Upload
ranjitpandey
View
21
Download
5
Embed Size (px)
DESCRIPTION
structure integrity
Citation preview
General Case Studies
Pipe Wrap, LLC
15832 W est Hardy Rd.
Suite 600
Houston, TX 77060
Tel: 281-999-7100 USA
www.piperepair.net
Case Study # 1- 16" Gas Transmission Line
A+ Wrap™ Repair South Texas - USA
Project Overview External corrosion on a 16” OD, API-5LX-42 cross country pipeline having 57% wall loss within 4 foot wide region. Original pipe wall was 0.281" and an MAOP of 1,062 psi The Solution Design a 20 year repair utilizing the A+ Wrap™ System to restore the structural integrity of the line back to pristine conditions. Repair Method Remove tape coating and sand blast to a NACE #3 finish. The first step of repair is to fill the anomaly with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the cigar wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat as applicable, then back-fill.
Case Study #2- Sub Sea Level Bayou Repair
Damaged Gas Transmission Line
Louisiana, USA
OVERVIEW: A 22” gas transmission pipeline12’ below sea level in a bayou, had been hit by a boat anchor and required structural repair.
Coffer dam built to expose
damaged pipe
THE PROBLEM: The pipeline (at 750 psi) needed to be exposed
for the repair. The anomaly was 4.36” and wall
loss was approximately 45%.
THE SOLUTION: A coffer dam was built and the water was
pumped out before digging down to
expose dented pipe. A+ Wrap System
was applied, then top coated and pipe was
reburied.
Wrapping 3 foot of pipe
Pipe ready for topcoat
View of Constrictor Wrap
Case Study # 3- 16" Field Bend Repair Gas Transmission Line
A+ Wrap™ System South Texas - USA
Project Overview A Field Bend had external corrosion at the 6 - 9 O'Clock positions on a 16” OD, API-5LX-42 cross country pipeline. The repair area encompassed a 9 Ft section having 62% wall loss. Original pipe wall was 0.281" and an MAOP of 1,062 psi
The Solution Design a 20 year repair utilizing the A+ Wrap™ System to restore the structural integrity of the line back to pristine conditions. The repair required 18 layers (0.396" composite thickness).
Repair Method Prep the pipe by removing any soft coating and sand blast to a minimum of NACE #3 finish. Fill the anomalies with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat as applicable, then back-fill.
Case Study # 4- Oil Rig Caisson Repair
Offshore Oil Rig 24”
Caisson Repair
Gulf of Mexico, USA
THE PROBLEM: Dented caisson prevented proper operation and access
to pumping unit located within.
THE SOLUTION: 1. Abrade the caisson leg with sand
blasting.
2. Secure 24" dia x 180 deg x 36" long
FRP Sleeve with 12 bands.
(Note: The FRP Sleeve to be gasketed with nitrile).
3. Apply EP-193 to create transitions around the FRP Sleeve
4. Apply SplashBond all around the caisson .
5. Apply 6 layers of A+ W rap
(To extend 1 ft beyond both edges of the sleeve).
6. Apply 6 layers of Pipe W rap (also has the 1 ft extension).
7. Apply SplashBond over entire repair area.
Case Study #4-Oil Rig Caisson Repair
Offshore Oil Rig 24”
Caisson Repair
Gulf of Mexico, USA
SWLP-B Caisson – Current State: Front View
Dented Area (Area of maximum curvature change)
Case Study #4-Oil Rig Caisson Repair
Offshore Oil Rig 24”
Caisson Repair
Gulf of Mexico, USA
SWLP-B Caisson – Current State: Front View
Case Study #5 Riser Repair Offshore Platform
Production Platform
Offshore Eastern Canada
OVERVIEW: A 3” MEG line with various
configurations needed coating
replacement.
THE PROBLEM: Several areas including an elbow
where epoxy coating was
corroding , system operating at
73°C.
THE SOLUTION: Pipe was sandblasted to near
white metal.
GenWrap™ polyolefinic corrosive
inhibitive under wrap was cut to
size to form over damaged
areas, then overwrapped with
MCU outer wrap for containment
and mechanical protection.
Preparing corroded elbow
repair zone
Applying GenWrap™ Overwrap
Case Study # 6 - Gouge Repairs at a Gas Plant
A+ Wrap™ System - Mechanical Damage North Texas - USA
Project Overview During the excavation of an area within the Gas Processing Plant, a backhoe struck two (2) 8" process lines located adjacently within 4 feet of each other. The 3rd Party mechanical damage occurred during preparation for installation of an additional process line that was to run perpendicular to the damaged lines.
Both pipes were 8" pipe, API-5LX-46, 0.344" wall and operating at 860 psi. The resultant damage was a 0.4" wide x 8" long gouge with 40% wall loss on one pipe section and a 0.12" wide x 1" long gouge with 35% wall loss on the other pipe section.
The Solution The A+ Wrap™ System was the selected material of choice due to its ease of application and structural strength. Based on the parameters provided by the customer, a 12 layer (0.265" material thickness) design was indicated to ensure the continued integrity of the lines.
Inspection of the lines via Dye Penetrant Testing verified that "no cracks" existed in the damaged areas. An important requirement was stipulated for preparation of the gouged areas and that was the removal of all sharp edges to ensure the elimination of potential stress concentrations.
Additionally, because the pipe coating was fusion bonded epoxy, sandblasting was not required. Abrading the existing coating with sandpaper is sufficient.
Di
Dig site - Gas Plant
Distance between pipe sections
View of 0.4" wide x 8" long gouge
Case Study # 6 - Cont.
Repair Method Whenever mechanical damage occurs, the line must be checked to ensure there are no cracks. Once this is confirmed, the primary task in preparing to repair a gouge type defect is to remove "all sharp edges".
The pipe is coated with FBE, so the repair zone only requires lightly abrading the surface with 24-80 grit sandpaper. Fill the anomalies with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat as applicable, then back-fill.
View of 0.1" wide x 1" long gouge
Removing "sharp edges"
Putty applied to gouge Abraded surface ready for putty
Case Study # 6 - Cont.
Applying primer to pipe Continue applying primer
Repairs constrictor wrapped Repairs curing for 2 hours
Ready to be back-fill
Case Study # 7- 14" Natural Gas Transmission Pipeline
A+ Wrap™ Repair Victoria, Texas - USA
Project Overview A large rehabilitation project by an Interstate Gas Transmission company encompassed twenty-six (26) miles of 14” Diameter pipe. The line had been assessed by a High Resolution MFL (Magnetic Flux Leakage) In-Line Inspection Tool. The survey results indicated multiple regions with sections having general corrosion anomalies ranging from 35-65%. The Gas Transmission Company worked closely with PWLLC by providing the pigging log and having PWLLC analyze the respective repair zones to determine the amount of A+ Wrap™ required to restore full structural integrity of the line. The pipe grade was an API-5LX-42, schedule 30 (0.375" original wall). Since it was a Class 1 line, it had 1,620 psi.
The Solution Based on the analysis conducted by PWLLC, the repairs ranged from 14 layers (0.308" of material thickness) for 35% wall loss to 26 layers (0.572" of material thickness) for the 65% wall loss conditions. The design is to provide a minimum of a 20 year service in accordance with ASME PCC-2 Standards.
To simplify things for the installation crews, PWLLC provided the A+ Wrap™ System in kits for the respective repair zones. This additional effort enabled the installation crews to focus just on the material application by removing the necessity for individual layer counting.
