rehabilitation of a pipeline in a new european country
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T
he management wanted to know the actual integrity status
of the pipelines and information regarding other details of
the lines (such as their exact route). Among other factors, the
study involved: Topography survey
Terrestrial survey
Pipeline detection
Geographical investigation for soil-resistivity assessment
Collecting and review of existing information
Collecting right-of-way information at the local city hall and
cadastral data for reimbursement contracts to be made by the
client
Pipeline inspection and integrity non-destructive testing
measurements
Production and delivery of alignment sheets.
The goal of the project was to gather integrity data on these
pipelines and to evaluate these data to determine the integrity
condition of the pipelines and facilities. The pipelines, constructed to
API 5L X52 with bitumen wrapping, were designed in the early 1970s.The pipelines were initially installed with
20 inch diameter pipe, but since 1986 some sections have been
replaced with 16 inch diameter pipe, due to leakage or other
circumstances.
Alternative scope of workAfter a few meetings and an ILF presentation of an alternative
project and survey plan, the client decided to reduce the scope of
work to some basic investigations in order to obtain a rst integrity
status of the pipelines. The survey work would therefore include a
topographic survey, a pipeline-detection survey, a terrestrial survey, a
long-range ultrasonic/guided-wave ultrasonic (LRUT/GWUT) survey,excavations, radiographic inspection (x-ray), and visual inspection.
Topographic surveyThis measured all topographical items, including landmarks,
buildings, streams, rivers, rail tracks, roads, visible crossings of
third-party infrastructure, etc., in a 50 m corridor on both sides of the
pipeline. The data collected were entered onto alignment sheets and
delivered as a database, conforming to the geographical information
system (GIS) database structure prescribed by the client, for direct
implementation into the GIS.
Pipeline detection survey
This was needed to gather the necessary data to develop detailedalignment sheets and to prepare reliable as-build documentation.
This survey recorded the exact pipeline position (x, y, z), bend
identication, and possible diameter changes.
Terrestrial surveyAll structures and landmarks, in corridor of 100 m on both sides
of the pipeline, were surveyed to gather reliable data on terrestrial
conditions and to mark the pipeline route with a grid of survey
reference markers for possible rehabilitation project execution on the
pipelines.
LRUT/GWUTThe most suitable positions for LRUT/GWUT were determined,
together with the client; these were at locations were the pipeline
route changes from above-ground to below-ground. With these
Rehabilitation of a pipeline
in a new European countryby Abraham Louwerse, ILF Consulting Engineers, Munich, GermanyILF was invited to assess the integrity status of two pipelines in a new European country. In the last few years there were someleakages and nobody really knew the exact position of these pipelines and equipment. The pipelines were installed 30 yearsago, and there was little documentation available; the pipelines are non-piggable and are without any cathodic protection.The client decided to carry out an integrity-assessment study for these two major pipelines before deciding on rehabilitationprocedures.
Figure 1: The LRUT/GWUT system in use.
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spot checks, at the most corrosion-sensitive area of the pipelines, it
was possible to evaluate the general integrity of the pipeline.
The advanced LRUT/GWUT system (Figure 1) is designed for rapid
screening of long lengths of pipe to detect corrosion and other
forms of axial and circumferential metal degradation. It can be
used on a wide variety of pipes including those that are insulated.
The tests can be done with the pipeline operational (inservice), sodisruption and any expensive down-time are minimised. Hundreds
of metres of pipe can be inspected in a single shift and 100 per cent
thickness of the pipe wall is inspected during a test.
The LRUT/GWUT system uses low-frequency ultrasonic guided-
waves that travel along the full wall thickness of the pipe as a
circular type wave front around the pipe circumference. The
pulse-echo application means that changes in wall thickness
(such as corrosion) along the pipe length will generate signals that
return to the transducers. These returning echoes are presented
on a simple amplitude versus distance A-scan signal, which theoperator can use to discriminate between genuine pipe features
(such as welds) and problem areas (such as corrosion wall loss)
via the operational software.
Figure 2: EMAT schematic.
