otc-7576-ms dewatering and commissioning the cats
TRANSCRIPT
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OTC 7576
Dewatering and Commissioning the UK Central Area Transmission
System (CATS) Pipeline
G.L. Langford, T,E. Krisa, and M.L. McCrary, Amoco Production Co.
Copyright 1994, Offshore Technology Conference
This paper was presented at the 26th Annual OTC in Houston, Texss, USA., 2-5 May 1994.
Thie peper was ealec ted for presentat ion by the OTC Program Committ ee fol lowing review of Information conta ined In an abstract submiftad by the author(a ). Contents o f the pap+3r,
as presented, have not been reviewed by tha Offshore Technology Conference end are subject to C=Jrrectlonby the author(e) . The mater ial, as presanted, does not necasssrily ref lect
anv rmelt ion of the Offshore Technolow Conference or ita off icers. Permission toCOPYIsrestricted to an abstract of not more than S00 words. I lluatrat lone may not be copied. The abatract
shi ti ld centa in consp lcuoua acknowledgment o f where and by whom tha paper Is“prasented.
ABSTRACT
A rnor?oethyler?eglycol swabbing technique was used to
successfully cfewafer the 36” diameter, 410 kilometer,
Central Area Transmission System CATS gas pipeline in
the United Kingdom, and condition it for hydrate inhibition.
The chronicle and analysis of the operation provides
insightful information for design of future dewatering and
commissioning operations. The process worked so
effectively that the pipeline was not only conditioned, but
was dried such that target product water dew points were
met shortly after start-up. The method was flexible and
integrated well with other associated project construction
work. The duration of the actual dewatering/conditioning
operation was significantly less than that for the commonly
used vacuum drying method. The keys to the success
were the excellent sweep efficiency of the pig/glycol train
and the aggressive and flexible execution philosophy.
INTRODUCTION
The Central Area Transmission System consists of an
offshore riser platform in the Central Graben Area of the
North Sea, a 410 kilometer long 36” diameter high-
-pressure subsea gas pipeline, and an onshore gas
receiving and metering terminal at Teesside on the
northeast coast of England. The Central Graben
Development, comprising the installation of the North
Everest and Lomond production platforms, and the CATS
Figures at end of paper
581
project, were executed concurrently. Please refer to ‘
Figure 1 for a schematic diagram of the production and
pipeline facilities and their relative locations. The Riser
Platform, located adjacent (and bridge connected) to North
Everest, receives dry gas from the North Everest and
Lomond platforms and transfers the production do the
CATS pipeline. The CATS pipeline has capacity to
transport additional gas production from future platfortns in
the central North Sea.
*
Referring again to Figure 1, the CATS pipeline runs from a
pig launcher on the Riser Platform to landfall at Teesside,
402 kilometers away. From there, the onshore portion of
the pipeline traverses a beach valve station, runs under the
River Tees in a flooded tunnel, and terminates at a ,pig
receiver at the gas terminal. The onshore pipeline is
approximately eight kilometers long.
The North Everest and Lomond platform and CATS
pipeline projects were executed with a “fast-track”
approach, in order to deliver gas by April 1, 1993, as
required by contractual agreements. Detailed engineering
kicked-off in April 1990. The pipeline was completed and
ready for service on schedule.
To meet the schedule, glycol swabbing, rather than
vacuum drying, was used to condition the pipeline. The
glycol swabbing technique used to dewater the CATS
pipeline was a major contributor to project success. The
dewatering and commissioning objectives were to
dewatet’, condition to avoid hydrates, and fill the pipeline
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2
DEWATERING AND COMMISSIONING THE UKCENTRAL
OTC 007576
AREA TRANSMISSION SYSTEM (CATS) PIPELINE
with sales quality gas from shore, prior to platform
completion, start-up, and gas production. Despite
numerous equipment problems and delays due to both
conflicting operations and bad weather, this method
allowed these objectives to be achieved.
Pipeline dewatering was accomplished using an eight-pig
train with monoethylene glycol (MEG) for water absorption
and hydrate inhibition. The train was propelled from the
onshore terminal to the offshore Riser Platform using dry
air. Valve damage resulting from the pigging operation
necessitated a variation to the original commissioning
program to allow repair. Rather than displace the remaining
air from the line after valve repair by pushing a buffer pig
train with gas from the onshore UK gas grid, the air was
displaced by low pressure nitrogen. The nitrogen was
followed by gas without involving the use of additional
pigs.
