Designing for high pressure

Monday, February 4, 2013


Engineering Challenge: 
For a yet-to-be-selected fabricator, design large-diameter, corrosion-resistant, filament-wound composite pipe with sufficient strength to resist burial and settlement loads as well as internal pressure and axial loads due to restrained contraction, without failing.
Design Solution: 
Supplement industry pipe guidelines with calculations and finite element analysis that account for job-specific conditions, and then design ply schedules for both conventional and continuous filament winding processes that will yield comparable finished-pipe performance.
 Underground pipe may seem mundane and unglamorous, but when those buried pipes are very large and specified in composite materials, design and fabrication is a big challenge. Although large-diameter composite pipes (48-inch/1,200-mm diameter and larger) have been specified as an alternative to thermoplastic, steel, iron and concrete pipe since the 1960s, a few spectacular failures during the 1980s forced the industry to take a hard look at its design process, notes Chris Renoud, professional engineer and CEO of Fiberglass Structural Engineering Inc. (FSE, Bellingham, Wash.). “Our corrosion industry has had a number of failures when compared to other composite applications,” he points out. “Underground composite piping is a growing application, great for many sectors, but good design is critical for success.”
FSE specializes in developing designs and specifications for project owners, who then procure pipes from third-party fabricators, Renoud explains. Fabrication techniques are typically standard helical filament winding or “continuous” winding (see “Making continuous composite pipe,” under "Editor's Picks," at right) but can include hand layup. The pipe sizes often exceed 10 ft/3m in diameter. The destinations for large pipe that will be buried below grade include power and chemical plants, oil refineries, desalinization projects and cooling-tower installations.



Underground pipe design process

A recent confidential project involved a design for about 5,000 linear ft/1,540m of 13-ft/4,000-mm diameter piping to convey seawater for a process cooling system at a Middle Eastern petrochemical plant. FSE’s principal engineer, Randy Rapoza, explains that composites were a given. They offered a favorable installed cost and neither coated steel pipe, cathodically protected steel pipe nor concrete pipe could match the 50-year maintenance-free service life of composites in a corrosive environment created by seawater, internally, and underground burial, externally. And, because fiberglass pipe has a smoother inside surface than other materials and accumulates no scale or deposits over time, it could permit a greater water flow over the life of the project.
The pipe was to be buried 7 ft/2.15m below grade and butt-and-strap joined. The joined pipe, therefore, would be restrained — that is, the pressure of the surrounding soil would lock the pipe in place with friction, limiting any movement without having to use thrust blocks (fixed structures that hold pipes in alignment). Rapoza stresses that the soil forces on the buried pipe are not trivial.
“You have to take into consideration the entire situation — the native soil conditions, the depth of water table, the temperature of the fluids that the piping will convey as well as ambient temperature during installation, traffic loads and so on. Loads due to burial, including those caused by differential soil settlement that causes the pipe to bend, far outweigh the typical forces on a pipe in an above-ground installation.”
The basis for the design was a widely used guide supplied by the American Water Works Assn. (AWWA), titled Fiberglass Pipe Design (a/k/a Manual M45). The manual provides equations that take into account the velocity and pressure of the conveyed fluid, head loss due to turbulent flow, water hammer, buckling pressure and surge pressure. But, explains Rapoza, that basic concept was supplemented with other calculations to cover a host of site-specific design conditions that can’t be addressed by the M45 guide, including soil type and density, depth of cover and allowable vehicular traffic load. Sometimes FSE also must consider severe live loads from cranes and construction equipment in the calculations, which the backfill must support, as well as average and maximum service temperatures, shape factor (or deflection due to bending stress from soil loads) and more. “It’s a fairly extensive calculation process,” he reports. Ultimately, this process led to an interim solution for the pipe wall thickness and stiffness that was necessary to handle water pressure loads and to prevent any buckling or excessive deflection and stress under the project burial and operating conditions.
The designers then employed finite element analysis (FEA) methods for detailed stress analysis, combining hoop and axial loads, to verify the pipe design. FSE uses ANSYS Inc. (Canonsburg, Pa.) for FE modeling software. Depending on the pipe’s modeled performance at the calculated wall thickness under project conditions, Rapoza says designers might have to go back through the calculations to tweak the design, optimizing thickness and laminate design or increasing axial stiffness to meet the performance goals. “The analysis often requires several iterations,” he says.
The final calculated wall thickness for the 13-ft/4m diameter pipe was a considerable 1.8 inches/46 mm for pipe sections that were 39 ft/12m in length. The design pressure was 10 bar (gauge)/145 psi (the operating pressure would be 8 bar/116 psi), and the design temperature was 150°F/66°C, although the operating temperatures were expected to be around 115°F/46°C.
Key to the analysis and design of the glass reinforcement schedule was “restrained thermal contraction and restrained contraction from the Poisson effect of internal pressure,” says Renoud, who points out that these often-overlooked conditions were the cause of many early composite pipe failures. When a pipe is buried in hot ambient conditions and then operated (or shut down) at a lower temperature, he explains, it wants to contract, but it is axially restrained by the soil and can’t move. Similarly, when the pipe tends to expand in the hoop direction due to pressure, it tries to contract in the axial direction but cannot, resulting in significant axial forces. Composite pipe, unlike steel or concrete, tends to be weakest in the axial direction, says Rapoza. “The tensile stress can literally tear the pipe apart.” To account for these restrained loads, he explains, sufficient axial fibers were specified in the design to ensure adequate axial tensile strength in the pipe wall. Additionally, the installation instructions specify the maximum temperature at the time of burial to control the differential between the installation temperature and the pipe’s minimum use temperature (60°F/15.5°C, in this case).