Chainage No.Diameter
(inches)
Wall
thickness
(mm)
Defects
144 IP3A 20 8.34 Coating degradation and damage
5054 IP22 24 11.9 OK
11628 IP34 16 9.36Coating degradation, dent in pipeline, welding anomalies
Bad support with corrosion indication
18081 IP36C 16 9.2Coating degradation and damage, welding anomalies
Bad support with corrosion indication
24417 IP37 16 8.39 Coating degradation and damage
31418 IP58 16 7.75 Crossing is sagging, welding anomalies
31681 IP60 14 12.2 Coating degradation and damage, four anomalies detected
32315 IP61A 16 7.75 Coating degradation and damage, two welding anomalies
32794 IP61B 16 7.95Coating degradation and damage, welding anomalies
Bad support with corrosion indication
36144 IP73 16 7.92 Coating degradation and damage
47534 IP77A 16 7.92 Coating degradation and damage
53144 IP85 20 14.38Coating degradation and damage, two remnant welding
anomalies, Bow crossing of ditch
54231 IP88 20 9.24 Coating degradation and damage
55726 IP92 20 9.8 Coating degradation and damage
62100 IP95C 20 7.92 Coating degradation and damage
85213 IP120 20 7.83 Coating degradation and damage, four anomalies detected(Class 2, 3), four welding anomalies
100026 IP139 16 9.35Coating degradation and damage, four anomalies detected
(Class 2, 3), nine welding anomalies
Table 1: LRUT and GWUT investigations or the Route 1 pipeline.
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Chainage No.Diameter
(inches)
Wall
thickness
(mm)
Defects
13 MS2 8 7.89 Coating degradation and damage
94 MS4 14 8.63 OK
466 MS6 16 7.25 Coating degradation and damage
643 MS7A 16 7.16Three leak repairs and coating with severe degradation
672 MS7B 16 6.9
3420 MS14 16 10.5 OK
6318 MS23 16 10.8 Coating degradation and damage
6318 MS24 16 12.33 Defects in welding
22271 MS47 16 7.6 OK
26757 MS54 16 8.63 Welding defects
Table 2: LRUT and GWUT investigations or the Route 2 pipeline.
Chainage Depth (m)Diameter
(inches)Pipe type Condition Radius (m) Angle ()
3,160 m 120 cm 16 Spiral 2.6 124
3,407 m 150 cm 16 3.0 127
3,439 m 130 cm 16 Seamless 1.5 148
8,976 m 130 cm 16 3.0 127
9,319 m 100 cm 16 7.0 114
18,655 m 120 cm 16 Spiral Corrosion 6.4 140
22,207 m 120 cm 16 Spiral Corrosion 5.0 134
Table 4: Pipe bends (elbows) and diameter or the Route 2 pipeline.
Chainage Depth (m) Diameter(inches)
Pipe type Condition Radius (m) Angle ()
6,375 m 150 20 Seamless 1.5 159
7,648 m 130 20 Seamless 1.5 147
32,489 m 150 20 Seamless Poor 0.6 90
32,792 m 190 20 Seamless Bad 0.7 110
33,664 m 60 20 Segments 116
55,569 m 95 20 Spiral Bad 4.6 138
62,725 m 130 20 Seamless Poor 0.8 112
63,425 m 150 16 Seamless Good 0.9 120
75,231 m 200 20 6 9091,747 m 160 20 6.5 140
Table 3: Pipe bends (elbows) and diameter or the Route 1 pipeline.
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Two types of guided wave longitudinal and torsional are
used to broaden the range of possible frequencies and to adjust
for dierent situations, for example the presence of liquids.
Symmetrical and exural waves allow defect detection and
interpretation of the results.
An important point to note is that LRUT/GWUT techniques do
not provide a direct measurement of pipe wall thickness, but
are sensitive to a combination of the depth and circumferential
extent of any metal loss. LRUT/GWUT is not able to distinguish
the dierence between internal or external material loss.
As a redundancy for the LRUT/GWUT we executed nineEMAT measurements on positions where the spiral-welded
pipe was giving bad readings via the LRUT/GWUT technology.
In this case, the electromagnetic acoustic transducer (EMAT)
technology was a hand-held tool which could be moved around
the pipe (it was not a collar, like guided wave). The EMAT must
be placed on the pipe and it shoots forwards by approximately
1.5 m (Figure 2). The transducer can be moved circumferentially
around the pipe and with this movement a 360 coverage with a
measuring length of
1.5 m can be achieved.