Measuring the repair zone
Pipe surface before prep
After Sandblast to NACE 3
Case Study # 7- Cont.
Repair Method Prep the pipe by removing any soft coating and sand blast to a minimum of NACE #3 finish. Fill the anomalies with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat as applicable, then back-fill.
Applying Load Transfer Putty
Encapsulating ILI Marker
"Marking" the repair zone
Primer Application
Begin applying A+ Wrap™
Case Study # 7- Cont.
Spray & apply with 50% overlap
Begin constrictor wrap
"Lightly" perforate constrictor
Complete application
Pull constrictor tightly
Ready to rebury
Case Study # 8 - 24" Flare Line Repair
A+ Wrap™ Repair Tennessee - USA
Project Overview A 24" O.D. AISI-106-B carbon steel Flare line having both external and internal wall loss for a total two hundred and twenty seven (227 ft) foot section required structural reinforcement. The line had a combined wall loss of 54% with an original wall thickness of 0.375". The medium in the line was dilute HF and propane having an operating pressure of 285 psi.
The Solution Based on the analysis conducted by PWLLC, the repair required 12 layers (0.264" of material thickness) of A+ Wrap™ to store the structural integrity back to its pristine conditions. The solution was deemed as a temporary repair as per the ASME Standards. The design provided a 5 year service life.
The complete repair from surface prep to final wrap was accomplished in 21 days without interruption of the refineries process.
Repair Method Prep the pipe by hand tools to remove any soft coating and etch the surface with 24 grit sanding pads. Fill the anomalies with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat edges of the repair to add additional protection from potential moisture ingress.
View Elbow Transition
Repaired Branch Connection
Wide View of Entire Repair
Case Study # 9 - 54" Municipal Water Line
A+ Wrap™ Repair San Juan, Puerto Rico - USA Territory
Project Overview An underground 54" O.D. Grade B main water feed line located in a concrete access tunnel had extensive external corrosion due to constant moisture droplets from the ceiling of the tunnel. The line is direct fed from a Reservoir Dam and is supported by 10 inch high concrete saddles located approximately every 30 feet. The 0.500" original wall had degraded by 50%. The line operates at 55 psi in ambient temperature. The designed repair required 26 layers (0.572" material thickness) of A+ Wrap™ to restore structural integrity to a 392 foot long section..
The Solution Due to the restricted access of the lower half of the pipe caused from the concrete saddles, it required specifying the roll size of the A+ Wrap™ to be 12" x 60 ft material. This particular size had a diametric measurement sufficient for work space. The A+ Wrap™ was selected because of it performance capabilities on wet surfaces.
The repair approach was to reinforce the sections between the concrete saddles, then lift the pipe (after materials were properly cured) and apply the materials to the saddle support areas.
The entire repair from surface prep to final wrap was completed in 20 days.
Repair Method Prep the pipe by hand tools and sandblasting to remove any soft coating and etch the surface with 24 grit sanding pads. Fill the anomalies with a load transfer epoxy putty.
View of pipe towards the Dam
View of pipe towards the exit
Preparing to prep the pipe
Applying primer Primer to larger area
Applying A+ Wrap™ Continue wrapping
Case Study # 9 - cont.
Repair Method - cont Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat edges of the repair to add additional protection from potential moisture ingress.
Applying putty
Completed repair
Case Study # 10 - 8" Riser Repair - Soil to Air Interface
SplashGard™ Repair Bakersfield, California - USA
Project Overview An 8" O.D. riser at a meter station within a gas plant had localized external corrosion at the "soil to air interface" which is a common occurrence due to the "wet-dry" conditions that the area is exposed to during seasonal changes.
The external wall loss was minimal (less than 20% of original wall) and only required re-coating. The SplashGard™ pipe protection system was selected because this system was originally designed for "wet-dry" conditions within the splash zone area of off-shore platform risers.
The Solution Due to the minimal wall loss, no structural reinforcement was required thus SplashWrap I was selected as the over-wrap material. The repair consisted of 2 ft above and below transition zone. The intended service life was a minimum of 5 years.
Repair Method Prep the pipe by hand tools to remove any soft coating and etch the surface with 24 grit sanding pads. Fill the anomalies with a load transfer epoxy putty. Apply the SplashBond™ corrosion barrier epoxy to the entire repair zone prior to wrapping with SplashWrap™. Allow to cure for 2 hours, then top coat with SplashBond™.
Prepped repair zone
Applying SplashBond™
Over-wrapped
Completed repair
Case Study # 11 - Corrosion Under Insulation Repair
GenWrap™ Repair Boston, Massachusetts - USA
Project Overview Various piping sections developed Corrosion Under Insulation (CUI) due to trapped moisture within the insulating material around the pipe. Although the corrosion appeared to be aggressive, once the insulation was removed and the piping surface was prepped, there was minimal wall loss (less than 34%). Based on the low operating pressure of the piping system (60 psi), the customer determined that only providing a protective coating was required. The GenWrap™ System was selected because this system prevents oxygen from reaching the pipe surface. Without oxygen, a corrosion cell cannot occur. This system is typically used on the top side of off-shore platforms.
The Solution All the insulation to be removed from the affected area and the surfaces to be prepped by removing all loose scale. The GenWrap™ System to be applied and extended beyond the defect area.
Repair Method Prep the pipe by hand tools to remove all rust, scale and etch the surface with 24 grit sanding pads. Apply the the GenWrap™ Underwrap and then the GenWrap™ Outerwrap. Both materials to be applied spirally in opposing directions.
Initial view of CUI
Corroded elbow - insulation
removed
Repaired Elbow section
View of repaired
reducing pipe
section
Case Study # 12 - 6" Pipe - Crevice Corrosion Repair
Pipe Sock™ Repair Long Beach, California - USA
Project Overview A common problem that occurs with supported piping sections is the development of crevice corrosion at the interface of the pipe and the support. This problem manifests itself from the relative movement of the pipe in relation to the support thus abrading the existing coating. This action may be cause by the physical movement of the pipe due to "fluid hammering" or the expansion/contraction from temperature variations.
In this repair, the movement was caused by "fluid hammer" which breached the coating under the support and creating a pocket that collected moisture which helped cause the corrosion cell. For this application, the patented Pipe Sock™ (Patent #US 8,087,431 B2) should solve the problem.
The Solution The installation of the patented Pipe Sock™ will eliminate the moisture capture zone by bonding to the pipe and creating a "watershed" along with a wear surface that is not the pipe. Designed service life is 10 years.
Repair Method Prep the pipe by hand tools to remove all rust, scale and etch the surface with 24 grit sanding pads. Attach the patented Pipe Sock™ to the pipe with Black Magic polymer.
Developing access under
support
Initial positioning of Pipe Sock
Final positioning of Pipe Sock Close-up of
Installed Pipe Sock
Exposed pipe with wax coating
removed
Sandblasting the repair zone
Measuring repair zone
Case Study # 13 - 12" Natural Gas Transmission Pipeline
A+ Wrap™ Repair South Texas - USA
Project Overview An Interstate Gas Transmission company completed an ILI run using a High Resolution MFL (Magnetic Flux Leakage) In-Line Inspection Tool. The survey results indicated multiple regions with sections having general corrosion anomalies ranging from 25-65%. In working closely with PWLLC, PWLLC analyzed the respective repair zones to determine the amount of A+ Wrap™ required to restore the full structural integrity of the line. This particular repair was made on a 12" O.D. x 15 ft repair section having the pipe grade as API-5LX-42, with an original wall of 0.375". The system design pressure was 2,470 psi with an MAOP of 1,778 psi for a Class 1 location designation.
