The Australian Pipeliner July 2020

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ISSUE 183 | JULY 2020

Taking flight

New jet fuel pipeline for Sydney Airport – page 32

Tremco supplies hot tap equipment

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Vale Michael Lynch

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ERIAS shares PNG experience

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32 COVER STORY

ASME work takes off at Sydney Airport ASME Projects is currently completing vital fuel infrastructure upgrades for Sydney Airport in New South Wales. Cover: ASME workers completing pipeline welding at Sydney Airport. Image courtesy of ASME Projects.

EXECUTIVE REPORT President’s message

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Chief Executive Officer’s report

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VALE Michael Lynch

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POLICY Gas and energy policy

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FFCRC Future Fuels CRC

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TRAINING AS 2885 and APGA’s PECS – why we need them both

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PIPELINES IN PNG A PNG approach to environmental and social approvals

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The shifting goalposts of PNG

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TRENCHLESS TECHNOLOGY A kwik and easy choice for pipeline projects

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Maxibor moves forward with HDD methodology

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Primed for a sea change

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PROJECTS ASME work takes off at Sydney Airport

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Vacuworx helps lift water reliability in NSW

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The Australian Pipeliner | July 2020


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INSPECTION AND MAINTENANCE Savcor Products Australia salvages unpiggable pipelines

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An alternative solution for high-quality data in low-pressure gas pipelines

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New testing system shows off Pipe Tek wares

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Iplex launches easy-to-use product

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WELDING Reducing costs with contemporary technologies

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HYDROGEN Hydrogen: A simple molecule but a complex business

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Jemena paves the way for lower emissions

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TOOLS & MACHINERY Continuous flow verification for heavy-duty processes

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Equipment and service combine for winning formula

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COMPANY NEWS PSSS becomes Australian dealer for SPC Coatings

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ORIX talks instant asset write-offs and small business

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APGA NEWS AND EVENTS APGA’s response to COVID-19

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POG Webinar Series thrives online

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An interview with a twist

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Second edition delivers as promised

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REGULARS Members and memos

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Advertisers’ index

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Features and deadlines

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The Australian Pipeliner | July 2020

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The Australian Pipelines and Gas Association’s (APGA) vision is to lead the sustainable growth in pipeline infrastructure for Australasia’s energy. APGA is a non-profit organisation formed to represent the interests of its members involved in: the ownership, operation, maintenance, design, engineering, supply and construction of pipelines, platforms and all other structures used in or in connection with the drilling for, extraction and transmission of hydrocarbons, solids, slurries and similar substances both onshore and offshore. As a single voice representing the collective interests of its members, APGA is dedicated to encouraging the extension and development of the industry. The Australian Pipeliner is the official journal of the Australian Pipelines and Gas Association (APGA) and is distributed to members without charge and circulated to interested organisations throughout Australia and overseas. It is also available on subscription. The publishers welcome editorial contributions from interested parties. However, neither the publishers nor APGA accept responsibility for the content of these contributions and the views contained therein are not necessarily the views of the publishers or APGA. Neither the publishers nor APGA accept responsibility for any claims made by advertisers. All communications should be directed to the publishers.

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The Australian Pipeliner | July 2020


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EXECUTIVE REPORTS

President’s message

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elcome to the July 2020 edition of The Australian Pipeliner. What a turbulent few months we have had since the last edition. Thankfully, here in Australia, we have made significant progress to curb the spread and impact of COVID-19 to allow recovery to commence. While this is welcome news, there is no doubt the impacts globally will have a significant influence on the length and shape of the recovery. Many of our members’ businesses will have had to make some unplanned decisions and review strategies to deal with the global pandemic. Using my own experiences in our business, the most difficult aspects to understand are: • How long is the economic impact of this going to last? • Where to get solid advice based on historical experience? The reality is the answers to both questions are unclear. Various commentators and views suggest it will last until 2022 and some beyond. As for getting advice and looking to historical events which we can learn from, there are none in modern times – making life harder when trying to make an informed decision. Back in early May, the Federal Government formed the National COVID-19 Coordination Commission (NCCC) and those of you listening to the head of the NCCC, Nev Power, on the ABC News would have been heartened to hear that a strong part of the recovery will be investment in infrastructure to provide affordable energy to give manufacturing the best possible opportunity to succeed and grow. As we have been discussing in APGA, we will continue to be at the fore of this discussion and to highlight the significant part that gas and investment in gas infrastructure will contribute to the recovery. This echoes comments from Energy Minister Angus Taylor who believes Australia should have a “gas-fired recovery”. Andrew Robertson covers some of APGA’s work in this critical area in his policy article later in this edition.

Another impact from the virus was the decision, regrettably, the Board and Secretariat made to postpone until 2021 the face-to-face Annual Convention in Brisbane. This is the flagship event of the association, but with the uncertainty around what limits and restrictions will be in place come October, it was the best long-term decision to postpone and have the 2021 Convention in Brisbane instead. Plans are already under way to deliver a virtual convention and details will be made available when finalised. Finally, COVID-19 means we are not able to show our gratitude and appreciation to Steve Dobbie on his retirement as we would have liked to have done before Steve formally retires. We all know the significant contribution that Steve had within the Secretariat behind the scenes, and we will in time acknowledge this appropriately and I have no doubt many members of the association will want to be part of these events. Since Steve announced his retirement, I have had numerous conversations with members that have reinforced what a huge part of the association Steve has been. First and foremost, everyone sees Steve as a friend, but what has struck me was the time and commitment to members, with which Steve was so generous. On behalf of the Board and all members we cannot thank Steve and his family adequately for dedicating more than 16 years of his life with such passion and commitment to the association. We will deeply miss his willingness to assist and include everyone, and above all his friendship. Please stay safe and let’s look forward to when we can all meet up again and continue the great friendships APGA has facilitated over the years.