ExcavationsFifty locations were selected to excavate the pipeline for the
bend identication and wall thickness measurements. Thediameter changes should have been excavated as well, but
because of the method used for pipeline replacement in the
past, these were not detectable.
Table 5: Wall thickness measurement or the Route 1 pipeline.
ChainagePipeline
depth (cm)Pipe type Grade
Pipe
condition
Pipe
diameter
(inches)
Wall
thickness
min (mm)
Wall
thickness
max (mm)
144 m API 5L X52 20 7.8 8.1
5,054 m Spiral API 5L X52 Bad 20 9.5 12.5
5,141 m AG API 5L X52 20 9.2 9.2
6,375 m 150 Seamless API 5L X52 20 12.9 13.6
7,648 m 130 Seamless API 5L X52 20 8.18 13.8
11,628 m AG Spiral API 5L X52 Bad 16 8.5 9.6
Spiral API 5L X52 Poor 8.7 8.7
Spiral API 5L X52 Poor 8.7 8.7
24,417 m AG Spiral API 5L X52 20 8.0 8.9
2628 km 130 Spiral API 5L X52 Bad 20 3.6 7.9
29,621 m AG Seamless API 5L X52 Poor 22 9.4 9.8
30,127 m AG Seamless Poor 20 7.7 7.8
31,418 m AG Spiral API 5L X52 Poor 20 7.5 7.931,604 m AG Seamless Poor 14 12.2 12.9
32,315 m AG Spiral Poor 14 7.2 8.8
32,465 m AG Spiral Poor 14 7.2 8.8
32,489 m 150 Seamless API 5L X52 Poor 20 7.5 9.8
32,792 m 190 Seamless API 5L X52 Bad 20 9.6 10.9
33,664 m 60 20 7.9 8.2
36,144 m AG Spiral API 5L X52 20 7.0 7.2
Spiral API 5L X52 Poor 20 6.9 7.5
53,144 m AG Seamless Poor 20 13.0 15.1
54,231 m AG Spiral API 5L X52 Poor 20 8.6 9.255,569 m 95 Spiral API 5L X52 Bad 20 7.9 11.9
55,726 m API 5L X52 Bad 20 7.8 9.1
Spiral API 5L X52 Poor 20 7.0 7.9
62,725 m 130 Seamless Poor 20 9.3 9.3
63,425 m 150 Seamless Good 20 9.4 10.8
75,231 m 200 20 8.3 9.3
85,213 m AG Spiral API 5L X52 Bad 20 6.5 8.2
91,747 m 160 API 5L X52 20 9 9.4
100,026 m AG Spiral API 5L X52 Bad 20 9.5 9.5
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According to the information received from the client, the
bypasses should have been constructed in parallel positions to the
old pipeline, and connected with elbows to the original line. It was
later discovered that this was not the way these bypasses had been
constructed.
After a second detection survey, in which these connections were
still undetectable, the client mobilised its eld inspectors and the
construction company who carried out the bypass construction
to indicate the positions in the eld. During this identicationsurvey we were informed about the changed construction method
for the bypass connections: over a length of 50100 m the new
pipeline was positioned in the original route of the old pipeline and
connected without the elbows as indicated during the project scope.
Due to some landowner issues and high water conditions, there
were some locations which could not be accessed, and at which
excavations were therefore cancelled by the clients project
management and ILF. At the other excavations, the pipeline
diameter and wall thickness were measured and a general
inspection of the coating was performed.
Bends (elbows)In agreement with the client, the locations of short-radius bends
and elbows which were excavated during the pipeline-detection
survey to investigate the bend type, radius, change of direction
angle, wall thickness, position, depth, and coating condition
were selected. Table 3 shows the data from these investigations.
According to EN 1594, eld bends for pipelines greater than 16
inches in diameter shall have at least 40 times the diameter: this is
a radius of 16 m for 16 inches, and 20.3 m for 20 inch pipes. Factory
bends can have smaller radii. In general bends, made of segments
(mitred, or cut elbows) are not permitted according to EN 14161.
While only performing visual inspection on the investigated
bends, it was not possible to identify if the bends were mitred orfactory bends.