The Solution Designing the repair in accordance with ASME PCC-2 & ISO 24817 resulted in 10 layer (0.22" material thickness) design to restore the pipe back to pristine condition. The design was based on a 20 year service life.
As part of the design approach, the repair zone size was included and noted on the kits provided to the installation crew. This results in assisting the crew to focus specifically on applying the materials and does not require them to count the layers because by applying the materials provided within the designated repair zone, the layer count will come out correctly..
Kneading the putty
Measuring the anomaly
Applying the primer
Completing primer application Begin wrapping A+ Wrap and
spraying water during the
application
Case Study # 13 - Cont.
Repair Method Prep the pipe by removing any soft coating and sand blast to a minimum of NACE #3 finish. Fill the anomalies with a load transfer epoxy putty. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with A+ Wrap™ using the spiral wrap method. Apply the material until the calculated layers have been achieved. Constrict and perforate, then allow to cure for 2 hours. Top coat as applicable, then back-fill.
Complete wrapping process Applying constrictor
Perforating the constrictor Completed repair
Case Study # 13 - Cont.
Case Study #14- Underwater Repair
Underwater In-Situ SplashGard Application
Offshore Norway
THE PROBLEM:
A 6” diameter submerged pipeline20 meters below
sea level had 25 meters failed concrete coating.
THE SOLUTION:
It was necessary to clean the pipeline of loose
corrosion product. The SplashBond h a d t o
b e m i x e d topside, then placed in buckets,
brought down and applied at approximately 30 mil
thickness. The repair was completed by applying
4 layers of SplashWrap followed by a topcoat of
SplashBond.
Completed repair
16
Case Study #15 - Fresh Water Pump Station
Project Overview:
The Water Supplies Department in Hong Kong is
responsible for m aintaining the pipe repair work within the
district.
Water supply facilities such as, water treatm ent plants
were look ing f or new m aterial to repair and strengthen
the water pipe externally, in particular those large diam
eter pipes inside the water treatm ent work s.
Project Details:
T he sites needing reinforcement were Pum ping Stations 1 & 2 located in Hong Kong.
Pipe Diameters ranged f rom 24” thru 54” with a total
coverage area of 190.4 square meters.
Structural Reinforc em ent f or 50 year design lif e operating at
10 bar (145 psi) was required.
The areas that needed reinforcing are highlighted in yellow
on the supplied drawings on the next pages.
For the areas of Y’s, T’s and against flanges the contingenc y was sm aller rolls sizes were used.
17
Case Study #15 - Fresh Water Pump Station
Table 1
Draw ing #1
18
Case Study #15 - Fresh Water Pump Stations
View s of Repair in Progress
Primer application for preparation of continuing repair of Site M3
Application of A+ Wrap over the
primer undercoat
Application of A+ Wrap over the primer undercoat
19
Case Study # 16- Fire Proofing Rural Water Line
Project Overview:
Pipeline pictured is located in Shek Kong –
Hong Kong China. Due to a brush fire, the
external bitumen protection was burnt entirely.
Pipe W rap LLC was asked to provide a
replacement protective coating that would
enable the protection of the piping under the
same conditions.
Project Details: • The site is located in Shek Kong.
• Each concrete pier about 16 m.
• The pipeline OD is 1.2 meter. The length
(225 meter).
Solution Overview:
View of Repair Site
4 layers of A+W rap was used and covered 225 meters (738 f eet)
of 1.2 m (47.54 inch) diameter pipe.
After A+ W rap had cured (24 hours), a topically
applied intumescent Fire Resistant
coating was used to protect the pipe from future
brush fires.
View of completed Repair
4 layers of PWAP with Fire Resistant Coating
Note: View shows an individual walking a section of the line. T he dark exterior m aterial on the coating
is debris and leaves fallen f rom trees.
Case Study #17-Riser Splash Zone Repair
Riser Coating Repair Mendicant Island Louisiana , USA
OVERVIEW: Badly corroded pipe under pier in need of coating
repair at the Splash Zone.
Pipe - 16” Diameter x .281 wall, API-5LX-42
Design Pressure = 1,475 psi; MAOP = 590 psi.
Recommended repair is the SplashGard™
Coating System (a two-step corrosion barrier
system composed of an adhesive undercoating
and a fiberglass outer wrap), specifically
developed for off shore risers.
THE PROBLEM: Repair to go 6’ above barnacle line.
THE SOLUTION: Materials needed f or wrapping the pipe with 6
layers using A+ W rap™ as follows:
• 1 each - Overwrap (4” x 50’ roll)
• 1 each - SplashBond Epoxy Coating (2-gal kit)
• 1 each - EP913-2Q Epoxy Paste (2 qt kit)
• 2 each - AK25 Application Kits
• 1 each - Constrictor Wrap Small (5” x 600’)
Risers were coated and wrapped using the
SplashGard™ Coating System (a two-step
corrosion barrier system composed of an
adhesive under coating and a fiberglass outer
wrap), specifically developed for offshore risers. View of completed repair using 6
layers of the SplashGard System
Case Study #18 – Air Products & Chemicals
Dust Collector Structural Rehabilitation
California, USA
OVERVIEW: Structural Repair for Dust Collector
Piping.
See piping schematics below
Client Contact: Arun Mahabirsingh Plant Engineer Air Products Manufacturing Corporation email: [email protected]
THE PROBLEM: Very low efficiency of the dust collection system due to holes and joint leakages. Hole sizes ranged from 1” – 4” diameter.
Overall result: High operating costs with minimal benefit.
THE SOLUTION: 26 FRP customized leak stop sleeves were used over each wall defect, overwrapped with A+ Wraps and topically coated with epoxy to provide a requested extended life of 10 years and UV protection.
Repair involved 171 feet of horizontal piping including 22 elbows varying in diameters of between 12” and 18”.
Area 1 - View of Dust Collector pipe
before repair.
Area 1 - View of Dust Collector pipe after repair.
Area 2 - View of before and after Dust Collector structural repair.
Case Study #18 - Air Products & Chemicals
Dust Collector Structural Rehabilitation
California, USA
Area 3 - View of duct
before repair.
Area 3 - View of duct after using
the A+ Wrap™ System.
'
Case Study #18- Air Products & Chemicals
Dust Collector Structural Rehabilitation
California, USA
{ _el
Case Study #18- Air Products & Chemicals Dust Collector Structural Rehabilitation California, USA
- - ;.-. - -•u)
·;,.- .
•; ,,
t---:>'
- \ .
I . '
Case Study #18 - Air Products & Chemicals
Dust Collector Structural Rehabilitation
California, USA
Aerial view of Facility Before
Aerial view of Facility After
Case Study # 19– Water Line Leak Repair
Combination Pipe Wrap™ & A+ Wrap™ Repair
Project Overview
12” Diameter main water line serving a
University.
The Problem
Thru-Wall crack in 12” Transite Pipe due to lateral soil pressure.
Solution Overview
Combination Composite System Repair utilizing Epoxy Putty, Stop Gap Clamp, Pipe Wrap and A+ W rap.
This approach contains the leak along with providing structural integrity.
Repair Procedure The surface was prepped. Putty was applied to the crack to “near-net” profile. The Stop Gap clamp was installed. PPR-2 was then applied to the surface. There were 6 layers of Pipe Wrap applied as well as 8 layers of A+ Wrap. The constrictor wrap was applied and allowed to cure for 2 hours.