Composites meet conditions

Next, designers specified E-glass, and a vinyl ester from Ashland Performance Materials (Dublin, Ohio), with a fiber-to-resin ratio of about 60 percent by weight. FSE’s senior project manager Steve Gaber says vinyl ester offers better corrosion resistance and is “more flexible and provides better strain properties than a polyester.”
FSE then developed the laminate architecture. Rapoza explains that because the fabricator had not yet been chosen, it was unknown whether standard helical winding or continuous winding methods would be used. “We actually developed one specification covering both methods, each about equal in thickness and with ... materials adjusted so that pipe performance would be the same, regardless.”
For standard filament winding, in which a fixed male mandrel equal in length to each pipe length is rotated by a headstock and tailstock, an initial C-glass surfacing veil (0.01 inch/0.25 mm in thickness) would enable a resin-rich inner surface, followed by one ply of chopped strand mat to complete a chemical-resistant and flexible pressure containment barrier. Then, 35 cycles of E-glass fiber would be wound (from the head to the tail and back) at a ±55° winding angle (with the pipe’s horizontal axis at 0°) to maximize axial strength, says Rapoza.
For pipe made in a continuous winding process, the reinforcement spec was considerably different. The same C-glass veil was followed by a layer of random chopped glass mat, then more than 100 plies of alternating hoop-wound glass fibers (90° winding angle) and chopped glass, with multiple interspersed plies of unidirectional (0°) tapes. The hoop fiber contains the internal pressure loads and provides the stiffness necessary to resist deflection or “ovaling” due to burial loads. The uni tapes, applied by hand or machine wound, add axial strength to resist the previously noted restrained thermal and Poisson loads and other axial loads.
To ensure that pipe lengths would be consistent with the specifications, FSE developed testing and quality-assurance guidelines for the fabricator. Samples would be taken periodically and tested for thickness, glass content (ASTM D2584), correct ply sequence, hoop tensile strength, hoop modulus of elasticity, axial tensile strength and axial modulus of elasticity and stiffness (per guidance provided in AWWA C950). A key FSE specification concerned the joining of pipes during installation. Rapoza and Gaber emphasize that FSE’s preferred method for this project type is a wet-laminated butt joint, using glass woven roving and chopped strand mat. “If correctly completed, the joint will be stronger than the pipe itself,” Gaber claims. FSE offers its clients the option of onsite QA surveillance of joining operations and can recommend contractors with experience in both joinery and repairs.
To ensure a consistent, predictable backfill, FSE specified a clean, well-graded soil and backfill with a density of no more than 120 lb/ft3, says Rapoza. Although some settlement is inevitable, he recommends that engineers design for no more than 20 mm/0.8 inch of settlement in each 20m/65 ft of pipe length.
Concludes Renoud, “A lot of these design steps are often overlooked by project engineers and designers. Everyone in the industry will benefit by recognizing that these large structures must be carefully engineered.”
Side Bar