EXECUTION
-Pi~elineDewatering
Equipment was mobilized at Teesside to facilitate the
launching of eight hi-directional polyurethane pigs using
alternating slugs of MEG and dry air. The trailer and skid
mounted equipment spread included seventeen air
compressors, six air dryers, two glycol pumps, and four
glycol tanks. The design called for a nominal flow of
17,000 m3/hr of 1800 kPag dry air to propel the pig train at
an average speed of 0.5 mh. Equipment mobilization at
the Riser Platform was minimal, as the overboard water
dumpline had been previously fabricated and installed by
the offshore hook-up contractor. A manifold allowed
pipeline water to be routed overboard upstream of the pig
launcher for maximum flow during the dewatering process,
or through the launcher, as required, to recover the pigs.
Refer to Figure 2, Riser Platform Pig Launcher Schematic.
The pig train was launched using the CATS Terminal
pipeline receiver as a launcher. This presented no problem
as the lines to the closed drain had been valved such that
they could be used as the “kicker” line. Refer to Figure 3
for a schematic of the CATS Terminal pig receiver. The first
pig was launched with compressed dry air. A buffer of
1500 linear meters of dry air at pipeline temperature and
pressure was injected prior to launching the second pig
with glycol. A 260 m3 slug of glycol then preceded the
launch of the third pig with dry air. This procedure was
repeated with alternating slugs of compressed air and MEG
separating the remaining five pigs. Figure 4 depicts the pig
train. An inhibitor was injected into the third glycol slug to
provide corrosion protection to the pipeline wall.
Launching the pig train took place as planned without
incident. Pig train location was determined by calculating
582
the linear distance traveled based on the metered volume
of air injected at Teesside, and by the volume of water
discharged at the Riser Platform.
With the actual pig train speed of 0.34-0.37 m/s, the
estimated time for the first pig to arrive at the Riser Platform
was approximately two weeks. However, within a week of
launching the pig train it became apparent that a conflict
with the installation of the bridge-linked North Everest
Platform would necessitate a slow-down of the pig train.
The Riser Platform would be left unattended during this
operation. No hazard was identified with continuing the
overboard dumping of water from the pipeline, but
manning would be required to recover the pigs. Thus a
slowdown was attempted to delay the arrival of the pig train
at the Riser Platform. The potential schedule conflict with
the weather-dependent platform installation was
recognized when the pig train was launched. The
likelihood of the conflict was low and the risk was accepted
in accordance with an aggressive project schedule
execution philosophy.
Although the attempt was made to just slow the train
speed, continuing weather delays extended the North
Everest installation period until a complete and continued
stoppage became inevitable. Access to the Riser Platform
was unavailable for twenty-three days, during which time
the pig train stopped twice. Meanwhile, the batteries for
the ultrasonic flow meter measuring the overboard volume
ran down, leaving metered air injection at Teesside as the
only method of determining pig train location. The first pig
arrived at the Riser four days after restating the pig train.
The pigs were recovered on the Riser Platform using the
pipeline pig launcher as a receiver. This proved difficult
because of its vertical orientation. An internal basket was
fabricated by the launcher manufacturer to catch and retain
the pigs for removal two at a time. However, the first pig
jammed in the bottom of the basket with a piece of a
welding bladder remaining in the pipeline from a previous
operation. The pig was jammed so tightly that it could not
be removed from the basket. The wear on the pigs was
minimal, therefore much of the oversized outside diameter
of the pig discs remained upon arrival at the Riser. Without
excessive disc wear, the pigs exerted sufficient
circumferential pressure on the pig launcher internal walls
to support their weight, and the decision was made to
abandon the use of the basket and recover the pigs
individually.
The second problem encountered in recovering the pigs
was a loss of sealing capability in the pipeline riser valves.
The first two pigs were recovered using the main valve
below the pig launcher for isolation, as customary.
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OTC 007576
G. L. LANGFORD, T. E. KRISA AND M. L. MCCRARY
3
However, the valve started passing at a rate that prevented
the launcher from being vented down upon attempting to
remove the third pig. The emergency shutdown (ESD)
maintenance valve was then used to isolate the pipeline for
pig removal. This method was successful for recovering
the second two pigs before it, too, began passing to the
extent that the launcher could not be vented. The
remaining pigs were then successfully recovered by
closing both the pig trap isolation and the ESD
maintenance valves and leaving the overboard dump line
open to atmosphere.