View of radial crack
Side view of defect
Completed Repair
Case Study #20 – Penstock Pipe Repair
A+ Wrap Repair
Project Overview: 60”Diameter penstock pipe with a 4” stub out.
The Problem: Thin wall due to corrosion, through wall holes.
Solution Overview : Customized leak repair made up of 5 layers designed to meet the customers’ requirements f or a maximum 2 year service lif e.
Area 2 – Front View of 60” Diameter
penstock before repair.
Area 1 – View of 4” Stub out before repair.
Area 3 – Side view of 4” Stub out before repair.
Area 4 – View of preparation of pipe by blast cleaning.
Area 5 – View o f fully exposed and clean 60” Diameter penstock pipe.
Case Study #20 – Penstock Pipe Repair
Area 6 – View of Epoxy application. Area 7 – View o f completed primer application.
Area 8 – Beginning of A+ Wrap application on 4” Stub out.
Area 9 – Near completion of A + Wrap application.
Area 10 – View of perforated constrictor wrap.
Area 11 – View of completed repair.
Case Study # 21 - Blast Furnace Cooling Water Lines
Project Overview Leaks and thinning pipe wall on a 24” line. Severe
external corrosion had been caused by corrosive
solution dripping onto pipe surface. Concern was
greatest at four tees, where numerous leaks had
formed, the largest having been sealed with wooden
dowels. There was concern that any work on the pipe
could lead to a major rupture. The pipe was operating
at 100 psi (7bar) and 100°F (40°C)
The Solution Repair method comprised of sealing the leak with
expanding polyurethane foam and applying
FormaShield ET (Epoxy – Fiberglass) System
Repair Method The wooden dowel was cut off to about ¼ “ (5mm)
above the pipe surface. Water leaked through the split
that ran up the center of the dowel, and this was
sealed by drilling out a hole using a ¼ “ (5mm) bit and
then sealing this with an expanding polyurethane.
The leaking area was cleaned using grit blasting with a
low pressure system. The pin holes were sealed using
a fast-curing epoxy putty. First, small balls ¼” (5mm)
diameter of putty were rolled and pushed in the holes
and held in place until they cured. Then larger balls ½”
(10mm) diameter were flattened over these to support
them before the whole area was covered. To do this.
The putty was mixed and held in a ball until it started to
warm from the cure. It was then spread quickly over
the area where it rapidly turned solid. Finally the area
was faired smooth using a spreadable epoxy putty.
The repaired area was left overnight to confirm the
putty had sealed the leaks.
Four (4) layers of FormaShield ET were then applied
over the tee. This supports the putty and bonds
strongly to the pipe, protecting it from further corrosion.
View of Leaking Pipe
Pipe Prep outside Defect Zone
Close-up of Putty application
Completed Repair
Case Study #22—Vessel Relief Line 4 Inch Line and Clamp Repair Using Pipe Wrap®
Project Overview : Repair of a 4” line on the outside of a natural gas storage vessel. Included in the repair is an area under the clamp that holds the line in place that has extensive corrosion and pin hole leaks
caused by water being trapped f or an extended period of time. Area
to be repaired will be the side of the vessel, the clamp and
the 4 inch line.
Solution Overview : Repair method was comprised of sealing the pin hole leaks under the clamp and encapsulating the entire clamp using Pipe W rap®. Once
this was accomplished 3 feet of 4 inch line was wrapped to prevent any further corrosion.
Repair Method: Repair required a technician to work from a man lift to at a
height of 45 feet. The entire area was prepped as close to
near white metal as possible and then cleaned with acetone. Once this was accomplished the leaks were repaired using Pipe W rap EP400 epoxy putty applied directly to the pin holes.
The two-part Epoxy Putty was kneaded until heat
began generating from the putty. This indicated that the
putty was near setting up. At this point the putty was
pressed into the pin holes and held for approximately 5 minutes until cured. Once all leaks were confirmed stopped, the entire area was primed using Pipe W rap PPR epoxy primer and all voids were filled to make sure of a smooth transition.
The next step was to apply 8 layers of Pipe W rap® to encapsulate the entire clamp and 3 linear feet of 4 inch pipe. Once the repair was cured the vessel was placed back into service. Work was accomplished within an 8 hour
period. This completed the repair.
4” 45’ Elevated Pipe
.237 Original W all Thickness
Corrosion Under Clamp
Repair Cleaned and Primed
Six Layers of Pipe W rap
A+™ to complete repair
Water pooling due to active
leaks
Strapping attempting to stop
flow
Temporary Dam to allow
access to pipe
Case Study # 23 - 26" Fresh Water Line - Active Leak Repair
RidgeBack™ Repair Northern Arizona - USA
Project Overview A 26" O.D. fresh water feed line for a Fish Hatchery managed by the US Department of Fish & Game developed multiple leaks within a section of line running through a river. The line at the river crossing was ductile iron and operating at 50 psi. The operation of the line could not be interrupted due to the impact on the hatchery. The initial challenge was to divert the river to allow access to the pipe for remediation. Once the river was diverted, there were five (5) noticeable leaks from holes that ranged in size from 1" to 3" in width. The existing coating on the pipe was a mastic rubber tape which easily flaked off. An additional problem incurred was the very limited ability to conduct surface preparation.
The Solution The product of choice for this type of active leak defect is the RidgeBack™ because a compression type seal is required that uniformly distributes the compressive forces thus minimizing the possibility of collapsing the pipe.
Metal clamps had been tried by the contractor, but did not succeed because the tightening process of the clamps did collapse the pipe sections.
As an additional prevention method for future leaks the Pipe Wrap® system was incorporated in the regions between the active leaks. This consisted of a primer and 24 layers of material (0.528" material thickness) utilized.
3rd leak area
2nd leak area - close-up of
make shift clamp
Attempt at wooden plugs
Close-up of installed
RidgeBack™
Installing RidgeBack™
Case Study # 23 - Cont.
Repair Method Position and secure the RidgeBack™ to each active leak area per the provided procedures. Tighten as required until the area is "drip free" for a minimum of 30 minutes.
Use hand tools to prep the pipe by removing all soft coating. Apply a corrosion barrier epoxy to the entire repair zone prior to wrapping with Pipe Wrap® using the spiral wrap method. Apply the material until the calculated layers have been achieved. Allow to cure for 2 hours. Top coat as applicable, then back-fill.
Over-wrapping the RidgeBack™
Repair approximately 75%
complete
Applying Pipe Wrap
Top coating wrapped area Repairing 2nd section
Require final top coat
Case Study # 23 - Cont.
Case Study #24- Offshore Leak Repair
Offshore Platform
Lift Pump Piping Repair
Gulf of Mexico, USA
OVERVIEW: Leak repairs on seawater lift piping
located on and offshore Truss SPAR.
THE PROBLEM: The three alternating stainless steel
piping sections supplying seawater
ballast for the SPAR were corroding in
a variety of locations and had active
leaks in all three lines.
There were approximately 39 leaking
areas in both the pipe runs and tees
on the three 10” lines (A, B, and C)
(Photo 1). All piping was 14’ above the deck. It was difficult to be sure of the exact number as some of the leaks were covered with a variety of clamps, tapes or screws.
THE SOLUTION: Erect scaffolding so there is a safe work area for the 2 man crew. Schedule alternating shutdowns and depressurize individual lines, working on them one at a time.
