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08:30 09:00 (30 mins)

Registration and Welcome Coffee

09:00 09:20 (20 mins)

Welcome from the Chair and 'Round the Room' Introductions

09:00 09:20 (20 mins)

Welcome from the Chair and Round the Room Introductions

  • Ian Frazer

09:00 09:20 (20 mins)

Welcome from the Chair and 'Round the Room' Introductions

  • David Bruton, Director Subsea, Crondall Energy

09:20 10:00 (40 mins)

Introduction to Integrity Management of Offshore Pipelines and Risers

  • Identifying the challenges
  • Pipeline failures and their causes
  • Inspection and integrity management
  • Impact of legislation

09:20 10:00 (40 mins)

Introduction to Riser Technology Options

  • Overview of riser options
  • Drivers for technology
  • Technology application to risers
  • Innovation solutions for deep and ultra-deepwater fields

09:20 10:20 (60 mins)

HPHT Pipelines: Challenges, Risks and Solutions

  • Why HPHT pipelines?
  • What is HPHT?
  • Identifying problems with pressure and temperature
  • Pipeline reliability

10:00 10:40 (40 mins)

Codes, Guidelines and Best Practices for Integrity Management

  • Offshore codes
  • Selected recommended practice
  • Planned developments and JIP updates

10:00 10:40 (40 mins)

Solutions for Ultra Deep Water Developments and IRIS, New Inspection Tool

  • Flexible pipe deepwater development

- Dedicated pressure vault wire

- Carbon fibre wires

- Anti h²S layer

  • IRIS, In-Service Riser Inspection System

- Versatile underwater inspection tool for pipe risers

  • Yannick Benedek, Flexible Pipe Business Development and Marketing Manager, Flexi France

10:00 10:40 (40 mins)

Introduction to Lateral Buckling and Walking of HPHT Pipelines

  • The history and development of lateral buckling as a design solution
  • What approaches are used to mitigate lateral buckling and do they work?
  • The history and development of pipeline walking as a design challenge
  • What approaches are used to mitigate pipeline walking and do they work?
  • Operational monitoring – is it essential and what have we learned?
  • Future technology developments and approaches 
  • David Bruton, Director Subsea, Crondall Energy

10:40 11:00 (20 mins)

Networking Refreshment Break

11:00 11:40 (40 mins)

Thermoplastic Composite Pipe - An Update on Recent Developments

  • TCP concept, design and qualification
  • Applications and benefits
  • Recent projects

- jumper installation in the North Sea

- downline application in the Norwegian deep-water

  • TCP risers on ultra deep water environments - case study
  • Qualification of new materials enabling deep-water risers
  • Teofilo Barbosa, Product Qualification Manager, Airborne Oil and Gas

11:00 11:40 (40 mins)

Influence of Pipe-Soil Interaction on Lateral Buckling and Pipeline Walking

  • Why is pipe-soil interaction the most significant design uncertainty?
  • The history and development of pipe-soil interaction (PSI) knowledge
  • Axial resistance – importance of breakout, residual & cyclic responses
  • Lateral resistance – importance of breakout, residual & cyclic responses
  • Operational monitoring – what have we learned about PSI?
  • Future technology development and approaches
  • David Bruton, Director Subsea, Crondall Energy

11:00 11:40 (40 mins)

Inspection, Repair and Maintenance of Deepwater Pipelines

  • Requirements for pipeline inspection: what, when and how
  • Pipeline maintenance and routine inspection
  • Pipeline damage during installation and operation in deepwater, causes and effects
  • Understanding the risks and potential need for repair
  • Repair systems and tools
  • Ian Nash, Managing Director EAME, Peritus International Ltd

11:40 12:20 (40 mins)

Advances in Flexible Pipe System Design Methodologies

  • Design considerations
  • Industry trends
  • Evolving analysis techniques

11:40 12:20 (40 mins)

Cost-Effective Geotechnical Design of HPHT Pipelines

  • Why is quality geotechnical data and analysis important? 
  • Cost implications for low quality geotechnical data acquisition
  • Strategy for implementing cost-effective geotechnics in HPHT
  • Improved tools for characterising soil conditions
  • Pipe-soil interaction analysis  

11:40 12:20 (40 mins)

Pipeline Integrity Management System (PIMS)

