Bombax Pipeline Project: Anti-Corrosion and Concrete Weight Coating of Large Diameter Subsea Pipelines

2003 ◽  
Author(s):  
John La Fontaine ◽  
Derek Smith ◽  
Gary Deason ◽  
Gary Adams
Keyword(s):  
Large Diameter ◽  
Pipeline Project ◽  
Subsea Pipelines

SAWL 485 for 48” Offshore Application in Thickness up to 41 mm

2008 ◽  
Author(s):  
Volker Schwinn ◽  
Alexander Parunov ◽  
Ju¨rgen Bauer ◽  
Pavel Stepanov
Keyword(s):  
Large Diameter ◽  
Development Program ◽  
Thick Wall ◽  
Diameter Pipe ◽  
Manufacturing Procedure ◽  
Pipeline Project ◽  
Qualification Testing ◽  
Nord Stream ◽  
Large Diameter Pipes ◽  
Subsea Pipelines

Vyksa Steel Works (VSW), part of United Metallurgical Company (OMK), has manufactured a trial batch of large diameter pipes for subsea pipelines in accordance with the DNV-OS-F101 standard and the specification of the Nord Stream project. The plates were produced by Dillinger Hu¨tte (DH). The batch included 1,220 mm (48″) diameter pipes of steel grade SAWL 485 (X70) with a wall thickness of 33 mm and 36 mm. All the requirements were met and OMK/VSW became Russia’s and the CIS’s first qualified producer of subsea pipes in accordance with DNV-OS-F101. In order to meet these high-class property requirements for thick wall pipes a successful development program was performed. The development program is outlined and the test results are explained. As a further consequence of the successful qualification work VSW became one of the two suppliers for the world’s largest and first 48″ diameter pipe subsea pipeline project (Nord Stream). Pipes will be supplied for the most sophisticated segment with wall thicknesses of 30.9 mm, 34.6 mm and even 41.0 mm. Results of manufacturing procedure qualification testing (MPQT) and start of production are presented.

Pressure Test Planning to Prevent Internal Corrosion by Residual Fluids

2012 ◽  
Author(s):  
Trevor Place ◽  
Greg Sasaki ◽  
Colin Cathrea ◽  
Michael Holm
Keyword(s):  
Structural Integrity ◽  
Large Diameter ◽  
Long Distance ◽  
Internal Corrosion ◽  
Pressure Testing ◽  
Practical Strategy ◽  
Leak Testing ◽  
Pressure Test ◽  
Transmission Pipeline ◽  
Pipeline Project

Strength and leak testing (AKA ‘hydrotesting’, and ‘pressure testing’) of pipeline projects remains a primary method of providing quality assurance on new pipeline construction, and for validating structural integrity of the as-built pipeline [1][2][3]. A myriad of regulations surround these activities to ensure soundness of the pipeline, security of the environment during and after the pressure testing operation, as well as personnel safety during these activities. CAN/CSA Z662-11 now includes important clauses to ensure that the pipeline designer/builder/operator consider the potential corrosive impacts of the pressure test media [4]. This paper briefly discusses some of the standard approaches used in the pipeline industry to address internal corrosion caused by pressure test mediums — which often vary according to the scope of the pipeline project (small versus large diameter, short versus very long pipelines) — as well as the rationale behind these different approaches. Case studies are presented to highlight the importance of considering pressure test medium corrosiveness. A practical strategy addressing the needs of long-distance transmission pipeline operators, involving a post-hydrotest inhibitor rinse, is presented.

The Development of Large Diameter and Thickness X80 HSAW Linepipe

2008 ◽  
Author(s):  
Weiwei Li ◽  
Chunyong Huo ◽  
Qiurong Ma ◽  
Yaorong Feng
Keyword(s):  
Bauschinger Effect ◽  
Pipeline Steel ◽  
Large Diameter ◽  
Base Material ◽  
Longitudinal Direction ◽  
Strength Loss ◽  
Ring Test ◽  
Low Carbon ◽  
Pipeline Project ◽  
Submerged Arc

For the requirement of 2nd West-East Pipeline Project of China, X80 large diameter & thickness linepipe with helical seam submerged arc welded (HSAW) were developed, with 1219 mm OD and 18.4 mm WT. Acicular ferrite type and super-low carbon, high Niobium chemical composition pipeline steel was adopted for the base material. The very stringent requirements at −10 °C for toughness, i.e. 220J/170J for average/minimum for pipe body and 80J/60J for average/minimum for weld and HAZ were meet successfully. The yield strength loss due to Bauschinger effect was found lower than 20MPa, which benefited. The very low residual stress level was testified by cut-ring test which cuts a section pipe about exceed 100mm long, and then cut the section apart from welds 100mm along the longitudinal direction.

