Hydrocarbon Processing - June 2021 - GP-14

SPECIAL FOCUS: PIPELINES AND TRANSPORT
Field marking of CMLs is of utmost
importance and can be achieved through
many ways, including in-house resources
or external support. Insulation demands
more work than bare piping; however,
it should be kept in mind that marking
CMLs is a one-time activity for as long
as the CMLs remain the same. Solutions
FIG. 2. Inspection port shown as an example for CML reading.
(FIG. 2) are available for each marking requirement
including piping, thin insulation,
thicker insulated tanks, vessels, hot
service and even cryogenic processes.
90° elbow
U-bend
45° elbow
Step 7: Performing inspection on
CMLs. After CMLs are defined, the core
business of recording the actual readings
starts. How to take these readings is of
utmost importance. A more relative term
used for thickness recording is thickness
monitoring locations (TMLs). If a CML
is defined only for thickness monitoring,
then TMLs can be defined for that specific
CML.
Each CML can have multiple TMLs.
Tee
Concentric reducer
FIG. 3. Typical TMLs for different piping fittings.
The type of inspection task to be performed
on a given CML also impacts the
total number of CMLs. Ultrasonic thickness
inspection, the most common task
performed on piping, gives only the data
related to corrosion or pressure boundary
thickness. Other necessary inspections
may include temperature monitoring at
desuperheater locations or profile radiography
to search for debris accumulation at
piping deadlegs. CMLs to monitor such
conditions are specific and largely unlimited.
Wall thickness measurements, obtained
through ultrasonic thickness testing, can
be limited or controlled to some extent.
During the project design phase, the
definition of corrosion allowance for
any piping system is given after carefully
studying the anticipated corrosion rate
of the metallurgy put into service, with
reference to a defined design life. The
corrosion allowance definition should
be respected; however, it should also be
14 MAY/JUNE 2021 | GasProcessingNews.com
reviewed and verified-this is the core
work of the inspection team monitoring
the piping systems.
When CMLs are defined for corrosive
services, an appropriate metallurgy
and corrosion allowance combination
for the design life must also be in place.
Careful attention must be paid to the
verification of this combination through
minimum CMLs.
Step 6: Field marking. CML markings
on isometrics should be replicated
as closely as possible in the field. This
becomes especially important when data
must be analyzed and CMLs must be
redefined. Inaccuracy in positioning the
CMLs can result in incorrect or irrelevant
readings for the analysis. When looking
into the records of any industry, the data
from a single, incorrectly located CML
can be seen to follow an erroneous pattern
over time.
Eccentric reducer
As a general rule, along a 360° band of piping,
readings should be recorded at each
quadrant, with each reading representing a
single TML. Different recommendations
are available to define TMLs on different
CMLs in piping. One recommended definition
for different piping configurations
and fittings is shown in FIG. 3.
Marking CMLs for all piping groups
provides a baseline work for evaluating
and maintaining piping integrity. When
performing this marking work, each step
as defined above should receive proper
attention. Ignoring any of the seven recommended
steps may lead to recording
incorrect data that may not be representative
of the piping integrity. GP
ASHFAQ ANWER is an Inspection
Engineer working in gas processing
in Ruwais, Abu Dhabi, UAE.
He has more than 14 yr of
professional inspection experience
in ammonia-urea complexes,
petrochemical units, and oil and
gas industries. He has extensive expertise in material
selection, corrosion mapping and control, fitness-forservice
studies, defining inspection framework and
implementing inspection plans for old and new units.
KAISER ALAM is an Inspection,
Corrosion and Metallurgy
Specialist with more than 7 yr
of experience in static equipment
inspection, fitness for service,
material selection, and inspection
strategies and procedures.
His experience is predominantly in the downstream
oil and gas industry in the Middle East.
http://www.GasProcessingNews.com

Hydrocarbon Processing - June 2021

Table of Contents for the Digital Edition of Hydrocarbon Processing - June 2021

Contents
Hydrocarbon Processing - June 2021 - Cover1
Hydrocarbon Processing - June 2021 - Cover2
Hydrocarbon Processing - June 2021 - Contents
Hydrocarbon Processing - June 2021 - 4
Hydrocarbon Processing - June 2021 - 5
Hydrocarbon Processing - June 2021 - 6
Hydrocarbon Processing - June 2021 - 7
Hydrocarbon Processing - June 2021 - 8
Hydrocarbon Processing - June 2021 - 9
Hydrocarbon Processing - June 2021 - 10
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Hydrocarbon Processing - June 2021 - 28
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Hydrocarbon Processing - June 2021 - 33
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Hydrocarbon Processing - June 2021 - 89
Hydrocarbon Processing - June 2021 - 90
Hydrocarbon Processing - June 2021 - Cover3
Hydrocarbon Processing - June 2021 - Cover4
Hydrocarbon Processing - June 2021 - GP-1
Hydrocarbon Processing - June 2021 - GP-2
Hydrocarbon Processing - June 2021 - GP-3
Hydrocarbon Processing - June 2021 - GP-4
Hydrocarbon Processing - June 2021 - GP-5
Hydrocarbon Processing - June 2021 - GP-6
Hydrocarbon Processing - June 2021 - GP-7
Hydrocarbon Processing - June 2021 - GP-8
Hydrocarbon Processing - June 2021 - GP-9
Hydrocarbon Processing - June 2021 - GP-10
Hydrocarbon Processing - June 2021 - GP-11
Hydrocarbon Processing - June 2021 - GP-12
Hydrocarbon Processing - June 2021 - GP-13
Hydrocarbon Processing - June 2021 - GP-14
Hydrocarbon Processing - June 2021 - GP-15
Hydrocarbon Processing - June 2021 - GP-16
Hydrocarbon Processing - June 2021 - GP-17
Hydrocarbon Processing - June 2021 - GP-18
Hydrocarbon Processing - June 2021 - GP-19
Hydrocarbon Processing - June 2021 - GP-20
Hydrocarbon Processing - June 2021 - GP-21
Hydrocarbon Processing - June 2021 - GP-22
Hydrocarbon Processing - June 2021 - GP-23
Hydrocarbon Processing - June 2021 - GP-24
Hydrocarbon Processing - June 2021 - GP-25
Hydrocarbon Processing - June 2021 - GP-26
Hydrocarbon Processing - June 2021 - GP-27
Hydrocarbon Processing - June 2021 - GP-28
Hydrocarbon Processing - June 2021 - GP-29
Hydrocarbon Processing - June 2021 - GP-30
Hydrocarbon Processing - June 2021 - GP-31
Hydrocarbon Processing - June 2021 - GP-32
Hydrocarbon Processing - June 2021 - GP-33
Hydrocarbon Processing - June 2021 - GP-34
Hydrocarbon Processing - June 2021 - GP-35
Hydrocarbon Processing - June 2021 - GP-36
Hydrocarbon Processing - June 2021 - GP-37
Hydrocarbon Processing - June 2021 - GP-38
Hydrocarbon Processing - June 2021 - GP-39
Hydrocarbon Processing - June 2021 - GP-40
Hydrocarbon Processing - June 2021 - GP-41
Hydrocarbon Processing - June 2021 - GP-42
Hydrocarbon Processing - June 2021 - GP-43
Hydrocarbon Processing - June 2021 - GP-44
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