APGA Board President Tony O’Sullivan MPC Kinetic Vice President Donna McDowall Quanta Services Australia Treasurer Wendy Oldham SEA Gas Immediate Past President Dave Maloney CNC Project Management Board members Peter Cox Worley Mark Dayman Fyfe Lou Guevara Vacuworx Australia Kevin Lester APA Group Leon Richards McConnell Dowell John Stuart-Robertson HDI Lucas

TONY O’SULLIVAN PRESIDENT

A complete APGA membership list is printed on pages 60 and 61

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The Australian Pipeliner | July 2020


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EXECUTIVE REPORTS

Chief Executive Officer’s report

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elcome to the July edition of The Pipeliner. What a journey we have all been on for the past four months. And we’re still on it, with the COVID-19 crisis dominating our lives, and the lives of everyone around the world, in a way none of us have ever experienced. In Australia and New Zealand, we are so fortunate to have avoided the devastating impacts on our health and communities that we are witnessing in other countries, and this is something to be very grateful for. Despite this, I am keenly aware so many of us are experiencing impacts to our businesses and operations because of the restrictions that have been put in place to ensure we do avoid the worst effects of the crisis. And so, for the first time in its history, the July Pipeliner does not have a preview of the upcoming APGA Annual Convention and Exhibition. As most of you know by now, the APGA Board met at the start of June and made the difficult decision to postpone the 2020 Annual Convention and Exhibition in Brisbane in October. While we are seeing an early easing of the most severe restrictions, there is still a lot of uncertainty regarding larger events. Our original intention was to continue planning for the event and make a final decision closer to the date, but there are two key factors that have led to our making the decision sooner rather than later: 1. We are seeing restrictions start to lift in varying ways around the country but we are also seeing the potential for restrictions to be reinstated. We see signs that conferences are working towards being exempt from this restriction, but it seems likely that, at the very least, social distancing will be with us for some time and that would impact our social events, business sessions and exhibition hall. 2. The social distancing restrictions that are in place vary around the country. We have been talking to venues and stakeholders and we do not see any indication that venues will be allowed to have people standing up and circulating. All plans are for fully seated events. Again, this is not what we see or want for our events. Further, distancing requirements mean tables that would normally seat 10 people will be seating less – five people is the highest we have been told so far.

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These two factors led us to the conclusion that, no matter what actual restrictions we are facing in October, the 2020 Annual Convention and Exhibition would not deliver our partners and participants the great experience we have all come to expect. This is particularly true given we were to be in Brisbane this year, with so much of the pipeline and gas industry’s activities based out of Brisbane now, we had especially high expectations for the experience we could deliver. We know that everyone who participates in the Annual Convention and Exhibition, whether exhibitor, sponsor, presenter or delegate, must put time, money and effort into their participation. We reached the conclusion it is in everyone’s best interest to save those resources this year. What really tipped the decision over was our ability to postpone to Brisbane in 2021. We hope that by then, the ‘gas-fired recovery’ being talked about will be in full swing, combined with a lot of activity in the water sector, and we can have a first-class event at its epicentre. In the meantime, we can put our efforts into delivering a quality virtual event this year, which has great potential to deliver much of the content of the Annual Convention and Exhibition in a way that requires fewer resources from all involved. We are still in the early stages of planning, but we are excited by some of the options we have available. Last issue, you will have seen the interview with certified APGA legend, Steve Dobbie. It is still hard for me to believe we are moving into a post-Steve Dobbie association. I have had the great privilege of having Steve as a colleague for more than half my working life and I have seen and learned first-hand how powerful his values of hard work, service and mateship are in delivering great outcomes for the members of the association. The association can say the same, we have been lucky to have Steve with us for almost 17 years – pretty much three quarters of our operation as a professional organisation. Most recently, I am very glad to have had Steve’s support and advice as we manage the impact of COVID-19 on the association and to share with him the difficult decision to recommend to the Board that we postpone this year’s convention. This is not the absolute goodbye yet, in one last act of service Steve is delaying his retirement to stay with us on a part-time basis The Australian Pipeliner | July 2020

ABN: 29 098 754 324 APGA Secretariat Registered Office: 7 National Circuit, Barton ACT 2600 (PO Box 5416, Kingston ACT 2604) T: +61 2 6273 0577 F: +61 2 6273 0588 E: apga@apga.org.au W: www.apga.org.au Chief Executive Officer Steve Davies Business Manager Steve Dobbie Communications Manager Karen Polglaze National Policy Manager Andrew Robertson Membership Officer Katy Spence Business and Finance Officer Peter Heffernan Administration and Events Officer Charmaine Ogilvie

to help us reduce costs and navigate the delivery of the best possible virtual convention. While Steve won’t be with us in the office again, his values are deeply instilled in the culture of the secretariat and I am sure we will feel his presence with us as we stand on the rock solid foundation he has built for the association as we enter the next chapter for APGA. Steve, you are a great friend to so many of us who have got to know you through the association, and I am sure we will stay in close touch. As you start your own new chapter, I thank you for the leadership and example you have set for me and the service you have provided the association over so many years, and I wish you and Anne all the very best for the years ahead.

STEVE DAVIES CHIEF EXECUTIVE OFFICER


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Michael Lynch

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VALE

Vale Michael Lynch The pipeline community lost a much loved and respected figure in May with the passing of Michael Lynch.

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orn on 14 March 1951 in Sydney, Michael Patrick Sean Lynch spent his childhood in The Rocks neighbourhood before attending St Stanislaus College, a private boarding school in Bathurst. Michael spent much of his early professional career in sales and promotional roles, including stints with Cadbury and Carlton and United Breweries, before he and his wife Lynnette (Lynne) opened a cafe in Windaroo, Queensland in the early 1990s. Michael was then approached by old friend and Heath Consultants Australia Owner Don Teskey to assist with walking the lines on some contracts in Queensland’s Surat Basin, and after some time working in the industry, he and Lynne were presented with the opportunity to buy the business in the mid-90s. Purchasing the business included acquiring Don’s old big yellow fifth wheeler, known around the gas fields as ‘Big Bird’, which Michael and Lynne used as their accommodation base during their first year. Although a working couple in the industry at that time was somewhat unusual, Michael and Lynne found professional success and Heath Consultants Queensland – the only independent leak survey company in the southern hemisphere at the time – was born. More importantly, they discovered early on that they loved the industry, its people and the regions they worked in, making it an easy choice to continue pursuing this line of work.