Wall thicknessAccording to EN 1594 the minimum required wall thickness is
calculated with following equation:
where:
DP = design pressure (bar)
DOD = outside diameter (mm)
fo = utilisation factor according to EN 1594Rt0.5 = yield strength according to API 5L (N/mm)
This equation does not consider any supplemental wall
thickness, such as might be used for corrosion. Also, the equation
Table 6: Wall thickness measurement or the Route 2 pipeline.
Table 7: Clients technical specifcation or wall thickness.
ChainagePipeline
depth (cm)Pipe type Grade
Pipe
condition
Pipe
diameter
(inches)
Wall
thickness
min (mm)
Wall
thickness
max (mm)
013 m AG Seamless API 5L X52 Fair 814 7.7 8.0
94 m 90 Seamless API 5L X52 Bad 16 8.2 8.9
466 m AG Spiral API 5L X52 Corrosion 16 6.9 7.3
657 m 80 Spiral API 5L X52 Corrosion 16 7.0 7.3
3,160 m 120 Spiral API 5L X52 16 10.0 10.8
3,407 m 150 API 5L X52 16 6.3 6.8
3,411 m AG Spiral API 5L X52 Corrosion 16 7.2 10.8
3,439 m 130 Seamless API 5L X52 16 10.9 11.8
6,318 m AG Spiral API 5L X52 Corrosion 16 11.3 12.8
Spiral API 5L X52 Corrosion 16 11.5 13.5
8,976 m 130 API 5L X52 16 6.3 6.8
9,319 m 100 API 5L X52 16 9.9 10.6
18,655 m 120 Spiral API 5L X52 Corrosion 16 10.0 10.022,207 m 120 Spiral API 5L X52 Corrosion 16 9.3 10.1
22,227 m 120 Spiral API 5L X52 Corrosion 16 7.5 7.6
26,757 m AG Spiral API 5L X52 Corrosion 16 7.6 8.8
Pipe diameter
(inches)
Design pressure classes
Wall thickness
(mm)
Alternative
wall thickness
(mm)
(client approval
needed)
GradeANSI ISO (bar)
16 400 64 12.5 8.8 L360 NB
20 400 64 14.2 10 L360 NB
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is only a rule of thumb and is valid for straight pipe (not for
bends).
For the Route 1 pipeline with its original operating pressure of
36 bar, an fo of 0.72 (which is the reciprocal safety factor), and Rt0.5
of 360 N/mm, this leads to a minimum wall thickness of 3 mm for
the 16 inch pipeline, and one of 3.9 mm for the 20 inch pipeline.
For the Route 2 pipeline with an original operating pressure of
42 bar, a wall thickness of 3.6 mm is the absolute minimum
required.
To these values a safety design factor of 2 mm and a corrosion
allowance of 3 mm is to be added, giving the following results:
Route 1: wall thickness >8 mm for the 16 inch and 8.9 mm
for the 20 inch pipelines
Route 2: wall thickness >8.6 mm for the 16 inch pipeline.
According to the clients technical specication, based on the
local standard for wall thickness calculations, the specications
in Table 7 are given, included the prescribed 2 mm safety design
factor and the 3 mm corrosion allowance. All wall thicknesses
below the minimum prescribed values are marked in red in
Tables 5 and 6.
Material
The information received from the client stated that there is onlyAPI 5L X52 and L360 linepipe material used for these pipelines.
According to API 5L, the API 5L X52 and the L360 linepipe
materials are equal. The minimum yield strength (Rt0.5) is 360N/
mm and the chemical composition for X52 gives maximum
contents (mass fraction) of 0.26 per cent carbon, 1.4 per cent of
manganese, and 0.03 per cent of phosphorous and sulphur for
welded pipes (in non-sour service).
Radiographic inspection (x-ray)During the ultrasonic testing (UT) of the pipelines, some
very badly welded seams were visually observed, and it was
recommended to the client that they be checked or examined
by radiographic means. Twelve welded joints were therefore
investigated by means of x-ray inspection to gather information
about the general quality of some suspicious welding joints. The
radiographic test where executed on three joints on the 20 inch
line, two joints on the 24 inch line, six joints on the 16 inch line,
and one joint on the 14 inch line.