Making continuous composite pipes

The continuous filament winding process was developed in the 1970s by Danish inventor Frede Hilmar Drostholm, and it was commercialized first by Toledo, Ohio-based Owens Corning’s engineered pipe systems business, in partnership with several entities, including Amiantit (Dammam, Saudi Arabia) and Vera Fabrikker (later Flowtite Pipe and Tank AS, Sandefjord, Norway). The ingenious process involves a cantilevered, horizontal rotating mandrel system. Customizable to a range of pipe diameters, the mandrel is made up of longitudinal aluminum beams fitted with small outward-facing roller bearings, a series of discs (sized to the pipe to be produced) that support the beams and a steel “band,” or endless loop. As the mandrel rotates, the steel band, which is about 2 inches/51 mm wide, is wound over the beams by a placement head on the mandrel’s supported end. As it is wound, the band also is pulled and, therefore, moves over the roller bearings in the axial direction, advancing toward the other (open) end of the mandrel. At that end, an exit head directs the band back through the mandrel’s core to the supported end, where the placement head directs it onto the mandrel again. In this way, the wound band forms a continuously advancing, smooth tool surface onto which the pipe materials are applied, via filament winding heads on either side. The wound pipe is pulled along by the advancing band through a heated zone near the mandrel’s open end to cure. Then the cured pipe exits the mandrel system, and the continuous pipe is cut to the desired length for transport to the project site. Some manufacturers can produce more than 30m/hr (98 ft/hr), and the technology can currently fabricate pipe up to 4m/13 ft in diameter. To see a continuous filament winder in action, visit YouTube for several videos, including this one produced by large-pipe fabricator Technobell London (Harrow, Middlesex, U.K.): http://www.youtube.com/watch?v=YAdwxIELLDU&feature=player_embedded#at=220.
CT JUN 12 Drawing
Fiberglass Structural Engineering's Large-Diameter Pipe Designs Illustration: Karl Reque
FSE pipe
Large-diameter composite pipe intended for burial underground requires careful design to account for a range of load conditions that can impact performance. Source: FSE
FSE pipe awating install
Completed large-diameter pipe (below) awaits installation at a project site. Source: FSE
T-junction pipe FEA
This screen shots show FE analysis of large-diameter pipe at a T-junction where two pipes will be joined using wet-laminating techniques (see also image below). Source: FSE
Another view of the large-diameter pipe T-junction shown above. Source: FSE
Pipe section test
A sample section of large-diameter filament-wound pipe is tested in the laboratory for axial tensile 


Thermal Insulation for Pipelines, Risers, Spools and Subsea Structures


Why apply Thermal Insulation Coatings?

Assets such as offshore pipelines, risers, spools and subsea structures which transport liquid products may be required to maintain a minimum temperature while the product is being transported within the asset, particularly offshore. Some liquids such as oil and gas can leave wax or hydrate deposits if a minimum temperature is not maintained. These deposits can, over time, build up and block the asset/pipeline either reducing or completely stopping flow/production. External wet insulation can be designed and applied to ensure the reduction in product temperature is kept within a range so the risk of deposits during production is acceptable. Insulation can also reduce the frequency of pigging operations during the life of the asset.
During other operational events, such as pipeline shutdowns, the product is contained in a stationary state within the asset/pipeline while the process facility has other operations performed. Similarly, to avoid deposits during these shutdown periods external insulation can be designed and applied to ensure the reduction in product temperature is kept within a range so the risk of deposits during shutdowns is acceptable.
The cycle time to apply and cure the wet insulation coating for offshore assets, particularly field joints on spoolbases and onboard S lay or J lay vessels is critical. To achieve the fastest and reliable cycle times, training of the OJS application crew, formulation of material properties (particularly curing time) and the design of equipment is essential.
OJS provides two types of wet Thermal Insulation Coating Services;
  • Injected Molded Solid Polyurethane Application (IMPU)
     
  • Injection Molded Polypropylene Application (IMPP)
     
IMPU
Injected Molded Polyurethane Applications provide thermal insulation and are commonly used offshore on flowline and riser field joints, spools and subsea structures. It is used less often onshore to thermally insulate pipelines and spools. The asset will require to have been pre-coated with an anti-corrosion layer prior to the thermal insulation application.
The preparation for IMPU requires that the anti-corrosion layer is in good condition and the bevel faces of the parent coating (usually PP) are cleaned, abraded and then pre-heated to build bond strength between the PP and IMPU. Once this preparation is completed a mold is placed over the area to be treated and Solid Polyurethane is injected into the annulus and often overlapping the parent coating bevel faces and onto the OD surface of the PP. Once the material cures the mold is removed and inspected.
OJS can apply all Solid Polyurethanes available on the market however we recommend our own formulated solid polyurethane material called Densiflex for IMPU coatings. Densiflex is mercury free and fast curing – which is suitable for the offshore market.