Larger than life The couple purchased a greyhound coach and made a series of modifications for living,

including adding 30 cm of height for head room, a bathroom, queen size bedroom, a living and dining area, separate office and water tanks, solar panels and a power generator to make the unit self-contained, while a large car tailer built to carry the 4WD used on the lines was also part of the procession. This set up allowed Michael and Lynne to stay close to the pipelines they were working on and significantly reduce travel time each day. Such a large and conspicuous rig drew significant attention, particularly in towns where populations were quite low. One on occasion, their arrival to Cheepie in outback Queensland doubled the town’s population and drew attention of those in the surrounding area who would come every morning to take photographs. Michael and Lynne made many lifelong friends throughout these long seasons of work and, with golf one of the great passions (and frustrations) of Michael’s life, they always made sure to attend the Oil Patch Golf Tournament each year. In 2004, Heath Pipeline Services was born, initially created primarily as an importer with specialised services to offer the industry. The two companies ran as separate entities for a time before merging in 2012 and continuing to be known as Heath Pipeline Services into the present day. This expansion led to the company’s involvement with APGA and the company has been a valued member of the association for many years now. Today, Heath Pipeline Services is run by Michael and Lynne’s daughter Sheril-lee who continues to operate the business on Michael’s mantra of innovation

The Australian Pipeliner | July 2020

and top-quality service, regardless of company size. Affectionately known to friends as ‘Lynchie’, Michael passed away in May after more than a decade battling prostate cancer. Throughout the struggle with the terrible disease, Michael continued to live as he had always done, spending time on his many and varied interests, including fishing, scuba diving, parachuting, sports and a plethora of others. Although COVID-19 has made his family unable to hold a traditional wake, Lynne and Sheril-lee hosted a fireworks display at Michael’s favourite place, the Links Hope Island Golf Club, with friends and family watching from golf buggies in separate vantage points, each with a bottle of whiskey or wine from Michael’s collection. All told, close to 200 buggies were present for the fireworks, and the golf club is now in the process of organising a Lynchie Trophy Day competition. Lynne says Michael was never afraid of a challenge, and in both life and business would always think ahead for the best outcome for all involved. “I am sure if you are in a crowded room and you mention Michael’s name someone will have a story about ‘Lynchie’,” she says. “Michael’s real gift was he made everyone feel important and listened to, he very rarely ever forgot a name and even more rarely found a person he could not communicate or work with.” A larger than life character who lived life to its fullest, Michael will be missed, but always remembered by those who were lucky enough to know him.

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MEMBERS AND MEMOS

Executive appointment at APA APA Group has appointed Julian Peck to the role of Group Executive Strategy and Commercial. Mr Peck will be responsible for delivering all business development and commercial contracting activities, coordination of corporate strategy development and undertaking corporate development and merger and acquisition activities. He will join APA from an investment banking role at Morgan Stanley, having previously advised and supported APA through its

original IPO in 2000. APA CEO and Managing Director Rob Wheals says the company has made a strong appointment. “Julian’s wealth of knowledge and experience makes him the ideal candidate to lead APA’s approach to identify and capture future growth opportunities, as we move into our third decade as a major Australian energy infrastructure business,” he says. Mr Peck will commence his role on or around 1 September 2020.

Chevron to sell NWS stake

APLNG hits milestone cargo

Chevron is putting its stake in Australia’s North West Shelf (NSW) project up for sale. The company’s 16.67 per cent interest in the $34 billion joint venture (JV) could be worth more than $5 billion, with Chevron moving ahead with the sale after receiving what it described as “a number of unsolicited approaches”. NWS is one of the world’s largest oil and gas projects and has shipped more than 5,000 LNG cargoes in the last 30 years, producing gas, oil and condensate from fields in Western Australia’s offshore Carnarvon Basin. Woodside operates the project with support from JV partners BHP, BP, Japan Australia LNG (MIMI), Shell and Chevron, with all six partners holding the same equity stake. While no interested parties have yet been named, Credit Suisse told The Australian potential buyers could include PetroChina, China National Offshore Oil Cooperation (CNOOC) and Woodside.

Australia Pacific LNG (APLNG) has shipped its 500th LNG cargo from Curtis Island in Queensland. APLNG shipped its first cargo in January 2016 and is one of the largest producers of natural gas on Australia’s east coast. A joint venture between ConocoPhillips Australia (37.5 per cent), Origin Energy (37.5 per cent) and Sinopec (25 per cent), the project has shipped LNG to 10 countries in Asia and across the Pacific, while also supplying about 30 per cent of Australia’s east coast gas demand. Origin Energy CEO Frank Calabria says the 500th cargo is a major milestone. “APLNG is a truly world class asset and the result of significant investment and collaboration by partners Origin, ConocoPhillips and Sinopec,” he says. “Reaching this milestone is a fantastic accomplishment, well done to all involved!”

Onshore gas bill passes in Victoria The Victorian State Parliament has passed legislation that will pave the way for onshore gas exploration to resume in the state. The Petroleum Legislation Amendment Bill 2020 passed the Legislative Council yesterday, which will allow the resumption of onshore gas exploration and development activity from 1 July 2021, once a best practice regulatory framework is in place. All new gas will be prioritised for local use and the Victorian Government said its production could generate up to $310 million annually for regional economies. The Victorian Gas Program has been undertaking scientific investigations on onshore gas for the past three years, with a

moratorium on the industry in place during this period. While bans on fracking and CSG remain, investigations led by Victoria’s Lead Scientist Dr Amanda Caples found an onshore conventional gas industry would not compromise the state’s environment. Victorian Minister for Resources Jaclyn Symes said an orderly restart of the industry would deliver jobs and benefits for Victorians. “Securing gas sources isn’t needed just for Victorian homes and businesses – it’s a key ingredient for manufacturing,” she said. “That’s why we’re making sure all new gas projects are prioritised for local use.”

AGIG joins IPLOCA Australian Gas Infrastructure Group (AGIG) is now a Corresponding Member of the International Pipe Line and Offshore Contractors Association (IPLOCA). IPLOCA has members in more than 40 countries around the world and said its mission is to “provide value to members through a forum for retaining and sharing knowledge globally, facilitating business opportunities, and promoting the highest standards in safety, innovation, quality, business ethics and sustainability

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throughout the pipe line construction industry”. AGIG is one of Australia’s largest pipeline operators, with more than 34,000 km of distribution networks around the country and assets including the Dampier to Bunbury Pipeline. IPLOCA’s Corresponding Member list is made up of oil and gas onshore and offshore owners and operators who wish to work with the association and benefit from its technical guidance and briefings.

The Australian Pipeliner | July 2020


MEMBERS AND MEMOS

New COO at Beach Beach Energy has appointed Ian Grant to the role of Chief Operating Officer. Born in Scotland, Mr Grant’s previous credits include being COO of Quadrant Energy and a stint as Santos’ Vice President of Production Operations during a career of more than 25 years in the energy industry. Beach Managing Director and CEO Matt Kay says the company

has gained an experienced operator. “We are thrilled to welcome someone the calibre of Ian to our executive ranks,” he says. “Ian is joining Beach at an exciting time as our company continues its focus on growth, safety and cost discipline.” Mr Grant will relocate from Perth to Beach’s base in Adelaide, commencing with the company on 20 July 2020.