Remove all existing repairs (clamps, tapes, screws, etc.).
Prepare all three pipelines using a side grinder to remove the rust and scale build up, bringing the pipe down to bare metal. Solvent wipe prior to application of epoxies.
Case Study #24- Offshore Leak Repair
Offshore Platform
Lift Pump Piping Repair
Gulf of Mexico, USA
On line A, fill the holes and anomalies
with 2 part epoxy putty, apply 2 part
epoxy primer 360˚ circumferentially, and
overlap repair zone axially by 3-4 inches.
Next, wrap with 24 layers of Pipe W
rap™.
On lines B & C, after preparing the
entire line, fill the holes and anomalies
with 2 part epoxy putty, then apply the
2 part epoxy paste from 3 o’clock to the
9 o’clock position, as all previous leaks
appeared to be in the bottom 180˚ of the
piping. This is in anticipation of new leak
zones developing . Next, apply 2 part
epoxy primer to remainder of bare piping,
and finish with 24 layers of Pipe W rap™.
Case Study #25– Cooling Tower Line Repair
Delaware, USA
Project Overview
12” return water line from chiller unit. The Problem:
The repair of thru wall defects near flange on a 12”
carbon steel cooling tower waterline operating at
140 psi and 90°F. View of Thru wall defects
Solution Overview: Multi-sequence repair requiring depressurization of
the line utilizing A+ W rap in conjunction with epoxy
putty and rubber .
Repair Procedure: Grinded all surfaces to clean steel. Installed ¼’ thick
piece of rubber stopgap over defects.
The rubber pieces were secured with galvanized
banding strap. Traditional method of repair (filling
pipe with putty stick) was not used due to extremely
thin bottom.
Covered the sharp sections of banding material and
all transitions between welded plate to pipe, flange to
pipe and rubber piece to pipe with fast set epoxy
putty stick.
Installed epoxy adhesive over entire repair.
Due to location of repair area (tight against flange
with bolts every 2”) a change was made from the
suggested spiral wrap over the patch and tight
against the flange. Two rolls were used making the
repair six layers thick. A spiral wrap was done
overlapping 2” of the hoop wrap with 3 rolls of
material over the rest of the repair.
Constrictor Wrap was applied over the material.
Line was recharged 2 hours after completion. The
temperature was of an estimated 78°F.
Pipe prepped for repair
Repair Applied and Curing
View of Completed Repair
34
Case Study #26– Gas Pipeline Dent Repair
Midstream Transmission Pipeline Dent Repair 2010
Project Overview:
Dent Repair to Midstream Liquid Transmission Pipeline in wet conditions in Louisiana, USA.
The Problem:
Dented pipe w ith all sharp edges ground out before filler material applied.
Dent filled w ith putty ready for Primer Coat.
Mechanical damage to Transmission pipeline 6.625 OD,0.188” wt. and X42.
Anomaly was a Dent 2.7” long, 1.9” wide, 0.12” depth at 11:16 O’Clock position.
Solution Overview:
The use of the A+ W rap System with Smart Pig Markers.
The A+ W rap System is an alternative to welding a sleeve or cut-out of the dented pipe area.
A+ W rap is suited for wet conditions.
The repair took 2 hours to complete.
View of Primer ap plied to repair
area. Completed A+ Wrap repair w ith
constrictor w rap during cure.
Case Study #27- Active Leak Repair-Gas Line
Gas Storage Area 1
Project Overview: A 6” gas pipeline had pinhole leaks, where metal
clamps have been previously installed, that required
the arrest of leaks with an approved leak repair
system.
The Problem: Leaks and minimum corrosion at two 6 O’Clock
locations of the pipe about 2’ above ground. The first
leaking pinhole was 0.3mm with a repair area of
6” and the two more leaking pinholes were 0.2mm
with a repair area of 12”, with a minimal operating
temperature and pressure. The pipe has anti-
corrosion paint as coating.
Solution Overview: The Active Leak Repair Kit (ALRK) is a three
component system for leak and corrosion protection.
Kits are specific to repair each area on the pipeline. First the leak on the pipe was arrested using
QuikStrap and then the remaining repair zone was
prepped using sandpaper and a metal file to near
white finish. Then the EP913-2 epoxy was applied for
corrosion protection before wrapping with Pipe W rap
for containment and mechanical protection. A final
layer of the epoxy was applied as a topcoat.
Epoxy putty, (EP407), was applied prior to the
QuikStrap step for additional protection.
Case Study #28 – Offshore Production Platform
Unique Emergency Offshore Riser Repair Cook Inlet , Alaska USA
OVERVIEW:
Due to the PHMSA denial of a special permit shortly after the Deepwater Horizon tragedy, the platform operator was out of compliance, subject to enforcement and was forced to immediately shut down.
An emergency structural repair for a liquid production line having a bend located inside of a support leg on an offshore production platform offered many challenges.
THE PROBLEM:
Repair location was inside the leg of an oil and gas production platform located in the Cook Inlet,
Alaska. The pipeline was DOT regulated and carried produced fluids.
The platform leg had an inside diameter of 7 feet and protected not just one 12 inch riser, but two additional 12 inch risers, plus several other pipes ranging in size from 1 inch to 6 inches.
Work space was limited inside and the metal loss location identified by ILI tool inspection was 100 feet from the top of one of the 12 inch diameter risers under 30 - 60 feet of water depending on the tide.
View inside platform leg.
Diver ready to enter platform leg casing.
Visibility was non-existent because the leg was flooded with salt water and silt from many years of tidal action. Water temperature ranged from 40° to 45ºF.
The outside pipe surface temperature was 37ºF. Cure time of the proposed composite repair was temperature dependent.
The riser had been de-rated from the original operational pressure to 340 psig and this pressure would be maintained as the maximum operational pressure for continued service.
The 12” pipe was Grade B, original wall thickness
0.500 inches and had a maximum wall loss of 69% due to external corrosion.
Up out of
the hatch
after
preliminary
pipe
preparation.
Down the hatch.
Case Study #28 – Offshore Production Platform
THE PROBLEM Continued:
Defect was located on a bend in the pipeline;
the bend radius was 24’ - 3”.
Defect was 10 ft. in length beginning 6 inches
from the entry of the pipe into support leg.
Primary defect was located plus 7 feet from the
entry of the support leg.
The repair needed to comply with DOT
requirements (in compliance with ASME PCC-2
Repair Standard for Non-Metallic Repairs). In
addition, the crew needed to be trained and
certified onsite to complete the repair.
Pig marker delectability was also a concern
for future ILI inspections to show that the
anomaly had already been repaired.
THE SOLUTION: The line was shut down and depressurized.
Divers descended inside the 7 foot diameter
platform leg and by blind feel sketched the
location of the various risers inside platform leg.
(See page 4).
Next, removal of sediment and water was
required before the area of metal loss could be
identified, cleaned and examined.
Remote Access Technicians (RAT) then needed
to be trained topside by Pipe W rap, LLC as the
composite repair was designed to DOT
Standards.
A certified Pipe W rap LLC trainer was utilized for
instruction and application procedures and
supervision.
First round of pipe prep
Preliminary pipe prep
Final pipe prep
Primer Coat mixing to send down hatch
Case Study #28 – Offshore Production Platform
THE SOLUTION continued:
The repair was designed to return piping to full strength from 69% wall loss using
26 layers of wrap.
