝑛𝐸𝑛)
Co
atin
g Ty
pe
Mill
or
fiel
d a
pp
lied
Co
atin
g A
ge
Soil
Res
isti
vity
No coating >25 years
<=1000
Ohm.cm or
Unknown
100%
95%
20-25 years 90%
85%
Asphalt /
Bitumen /
Coaltar
80%
15-20 years1000 - 5000
ohm.cm75%
Tape wrap 70%
65%
10-15 years5001-10000
ohm.cm60%
55%
Epoxy Paint 50%
45%
THREAT MATRIX - THREAT DRIVER
Ver
y H
igh
Hig
hM
ediu
m H
igh
Med
ium
Threat Matrix
Slide 12
APPLICATION
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑆𝑛
1 − 1 −𝑀1𝐸1 …(1 −𝑀𝑛𝐸𝑛)
Co
atin
g Ty
pe
Mill
or
fiel
d a
pp
lied
Co
atin
g A
ge
Soil
Res
isti
vity
No coating >25 years
<=1000
Ohm.cm or
Unknown
100%
95%
20-25 years 90%
85%
Asphalt /
Bitumen /
Coaltar
80%
15-20 years1000 - 5000
ohm.cm75%
Tape wrap 70%
65%
10-15 years5001-10000
ohm.cm60%
55%
Epoxy Paint 50%
45%
THREAT MATRIX - THREAT DRIVER
Ver
y H
igh
Hig
hM
ediu
m H
igh
Med
ium
Threat Matrix
Mitigation Matrix
Slide 13
APPLICATION
𝑆𝑒𝑣𝑒𝑟𝑖𝑡𝑦 𝑅𝑎𝑡𝑖𝑜 = 𝑆𝑛
1 − 1 −𝑀1𝐸1 …(1 −𝑀𝑛𝐸𝑛)
Co
atin
g Ty
pe
Mill
or
fiel
d a
pp
lied
Co
atin
g A
ge
Soil
Res
isti
vity
No coating >25 years
<=1000
Ohm.cm or
Unknown
100%
95%
20-25 years 90%
85%
Asphalt /
Bitumen /
Coaltar
80%
15-20 years1000 - 5000
ohm.cm75%
Tape wrap 70%
65%
10-15 years5001-10000
ohm.cm60%
55%
Epoxy Paint 50%
45%
THREAT MATRIX - THREAT DRIVER
Ver
y H
igh
Hig
hM
ediu
m H
igh
Med
ium
Co
atin
g Ty
pe
Mill
or
fiel
d a
pp
lied
Co
atin
g A
ge
Soil
Res
isti
vity
An
earo
bic
So
il
Soil
Co
rro
sivi
ty
An
y ev
iden
ce o
f D
C
inte
rfer
ence
Do
es t
he
pip
elin
e ru
n
par
alle
l to
HV
AC
po
wer
lines
Cas
ing
insu
lati
on
sta
te
Esti
mat
ed C
oat
ing
Co
nd
itio
n
Exte
rnal
Co
rro
sio
n
Failu
res
in t
he
last
yea
r
Coating Survey date 60% 60% 60% 60% 50% 50% 50% 70%Results of coating Survey (e.g. highest IR% drop,
DCVG)
Were necessary coating repairs completed?
CP system fitted and active 80% 80% 80% 80% 80% 20%
CP Minimum Protection Criteria
Date of inspection (CIPS)
CIPS Survey Results
Date of Test post ON/OFF inspection
Test Post ON/OFF CP Survey Results
Isolation Joints fitted 50% 50%
Isolation Joint Inspection
Has any DC remediation been necessary 80%
Casing Inspection 50%
Bug Count 60%
Has any AC remediation been necessary 80%
Compliance with the external corrosion program
according to the PAI30%
External Corrosion
THREAT DRIVERS
MIT
IGA
TIO
N M
EASU
RES
Threat Matrix
Interaction Matrix Mitigation Matrix
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The adaption of the model is as follows:
• The pre-assessment is an index based on the average threat severity
parameter from the threat matrix
• Regions will be defined based on changes in threat parameter and pipe
dimensions/properties
• Indirect inspection results are characterised according to the mitigation matrix
• The QPRAM algorithm will be used to determine those section most likely to
contain external corrosion
APPLICATION
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• Start
• Feasibility Assessment
• Data Requirements
Data is entered in tabular format as follows:
PRE-ASSESSMENT
❸ Any sections of above ground or bare pipe
No ✓ Sections of bare pipe should be assessed in accordance with guidelines contained in NACE SP0207. Similarly, above ground
sections of the pipeline cannot be assessed using the ECDA indirect inspection process and should be treated seperately.