Woodside enlists Civmec for Pluto-Karratha project Civmec has won a supply and fabrication contract for Woodside’s Pluto-Karratha Gas Plant (KGP) Interconnector project. The Interconnector will transport gas from the Pluto LNG facility to the KGP via a 5 km pipeline constructed along the existing Dampier to Bunbury Natural Gas Pipeline corridor. Civmec will carry out the fabrication of structural steel, piping, a module and skids located within the Pluto plant that will be used to support the project.

The company has a pre-existing relationship with Woodside, having previously completed supply and fabrication contracts pertaining to the Pluto LNG and Greater Western Flank 2 projects. Woodside says it expects the piping and module construction will support approximately 40 jobs, with works anticipated to run for around seven months commencing this year. The Interconnector is expected to come online in 2022.

New senior management lineup at CNC CNC Project Management has welcomed four new members to its Senior Management Team: Anthony Trantino, Nikolaas Kostraby, Sjaan Bidwell and Melissa Singleton. New Manager of Operations and Engineering Anthony Trantino brings 20 years’ experience in the pipeline, energy and manufacturing industries. He has worked for national and global organisations, including most recently Jemena where his project management skills, professionalism and personal attributes were highly regarded. Nikolaas Kostraby is CNC’s new Manager Spatial, Data and Digital and brings a wealth of industry knowledge and experience to the role. He is an innovative and driven spatial scientist with a focus on industry trends, who has worked on projects across the country. Mr Kostraby is focused on expanding CNC’s spatial, data and digital

capabilities across the business and the company says he is a great contribution to the team. Sjaan Bidwell is the new Manager Environment and Regulatory. With a PhD in Botany, she has completed more than 100 environmental approval projects and responded to more than 400 planning permit applications throughout her career. CNC says it is excited to have her as part of the team. Melissa Singleton is the new Legal Counsel at CNC. With more than 14 years behind her as a legal practitioner working in both government and private sectors, her experience includes environmental compliance and project permitting for mining and gas projects across multiple Australia jurisdictions, making her a valuable addition to the company’s team.

Interested in submitting an item to Members and Memos? Email The Australian Pipeliner Managing Editor David Convery with your pipeline company news at dconvery@gs-press.com.au

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POLICY

Gas and energy policy by Andrew Robertson, National Policy Manager, APGA

Far reaching changes are occurring in the Australian energy system in both market reforms and long-term initiatives to decarbonise the Australian energy mix. These developments present challenges as well as opportunities for the gas sector, but one thing is clear – gas is here to stay and will continue to play a pivotal role in the Australian economy.

A

point often overlooked in discussions on energy investment and initiatives to decarbonise the energy system is that electricity is not synonymous with energy. In fact, natural gas provides more end-use energy to the Australian economy than electricity, with 943 PJ gas delivered to Australian end-users versus 835 PJ electricity in 2017–18 (Australian Energy Update 2019). This makes gas a critical part of Australia’s energy and manufacturing prosperity mix. A key part of APGA’s focus is ensuring the energy mix is properly understood by policy makers, media and the public. Several positive reports for the role of gas, both in the economic recovery and in reducing long‐term carbon emissions, were issued in May. This includes the report by the National COVID-19 Coordination Commission’s (NCCC’s) Manufacturing Taskforce with a list of proposals to drive increased investment in gas and lower prices in the gas market, and the King Review with its 26 recommendations targeted at supporting an emerging trend of voluntary emissions reductions and maximising coinvestment from the private sector and other levels of government. However, the development with perhaps the most significant long-term implications for the role of gas in the Australian economy was the publication of the Technology Investment Roadmap discussion paper. The Technology

Andrew Robertson.

Investment Roadmap provides a framework for setting economic ‘stretch’ goals that could help establish pathways for the cost-effective deployment of priority technologies. Its key goal is ensuring Australia remains at the forefront of global low emissions technological innovation. Some of the priority technologies identified in the discussion paper include hydrogen (with a stretch goal to produce hydrogen for under $2/kg), carbon capture and sequestration (CCS) and increased deployment of firmed renewables. The paper also lists ‘substantial gas reserves’ as one of Australia’s comparative advantages internationally and identifies natural gas itself as one of several ‘lower emissions’ energy sources. All of this points to a flexible, and essentially technology-neutral approach, allowing any energy source or technology that can contribute to accelerating the development and deployment of low emissions technologies to be considered. The potential for the gas industry to play a key role through the roadmap in Australia’s economic development and the government’s drive to transform the energy industry and reduce greenhouse gas emissions is therefore very high. To look more at some of the specifics, two key areas of opportunity for the gas industry that are enhanced by the Technology Investment Roadmap are: ‘blue’ hydrogen production and distribution; and using gas-fired generation to

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support much greater uptake of wind and solar electricity generation.

Hydrogen One of the most cost-effective ways to produce hydrogen is to produce it from natural gas via steam methane reforming. This can also be done in conjunction with CCS (i.e. ‘blue’ hydrogen production). Natural gas driven ‘blue’ hydrogen could enable zero-emission, large-scale, cost-effective production of hydrogen, all while using Australia’s abundant natural gas reserves. As well as hydrogen production, the gas industry is also well placed to facilitate largescale hydrogen distribution. The cost-effective use of existing gas distribution networks (and potentially also transmission networks) to supply hydrogen on a large scale to end users – either on its own or blended with natural gas – is another way the gas industry can effectively contribute to the long-term decarbonisation of the energy system using pre-existing assets. The economic case for large scale distribution of hydrogen to end users is much harder to make without the potential to use distribution infrastructure that is already in place.

Renewables firming The discussion paper highlights the interesting interplay of gas and renewables in South Australia. In SA, natural gas already supports a

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POLICY

high percentage of intermittent renewables in the electricity mix. It is this role – supporting intermittent renewables in the electricity mix and thereby enabling higher renewable use overall – where gas can make a real contribution to reducing the carbon intensity of the electricity system. In this sense, SA is an example of what the electricity system of the future may look like. It has a much higher percentage of zero carbon wind and solar than other NEM states, supported at regular intervals by plenty of faststart gas, and its carbon intensity is incredibly low due to the absence of coal.

Flexible, technology neutral approach Another aspect of the Technology Investment Roadmap discussion paper that favours use of gas and gas infrastructure to help accelerate the development of low emissions technologies is its pragmatic, technology-neutral approach. In other words, if a technology can contribute to lower emissions then it can be considered in the roadmap on its own merits. With this approach, the relatively low emissions intensity of natural gas and the economic value of domestic, cost‐effective

energy resources can be taken into consideration. This also leaves open the possibility of a graduated approach. For example, hydrogen production from natural gas using steam methane reforming could be used, even without CCS at first, to enable the production and use of hydrogen at scale, opening the door to the development and implementation of many other hydrogen associated technologies and helping get the hydrogen economy moving. The emissions profile of this approach could be reduced still further over the medium-term with the introduction of CCS technology as commercial deployment becomes more cost effective. It could also give way over time to additional ‘green’ hydrogen produced using electrolysers from renewably produced electricity if this technology too becomes more cost effective.