  • What is PIMS?
  • What does a PIMS involve?
  • What are the key benefits?
  • Development and implementation of a PIMS
  • Examples/case studies

12:20 12:30 (10 mins)

Discussion and Q&A

12:30 13:30 (60 mins)

Networking Lunch

13:30 14:10 (40 mins)

Monetizing a Drilling Vessel - Early Production Through a Thermally Insulated Pipe-in-Pipe Riser with Threaded Connection

Authors: Aurelien Damour, Simon Thiollière and Christian Geertsen, ITP InTerPipe

Most deepwater fields require some means of flow assurance to overcome hydrate issues not only during production phases, but also during the earlier drilling and testing phases where hydrocarbons flow to surface facilities. Mitigation against wax/gelling may also be required. Stopgap measures may not be enough, especially if the field economics justify a temporary early production scheme through the drilling system. A thermally efficient drilling riser provides a passive solution to many of the flow assurance concerns by preventing produced fluids from cooling into the hydrocarbon zone.

Based on experience with flowlines and in-well insulated tubing, ITP Interpipe has developed, together with Total and a drillpipe manufacturer, an offshore thermally insulated drillpipe. These drillpipes can be threaded together into a pipe-in-pipe Work Over Riser (WOR) with an overall U-value down to 0.8 W/(m².K) from surface to 1800 meters water depths. A strengthened design has also been developed for 3000-meter water depth. The proposed system is a tool for drillers and operators to mitigate thermal issues while cleaning wells after drilling or to allow early production for some months while waiting for more permanent facilities being developed and installed. The installation of this riser can be made by drilling rigs with the same operations as for a standard drill pipe. The authors will discuss the salient features of the design and present test results from the qualification which was conducted in line with DNV-RP-A203. These tests were performed on full-scale prototypes and included the following design validations:

  • Onshore construction (validates production process)
  • Drill pipe make & break test (validates offshore assembly into riser in drill rig)
  • Heat loss measurements (validates flow assurance)
  • Resonant fatigue test (validates choice of fatigue curves for design life
  • Simon Thiollière, ITP InTerPipe

13:30 14:10 (40 mins)

Flow Assurance Challenges in HPHT Developments

  • What is flow assurance?
  • Flow assurance design process
  • HPHT flow assurance modelling and flow assurance challenges
  • Murray Anderson, Director, Crondall Energy

13:30 14:10 (40 mins)

Risk Based Inspection (RBI) of Rigid Flowlines

  • What is RBI?
  • Why perform RBI?
  • Controlling risk through inspection
  • Managing uncertainty in the condition of ageing pipelines

14:10 14:50 (40 mins)

Low Cost Field Development Using Hybrid Risers

  • Typical field development options and proposed alternatives
  • Free standing hybrid risers
  • Applications

14:10 14:50 (40 mins)

Benefits of a Full Probabilistic Approach to Lateral Buckling Design

Authors: Malcolm Carr, Ian MacRae and David Bruton, Crondall Energy

A pipeline lateral buckling design must deal with huge uncertainty in key input parameters.  This uncertainty forces the designer to adopt a very conservative approach to buckle initiation; often involving unnecessary, complex and costly, buckle initiators.  This paper describes a fully probabilistic approach for the design of these pipelines.   Under this approach, the local buckling and fracture limit states are evaluated, accounting explicitly for uncertainties in pipe-soil interaction, pipe out of straightness and pipeline material properties.  As the uncertainties are addressed in a rational way, the approach leads to a more appropriate design strategy.  The improvement in design can lead to significant project cost savings.

  • David Bruton, Director Subsea, Crondall Energy

14:10 14:50 (40 mins)

Heat Traced Pipe-in-Pipe: Extending the Lifetime of Existing Facilities with Minimal Disruption

Authors: S. Cherkaoui, A. Reveilloux and S. Giraudbit, Subsea 7 and N. Raveaud and C. Geertsen, ITP InTerPipe

Subsea 7 has been successfully installing active heating systems since 2007. The company, with its market-leading track record in the design, fabrication and installation of pipe-in-pipe (PIP) solutions, is collaborating with ITP on the qualification of the most efficient active heating technology, the “Electrically Heat Traced Flowline” (EHTF). This technology was originally introduced in 2000w, and has undergone tests and improvements since 2009 within the framework of Subsea 7 and ITP cooperation. It is now considered by multiple operators as a qualified solution for field developments. Early on, Subsea 7 recognized the enabling nature of the EHTF technology, due to its distinguishing features:

  • Low footprint on host facilities due to low power requirement (some 100 kW). This is an enabler, in particular for tie-backs to existing facilities;
  • High level of operational flexibility, reliability and redundancy thanks to a multiplicity of heating cables in the cross-section, which allows to face different heating level scenarios: both fluid preservation and permanent heating are envisaged during the operating field life.