The nding after evaluation of the discontinuities on the
radiographic lms were that there had been incomplete
Figure 3: Examples o poor welding.
Table 8: Inspected welded joints.
Chainage value No. Measured Positive result Negative result
3411 MS14 1 (joint) on 14 inch Rejected
6318 MS23 1 (joint) on 16 inch Rejected
5054 IP22 1 (joint) on 24 inch Approved
5054 IP22 1 (ws) on 20 inch Approved
11628 IP34 w1 1 (joint) on 16 inch Rejected
11628 IP34 w2 1 (joint) on 16 inch Approved
11628 IP34 w3 1 (joint) on 16 inch Rejected
31604 IP60 1 (joint) on 14 inch Rejected
32315 IP61 1 (joint) on 16 inch Rejected
53144 IP85 1 (joint) on 20 inch Rejected
85213 IP120 w1 1 (joint) on 20 inch Rejected
85213 IP120 w2 1 (joint) on 20 inch Rejected
Results of the 12 investigation points 3 Approved 9 Rejected
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penetration and/or incomplete fusion, and nine of the 12
investigated joints were therefore rejected. Figure 3 ab and
Table 8 give further details.
Visual inspectionFor all above-ground installations, excavations, and
UT investigation sites, a visual inspection was carried out
which included identification of the pipe type (spiral or
longitudinally welded), the identification of bends, and the
measurement of diameter and wall thickness. Also the general
state of the coating was evaluated and recorded.
For above-ground installations such as flanges and
valves, the general state, presence of all bolts and nuts, and
the corrosion condition, were recorded. The presence of
handwheels for the valves were also checked.
Along the pipeline route there are many roads crossings,
some of which have ventilation pipes which indicate an
installed casing. On the locations where there were no
ventilation pipes observed, especially on the national roadsand highways, it was assumed that, according to the old
standard that was in place during the construction of the
original pipeline, the ventilation pipes were corroded, had
disappeared or been stolen for scrap metal collection.
Data on all road crossings was obtained, regardless of road
type minor, secondary, national, or highway. Some casings
made of old oil barrels under a minor road were detected,
as well as some concrete pipes as a kind of casing under a
secondary road. It was assumed that many of these crossings
had not been constructed in conformity with the old standard,
and certainly they were not in accordance with new standards
and practices.
At some water crossings the pipe could be seen lying directly
in the watercourse. According to European norms, the rule for
thumb for water crossings is to cross at least 0.8 m below the
deepest point of the water course.
Instrumentation and pipeline valvesIn general, the inspected instrumentation and valves were in
a very poor condition, and it was not certain whether the valve
diameter matched the pipeline diameter for many valves. None
of the valves could be remotely controlled and, in many cases,
the handwheels to operate the valves were missing. Even if
there was a handwheel, it was very hard or even impossible
to operate due to corrosion. In some cases flange bolts weremissing. Mostly the external conditions were between bad
and poor, and paint had been used for corrosion protection (if
existent at all). At facilities, where identifiable, the pressure
class was PN64.
LeakagesDuring the pipeline detection survey leakages were detected
which were immediately reported to the client. The client had
recorded all leakages on the pipelines in the previous two
years: the total number of reported/recorded leakages in 2008
was 28.
The repair methods were neither in accordance to the qualitycontrol and safety standards of the client nor to internationally
accepted standards (Fig.4 a-c). Most repairs were observed as
being executed by simple steel screwed-on clamps, withoutFigure 4: Examples o poor reinstatement.
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even removing and reinstalling the coating. Some severe
damage caused by excavation works for leakage repair was
also observed on the pipeline.
Buoyancy protectionIn areas where the soil contains a lot of water (moor or
marsh), and also for larger river crossings, buoyancy protection
for the pipeline is required and is mandatory. According to the
European standard EN 1594, the pipe should be ballasted or
anchored, if necessary, in areas where the pipe tends to float or
because of the high groundwater table.
It was seen that some kind of buoyancy protection for the
pipelines had been used in a few locations, although this was
neither according to European standards nor sufficient. At
a few locations the bare pipe was seen lying directly in the
water, covered by some concrete blocks (Figure 5).