Next steps The discussion paper recognises the role gas can play to drive economic development and decarbonisation. While acknowledging that industry investment is critical to unlocking this potential, APGA is committed to making government recognise the role it plays in ensuring a stable policy environment that

encourages rather than hinders investment. As a case in point, the pipeline regulation RIS currently under consideration by the COAG Energy Council includes a wide range of policy proposals, some of which – if adopted – could lead to heavier regulation and a consequent loss of market flexibility and less favourable investment climate. To reduce the risk of such counter-productive outcomes, APGA is working hard to stress to policy makers the importance of retaining strong incentives for pipeline infrastructure investment and maintaining the flexibility and speed of the commercial investment process. For example, APGA has commissioned economic advice to support and further develop the proposal for a strengthened greenfield exemption from economic regulation for new pipeline developments, which will be shared with government policymakers. The gas industry stands ready to play its part in helping make the goals of the Technology Investment Roadmap discussion paper a reality and bring about win-win outcomes for the industry, the economy and the environment. APGA is working to ensure that government enables us to maximise this potential.

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FFCRC

Future Fuels CRC by David Norman, CEO, Future Fuels Cooperative Research Centre

Public trust plays a vital role in major infrastructure upgrades.

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David Norman.

s Future Fuels CRC carries out its research to enable Australia's energy sector to adapt its infrastructure to net zero emissions fuels, the issues of social acceptance are just as important as the technical and economic ones. In July, we are making public our latest research report, because the role of public trust will be fundamental to this future transition and we must all work hard to raise its profile across the industry. The research report Lessons Learned from Australian Infrastructure Upgrades was authored

by Dr Carol Bond and Dr Angus Veitch at RMIT in Melbourne and looks in detail at past transitions to learn the lessons we will need to successfully deliver future transitions to new fuels. I encourage everyone read this short summary and to learn more about the report available at www.futurefuelscrc.com and share it with your colleagues across the industry. This project is just one of 56 we are now running for the industry and I look forward to sharing more research next month.

Extract from the Lessons Learned from Australian Infrastructure Report by Dr Carol Bond, MIS, PhD, Lecturer in Management and Human Resources Management, RMIT School of Management and Dr Angus Veitch, PhD, Postdoctoral Researcher, RMIT School of Management.

To prepare for future transitions to net zero emission future fuels it is valuable to understand and learn the lessons from previous infrastructure upgrades and fuel transitions in Australia. As part of our research for the Future Fuels CRC we researched three different events, technologies and incentive schemes from the 1960s to 2000s. Across all of them there were similarities and overlaps in the lessons that they contain. First and foremost, the three case studies illustrate the importance of gaining and maintaining the public’s trust in a new industry or fuel. 1960s town gas to natural gas The first case is the towns gas conversion. In the late 1960s, many gas consumers in Australia were presented with a new fuel. Natural gas was not only cheaper but also cleaner and more reliable than the coal gas it replaced. Nonetheless, gas companies The Australian Pipeliner | July 2020

had to invest considerable effort to ensure that customers accepted the so-called “lazy blue flame”. Thanks in part to those efforts, the conversion to natural gas was well-supported by government and industry, thus widely considered successful. 1990s ethanol and LPG as motor fuels The second case is the development of additives for motor fuel. When petrol stations in New South Wales started blending ethanol into petrol in the 1990s to produce a cheaper fuel, motorists were initially happy to use it. Ethanol was only ever competitive with petrol because it was not taxed as heavily. But by the early 2000s, concerns about engine damage and poor governance caused a consumer backlash which no amount of government subsidies, consumption mandates and awareness campaigns was able to fix. The LPG motor fuel

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FFCRC

industry managed to recover from a safety scare in the late 1970s and had a boom in the years around 2005 on the back of generous government subsidies, but the popularity of LPG reduced when subsidies were removed and with the emergence of new diesel and hybrid technologies. 2000s CSG The third case is the rapid expansion of the CSG industry across a broad geographic area. The CSG industry initially began to develop in the 1990s without issue, but grew increasingly controversial from the mid-2000s. Communities were not prepared for the impacts that occurred when a vast network of infrastructure expanded onto highvalue agricultural and rural residential areas. The initial failure of the industry to build productive relationships with landholders and communities contributed to ongoing trust problems and widespread public opposition that ultimately ensued. Drawing on published information, these three case studies provide accounts of the issues that arose during the upgrade or transition and the approaches that industry and government used to manage these issues. Throughout our analysis of these cases, there were some key lessons that emerged which may prove

helpful in avoiding known issues to focus on as Australia transitions to a lower carbon energy sector. The lessons we can learn Public trust The case studies illustrate that earning public trust is not a simple matter of selling a reliable product while minimising social, financial and environmental impacts. Trust has many drivers, and chief among them are perceptions of fairness, integrity and good governance. Australians’ trust in government was much higher in 1969 than it is today, a factor that may have contributed to the successful transition from town gas to natural gas. In contrast, a lack of confidence in both the capability and integrity of government has subsequently contributed to the public’s reluctance to accept ethanol and coal seam gas nationally across Australia. Local context Public reactions to new fuels and infrastructure are highly context dependent. For example, the experiences with gas conversion were markedly different in Sydney compared to Melbourne. Consumers’ responses to ethanol have been different in Queensland compared with NSW, as have the reactions of

rural and urban communities and governments to CSG in Queensland, Victoria, and NSW. Limitations of mandates The ethanol case study illustrates the limitations of mandates as a policy mechanism to increase the production or consumption of a fuel. It also shows that while lower prices can make an alternative fuel more popular, some consumers will pay more to avoid a fuel they do not trust. In contrast, the experience with LPG shows that subsidies and rebates can be hugely successful in driving demand if consumers already trust a fuel. Equally, however, the outcomes of LPG demonstrates what can happen when there are no prospects for a fuel to become competitive without on going subsidisation. Find out more This research is important for everyone in the industry planning a rollout or transition of new technology or practices and has been published in full by the Future Fuels CRC. The case studies and the full report ‘Lessons Learned from Australian Infrastructure Upgrades’ RP2.1-0.1 is available at www.futurefuelscrc.com. A toolkit to implement these lessons within your organisation or project is also available to the participant organisations of the Future Fuels CRC.