This makes it an ideal candidate for tie-backs to existing hosts or even tie-backs to existing subsea well-head templates. The limited modifications to topsides is a boon for space and weight-strapped, possibly ageing, structures, and the low-power heating system allows immediate shut down and start-up from any situation. A distributed temperature profiling provides the means of accurately controlling and predicting system performance and host arrival temperatures. It opens up a whole range of new developments, by improving access to thermally demanding reserves, bringing flexibility and redundancy, and also allowing permanent heating and long tie-backs of up to 30km or more. Key steps of the EHTF qualification programme will be described. It includes the flowline components, the corresponding structures, termination modules and topside facilities.

  • Saad Cherkaoui, Subsea 7
  • Nicolas Raveaud, Assistant Project Manager, ITP InTerPipe

14:50 15:10 (20 mins)

Networking Refreshment Break

15:10 15:50 (40 mins)

Threat Based Approach for Inspection and Repair Solutions to Extend the Life of Damaged Flexible Risers

  • Review of installed base and issued faced
  • Failure modes of flexible pipe payers and detection/inspection methods
  • Monitoring and repair methods
  • Event based life extension re-assessments
  • Gilles Gardner, Technical Manager, 2H Offshore

15:10 15:50 (40 mins)

Effects of Elastic Shakedown and Bulk Corrosion Thinning at Lateral Buckles

Authors: Jens Fernandez and Arek Bedrossian, KW Subsea

It is now generally accepted that when surface laid pipelines buckle laterally, either at engineered triggers or naturally on the seabed, any plasticity induced as a result of the pipe buckling for the first time is not reversed or repeated, at least at the ‘global’ or nominal level, under subsequent shutdown and start-up cycles of equal or lower magnitude. The pipeline is then said to have undergone global elastic shakedown.

The aim of the work presented in this paper was to investigate the methods that could be used to address the issues associated with the effect of global shakedown on local strain concentration regions caused by mismatch effects at a girth weld located on the buckle crown. The work was done using FE models in the context of natural, on-bottom, buckling combined also with general, or bulk, internal corrosion. The effect of cyclic build-up of berms at the buckle crown was also taken into account. The focus of the study was on the cyclic behaviour of the local strain concentration the initial acceptable size of which is determined by limits on the acceptable nominal strain at the buckle crown set in international guidelines, such as DNV OS-F101. Other, smaller, cyclic plasticity regions that may exist locally at the weld toes or caps were not considered by assuming weld cap and root were flush with pipe surface but weld yield overmatch was assumed.

The study was carried out by embedding in the FE models a detailed 3-D solid brick representation of the pipe, girth weld and mismatch on either side of the buckle crown, within a pipe element representation of the pipeline. Appropriate initial checks were carried out to ensure that the hybrid solid-pipe model results were in good agreement with the pipe only model for a test pipeline section with no girth weld but loaded into the plastic regime. The models were then extended to include girth weld, yield and geometric mismatch, and general internal corrosion thinning. The latter was achieved through progressive removal of element layers with pipeline in operating mode and with a number of intervening buckle cycles over the loss of wall thickness given by the corrosion allowance.

The paper focuses equally on the techniques of embedment of 3-D solid continuum elements within pipe element representation, the modelling of geometric and material mismatch at the girth weld, and the gradual removal of element layers from the inner bore of the pipeline, as well as the implications of the results. The results mostly depend on the assumptions made regarding the extent over which the mismatch, for example the yield mismatch, is assumed to prevail in the models. This is illustrated by reference to typical representative examples.