IMPP

Injected Molded Polypropylene Applications provide thermal insulation on pipeline and riser field joints and spools. The asset will require to have been pre-coated with an anti-corrosion layer prior to this thermal insulation application.
The preparation for IMPP requires that the anti-corrosion layer is in good condition and the bevel faces of the parent coating (usually PP) are cleaned, abraded and then pre-heated to build bond strength between the PP and IMPP. Once this preparation is completed a mold is placed over the area to be treated and Solid Polypropylene is injected into the annulus. Once the material cures the mold is removed and inspected.
OJS offers IMPP in co-operation with Bredero. OJS applies the FBE and CMPP layers and Bredero inject the PP.
Densiflex®, Sea Sleeve®, and Deep Sea Sleeve® are registered trademarks of Offshore Joint Services, Inc.
Source:

Bending steel pipe with a concrete coating


Considering that, within limits, everything can be deformed in an elastic way. Steel pipe with concrete coating can thus be deformed in its elastic area and return to its original form after the applied forces are taken away. For the spiraling pipeline it is interesting to find the constraints of this elastic bending.The differences between steel and concrete during the deformation is that afterv the elastic deformation steel will start flowing and deforms plastcally while the concrete will start to form micro cracks before it finally breaks.
Due to the limitless tests that have been performed on steel and especially on pipeline it is easy to predict what the constraints for bend pipeline will be.
As we can see in the diagram the pipe will deform from the yield point onwards in a way that the steel pipeline will change its form irreversible. Besides that, the structure of the steel will change and harden, the round form of the pipe will become oval.  When the pipeline roundness deformation becomes too large, the inspection tools and pigs that will be utilised in a later stage could have problems passing the deformed
parts of the pipeline.
By using additives the concrete can extend its elasticity. The concrete has a lower E-modulus and by including certain additives the concrete does allow more strain before micro cracks will occur. Therefor the concrete is not the determining factor when it comes to bending to the limits in the elastic area.
To get not into the plastic area of the steel (or of the concrete ) we have to make sure the strain doesn't pass the point where plastic deformation (or plastic yield) starts to occur.

For the pipe’s integrity it is best that deformations remain within the elastic area

Plastic yield occurs in the spiral when:
r/R > Y/E
where r = outside pipe radius
R = spiral radius (more exact, from center of first layer to the pipe axis)
Y = yield stress of the steel
E = modulus of elasticity or Young's Modulus
For a pipe the values of r, E and Y are known. Therefore the R can be calculated.

Example:

For a pipe X65 (API 5L) with OD of 508 mm, E = 2,06*105 N/mm2, Y= 450 N/mm2.
The first winding of the spiral will be minimum 508 X 206000 / 450 > 233 meter.
Generally one could say that the diameter of the first layer of the spiral should be roughly 500 X the diameter of the pipe. As long as the pipeline will stay within its own elastic area, the pipe will not transform into a permanent oval shape. Ovalisation will occur when a pipe is bent beyond the boundaries of elastic deformation. Excessive ovalisation is not acceptable because of the fact of its incompatibility with the use of pigs and TFL tools in a later stage.

With the O-lay method it is possible to prepare any diameter of pipelinewhich has to be installed on the sea-bed.

The advantage of this method is that pipeline will not be plastically deformed during spiralisation and the pipe will always return to its original form after the applied forces are taken away from the pipe.

Source:
http://o-lay.net/method/pipeline-spiraling-stage.html 

Bottom Stability Analysis


Pipeline On Bottom Stability Analysis




















Pipeline on bottom stability is an interaction of pipe, water and soil. The important factor that taken into account is the water flow whereby determining the magnitude and time variation of hydrodynamic drag and lift forces.

The second factor is soil. There have 3 friction will happened which are static, sliding and cohesive friction. So, it’s very important to understand the soil condition at the pipeline route area so that accuracy of analysis achieved.

These are some input provided for on bottom stability analysis :
1. Pipeline Data

Outside diameter 
Wall thickness
Density of Pipe
Corrosion Coating Thickness
Corrosion Coating Density
Concrete Coating Thickness
Concrete Coating Density
Field Joint Material Density
Concrete Coating Cutback
Corrosion Coating Cutback
Pipe Joint Length




2. Wave and Current Data 

Significant Wave Height (Hs)
Spectral Peak Period (Tp)
Wave Angle
Wave Spectrum Type
Water Depth 
Current Velocity
Current References Height from Bottom
Peakedness Parameter