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TRAINING

AS 2885 and APGA’s PECS – why we need them both by Chris Harvey, Chair, PECS

APGA has been the key sponsor of AS 2885 Pipelines – Gas and Liquid Petroleum since the first version was released in 1987.

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S 2885 – or as it is commonly referred to in the pipeline industry, ‘the Standard’ – has been the basis for the petroleum pipeline industry ensuring that pipelines are designed, constructed, operated, maintained and properly abandoned so they are safe, reliable and environmentally sustainable. The Standard began in 1987 as a single part covering all aspects of the pipeline lifecycle. In 1995, the Standard was split into two parts with Part 1 covering the majority of matters in relation to pipelines’ lifecycles, while Part 2 focused on pipeline welding. Part 3, covering pipeline operations and maintenance, was released in 1997. In 2002, AS 1978, the pipeline field testing standard, was withdrawn, revised and republished as AS 2885.5. In 2003, Part 4 covering offshore pipelines was created; comprising DNV’s offshore pipeline standard AS F101 plus some uniquely Australian requirements. There are three associated standards for coatings: • AS 1518 – Extruded HDPE coating • AS 3862 – FBE coating • AS 4822 – Field joint coating. In 2007, after a 10-year process of revision, Part 1 (Design and Construction) had major modifications, the centre piece of which was allowing a pressure design factor of 0.8 instead of 0.72. This increase of design factor had required in depth investigation and deliberation for the members of the Standards committees to be satisfied that a higher design factor was safe. As part of this, in the 2007 revisions a formal risk assessment for pipelines was introduced through the SMS process. Since that time, Part 0 has been added, to cover general matters applicable to all parts and provide for better integration of them. In 2018, the Safety Management Process was taken out of Part 1 and given its own part, Part 6. This was because the Safety Management Process is a fundamental part of pipeline safety and applicable at all stages of a pipeline’s lifecycle. It is important to understand that as AS 2885 and its precursors, AS 1697 and CB 28, were

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heavily based on ASME’s B 31.4 (liquids) and B 31.8 (gas). These standards were characterised by rules of thumb, and prescriptive processes, based on what had worked in the past, but did not have a strong theoretical basis. In contrast, as AS 2885 evolved it moved away from this style of standard and became based on the most recent scientific research, much of which came out of research projects led by APIA’s (as it was then) Research and Standards Committee. Those developing the Australian Standard said they were “developing the Australian pipeline standards according to the ‘laws of nature’ rather than the ‘laws of man’ . The resulting content of the Standard set down principles and procedures that relied on the expectation that pipeline engineers with the requisite experience and expertise would be applying the Standard. The resulting Standard became considered as “one of the best, if not the best, petroleum pipeline standard[s] in the world” . In 1995, the Council of Australian Governments (COAG) effectively endorsed the quality of the Standard when it agreed that AS 2885 should be the basis of regulation of petroleum pipelines in all Australian jurisdictions. Each state and territory has, since that time, required that petroleum pipelines be designed, constructed, operated and maintained in accordance with AS 2885 and it is enshrined in their pipelines legislation. In accordance with the philosophy that AS 2885 is to be applied by competent professionals engineers, the Standard identifies that it “provides an authoritative source of important principles and practical guidelines for use by responsible and competent persons or organisations”. It “is not to be regarded as being either an instruction manual for untrained persons or a complete detailed specification”. And that “fundamental” sound engineering principles should be followed when applying the requirements, principles and practical guidelines of the AS(/NZS) 2885 series. A critical concept in the AS 2885 is that of the “competent person or organisation”, who is defined as ‘person’ or organisation having an appropriate combination of knowledge, skills and experience to safely and effectively perform The Australian Pipeliner | July 2020

the task required. A competent person is required to make all the major technical decisions set out in the Standard. Often the major decisions are to be made as part of an approval, and the person who undertakes an approval must be a competent person or be advised by one. This underlines the need to be able to identify who is a competent person and how do we know they are competent. Prior to 2010, when APIA’s Pipeline Engineer Competencies were first published, the only tool that pipeline engineers and their employers had in ascertaining if an engineer was competent for a task or role was to review their resume, interview them and refer to others who had worked with them. The problem is that there was no clear description or prescription of what it meant to be competent for a particular role or task. It would be easy for two people to think that they knew, and yet have quite different criteria. It was in this environment APIA recognised the need for the industry to be able to define and describe the range of competencies that the industry needed. The result has been the development of the Pipeline Engineer Competency System (PECS), first released in part in 2010 and finalised in 2016. The PECS includes 230 onshore and 57 offshore pipeline engineering competency standards that, together with a number of tools and resources that provide significant aid in its application, are able to provide real clarity about what it means for a pipeline engineer to be competent in any aspect of the roles that they can be expected to fulfil and particularly when it comes to identifying a competent person that is required by AS 2885. This means that, together, AS 2885 and the APGA PECS can provide a strong basis for confidence about the safety, reliability and environmental sustainability of petroleum pipelines in Australia – as long as the industry adopts and applies them. AS 2885 has been a crucial part of the pipeline industry since its development in 1987 and APGA members are committed to it; however, take-up and application of the PECS since 2010 has been patchy. It is in this context the APGA Board has established a committee to work with industry to see the APGA PECS as an embedded part of the pipeline technical community. This will provide the full-level assurance that the industry, government and the general public seek. If you are unaware of APGA’s PECS and wish to know more, APGA’s website is a good place to start or you can contact Karen Polglaze, APGA Communications Manager.

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PIPELINES IN PNG

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A PNG approach to environmental and social approvals ERIAS has undertaken environmental and social impact studies in Papua New Guinea for several major gas projects. The company’s vast experience in an undeniably amazing, but also challenging, environment draws parallels to its Australian assignments and has facilitated the exponential growth of ERIAS’ industry-relevant knowledge.

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t the 2017 APGA Convention in Cairns, ERIAS Founding Director Andy Pym presented a paper discussing the challenges and rewards of delivering environmental and social approvals for projects in Papua New Guinea. Now, Mr Pym has further insights to share of his experiences and those of his colleagues, working on major PNG developments including PNG LNG, Papua LNG, Pasca A Gas/Condensate FLNG, P’nyang and more. With ERIAS staff having more than 30 years’ experience working in the challenging environment of PNG, Mr Pym says there are stark contrasts and comparisons drawn to the company’s gas project assignments completed in Australia.