  • Arek Bedrossian, Pipelines Consultancy Manager, KW Subsea

15:10 15:50 (40 mins)

Case Study: Inspecting and Managing Pipeline with Internal Surface Roughness Due to Top of Line Co2 Corrosion

Author: Kai Xin Toh, Quest Integrity Group

Ultrasonic (UT) in-line inspection technology, which uses the propagation of ultrasonic waves to obtain pipe wall measurements, generally has issues with internal surface roughness, which scatters the ultrasonic waves and reduces the quality of the returning echo. This often leads to echo loss, causing a blind spot in the area of internal surface roughness, which can hide severe corrosion detrimental to the integrity of the pipeline.

When an Operator discovered a pinhole leak adjacent to girth weld in their partially-insulated pipeline, they quickly repaired it and commenced a root cause failure analysis. As the previous inspection did not identify metal loss defects in the area, the Operator also needed to re-inspect the line to detect any other potential areas of high risk of aggressive corrosion growth. The pinhole leak was in an area of internal surface roughness, which posed a challenge to UT (Ultrasonic Technology) inspection technologies. Thus, a flow test with a UT vendor was commissioned. However, the vendor failed to collect data at areas of internal surface roughness. Subsequently, the operator approached Quest Integrity to conduct a flow test with the InVista™ UT inspection tool. The InVista™ UT inspection tool successfully collected data throughout the flow loop, and was then used for the full pipeline inspection. The in-line inspection data was subsequently used to conduct a fitness-for-service (FFS) and remaining life assessment for the pipeline.

  • Kai Xin Toh, Pipeline Assessment Engineer, Quest Integrity Group

15:50 16:30 (40 mins)

Identifying the Optimum Pipe-in-Pipe Configuration for Subsea Developments

15:50 16:30 (40 mins)

Monitoring Systems for Deepwater Risers

  • Introduction
  • Purposes and value of monitoring
  • Remote access to data and collection

15:50 16:30 (40 mins)

Pipeline Valve Integrity Management - Technology Innovations

Pipeline integrity and maintenance has increased focus over the years on the importance on the pipeline valves and associated isolation systems. This has been so because of the increased failures of the valves during operation or lack of isolation when required to perform a specific function. Therefore, resulting in costly remedial actions to either maintain the valve criticality, for pigging operations or to carry out repair work on other parts of the pipeline.

The key value proposition and knowledge gained from the presentation will be awareness of safety, integrity of valve operation and opportunities to reduce operating costs

Pipeline Valve Integrity and Maintenance

Current practices for managing integrity of pipeline valves involves the use of performance standards set criteria as the leading factors (i.e. visual, partial, full and leak tests). The use of a best practice method of managing pipeline valves and an understanding of the indicators that are fed back through operators, failures, engineer and other sources could significantly increase the reliability of a valve.

Through the use of operational signals and the already existing processes with a focus on how reporting, data analysis and critical signals operators can prevent failures (therefore reducing lost production) and/or reduce the requirements for maintenance / intervention. A theoretical case study on the impact of lack of adequate valve integrity management will be used.

Cost Effective Innovation – Pipeline Isolation and Improving Valve Seal Integrity

Ball valves are an integral part of Oil & Gas applications that ensure optimized unit operation through leakage free performance. The valve seating arrangement is a key feature that contributes significantly to the sealing capability of a valve. Valves installed in frequent cycling applications suffer the risk of damage to internal components due to constant contact between the sealing surfaces during the opening and closing operation.

The presentation will conclude on highlighting a new technology and process of achieving pipeline isolation which reduces the requirements for the use of plugs (which are extremely expensive) and valve sealant (which damages both the valve and the pipeline internal). The technology is the Hydraulic Assisted Seat, within a JIP initiative championed by IRMS with technical expertise from Flowserve.

This feature enables automatic retraction of the seats caused by hydraulic pressure through activation of the Hydraulic function (manually or automatically from the actuator) ensuring that the valve sealing surfaces are not in contact during valve operation

  • David Obatolu, General Manager , IRM Systems
  • Giuseppe Vignati, Director Engineering, Flowserve

16:30 17:00 (30 mins)

Discussion Forum, Q&A and Summary

An opportunity to ask further questions, share your observations and continue discussions on those issues of interest to you. 

16:45 16:45 (0 mins)

Close of Seminar

18:00 19:00 (60 mins)

Ice-Breaker Drinks Reception

Join us for a glass of wine and take this opportunity to meet and network with fellow attendees ahead of the conference.  All conference and seminar attendees welcome.