Machine Learning for Subsea Pipeline Reeling Mechanics

2020 ◽  
Author(s):  
Eric Giry ◽  
Vincent Cocault-Duverger ◽  
Martin Pauthenet ◽  
Laurent Chec
Keyword(s):  
Design Of Experiments ◽  
Wall Thickness ◽  
Large Diameter ◽  
Local Buckling ◽  
Statistical Regression ◽  
Element Analysis ◽  
Excessive Strain ◽  
Weld Area ◽  
Subsea Pipelines ◽  
Pipeline Design

Abstract Installation of subsea pipelines using reeling process is an attractive method. The pipeline is welded in long segments, typically several kilometers in length, and reeled onto a large diameter drum. The pipeline is then transported onto such reel to the offshore site where it is unreeled and lowered on the seabed. The deformation imposed on the pipeline while spooled onto the drum needs to be controlled so that local buckling is avoided. Mitigation of such failure is generally provided by proper pipeline design & reeling operation parameters. Buckling stems from excessive strain concentration near the circumferential weld area resulting from strength discontinuity at pipeline joints, mainly depending on steel wall thickness and yield strength. This requires the characterization of critical mismatches obtained by trial and error. Such method is a long process since each “trial” requires a complete Finite Element Analysis run. Such simulations are complex and lengthy. Occasionally, this can drive the selection of the pipeline minimum wall thickness, which is a key parameter for progressing the project. The timeframe of such method is therefore not compatible with such a key decision. The paper discusses the use of approximation models to capitalize on the data and alleviate the design cost. To do so, design of experiments and automation of the computational tool chain are implemented. It is demonstrated that initial complex chain of FEA computational process can be replaced using design space description and exploration techniques such as design of experiments combined with advanced statistical regression techniques in order to provide an approximation model. This paper presents the implementation of such methodology and the results are discussed.

Developments of Subsea Pipeline Technology for Norwegian Waters

1999 ◽  
Vol 122 (1) ◽  
pp. 33-39 ◽  
Author(s):  
Sverre Lund
Keyword(s):  
Cost Efficiency ◽  
Large Diameter ◽  
Transportation Systems ◽  
Subsea Pipeline ◽  
Deep Waters ◽  
Mapping Technology ◽  
Efficiency Cost ◽  
Large Water ◽  
Operational Issues ◽  
Subsea Pipelines

Norwegian waters have been a main arena for development of subsea pipeline technology over the last 25 yr. The gas transportation systems from Norway to continental Europe comprise the largest and longest subsea pipelines in the world. The challenges of pipeline projects in and from Norwegian waters include large water depths, large diameters, long distances, uneven seabed, rocky landfalls, and hostile environmental conditions, all within strict requirements for safety, regularity, cost efficiency, and environmental impact. This paper provides an overview of the technology developments performed in this period, initially focusing on ability to cross the deep waters of the Norwegian trench by large-diameter pipelines, then on subsea design aspects such as stability, free span design, and mapping technology, and in recent years also on improvements in transportation efficiency, cost reductions, and operational issues. The paper is based on a Plenary Lecture presented at the 1998 OMAE Conference in Lisbon, Portugal. [S0892-7219(00)00601-4]

Pipeline Stabilisation Using Pre-Trenching and Sand Backfill

2012 ◽  
Author(s):  
David J. Chamizo ◽  
Dean R. Campbell ◽  
Carl T. Erbirch ◽  
Eric P. Jas ◽  
Liang Cheng
Keyword(s):  
Natural Gas ◽  
Large Diameter ◽  
Mechanical Damage ◽  
Clay Content ◽  
Carbonate Sand ◽  
Natural Gas Pipelines ◽  
Limited Success ◽  
Wave Heights ◽  
Subsea Pipelines ◽  
Very High

Stabilizing large diameter natural gas pipelines on the seabed against extreme hydrodynamic loading conditions has proven to be challenging in the northwest of Australia. Tropical storms, which affect the area annually between November and April, can generate wave heights exceeding 30 m and on-bottom steady-state currents of 2 m/s or more. Consequently, in shallow water depths, typically less than 40–60 m, subsea pipelines can experience very high hydrodynamic loads, potentially causing significant lateral movement. If the seabed is rugged, or at locations where the pipeline approaches a point of fixity, this can lead to the pipeline suffering mechanical damage, which is undesirable. In many places on the Northwest Shelf of Australia, there is a layer of minimum 3 m deep marine sediments. The sediments predominantly comprise of relatively stable, fine to medium sized carbonate silts and sands, sometimes with some clay content. Traditionally, in Australia and other parts of the world, post-trenching techniques such as ploughing and jetting have been applied in such areas. These techniques can successfully lower the pipeline into the seabed. However, in many situations on the Northwest Shelf of Australia, post-trenching has had limited success. This has in part been due to the unpredictable levels of cementation of the carbonate sand, which has often resulted in an insufficient trench depth, with the need to implement costly and time consuming remedial works to ensure pipeline stability. The uncertainties in the success of post-trenching tools lead to the development of the pre-trenching and sand backfill method, which was first applied in Australia in 2003 on a 42-inch diameter natural gas trunkline. This technique has several advantages compared to post-trenching and other conventional pipeline stabilization methods such as rubble mound pipeline covers or gravity anchors. This paper presents an overview of the pre-trenching and sand backfill method, its design principles, benefits, and risks and opportunities.