3. Physical Parameter

Density of Content
Density of Seawater
Marine Growth Thickness
Soil Type
Mean Grain Size – DNV RP E305
Roughness – DNV RP E305
Undrained Shear Strength (Su) – DNV RP E305
Lift Coefficient – –DNV RP E305
Drag Coefficient – DNV RP E305
Inertial Coefficient – DNV RP E305








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Corrosion Technology


STOPAQ - Offshore Corrosion Prevention and Insulation Systems



When Frans Nooren founded STOPAQ in 1988, he started a waterproofing contracting company aimed at solving many civil structure water problems, a major concern in a country like the Netherlands. Drawing on his practical experience, he set out to improve sealing technology products and developed an innovative product, which he demonstrated to great success by sealing leaks in the harbour walls at Rotterdam.
Due to erosion of the soil behind the dock wall pilings, corrosion had taken place and corroded the sheet from the rear, leading to perforations. These had to be sealed from the harbour side using novel technology involving a sealing compound applied and cured under water. This product was the start of a new generation of sealants and coatings.

Polyisobutene resin sealants for the offshore industry

The polyisobutene resin technology STOPAQ's product range is based on make it ideal for field joint coating of pipelines. The company's latest innovation of visco-elastic coatings – which are patented innovative polymer technology and available worldwide – can provide pipeline owners and operators with reliable, long-lasting anti-corrosion coatings for field joints and for the repair of damaged areas on the main pipeline coatings.
As the coatings are 100% self-healing, chemical and temperature-resistant, and less likely to damage in service, they can be easily and quickly applied without the need of special equipment or highly skilled operators. This, in turn, means there are fewer application and through life costs.

Advanced corrosion prevention and insulation systems

The offshore world requires advanced corrosion prevention and insulation systems. Corrosion processes can sever offshore equipment and pipe rupture may occur. Hard and tough coatings may break. Very low PH (2-3) electrolyte solutions can cause CUI. Other chemical reactions and or moisture / water penetration must be prevented at great depths.
In response to the offshore industry's demands, STOPAQ and BASF have joined forces. The result of combining STOPAQ's visco-elastic corrosion prevention layer with BASF's PU is a cost-effective solution delivering long-term protection against corrosion by locking out negative influences. We see stopping corrosion as our common mission now. Via our system, we can offer you more control in all process steps from preparation, application and control beyond design life.

Corrosion prevention systems for offshore pipelines and platforms

Pipelines and platforms need to be safe constructions – for people and for the environment. STOPAQ / BASF Offshore can seal spools, under insulation, under fireproofing, J-tube filling, flanges, risers, christmas trees, pp-coating repair, pipe joints, subsea repair, and piles (splash zone). STOPAQ / BASF applications can be found on many important offshore installations worldwide and on offshore pipeline joints.
STOPAQ / BASF offers fully integrated solutions, including service preparation on-board of lay barge vessels. The joint system offers a simple, safe and fast-turnaround job, guaranteeing 100% adhesion. Mechanical protection is ensured by using tapes, shrinkable sleeves or PU infill.

Tailor-made corrosion-resistant coating systems

STOPAQ / BASF's coating system can be tailor-made for each project, and easily applied. Furthermore, it also allows a quicker preparation of steel and adjacent factory applied coating by at least St2/3 brushing method, cold application of the visco-elastic anti-corrosion layer, and immediate and permanent attachment of the impermeable visco-elastic layer to steel, concrete, polypropylene, polyurethanes and polyethylene. There is no risk of osmosis.
Some of the system advantages are:
  • Increasing the speed of application
  • Eliminating the need of flame torch
  • No need for primers
  • Cost-effective: reduces inventory requirements eliminating diameter specific solutions
  • Outstanding impact resistance
  • Cold flow; providing corrosion protection by penetrating into the finest pores of the substrate
  • Very surface tolerant; no grit blasting, only wire brushing or hand tool cleaning required
  • Higher temperatures resistance

Contact Details


STOPAQ
PO Box 285
9500 AG Stadskanaal
Netherlands
Tel: +31 599 69 61 70
Fax: +31 599 69 61 77





source:
STOPAQ's coatings are based on polyisobutene resin technology, making them ideal for field joint coating of pipelines.
Poor adhesion and disbonding may lead to pipe rupture.
STOPAQ provides pipeline owners and operators with reliable, long-lasting anti-corrosion coatings for field joints and for the repair of damaged areas on the main pipeline coatings.
The result of combining STOPAQ's visco-elastic corrosion prevention layer with BASF's PU is a cost-effective solution delivering long-term protection against corrosion by locking out negative influences.
Our corrosion-prevention coating system can be tailor-made for each project, and easily applied.


 
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