Pipeline integrity assessment
Pipelines to be rehabilitated
The pipeline system is a combination of pipelinesconstructed in the 1970s and some new sections that have
been constructed in recent years due to leakages. The newly
constructed pipeline are 16 inch diameter L360 NB with a
three-layer polyethylene (PE) coating; the old, original, 20 inch
diameter pipeline was constructed from API 5L X52 steel with a
bitumen coating.
Because of the bad coating condition of the old pipelines,
frequent leakages, river and road crossings situations, reduced
wall thicknesses, poorly maintained pipeline furniture,
non-classified elbows, non-existing cathodic protection
(CP) system, non-piggability, and bad welding quality, a
rehabilitation was considered for all the old pipelines to thespecification of the newly constructed pipelines to bring this
pipeline system back to fit-for-purpose condition and to be in
line with the standards and pipeline safety regulations.
This meant that there should be rehabilitated 101 km of
new 16 inch pipeline would be installed. The rehabilitation
sequence/steps and detailed explanation are discussed later.
Integrity status conclusions
Integrity managementA pipeline integrity management plan had not been
implemented, and there was no knowledge of the pipelines
integrity. Maintenance had only been carried out in a poor
manner following failure, leakage, or breakdown. The followings
aspects were observed:
Generally, there was no CP system installed; the one that
was partly installed on Route 1 was not maintained.
Wall thickness measurement indicated that, in thelocations that were investigated, +/- 90 per cent, was not
sucient according either the clients standard or the EN
standard.
There was no coating investigation routine, such as direct
current voltage gradient (DCVG).
The lines are not piggable because of:
Elbow and bend radiuses and welds
Gate valves are not full-bore
Diameter reductions
Dierent pipeline diameters
No pig launcher or receiver stations.
Health, safety and environmentThere had been frequent leakages along the pipeline because of
internal and external corrosion, pipe stresses, and geographical
Figure 5: Concrete blocks used at a river crossing.
Figure 6: Concrete block laying on the pipe.
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inuences (such as landslides). This was environmentally
unjustiable and public safety, as well as the safety of the clients
personnel, was in jeopardy. Corporate reputation was also at
stake; when a serious incident occurs, it is realistic to assume
that the pipelines present integrity status will be examined and
published by the public media. As mentioned already, there had
been 28 leakages detected and reported in the last two years.
Pipeline operationWhen looking at the status of the installations and situations
along the pipelines, very strong doubts arose concerning the
qualication and pipeline integrity knowledge of the pipeline
operators. It was strongly suggested that the pipeline operators
and inspectors should be urgently trained in pipeline integrity,
safe operating work procedures, and safety awareness.
For example, an inspectors alarm bells should normally
go o if he observes a heavy concrete block of a few 100 kg
laying on top of the pipeline (Figure 6), or when a pipeline is
completely kinked because of the support of the river crossing
has collapsed (Figure 7).
Steps for rehabilitationThe integrity status of the pipeline had a very low quality, and
the situation was very dangerous for both public safety and the
pipelines direct environment. The asset utilisation and asset
capability were both greatly reduced because of this poor integrity
status, and it was just a matter of time before the pipeline would
have been out of service for a lengthy period because of an
incident.
The following steps for rehabilitation were therefore considered:
Coating integrityChecking the coating of the previous, already constructed
L360 NB pipelines by DCVG and measure the soil resistivity of
the complete pipeline routes.
Design for cathodic protection and isolation couplingsThe CP system must be designed, taking the previous soil
resistivity survey results as base, for an adequate external
corrosion protection. During this design the optimum
and preferable positions for isolation couplings are to be
calculated.
Pipeline exchangeExchange the old API 5L X52 pipeline material with the L360
NB and three-layer PE coating (according to DIN EN ISO 21809).
This means the complete exchange of the 26.766 km Route 2
line and the remaining 74.899 km of 16 inch diameter old Route
1 pipeline. The design of the new pipeline should be piggable
with launcher and receiver stations, and with piggable bends
and valves.
CrossingsAll pipeline crossings should be made by directional drilling,
horizontal directional drilling, or prefabricated siphons; if this
is not possible, existing crossings should be rehabilitated to beof a safe and reliable construction (Figure 8).