‘Same but different’ PNG is one of the world’s most culturally diverse countries with more than 800 languages spoken by a population of 8 million people. While modernisation has been growing through this unique culture, the diversity remains vital in villages and urban cities with strong bonds to traditional land and customs. Alike to Australia, Mr Pym says it is

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important identification of affected stakeholders is undertaken early to inform the community consultation program. “Despite Social Mapping and Landowner Identification being a mandatory requirement of PNG’s Oil and Gas Act 1998 for proposed gas developments, it is also critical to ensuring that the correct landowners are engaged and compensated, and potential disputes avoided,” he says. “As is the case with our projects in Australia, community engagement follows the usual ‘relationships first’ model where time is spent building trust and respect with the communities. “Having the right personnel, a combination of both PNG and expatriate social performance specialists with an understanding of the complex cultural sensitivities and international standards, is critical to the success of the consultation program, and ultimately the project.”

Offshore development challenges PNG’s marine environment boasts a variety of habitats and a large coastal community who are significantly dependent on the sea and its The Australian Pipeliner | July 2020

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A. Kaevaria village dancers welcome ERIAS’s Papua LNG social studies team. B.

ERIAS’s social team undertake village-based community consultation on Papua LNG.

C. Lined gecko, scientifically titled Gekko vittatus, found on a Papua LNG ecological survey. Photo: S.Richards

major waterways for food provisioning, commercial trade and transportation. PNG’s onshore oil and gas reserves are wellknown, but the country is yet to commercialise an offshore field. As the environmental assessment and approvals consultant for Twinza Oil’s Pasca A Gas/Condensate FLNG project, Mr Pym says ERIAS recognised that PNG regulators were understandably cautious and required assurances considering they had not previously been exposed to offshore developments. “Drawing on our experience of permitting a number of offshore oil and gas developments in Australia, the ERIAS team developed a strategy of engagement with various government agencies that involved technical briefings and included representatives of regulatory agencies on the survey vessels during the marine studies conducted by ERIAS’ marine scientists,” Mr Pym says.


PIPELINES IN PNG

New species need new studies PNG is reported to be among the countries with the highest biodiversity, exceeding that of the rainforests of the Amazon, Bornea and the Congo. Mr Pym says during virtually every ecological study – undertaken to support resource development project approvals – discoveries of species new to science take place. “The ecological studies conducted for PNG LNG, Pasca A Gas/Condensate FLNG and Papua LNG all reported previously unrecorded and yet to be named plants and animals,” says Mr Pym, which is attributed to PNG’s biodiversity remaining poorly studied. “Many PNG resource projects are developed within the context of the IFC Performance Standards, particularly where there is foreign investment, which, in concert with PNG’s environment, heritage and industry legislation, govern the scope and execution of baseline studies.” To complete a resource development ecological study – whether to meet PNG legislation or IFC Performance Standards – investigations by competent specialists must take place. Coupled with remote and difficult terrain, a tropical climate and health and safety risks, the logistics for such studies require

military precision remote communications and dedicated security, and medics. Mr Pym says a saying in PNG is ‘the forest always wins’, referring to the innate capacity of the rainforest to regenerate and eventually reclaim the landscape. While somewhat true, Mr Pym says this overlooks the fact that natural regeneration’s success depends on specific conditions and in the absence of managing other influencing factors, rehabilitation success is relying more on good luck than good management. “ERIAS’ experience in developing and implementing rehabilitation plans for exploration drilling and pipelines, as well as oil and gas field and production facility decommissioning has reinforced the concept that cost-effective rehabilitation starts with good planning well before development commences,” says Mr Pym. “ERIAS undertakes assignments throughout Asia Pacific, and importantly seeks to ensure that we execute our work programs such that they deliver real benefits to communities, both locally and at a state and national level. “Seeing the outcome of our investment in capacity building for both government and local communities, and for our team of environmental and social professionals in PNG, is extremely satisfying.”

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PIPELINES IN PNG

The shifting goalposts of PNG It’s been a turbulent year for oil and gas around the globe, thanks in no small part to a global pandemic and international disagreements that bottomed out the oil price. But, in Papua New Guinea, the winds of change have been blowing for longer than just 2020, and while energy projects figure to remain a major fixture in the country’s economy, just who reaps the greatest rewards continues to be a sticking point.

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n June 2020, after just over 12 months in the country’s top job, Papua New Guinea Prime Minister James Marape tabled significant changes to PNG’s oil and gas legislation. Mr Marape came to power in May 2019 following the political fallout from a controversial loan taken by the PNG Government to buy a 10 per cent stake in Oil Search. Once the dust settled, Peter O’Neill had been removed from his role as Prime Minister and Mr Marape had signalled his intentions to renegotiate agreements with major LNG projects and acquire more favourable terms for the country. On its list of renegotiations was the Papua LNG Gas Agreement, a deal that had been originally agreed to in April 2019. Papua LNG and the P’nyang development, operated by Total SA and ExxonMobil respectively, are part of a US$13 billion AU($18.95 billion) plan to double PNG’s LNG exports through three new LNG processing trains at the Exxon-operated PNG LNG plant. The plan is for the projects to share infrastructure and save billions on construction costs. Although the government eventually validated the Papua LNG Gas Agreement in September 2019, a deal on P’nyang has not been so forthcoming for the stakeholders involved, such as Oil Search and Santos, raising questions about the entire endeavour.

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Adobe Stock © ead72


PIPELINES IN PNG

In late January 2020, Mr Marape called off negotiations with Exxon over P’nyang, saying the country refused to give away the same concessions it had for the PNG LNG and Papua LNG projects. He says the gas belongs to PNG’s people and he is “willing to allow international oil companies to develop the field and achieve decent returns by exporting most of the gas, but PNG must also benefit”. After no movement on negotiations for months, Mr Marape indicated in early June the government would soon be sending Exxon its “final position” and says talks between Exxon, Oil Search and PNG’s negotiating team were headed in the right direction. Mr Marape says the new Oil and Gas (Amendment) Bill 2020 now seeks to amend the Oil and Gas Act 1998 and put national interest at the forefront of the country’s laws, rather than the commercial interests of foreign parties. “This necessarily means taking control of exploration activities through to development,” says Mr Marape.

“Unless positive changes are made without destroying the industry, PNG’s total share of project revenue will continue being lower than most producing countries.”