The recovered glycol met the established acceptance
criteria and the dewatering was complete. Piping re-
instatement, valve investigation and repairs, and nitrogen
leak testing of the Riser topside gas process piping were
then carried out. The pipeline had to be vented to perform
the valve repairs. A gauging pig run (discussed in a later
section) also became necessary prior to commissioning.
N-Moue
n/Hydrocarbon Gas Pura
ina and Line Packinq
The pipeline was purged with atmospheric pressure
nitrogen using a nitrogen pump/vaporizer at Teesside and
opening the pipeline to flare on the Riser Platform. The
target flowrate was 3,000 m3/h, with a minimum flow of
1,200 m3/h. These flowrates were required to prevent
excessive nitrogen-air interface mixing, likely when
velocities fall below 0.5 m/s. A total of 1-1/2 pipeline
volumes of nitrogen were injected to purge the line.
Following the introduction of the first line volume, sampling
of the purge gas commenced on the Riser Platform. Once
the oxygen COtWfIt
measured
SO/.
or
k?SS,
pUrging Of the
deadleg piping on the Riser topsides was carried out.
Purging continued until the entire volume of nitrogen had
been injected at Teesside.
Hydrocarbon gas-up of the pipeline commenced
immediately after nitrogen purging. Natural gas from the UK
gas grid was used for this purpose. The gas purge was to
be at atmospheric pressure, similar to the nitrogen purge,
though the gas supply pressure was 6000 kPag. This
necessitated the use of a water bath heater to warm the
gas to at least -5°C to offset the cooling effect of the
pressure reducing valve, and thereby avoid hydrates. After
injecting )7Y0 Of a tine VOkH?N? Of natUral gas intO the
pipeline, sampling commenced on the purge gas at the
Riser Platform. Once the hydrocarbon content of the gas at
the Riser reached 950/., the pipeline was shut-in and gas
injection at Teesside continued in order to pack the line,
completing the commissioning process. The topside gas
piping at the Riser was left with a nitrogen blanket,
500 kPag above the final pipeline pressure, to prevent
hydrocarbon gas from entering the process piping prior to
platform commissioning and start-up.
The purging and commissioning operations were
successful with no problems encountered. The interfaces
between air and nitrogen, and between nitrogen and
hydrocarbon gas, were distinct, with only a fifteen-to-
twenty minute time duration between detection of the
purge gas and attainment of acceptance criteria.
DESIGN OF DEWATERING PROCESS
The objective of the dewatering/commissioning process
for the CATS pipeline was to bring the pipeline into
operation as quickly as possible, while meeting the delivety
gas dew point target as early as possible in its operating
life. The alternatives considered for the drying operation
were: (1) bulk water removal by pigging, followed by
vacuum drying, (2) swabbing with a methanol train, and
(3) swabbing with a glycol train. Vacuum drying, which
would have given the highest likelihood of achieving the
delivery gas dew point early in operating life, was not used
because of the long time period for the drying process.
Even without layout limitations at the Riser Platform end,
the duration of the vacuum drying process was
unacceptable considering project schedule constraints.
Glycol swabbing was chosen in preference to methanol,
because the low volatility of glycol results in glycol
remaining with any residual water in the pipeline after the
operation to inhibit hydrates. Glycol also poses a lower fire
risk than methanol.
To achieve the glycol swabbing, the glycol train was
designed to travel from the onshore terminal to the
offshore Riser Platform. The prime factors for flowing in this
direction were the available space onshore to arrange the
large air compression system, and the availability of a large
supply of gas from the national grid to provide an initial fill
for the pipeline.
The key elements of the pig train design were as follows:
9
583
Two 260 m3 slugs of glycol were expected to be
adequate based on experience. A third slug was
added as a safety margin to reduce the possibility of
failure which would result in the requirement to repeat
the operation.
Air was used as the propelling agent for the pig train to
enable the running of a second train if the glycol
dryness criteria was not met.
The buffer zones between glycol slugs provided the
ability to sweep bypassed ~quids and allowed liquid
accumulations in the subsea tees to drain into the
pipeline
for removalby the following pigs
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4
DEWATERINGAND COMMISSIONING THE UKCENTRAL
OTC 007576
AREA TRANSMISSION SYSTEM (CATS) PIPELINE
Though the pipeline was internally coated to facilitate
gel cleaning prior to dewatering, the design of the
dewatering pigs did not consider reduced roughness
of the pipe. This was because the reduced disc wear
afforded by the coating could not be quantified.