Line valves and valve stationsNew 16 inch full-bore line valves should be located in above-
ground stations, and preferably equipped with remote process
control (safety response), and pressure and temperature
transmitters. This means that electrical power supply and
communication, by public network, satellite, or by dedicated
fibre optic cables along the line, will be necessary.
Location of isolation couplings
The requirements for isolation couplings depend on the CPsystem that is to be installed. The exact locations for isolation
couplings cannot be specified until that time.
Figure 8: Pipe bent due to
ground movement.
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Fencing and markersAll above-ground installations should be fenced-in to out keep
unauthorised people and to hinder unauthorised operations.
On the fences, the product identication codes and telephone
numbers should be visible.
All changes in direction and crossings should be identied
with state-of-the-art markers. These markers should have
the clients identication/tag plates on which the emergency
telephone numbers and the position identications are clearly
visible. According to the new standards, the next upstream and
downstream positioned markers should always be able to be
seen, to enable the identication of the pipeline route.
PIMS (pipeline integrity management system)
Pipeline operationsA training programme for pipeline operators and pipeline
inspectors should be set up to make them a part of the PIMS. This
will stimulate a professional dedication to their job and a sense of
responsibility.
It is also important that the operators report their work and
observations to a focal point at their department (the integrity
engineer) in order to gather together all relevant information for
implementation in the new GIS system, and to make it possiblefor the integrity engineers to evaluate the right statistics in order
to initiate maintenance and other relevant actions for integrity
management. The PIMS should include an inspection programme
and a maintenance programme.
Route inspection programmeFor an inspection programme, the following aspects are to be
included:
A time schedule for car, walking, and/or helicopter
inspections.
The pipeline must be clearly indicated by markers.
Templates for inspection reports are to be made. All itemsand installations must be listed, dening how and what is
to be checked and inspected; this includes geographical and
topographical changes.
Figure 9: Unauthorised
excavation o unused section
o line.
Figure 10: The process o managing integrity.
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Procedures are to be set up concerning what is to be
inspected, what is be to reported, how the reports are to be
made, and to whom the reports are to be given.
A schedule for ILI to observe the feature degradation and to
plan maintenance.
Maintenance programmeIn the course of time, several maintenance strategies were
developed with their own advantages and disadvantages. The three
major existing categories of maintenance are:
Corrective maintenance (CM)
Preventive maintenance (PM)
Risk-based maintenance (RBM).
Corrective maintenanceThe CM strategy is independent of time or condition of
the system, and the work consists only of repairing defective
equipment. Thus, the unscheduled and unpredictable work leads
to relatively low costs. High expenditures could arise, however,when the whole system has to be shut down because of the repairs.
Preventive maintenancePM contains all the work/interventions performed periodically
on critical units according to specied instructions, or vendor
maintenance manuals, recommendations, and procedures.
Examples of PM are:
Greasing the valves
Function testing line valves
Emission testing valve seals and compressor/pump seals
Intelligent pig runs
DCVG coating investigation
Close interval potential survey measurements
Cleaning/drying liquids in the pipeline (semi-routine) by
pigging or drain systems.
An extension of preventive maintenance is condition-based
maintenance, which has to be developed for each individual
pipeline system on the basis of the experience during the rst
years of operation, followed by continuous improvement based
on actual experience (the Deming circle).
Risk-based maintenanceIn risk-based maintenance, the system and its components are
evaluated in terms of their probability of failure and the risks
involved (Figure 10). The results are visualised in a risk matrix.
With the focus on the relevant system components for the
operation, the integrity of the whole system is improved. Highly
qualied sta are required to undertake this analysis.
In central Europe, it is recommended that condition-based
maintenance is regularly undertaken to achieve a high reliability
of the individual components and thus for the whole system.
Quantitative risk assessmentBefore commissioning a pipeline a quantitative risk
assessment (Bowtie) should be set up and implemented for
all installations and equipment as well as for the pipeline route
itself. By evaluating the possible internal and external risks it is
possible to direct and customise the operational and integrity-
management system in the high-risk areas along the pipeline,
which include high density population areas, industrial areas,
environmentally sensitive areas, landslide areas, mining areas,
rivers and water crossings, direct current rail tracks, highways,
and parallel crossings with high-voltage power lines.
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