Curing was assisted by forced heated air down to the bottom of the riser. This resulted in raising the pipe temperature to 95ºF for 12 hours.
A PHMSA representative and the Director of Technology from Pipe W rap LLC were on-site to observe, assist and ensure compliance with the riser repair.
Prior to product installation, a certified NACE inspector went down-hole to verify surface preparation requirements.
Technicians installed Pipe W rap LLC’s exclusively licensed patented pig marker into the repair in the direction of oil flow.
(See page 5.)
Due to the critical nature and location of the repair , a project specific QC sign- off was employed for each major step.
Once the repair cured to the required hardness (minimum of 85 shore A scale), the PHMSA representative agreed that the riser had been adequately repaired and platform was restarted.
Oil is again flowing through the seafloor pipeline and the repaired riser is compliant with 49 CFR Part 195.
Splashbond Epoxy Primer ready to
be sent down hatch in bucket
Splashbond Epoxy applied ready to
be overwrapped
A+ W rap applied for structural repair
Inspection of Cure Hardness
Case Study #28 – Offshore Production Platform
Sketches made by Diver inside platform leg
'l•· cu. 9.•ii!¥'.
... .; '' 3f 4£C f ('L
•' u6t.I*P tt\oi.H•tO iM·t:f ·,-.:. (Jr.,i.4l -:\rl" .t:;
«<'< t.- ,.,.. '
' tl ""tl'".:n ··(»io!o,. t-fq
1;,.,,\J. 't o,,3!..u {d.J'I •.iJrni . t ,r l"r.t-:1 '
(;I.O.f./IL rit y-t
..,f ,(;>f"r) i'f N -:.ii( itf'
rd •1i1'l ev:;.-;-;--< _.l f'oc.-: 1t:tL , Pwt,<.:J. t:l'tt!.S{II:
.
.
.
-
.. :-
Case Study #28 - Offshore Production Platform
,.
.:.;.·
........ .·'·. :. -.
,: ..:
COMPLETED \\>R AP
: '• ·": i·· ... -
\-\ / AHAK MAGNET
,\t \ _;,
..· ' •
·:...
·...: ..
...... ,·.·
':·. . ....·. :: · ;
·.·, C...l •.. ...J
·:... ·• .0.:.:
2 ... . ;;.: ·'.
.... - .. ...
i ·.,
••
..
ILI Report
Case Study #28 – Offshore Production Platform
ILI Report
Repair Schematic
Case Study #29 –Elbow Repair Transmission Pipeline
Gas Transmission Pipeline Elbow Repair 2010
Project Overview : Structural repair needed for a 10.75” OD 90º Elbow with 40% wall loss due to external corrosion.
The Problem: Immediate repair needed to be conformable, easy to apply, safe and durable. This DOT regulated high pressure gas transmission pipeline had general corrosion with 40% wall loss and needed pig detection for later pig runs.
Defect depth was 0.200 inches Defect width was 8.40 inches Defect Length was 28 inches.
Solution Overview: The A+ Wrap System with Pig Detectible Markers provided a repair thickness of .320 inches based on design calculations.
A UV protective topcoat was applied after constrictor wrap had been removed.
Anom aly area
sandblasted to near
white m etal.
Coated elbow over wrapped with A+ W rap
W rapping conform able A+ W rap.
Continuation of wrapping process.
Cured repair to be topically coated f or UV protection. Removing constrictor wrap after 1 hour.
Case Study # 30 – 24” Natural Gas Line Repair
A+ Wrap™ Repair-Kenner, LA
Project Overview
Repair of a 24” O.D., .500” wall X-46 Natural Gas line at a metering station. The line had
27” of corrosion that gathered under pipe support at the 6 oclock position that caused
45% wall loss.
The Problem C r e v i c e c o r r o s i o n r e s u l t e d f r o m c o n d e n s a t i o n s o a k i n g t h e w o o d e n s u p p o r t , o v e r t i m e t h e c o n d e n s a t i o n c a u s e d a 2 7 ” l o n g d e f e c t t o f o r m . T h e c o r r o s i o n d e g r a d e d 4 5 % o f t h e p i p e w a l l r e d u c i n g t h e m a x i m u m a l l o w a b l e p r e s s u r e f r om 68 5 p s i t o 3 5 0 p s i.
Solution Overview
Based on the extent of the defect, the repair was designed in accordance to ASME PCC-2 standards which resulted in 18 layers of A+ W rap™ having an overall repair thickness of 0.396”. The repair was complete from start to finish in 2 hours.
The pipe was media blasted to near white metal and cleaned with MEK solvent, corrosion was filled with EP400 epoxy putty and then coated with PPR primer. A+ W rap™ was applied 31” f rom right to left. T he pipe was then coated with a corrosion and UV resistant paint as a finishing coat over the repair. As stipulated by the Standards, only certified installers are allowed to apply the product .
24” Pipeline with corrosion
Primer-East Side
Primer-West Side
Finished
Repair-East
and West
Side
Case Study #31 – 6” Vertical Caustic Line
Formashield™ ET Repair Pasadena Texas
PROJECT OVERVIEW:
18 linear foot repair of a 6” x 0.281” wall Grade
B carbon steel caustic line at ambient
temperature.
THE PROBLEM:
The line had external corrosion with 65% wall
loss at ambient temperature; there was also a
leak that was present around a 6” clamp.
THE SOLUTION:
The repair was designed in accordance to
ASME PCC-2 standards. Presence of caustic in
the line required Formashield™ System be
used.
Based on the extent of the defect area, 6 layers
of Formashield™ were required for an overall
repair thickness of 0.17”. EP913 epoxy filler
and EP400 epoxy putty were used to
encapsulate the clamp.
The entire repair area was prepped using a
non-sparking grinder as well as wire brushes.
Pin hole leaks surrounding the clamp were filled
in using EP400 epoxy putty. All sharp edges
were ground away. A form was then built to
encapsulate the clamp and filled in using EP913
epoxy filler. The next day after determining the
area was leak free, the rest of the 6 inch pipe
was prepped using the same methods listed
above.
The pipe was primed using PPR-2 and the
required 6 layers of Formashield™ applied
spirally. Then the entire area was wrapped in
constrictor banding. After all material was fully
cured, the constrictor banding was removed
and the area was coated with an epoxy UV
topcoat.
Case Study #32 – Formashield™
Formashield™ ET Pasadena Texas
OVERVIEW:
Repair of a 24” O.D x 0.375” wall, water line
inside a refinery had 31 feet of external
corrosion and 3 areas with pin hole leaks. The
external corrosion on the pipe had a defect
depth of 60 percent wall loss.
THE PROBLEM:
External corrosion resulted from natural causes
over a long period of time caused minor pin hole
leaks and external corrosion, over 31 feet to
occur. The corrosion degraded 60% of the pipe
wall.
THE SOLUTION:
Based on the extent of the defect, the repair
was designed in accordance to ASME PCC-2
standards which resulted in 6 layers of
Formashield™ of an overall repair thickness
of 0.20”. The repair was complete from start
to finish in 3 days.
The pipe was first blasted to near white metal
and cleaned with MEK solvent. The 3 pin hole
repairs were stop- gapped and held leak free
for 1 full day. The remaining 31 feet of
corrosion was filled with proprietary epoxy
putty, coated with PPR primer, then 6 layers
of Formashield™ was applied to the entire 34
feet encapsulating the stop gaps.
The pipe was then coated with a corrosion
and UV resistant paint as a finishing coat
over the repair.