Success for the dewatering operation was established
as a 95”A glycol concentration in the final slug of glycol
arriving at the Riser Platform. This was selected as a
level which would ensure that any residual water in the
line was well-inhibited for hydrates during start-up
operations.
A few additional problems were anticipated during the
design stage of the pipeline. The subsea safety valve at
the Riser end of the pipeline was a swing check valve. This
valve had to be capable of being held open to allow pigs to
traverse the check in either direction. Any materials carried
by the pig train had the potential to damage the ESD valve
at the platform. The risks associated with this potential
problem were accepted, because the valve was designed
so that it could be repaired in place, and the pipeline would
be gel cleaned after construction. The final glycol slug
contained a corrosion inhibitor to protect the pipeline from
corrosion induced by residual water, until the drying
process was completed and the pipeline was in normal
operation.
PIG DESIGN AND TRIALS
uLQ.wm
A number of design characteristics were identified as being
necessary for a successful pig design. Foremost, the pig
was to be a hi-directional design to offer maximum flexibility
in case pig sticking problems were encountered. The
sweep efficiency of the pigs needed to be high to minimize
the residual water on the pipeline wall. Thus, the pig
sealing discs were oversized to 1070/. of the pipeline
internal diameter to allow for wear as the train traveled the
410 km length of the pipeline. The discs were constructed
of a proprietary “high performance” polyurethane for
additional strength and wear resistance.
The pig design was further complicated because the pigs
were required to navigate the short radius ells of the tunnel
under the River Tees, and had to pass through the check
valve at the base of the Riser Platform in the reverse
direction. The pigs needed to be long enough to “bridge”
the drop-off in the check valve, but not so long that they
would have difficulty passing through the short radius ells.
It was also desirable to keep the weight of the pigs to a
minimum, again to help prevent the nose sections from
dropping down and hanging in the check valve, and also to
reduce the energy required to propel the pig train. Finally,
the front and rear sections of the pigs featured nose cones
to aid the pigs in traversing the check valve. See Figure 5
for a general arrangement drawing of the final pig design.
-
To ensure that the pigs would be able to navigate the ells
in the pipeline and pass through the check valve in the
reverse direction, pigging trials were conducted. Sections
of 24” pipe were joined with ells and a mock-up of the
check valve. A 24” pig scaled down from the dimensions
for a 36” pig was used in conducting the trials. Tests
included propelling the pig with both compressed air and
water, and with varying degrees of simulated disc wear.
The test pig passed through the ells and mock check valve
in all cases, significantly increasing confidence in the pig
design.
The pig trials also confirmed the pressure drop necessary
to propel the pigs, thus verifying the validity of the
assumptions used for determining the compression
requirements. The trials were beneficial and are highly
recommended for future applications where the design
effectiveness is uncertain.
PROCESS RESULTS
From a process and operating standpoint, the success of
the dewatering far exceeded design expectations. The
first glycol slug met the acceptance criteria of at least
95’ glycol for the swabbing operation and the latter two
slugs exceeded the criteria substantially. When production
operations began in May of 1993, the gas in the pipeline
met the dew point target for delivery gas shortly after stait-
up. Dew point data for the gas arriving at the onshore
terminal for the first two weeks of operation is shown
below. (The data shown is a spot reading at the same time
each day for the first two weeks of operation. Flow rates for
the first few days were very low and represent a very small
volume of gas. Additionally, there were typical start-up
problems with the dew point analyzers and, particularly in
the early days, calibration was in question).
Dew ?olnt
C) Dew Point ~ Q
1 6.7
8
-22.1
2
5.8 9
-24.2
3
-14.4
10
-28.7
4
-18.5
11 -29.4
5
-21.9
12
-28.9
6
-23.9 13
-26.5
7
-22.7 14
-27.1
No liquids were collected at the onshore terminal. Overall,
the dewatering process was a complete success, resulting
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OTC 007576
in an essentially dry pipeline,
inhibited condition expected.
SCHEDULE
G. L. LANGFORD, T. E.KRISA AND M. L. MCCRARY
5
rather than the wet, but
The dewatering and commissioning operations took place
over a five month period, due to the schedule conflict with
the North Everest production platform installation, valve
testing and repairs, a tanker grounding incident, and
weather delays. Excluding mobilization, demobilization,
and uncontrollable stoppages and delays, however, the
principal dewatering and commissioning activities were
accomplished in seventeen days and eleven days,
respectively. The following table lists key dates during the
dewatering and commissioning operations:
Nov. 2
Nov. 11
Nov. 13
NOV.