Rock Berm Design for Pipeline Stability

2012 ◽  
Author(s):  
David J. Chamizo ◽  
Dean R. Campbell ◽  
Eric P. Jas ◽  
Jay R. Ryan
Keyword(s):  
Traditional Approach ◽  
Large Diameter ◽  
Mechanical Damage ◽  
Small Scale ◽  
Lateral Movement ◽  
Functional Requirements ◽  
Natural Gas Pipelines ◽  
Hydrodynamic Loading ◽  
Wave Heights ◽  
Subsea Pipelines

Stabilizing large diameter natural gas pipelines on the seabed against extreme hydrodynamic loading conditions has proven to be challenging in the northwest of Australia. Tropical storms, which affect the area annually between November and April, can generate wave heights exceeding 30 m and storm steady state currents of 2 m/s or more. Consequently, in shallow water depths, typically less than 40–60 m, subsea pipelines can be subjected to very high hydrodynamic loads, potentially causing significant lateral movement. To mitigate the risk of the pipeline suffering mechanical damage due to excessive lateral movement, quarried and graded rock is often dumped over the pipeline as a secondary stabilization solution. In order to satisfy functional requirements, the rock berm must comprise of a sufficiently large rock grading size and berm volume to withstand the design hydrodynamic loading such that the pipeline cannot break out of the berm. The design of rock berms for pipeline secondary stabilization has traditionally followed a deterministic approach that uses empirical equations for preliminary rock sizing, followed by small-scale physical modeling for design verification and optimization. Whilst the traditional approach can be effective in producing a robust rock berm design, opportunities for further optimization are inhibited by a lack of available data and an imperfect understanding of the failure mechanisms. This paper presents an overview of an improved approach for rock berm design optimization. A general overview of rock berms, the design principles, benefits and risks are also presented.

Development of Large Diameter Heavy Wall Seamless Tee Fitting of WPHY-80 Grade for Low Temperature Pipeline Station Application

2018 ◽  
Author(s):  
Yu Liu ◽  
Tao Han ◽  
Yezheng Li ◽  
Zhanghua Yin ◽  
Peng Zhu ◽  
...  
Keyword(s):  
Fracture Toughness ◽  
Low Temperature ◽  
Production Process ◽  
Large Diameter ◽  
Steel Production ◽  
Hot Extrusion ◽  
Gas Pipeline ◽  
Tensile Yield Strength ◽  
Fitting Production ◽  
Pipeline Project

This paper describes the development of large diameter heavy wall seamless tee fitting of WPHY-80 grade for low temperature pipeline station application. Steel tees with thicker wall generally tend to have low fracture toughness either in pipe body or in weld joint and low weldability. Therefore, improvement of fracture toughness and weldability are particularly important with respect to development of higher strength and thicker wall seamless tee fittings. For the requirement of the China-Russia Eastern Gas Pipeline Project, WPHY-80 large diameter, seamless heavy wall reducing outlet tees were developed, with DN1400 × DN1200 and 57mm wall thickness. The billet steel production process was electroslag remelting (ESR), and the tee fitting production process used a forging and hot extrusion combination. Finally, quenching and tempering were carried out. In this paper, the mechanical properties and microstructure of WPHY-80 seamless tee were studied. The results of mechanical testing showed that the tensile yield strength of the tee body was more than 590 MPa and also provided excellent low temperature toughness (CVN > 200 J at −45°C), which met the requirements of the specification for fittings applied in the China-Russia Eastern Gas Pipeline Project. In addition, the results of welding procedure qualification showed that the welding performance of the WPHY-80 seamless tee was excellent.

Implementation of Alternative Integrity Validation on a Large Diameter Pipeline Construction Project

2008 ◽  
Author(s):  
Joe Zhou ◽  
Alan Murray ◽  
Jake Abes
Keyword(s):  
Quality Control ◽  
Effective Means ◽  
Large Diameter ◽  
Construction Project ◽  
Third Party ◽  
Successful Implementation ◽  
Free Condition ◽  
Pipeline Project ◽  
Detection Technologies ◽  
Made In

Hydrostatic testing has been used by the pipeline industry for many decades as an effective means to demonstrate safety and the leak-free condition of a newly constructed pipeline. However, significant advancements have been made in material, construction and leak detection technologies and quality control processes. These advancements have created the possibility of implementing an alternative to hydrostatic testing while still meeting the original purpose of demonstrating safety and leak-free condition of newly constructed pipelines. TransCanada PipeLines Limited (TransCanada) initiated the development of its Alternative Integrity Validation (AIV) approach in 2004. During 2004 and 2005, TransCanada successfully implemented AIV on a NPS 24 construction project under the jurisdiction of the Alberta Energy and Utilities Board (EUB). With the learnings obtained from the first pilot AIV implementation, TransCanada subsequently implemented AIV on a NPS 42 construction project under the jurisdiction of the National Energy Board (NEB), with CC Technologies (CCT) as the independent third party auditor. As a result of the successful implementation of AIV, the hydrostatic testing requirement was waived for both projects by AEUB and NEB, respectively. This paper summarizes the AIV implementation on the larger diameter pipeline project and provides the perspectives from the pipeline company, regulator, and independent auditor.

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