As stipulated by the PCC-2 Standards, only
certified installers were allowed to apply the
product.
Sandblast Pipe
Apply primer
Wrap prepared section
Top coat for UV resistance
Case Study # 33- 96” Water Pipe
A+ Wrap™ Repair Nuclear Plant, Byron IL
Project Overview Severe corrosion was determined at the lower portion of a 96” CW Return Line. Randomly selected UT measure- ments in the degraded area were performed to obtain a baseline wall thickness of the 96” piping. From these measurements, localized spots in corroded region are below minimum wall thickness. Applying Pipe W rap’s
A+ W rap™ will re-establish margin by restoring pipe strength, Installation of the Pipe W rap material will be from the floor 18” up on the 96” pipe, completely around a 4” stub and, out to the valve on 6” lines 1CW 20AA/B/C/D.
A 2-part elastomeric coating was applied to the wrap and the floor to seal the interface between the wrap and the floor. The wrap is validated through testing for use under the ASME PCC-2 Article 4.1 2006 for B31.1, B31.3, B31.4, and B31.8
The Solution
Pipe - 96” Diameter located 1 story below ground level. Repair was done using is A+ Wrap™ coated with PPR-2™ Epoxy System Repair completed with RC-350™ Rubber Coating for an additional water barrier.
Repair Method
Repair was done with no down time and completed in less than 2 days. Pipe was wrapped with 12 layers of A+ Wrap™ for 1
st 10” and
an additional 5 layers for remaining 8”. Photo shows A+ Wrap™ overwrapped with constrictor wrap.
View of 96” Water Pipe before Repair
12 Layers with A+ Wrap™
Pipe with beads of Black Magic™ followed by PPR-2
Final view of completed repair
Case Study # 34- Special Sequencing Batch Reactor Waste Water Piping Smithville, TN
Project Overview Our Client manufactures a special sequencing batch
reactor (SBR) system, demonstrating lower operating costs and lower sludge production than conventional SBRs, is providing greater than 99% removal of organics for a 2.4 mgd wastewater treatment plant. Due to trouble with internal nozzles the needed to cut two 8 inch holes in the 16 inch line to make repairs and then seal the line. The close proximity of a smaller line added to the difficulty of making the repair
The Solution After reviewing the problem Pipe Wraps’ Formashield was chosen for the repair due to its’ ability to be sized to fit between the two lines and provide a repair that would return the line to its’ original structural strength.
Repair Method Step 1:
The first step in the repair after the internal repairs were
completed was to identify and prepare the repair zone
by abrading the entire area that was to have material
applied.
Case Study # 34- Special Sequencing Batch Reactor
Waste Water Process Piping Smithville, TN
Step 2:
The second step of the repair was to apply epoxy adhesive and place a fiberglass patch over the 8” hole, fasten in place and allow to cure.
Step 3:
The third step of the repair was to apply epoxy putty around the patch then coat the repair zone with Epoxy paste and allow to set for a minimum of 15 minutes.
Step 4:
The final step in the repair was to wetout and apply Formashield using 50%Overlap to provide 12 layers over the center of the repair. Material was constricted, lightly perforated and allowed to cure. The line was returned to service 24 hours after start of repair.
Case Study # 35-Jet Fuel Line Skytanking, USA
Formashield™ New River Airport, New River NC
Project Overview Repair involves structural damage to a 6” GFE Pipe that carries jet fuel from storage tanks to the refueling area. Maintenance equipment had cut a 6” long hole in the elbow at ground level. Pressure rating of the line is 150 PSI so the repair design would be critical to assure at least original pressure capability.
The Solution
Because standard pipe repair calculations would
not be accurate for this type of repair the design
was based on known parameters for this type of
pipe. Because of superior strength, ease of
application to this configuration, good service life
and excellent bonding characteristics
Formashield™ was chosen for the repair.
Repair Method Step 1: The first step in the repair was to identify the repair zone, in this case approximately a 15” long area and prep it using sandpaper to provide a satisfactory anchor pattern.
Case Study # 35-Jet Fuel Line Skytanking, USA
Formashield™ New River Airport, New River NC
Step2: The second step of the repair was to apply epoxy putty to the damaged area to create a
seal/load transfer. Putty is contoured then allowed
to harden.
Step 3: The next step of the repair was to mix and
apply epoxy paste to the entire repair zone and
allow to set until it has reached the consistency of
“cold honey”.
Step 4: At this point the pre-measured epoxy resin
was mixed and applied to the Formashield cloth.
Cloth was rolled up and moved from wet=out area
to the repair. For this particular repair 2” wide cloth
was used for ease of application to the curved
surface of the elbow.
Case Study # 35-Jet Fuel Line Skytanking, USA
Formashield™ New River Airport, New River NC
Step 5: 10 layers if Formashield™ cloth was
applied to the repair zone using the “Spiral Wrap”
method with 50% overlap. After wrapping was
complete, a constrictor wrap was applied and
lightly perforated to allow for out-gassing and for
the release of excess resin. Repair was allowed to
cure for 2 hours and then constrictor wrap was
removed.
Step 6: Exterior of repair was coated with Epoxy
Primer and entire repair was allowed to cure for 12
hours. Line was put back in service and functioned
perfectly.
Case Study #36- Production Platform Export Riser
GenWrap™ Production Platform
Offshore Eastern Canada
OVERVIEW: An 18” export riser had areas where
existing neoprene rubber coating was
cracking and needed patching using an
approved corrosion barrier system.
THE PROBLEM: Corrosion under cracked neoprene on a 18”
OD riser about 15 feet above water line.
Pitted area was 330.2 mm (13”) x 50.8mm
(2”), operating temperature 73C-78C.
The neoprene coating was 2mm (79 mils)
thick.
THE SOLUTION: GenWrap™ had been laboratory
tested (per Exxon Mobil protocol ) to
have no disbondment , so a field trial
using the two-component corrosion
inhibitive system composed was
custom kitted to repair each area on
the W T riser.
First the pipe was sandblasted to
near white metal, then GenWrap™
polyolefinic corrosive inhibitive under
wrap was cut to size to form over
damaged areas, then overwrapped
with MCU outerwrap for containment
and mechanical protection.
Corrosion under failed neoprene coating on 18” riser
View of completed repair
Case Study #37- Crude Oil Pipeline Repair
Submerged Concrete Coated Crude Oil Pipeline Repair Offshore Columbia
OVERVIEW
Concrete coating on a submerged (15
meters) 48” diameter crude oil pipe
had been scratched and cracked by a
dragging anchor.
THE PROBLEM: Failed concrete coating from
mechanical damage in 15 meter deep
water in 2 separate locations
compromised carbon steel pipe
underneath.
At almost 50 feet deep, all materials
needed to be mixed topside, and
brought down to ocean floor using
weighted buckets. Murky conditions
with limited visibility.
THE SOLUTION: Divers removed damaged concrete,
then measured the concrete thickness
to replace coating. After measuring
the thickness of the existing cracked
concrete coating, a stainless steel
enclosure was fabricated to surround
repair areas to tie the existing concrete
OD on either side of repair zone. The
enclosure was secured with tie-downs
and epoxy aggregate was injected into
an annulus at the top of the stainless
steel enclosure. Final step was to
overwrap the enclosure with A+ Wrap
and topically coat with SplashBond.