16
Nov. 20
Nov. 21
NOV.
25
NOV.
27
NOV. 28
NOV.
29
Dec. 10
Dec. 14
Dec. 17
Dec. 23
Jan. 19
Feb. 22
Mar. 2
Mar. 6
Mar. 13
Mar. 14
Mar. 16
Mar. 17
Mar. 18
Mar. 25
Mar. 26
Commence personnel and equipment
mobilization
Launch first dewatering pig (No. 1)
Launch last dewatering pig (No. 8)
De-man Riser Platform in anticipation of North
Everest Platform installation
Compressor spread shut down 8 hours to slow
pig train
Pig train travel ceases
Pig train commences movement at low speed
Pig train travel ceases once more. Operation put
on hold until personnel able to re-board Riser
North Everest installation complete
Temporary access to Riser allows closing of
dewatering discharge valves
Regain access to Riser. Compressor spread re-
started, pig train commences moving
Pig No. 1 recovered
Pig No. 8 recovered
Commence Riser mainline valve seat testing
Testing complete
Repairs to 36 ESD valve complete
ESD Valve and Riser topside piping leak testing
complete. Tanker drags anchor across pipeline
route during storm
Commence gauging pig run
Gauging run complete
Commence nitrogen purging
Receive consent to operate pipeline from UK
authorities (required to introduce hydrocarbon
gas)
Nitrogen purge complete, commence
hydrocarbon purge
Hydrocarbon purge complete, pipeline shut-in,
continue line packing
Pipeline at 4600 kPag, line packing complete
Receive Certificate of Fitness for Riser Platform
{required to start operation)
Mar. 27 Demobilize pipeline commissioning equipment
Much of
and personnel
the delay during the valve testing and repair
period was due to extended off-station time for the flotel
because of weather. A key to success is starting activities
as soon as possible to allow for unavoidable delays. Even
with the problems and delays encountered, the CATS
pipeline was ready for operation before the April 1, 1993
target date.
The glycol swabbing technique afforded substantial
schedule savings compared to vacuum drying. The actual
vacuum drying process could not have started until the
bulk of the water had been removed by a pigging
operation. Therefore, the several months required to
vacuum dry could not have started until essentially the end
of the glycol swabbing operation.
EXECUTION ISSUES
@ioment ~out and @ace R~emen
Space requirements for launching the dewatering pig train
were significant, with the compressor spread required to
generate 17,000 m3/hr of 2000 kPag compressed air, and
the ancillaty dryers, glycol, diesel and nitrogen tanks,
stores, control cabin, pig handling equipment, etc. The
space required did not present a problem because the
train was launched from an onshore location. Equipment
layout and spacing, as well as weight limitations on the
platform, must be considered in the case of using this
method between two offshore locations. Minimal
equipment was required at the Riser Platform for receiving
the pig train and consisted of small equipment stores and a
control cabin.
The glycol required for the three 260 m3 slugs was
delivered by five road tankers making eight round trips
each, wohing on a 24-hour basis. Delivery and storage
logistics are therefore another critical consideration. In
order to ensure that adequate preparations are made and
facilities are available, the commissioning contractor should
be consulted as early as practical during the design phase.
orafy PlOework
The original design for the temporaty pipework on board
the Riser Platform called for a hard-piped dewatering
manifold with a 12“ flexible hose routed overboard. This,
however, proved to be impractical. The weight and size of
12” flexible hose of appropriate pressure rating makes it
difficult to handle, and requires large arcs to bend.
Furthermore, air slugs tend to generate large forces that
require robust piping
and supports
for strength and rigidj?y.
The final piping configuration consisted of 12” steel piping
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6
DEWATERING ANDCOMMISSIONING THE UK CENTRAL
OTC 007576
AREA TRANSMISSION SYSTEM (CATS) PIPELINE
from the manifold to just above sea level, where a
12“ flexible hose was attached to absorb the wave action
as it discharged subsea. This arrangement proved
satisfactory.