Slide 16
• Pipeline Data
PRE-ASSESSMENT
Slide 17
• Coating Type & Age
• Pipeline Equipment
• Soil Resistivity
PRE-ASSESSMENT
Slide 18
• Anaerobic Soil
• DC Interference
• AC Interference
PRE-ASSESSMENT
Start Distance (m) End Distance (m) Comment
21 300
351 363
DC Interference
Please identify any known sections of the pipeline where possible DC interference may
be an issue e.g. in common wayleaves
Start Distance (m) End Distance (m) AC Source
21 250 Power lines (>10 KVAC)
301 399 Other AC Source
AC Interference
Please identify any known sections of the pipeline where possible AC interference may
be an issue e.g. HVAC power lines
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• Casings
• Previous Failures (EC)
PRE-ASSESSMENT
Start Distance (m) End Distance (m) Last Inspection Date Status
11 45 01/05/2010 Short metallic
220 263 01/01/2013 Isolated
Casings
please identify the locations of any casing and their insulation state (most recent inspection)
Distance (m) Status
11 Full Root Cause Analysis
220 Repair Only
Previous Failures due to External Corrosion
please identify the locations of any failures due to external
corrosion. The model will apply a higher likelihood to all
sections within 100 m of the
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A new ECDA region will be defined wherever a change in following occurs:
• Diameter
• Wall Thickness
• Pipe Type and Age
• Coating Type & Age
• Areas of Anaerobic Soil
• Areas with known AC/DC interference
• Crossings (Casings)
An index score will be assigned to each region
based on the threat severity
ECDA REGION DEFINITION
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INDIRECT INSPECTION
Indirect inspection may be carried out in specified areas as per the region
definition and index score or along the whole length of the line.
4 elements of indirect inspection have been defined within the model:
• Close Interval (Protection) Survey – CIS/CIPS
• Direct Current Voltage Gradient – DCVG
• Pipeline Current Mapping – PCM
• Results of historical digs/investigations
The minimum data requirements are CIPS/CIS and DCVG or PCM
Data is entered as follows
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• Coating Survey Date
• DCVG Results
INDIRECT ASSESSMENT
Slide 23
• PCM Results
• CIS/CIPS Date
INDIRECT INSPECTION
Slide 24
• CIS/CIPS Results
• AC/DC Remediation
POST ASSESSMENT
Slide 25
• Previous Dig Results
Once all the data has been entered, the results of the indirect inspections are
compared to the threat severity as a ratio, suggestion for dig sites will be ranked
as follows:
• High threat / poor inspection results – high
• Low threat / good inspection results - low
INDIRECT INSPECTION
Slide 26
Site Ranking
List Chart
INDIRECT INSPECTION RESULTS
Slide 27
DETAILED EXAMINATION
Data Element When Collected Field Measurement / Comment Use and Interpretation of Results
Pipe-to-soil potential Prior to coating removal.
Useful for comparison with ground surface pipe-to-soil
potential measurements.
Soil resistivity Prior to coating removal.
Related to soil corrosiveness and soluble cation
concentration of soil. Useful for comparison with results of
soil and groundwater analyses.
Soil samples Prior to coating removal.
Useful in confirming terrain conditions. Soil analysis
results can be trended in predictive model.
Groundwater samples Prior to coating removal. Chemistry results can be trended in predictive model.
Underfilm liquid pH Prior to coating removal. Useful for detemining the corrosivity of the soil
ECDA Field Investigation Data Sheet
Data Element When Collected Field Measurement / Comment Use and Interpretation of Results
Photograph of dig site Prior to coating removal.
Useful in confirming terrain conditions, coating system, and
coating condition.
Data for other integrity
analyses Before and after coating removal. Data for other analyses (e.g. SCCDA)
Assessment of coating
condition Prior to coating removal. Can be related to extent of EC found.
Assessment of coating
degradation (blisters,
disbondment, etc) Prior to coating removal. Can be related to extent of EC found.
Corrosion product data
collection After coating removal. Can assist in precise diagnosis of corrosion mechanism
Corrosion Mapping After coating removal. Required for integrity assessment
ECDA Field Investigation Data Sheet
Corrosion Features:
ECDA Field Investigation Data Sheet
Additional Notes
ECDA Field Investigation Data Sheet
Slide 28
POST ASSESSMENT
Step 4: Post Assessment (Guidelines Only)
Immediate Integrity Assessment
• Category 1 - Superficial corrosion or surface rusting
• Category 2 - Estimated Repair Factor (ERF) >0.7
• Category 3 - ERF >0.9
• Category 4 - ERF ≥1
Future Integrity Assessment
• Category 1 - Failure life exceeds 10 years
• Category 2 - Failure life exceeds 5 years
• Category 3 - Failure life exceeds 2 years
• Category 4 - Failure may be imminent
Actions
• No Corrosion or Category 1 - Establish re-assessment period
• Category 2 to 3 - Engineering Critical Assessment (ECA)
• Category 4 - Immediate pressure reduction and inline inspection or hydrotest
Slide 29
Questions