Case Study #37- Crude Oil Pipeline Repair
INITIAL APPLICATION OF RESIN
FINAL FILL APPLICATION SHROUD
Mixing of com ponents A and B, SplashBond resin. Gravel to the Mix
Mix Epoxy Resin and Gravel Final Appearance of fill material
FINAL FILL APPLICATION
Enlistment of divers Final Photos.
AELD REPORT ACCOMPANYING THE AREA DURING THE ENTIRE BOARD REPAIR GW D-440
KM 5 +322 COVEN LINE OFFSHORE TERMINAL
REVISION CONTROL Revision No. Date
(DD I MM I YYY'I')
Description
0 271Jun I 2008 Documentation of the process.
Developed:
Jotge Tormdo I Junior Engineer Integrity.
ReviewedI Approved:
carlos Vergara I Engineer lntegrity.
I. OBJECTIVE
Supply constraints In the field during the repair activities of system board siding GW0-440, located at Km 5 +322 OCENSA Offshore Line.In order to ensure and document this process.
2. SCOPE
Field activities consisted of the permanent support to the process of implementation of ECO Engineering Standard-IG-368-004-RP-056-E, for the completion of the repair ooating system
against extemal corrosion of the Board GW0-440 ,located at Km 5 +322 OCENSA Offshore Line.
3. METHODOLOGY
The field visit took place between Monday June 16th and Monday June 23,2008 atTermlnal Covenas.
Case Study #38- Crude Oil Pipeline Repair
Submerged Concrete Coated Crude Oil Pipeline Repair Offshore Columbia
OVERVIEW
Concrete coating on a submerged (15
meters) 48” diameter crude oil pipe
had been scratched and cracked by a
dragging anchor.
THE PROBLEM: Failed concrete coating from
mechanical damage in 15 meter deep
water in 2 separate locations
compromised carbon steel pipe
underneath.
At almost 50 feet deep, all materials
needed to be mixed topside, and
brought down to ocean floor using
weighted buckets. Murky conditions
with limited visibility.
THE SOLUTION: Divers removed damaged concrete,
then measured the concrete thickness
to replace coating. After measuring
the thickness of the existing cracked
concrete coating, a stainless steel
enclosure was fabricated to surround
repair areas to tie the existing concrete
OD on either side of repair zone. The
enclosure was secured with tie-downs
and epoxy aggregate was injected into
an annulus at the top of the stainless
steel enclosure. Final step was to
overwrap the enclosure with A+ Wrap
and topically coat with SplashBond.
Case Study #38- Crude Oil Pipeline Repair
INITIAL APPLICATION OF RESIN
FINAL FILL APPLICATION SHROUD
Mixing of components A and B, SplashBond resin. Gravel to the Mix
Mix Epoxy Resin and Gravel Final Appearance of fill material
FINAL FILL APPLICATION
Enlistment of divers Final Photos.
AELD REPORT ACCOMPANYING THE AREA DURING THE ENTIRE BOARD REPAIR GWD-440 KM 5 +322 COVEN LINE OFFSHORE TERMINAL
REVISION CONTROL Revision No. Date
(DD I MM I YYY'I')
Description
0 271Jun I 2008 Documentation of the process.
Developed:
Jotge Tormdo I Junior Engineer Integrity.
ReviewedI Approved:
carlos Vergara I Engineer lntegrity.
I. OBJECTIVE
Supply constraints In the field during the repair activities of system board siding GW0-440, located at Km 5 +322 OCENSA Offshore Line.In order to ensure and document this process.
2. SCOPE
Field activities consisted of the permanent support to the process of implementation of ECO Engineering Standard-IG-368-004-RP-056-E, for the completion of the repair ooating system
against extemal corrosion of the Board GW0-440 ,located at Km 5 +322 OCENSA Offshore Line.
3. METHODOLOGY
The field visit took place between Monday June 16th and Monday June 23,2008 atTermlnal Covenas.
Case Study #39- Underwater Dent Repair
Offshore Malaysia
OVERVIEW: A 24” concrete coated X60 submersed
gas pipeline was caliper pigged that
identified three dent anomalies.
THE PROBLEM: The pipeline lay on the sea bed with
nominal wall thickness of 15.9 mm and
the three defects were located in a 2
meter section.
The water depth was 25 meters,
expected free spanning and surrounding
in Dregs condition.
THE SOLUTION: Concrete coating was removed for bare
surface area ready for wrapping.
SplashGard was utilized to ensure the
structural integrity of damage caused
from anchors.
Case # 39- Underwater Dent Repair cont'd
Case # 39- Underwater Dent Repair cont'd
Case Study #40- Production Platform Water Line
Production Platform Water Line with Leaks
Offshore West Africa
OVERVIEW: Production facility operating 250
miles offshore with a 24” carbon
steel line experiencing internal
corrosion.
THE PROBLEM: Personnel from Pipe Wrap, LLC
needed to inspect sections of
UT’d pipe that needed structural
wrapping. The produced water lines
had an operating pressure of 62 psi
with a defect area of 84” with 3 mm
(.118”) remaining wall on Grade B
(original 9.52 mm (.375”) wall
thickness.
Sections of pipe that needed
structural wrapping had an I beam
with 6.0 mm clearance above
component 53. As a result,
wrapping could only be performed
area illustrated in Figure 1. (see next page for Sketch of Inspected Repair Zone).
THE SOLUTION: Since the coating was fusion
bond epoxy, minimal surface
preparation (abraded with sand
paper) was all that was required.
Next, PPR (epoxy primer) and 19
layers of A+ W rap were applied.
Photo 1 – I Beam Obstruction
Photo 2 – View of Repair Zone
Photo 3 – Bottom View of I-Beam
Case Study #40- Production Platform Water Line
Production Platform Produced
Water Line with Leaks
Offshore West Africa
OVERVIEW: FIGURE 1 – Sketch of Inspected Repair Zone
See next page for Isometric Drawing Reference
Case Study #40- Production Platform Water Line
Production Platform
Produced Water Line with Leaks
Offshore West Africa
OVERVIEW: Isometric Drawing Reference
See next page for additional photos of repair
Case Study #40- Production Platform Water Line
Production Platform
Produced Water Line with Leaks
Offshore West Africa
Photo 4 – View of Prepped Pipe
Photo 5 – View after Repair
Case Study #40- Production Platform Water Line
Production Platform
Produced Water Line with Leaks
Offshore West Africa
Photo 6 – Upstream View of Repair
Photo 7 – Ground View of Completed Repair
Case Study #41- Production Platform Piping
Production Platform Piping Gulf of Mexico, USA
Outside and Topside Platform Deck
Facilities
THE PROBLEM: Pipe line to be repaired ranged in diameters
of 6”, 4” and 3” Schedule 40 to Schedule 80,
Grade B. With an operating temperature of
40° F minimum to 100° F maximum and an
operating pressure of 50 psi. Four layers of
A+ W rap™ were applied to the pipe bodies
with less than 80% wall loss.
Repairs were to be done while the system
was operating. Some lines were actively
leaking.
THE SOLUTION: W here the pipe works had leaks (100%
wall loss) a mechanical clamp was applied
to defect and over wrapped with 15 layers of
Pipe Wrap™ and then reinforced with 4
layers of A+ Wrap™. Girth welds with less
than 80 % wall loss were repaired using
8 layers of A+ W rap.
Girth welds that leaked (100% wall loss)
were clamped first and then over wrapped
with 15 layers of Pipe Wrap™ and 8 layers of
A+ Wrap™ to provide additional axial
stiffness.