Mete nalp _
i ia Train Po
sition/Tracking
Pig train location was determined from volumetric
calculations of air injected behind the pig train and water
discharged on the Riser Platform. The air was measured
with an orifice meter and the discharge water was
measured using an ultrasonic flow meter. Originally, the
primary tracking mechanism was to be the water discharge,
with the air measurement as a
he k However, during the
extended delay, the battery pack for the ultrasonic flow
meter ran down, and cumulative water discharge readings
were lost. Though such a delay was considered during the
design, the actual delay exceeded the battery capacity.
The metered air values had compared favorably with the
water discharge values prior to losing the ultrasonic meter,
so confidence remained in the ability to use the metered air
values to track pig position. Large air slugs in front of the
pig train as it approached the Riser Platform further
reduced the effectiveness of the ultrasonic meter. The
ultrasonic meter was, however, helpful in determining the
pig train velocity. The discharge flow measurement device
was designed early in the project, prior to involvement by
the commissioning contractor. It would have been
beneficial to have had the pipeline commissioning
contractor involved in its design to ensure correct
operation and functionality, calling on experience with
similar operations.
The first and last pigs were equipped with electronic
“pingers” that could be used to locate the pig train
accurately in the case of it becoming stuck. A more
complex system that would have allowed precise tracking
during the operation could have been utilized, but the
additional cost was not justified. The pipeline had been
gauge pigged and gel cleaned prior to being flooded for
hydrotest, therefore the likelihood of the pig train
becoming stuck was considered low, and the pingers
provided adequate ability to locate the pig train should it
have become necessary.
Process Inter
m
An expected key to a successful dewatering operation was
maintaining a pig train velocity between 0.1 and 0.5 tis to
achieve the required pig sweep efficiency. In practice, the
minimum velocity was not maintained, and the train
stopped completely on two separate occasions, once for
four days and again for thirteen days. In spite of these
stoppages, the glycol slug concentrations were well within
the 951?40cceptance criteria. This success is believed to be
due to the combined effect of oversized pig discs to effect
a good seal, and the strength of the high-performance disc
material, which prevented the pigs from settling during the
stoppages. The internal coating of the pipeline significantly
reduced disc wear and probably helped disc sealing.
Pia Ret
rieval
The original procedure called for recovering the pigs in
batches, primarily to simplify the recovery process with
regards to the number of times the pig receiver had to be
vented, opened, and reclosed. However, it became
necessary to recover the pigs individually after the first pig
became stuck in the bottom of the retrieval basket and the
basket was removed and abandoned.
The design of the pig recovery procedure should consider
the possibility of valve seat leakage. Contingencies should
be developed to accommodate such an occurrence. Also,
additional valves may be necessary around the pig trap
pipework if pig receivers are to be used as launchers and
launchers as receivers. Early review of pig trap design and
appurtenance piping by the pipeline commissioning
contractor is beneficial. The design should be specific for
the pigs involved and consider the likelihood of debris. A
recovery basket should be avoided in the interest of
simplicity if possible.
.RiserMainline
Valve Problems
As previously mentioned, valve seat leakage became a
problem during the pig train recovery operation. The ESD
maintenance valve and the pig trap isolation valve were
both used in the pig recovery operation, and began
noticeably leaking after two to three losures The pig train
was successfully and safely recovered after modifying the
venting method as described earlier. The use of
compressed air as the propelling mechanism allowed the
acceptance of minor valve leakage during pig recove~.
Although not operated during the pig recovery operation,
the ESD valve began passing during testing that followed
the pigging process,
again showing evidence of
worsening with continued valve closures. Both the ball and
seat of the ESD valve were severely scored. The specific
cause of the damage was never determined. The quantity
of debris recovered from in front of the pigs was less than
one cubic meter, which was small considering the size of
the pipeline. One possible cause of the valve damage was
the oversized pig discs lifting the spring loaded seats off
the ball and allowing dirty water and debris into the valve
cavity. Valve operations following this may have scored the
seats and ball. Oversizing the bore of pipeline valves may
reduce the possibility of this occurring. During similar
dewatering operations on the 20” gas pipeline between
Lomond and the Riser Platform, valve damage did not
occur. For that operation, the ESD valves were removed
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OTC
007576
G.
L. LANGFORD, T. E. KRISAAND M. L. MCCRARY
7
and inhibited water was flushed through the cavities of the
remaining valves. It is not possible to make a direct
comparison between the two operations, however,
because of differences in pipeline size, length, and valve
manufacturers.
The ESD maintenance valve and pig trap isolation valve
were of all-welded construction, and therefore not suitable
for in-situ repair. Fortunately, they were not leaking as
badly as the ESD valve and were brought into acceptable
standards by injecting sealant into the seat rings. A top
entry valve was chosen for the main ESD valve
construction, which allowed the valve to be repaired in
place. The repair consisted of replacing the ball, seats, and
all other sealing components.
Following these repairs, all three valves were rigorously
tested with high pressure nitrogen and proved to be
acceptable. A valve for injecting nitrogen into the area
between the ESD maintenance valve and the ESD valve
was added to the pipeline during this time in order to test
the downstream seat of the ESD valve without pressurizing
the entire pipeline. Although the original intent during the
design of the pipeline was to minimize the number of leak
paths below the ESD valve, a pressure injection point in
this location was necessary to properly test the sealing
integrity of the ESD valve prior to placing the pipeline in
service.
Ta
nker Groundina Damaae Assessment/Gaua na ~
Following the repair and testing of the mainline valves at
the Riser Platform, and just prior to the nitrogen purging
operation, a tanker ran aground in the immediate vicinity of
the shore approach at Teesside during a storm. As part of
the resulting investigation, a gauging pig train was run past
the point of concern to insure that the pipeline had not
been damaged by the vessel or its anchors. The train
consisted of three pigs separated by glycol slugs.
The pipeline was first pressurized with air to 600 kPag to
provide a driving force to allow recovery of the gauging
pigs at the terminal, rather than at the Riser Platform. The
train was then launched from Teesside using compressed
air. After the pig train had traveled sixteen kilometers, the
terminal side was vented, allowing the pipeline pressure to
propel the pig train back to shore. The pig train stopped in
the tunnel under the River Tees, and required additional
pressure to dislodge. Fortunately, the river crossing is
between the terminal and the onshore beach valve station.
Air compression equipment was mobilized at the beach
valve station and the line segment further pressurized until
the pigs were dislodged. Upon recovery, the gauging pigs
were examined and found to be in satisfactory condition,
and further investigation was deemed unnecessary.
587
SAFETY/ENVIRONMENTAL/START-UP ISSUES
Safet Considerations
A hazard analysis of the procedure for dewatering and
commissioning the CATS pipeline was performed to
identify safety risks that could be eliminated or reduced.
The analysis team was composed of engineering,
operations, safety, and commissioning contractor
representatives. The study was beneficial in contributing to
the safe performance of the dewatering and
commissioning operations.
All dewatering and commissioning activities were carried
out using a work permit system. This ensured that all
parties on location were aware of the operations being
performed and that appropriate safety procedures were
followed. it also helped in preventing conflicts with other
ongoing hook-up activities. Impromptu safety meetings
were heId prior to each critical activity to reinforce the safe
performance of the operations.
f20mmunicat ons
Communication between the onshore and offshore
locations was initially provided by a patched radio link
through a nearby platform, then through the permanent
platform telecommunication system when it became
available.
The flotel ship-to-shore radio was available as a
backup if required. Levels of communication were
established prior to commencement to ensure proper
transfer of information during critical activities or in case of
an emergency.
E~
A lockout of the ESD systems at the terminal and Riser
Platform was necessary during the pigging operations to
prevent spurious alarms from inadvertently closing the
ESD valves. Considerable damage to the valves and pigs
would have occurred if a valve closed while a pig was
passing through. An operator was designated to manually
trip the actuated ESD valve in the event of an emergency.
The lockouts were removed and the systems thoroughly
tested prior to the introduction of hydrocarbon gas.
9VefbOad Rum rw
oi f Inhibited Water and Glycoj
The pipeline volume of inhibited hydrotest water and the
three MEG slugs were dumped directly overboard during
the dewatering operation. The concentrations of biocide,
corrosion inhibitor, and oxygen scavenger in the hydrotest
water were low enough to allow this, and MEG is
biodegradable. No environmental damage was incurred,
and approval from the Scottish Office, Agriculture and Fish
Division Marine Laboratory was received prior to obtaining a
Gonsent to Discharge from the Department of Trade WI
Industry.
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8
DEWATERING AND COMMISSIONING THE UKCENTRAL
OTC 007576
AREA TRANSMISSION SYSTEM (CATS) PIPELINE
en Leak Tests
Following the removal of temporary pipework and
reinstatement of dismantled permanent pipework, the
Riser topsides gas process piping was leak tested with
high pressure nitrogen using helium as a leak tracer. The
purpose of the testing was to ensure gas containment at
normal operating pipeline pressure upon start-up. This
testing was performed at the Teesside terminal as well.
.
ctlon of Hydrocarbon Gas
Safety was always a high priority during the dewatering
operations, but became even more so during the gassing-
up operations, as this was the first introduction of
hydrocarbon gas to the offshore facilities. From this point
on, hot work permits were required with appropriate
operations coordination and approval for all activities.
Though the gassing-up procedure was developed by the
commissioning contractor, all valve operations were
performed directly by, or under the guidance of, the
permanent facility operators.
After closing in the pipeline for line packing, the Riser
Platform topside process and flare system piping was
purged with nitrogen. The piping section immediately
above the ESD valve was pressurized with nitrogen to
500 kPag above the pipeline pressure to ensure that any
seat leakage of the isolation valves would be to leak
nitrogen into the pipeline and not hydrocarbon gas ,into the
topsides piping.
The final operation was to mobilize a diving vessel and crew
to lower the flap on the subsea check valve located at the
base of the Riser Platform to its normal operating position.
KEY POINTS FOR FUTURE PROJECTS
The Central Area Transmission System (CATS) pipeline
was successfully dewatered and commissioned using
glycol swabbing followed by a low pressure nitrogen purge
to achieve a low dew point gas delivery on start-up. The
following key points were identified during the process and
should be considered in future applications:
The glycol swabbing method provides a reliable means
of removing residual hydrotest water from a pipeline to
achieve a low dew point gas delivery on start-up.
The combination of the oversized, high-performance
polyurethane sealing discs and the pipeline’s internal
coating resulted in high sweep efficiency for the pigs.
Using proper methods and technique, large pipelines
can be purged of air and commissioned without the
use of separation pigs.
588
w
Pig train stoppages are not necessarily detrimental to
the success of the glyml swabbing method.
Pigging trials are beneficial in designing and proving
critical application pigs.
Open and early discussion and coordination with
vendors, contractors, engineering, and operators are
crucial to the success of the operation.
The implications of pigging through valves need to be
considered early in the design phase and options
explored to minimize or handle valve problems if they
occur.
Careful thought should be given to the design of
tempora~ pipework, especially overboard dumplines.
The pipeline commissioning contractor should be
consulted early in the facility design for issues such as
pig retrieval methods, temporary pipework and
blinding, equipment requirements and layout, and
metering applications.
Activities must commence as early as possible, and
sufficient time allowed in schedules to accommodate
unexpected delays and problems. Contingency plans
should be developed as appropriate for all potential
eventualities.
ACKNOWLEDGMENT
We thank Amoco (UK) Exploration Company and Nowsco
Pipeline Services for their cooperation in preparing this
paper.
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Figure 1
Central Graben Development Project and
Central Area Transmission System CATS Pipeline
Valve ’1’yp
r“:z’?l “0”’”
/
Beach Valve
/
Station
/
36” CATS
589
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Figure 2
Riser Platform Pig Launcher Schematic
To Flare
@ I
t
13as Fmm
Pmcesa
-P
To Pipeline
Flare
t-
i
1
I
T
Pressurizing
r’ -1
Sample Point
Tempora~
Maintenance
I
. . . .
Level
[
,Irs,m
u
Ultrasonic
Flowmeter
sea
To Ov&board
F@me 3
CATS Terminal Pig Receiver Schematic
I
I To Flare
I
l---M________
t 1~ I Ill 1
36” CATS
I
Pipel ine c
I
I
l ’b
alve added to
36” CATS
Pipeline
---
I
I
I
I
1
I
I
I
I
1
enable use as
I
“Launcher”
I
-——- -——— ———— ———— —
———
4
I
Glycol/Air/Purgeas
Injection Point
+TOclOsedDrain PILOOP
4
addedfor Gss
Pig Launching
Commissioning
Injection Point
590
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Figure 4
36” Pipeline Dewatering Pig Train Schematic
PIG NO. 8
+ +p’GNO”’
PIG NO. 7
PIG NO. 5 PIG No, 4
PIG NO. 3
PIG NO. 2 PIG NO. 1
I
L MEG slug s Linear Metera (Typ,)
I
Dry Air Slug -1500 Linear Metera (Typ. )
n
Dry Air a t Work ing
Preseure
Hydrotest
Water
F@re 5
CATS 36” Dewatering Pig General Arrangement
Seali ng Disc
support D isc
Nose Cone
591
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