A new development Outside of the major Exxon- and Total-operated projects, Twinza is making serious inroads in the development of its Pasca A gas-condensate field in the Gulf of Papua. In May 2020, Mr Marape and the National Executive Council endorsed the submission for development of the field, setting the stage for negotiations on a Gas Agreement in the near future. Twinza believes the Pasca A field will become a “critical piece of infrastructure” in the Gulf of Papua and would be the first offshore development for PNG. The company said the project has the potential to produce approximately 200,000 t/a of LPG with the current design for gas export from the field using floating LNG technology.

Twinza CEO Ian Munro says the company and the PNG Department of Petroleum and Energy was on the verge of creating a new wave of offshore exploration drilling. “The planned development will not only provide significant investment and jobs for PNG but also a source of LPG for the local market,” says Mr Munro. “PNG has developed a strong reputation as a reliable supplier of LNG into the premium North East Asian market. We look forward to building upon this through the production and export of Pasca A gas and being ‘open for business’ to facilitate the development of third party fields via Pasca infrastructure.” Assuming a successful negotiation, Twinza anticipates Pasca A will enter the front-end engineering and design phase later in 2020. The PNG Government has the right to back-in and acquire up to a 22.5 per cent working interest in the project by paying back costs and forward costs.

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TRENCHLESS TECHNOLOGY

Pezzimenti Trenchless used kwik-ZIP spacers on its Holden Reservoir Inlet Pipeline Project.

A kwik and easy choice for pipeline projects Pezzimenti Trenchless used kwik-ZIP spacers to facilitate the sliplining of a water main for the Holden Reservoir Inlet Pipeline in Melbourne.

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sed for many years by Pezzimenti Trenchless, kwik-ZIP’s large range of spacers cater for many inner diameter and outer diameter combinations while providing the flexibility to deal with project alterations. On a recent project, namely the Holden Reservoir Inlet Pipeline – Melton Highway Crossing for Western Water, kwik-ZIP’s HDX-90 spacers, which are 90 mm high, were installed to assist the 813 mm cement lined steel water main into a steel encasing pipe. The steel casing of the pipe was DN 1050 while the carrier size was a DN 800 MSCL water main. The HDX’s unique load sharing design maximises the load bearing capacity of each runner and reduces point loading. The simple

and efficient installation process does not require any special tools, allowing Pezzimenti Trenchless to promptly complete the installation of the spacers. kwik-ZIP spaces have no metal parts and are made from the company’s engineering thermoplastic blend that is flexible, extremely tough and has a low co-efficient of friction. Pezzimenti Trenchless Managing Director Joe Pezzimenti says the company has been using kwik-ZIP spacers for sliplining installations for many years. “Whether the carrier pipe is plastic, GRP or heavy weight steel, kwik-ZIP has a spacer to do the job,” he says. “Their technical support and excellent customer service make using kwik-ZIP spacers an easy decision.”

About kwik-ZIP kwik-ZIP manufactures and supplies centralisers and spacer systems for many industry sectors including production well drilling, trenchless pipeline, horizontal directional drilling and the general civil and construction markets. Developed to solve support, grading and centralisation challenges in the trenchless and pipeline, vertical production drilling and ground engineering industries, kwik-ZIP products are used by pipeline and civil contractors, water and gas utilities, drilling companies and engineering firms across the globe. kwik-ZIP spacers are the only Australian-owned spacer on the market and provide clients with a cost efficient and simple solution to their spacer and centraliser requirements.

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The Australian Pipeliner | July 2020


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TRENCHLESS TECHNOLOGY

Maxibor moves forward with HDD methodology Maxibor is using its experienced HDD design engineering capabilities alongside asset owners, engineering design firms and T1 contractors to help provide intelligent and creative solutions to complex pipeline project challenges.

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here is an increasing appreciation in the infrastructure and mining sectors that horizontal directional drilling (HDD) can provide intelligent and creative solutions to complex problems faced by asset owners. Intelligent HDD design solutions offer significant project and whole of life asset benefits, while helping preserve the local environment and cultural heritage. HDD solutions have relevance across many sectors including water and sewer, gas and oil, power, telecommunications, rail, mining and renewables. It is also becoming an important climate change adaptation action to mitigate the impact of fire, wind, flood, inundation and drought. HDD Engineering Director of Special Projects Stephen Loneragan – who has records for the design and delivery of some of the longest underground pipelines in the world – says Australia is poised to take greater advantage of HDD as a solution to many challenges associated with pipeline projects. “It is just a matter of getting the right minds together at the right stages of a project so that the full range of solutions can be considered, including HDD,” says Mr Loneragan. “The disciplined design and drilling methodology development approach used by Maxibor and its cooperative knowledge sharing attitude is something asset owners and design engineer consultancies are being very receptive to. “First principles, foundation-based engineering is key to delivering longer, larger and more complex projects. It is about using the combined knowledge to get a better outcome for all the project stakeholders.” In the context of Maxibor, the foundation for the success of this approach is a combination of experience in engineering design and the delivery of complex and challenging pipeline projects installed by HDD. Bringing this knowledge together in a cooperative manner is the best way to optimise value for all stakeholders on a project.

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Maxibor’s methodology Maxibor applies a procedure for each project that adapts accepted practices and then focuses on specifically solving the project issues through engineered design. “Maxibor’s HDD design and methodology development processes are highly iterative for the more complex bores,” says Mr Loneragan. “Each step in the design process feeds back to the previous parameters which causes an evolution in the design to get to a point that provides a pipeline installation solution which considers safety in design, constructability through engineering application and ultimately usable infrastructure.” Mr Loneragan says Maxibor’s approach is developed within an integrated discipline framework, with the design and methodology development processes requiring a wide range of engineering, HDD operations and commercial knowledge to achieve successful installation. The key steps in Maxibor’s integrated discipline framework include: • Pre-planning – project objectives. • Build of initial bore plan – design profile, preliminary hole, casing design. • Torque, drag and hydraulics – friction factor analysis, maximum loads, maximum torque, pipe buckling. • Rig and equipment specification – rigs, pipes, pumps, cleaning systems. • Case wearing – will profile cause excessive wear? • Bore hole trajectory – objectives to minimise tortuosity, target size, ellipse or collision analysis, survey and program design, target, anti-collision. • Bore hole stability – fracture gradient analysis, collapse, rock mechanics, clay inhibition, swab and surge pressures, geotechnical investigation. • Product pipe design – formation type, collapse pressures, tensile loading, floatation devices, safety factors, rig limitations, pipe wall force, coating type selection. • Bore hole assembly design – drilling

tendency, bending stress state, hole size evaluation, torque reduction tools, vibration, tooling layouts, bore hole assembly (BHA) analysis, stabiliser placement. • Fluids and hydraulics – hole cleaning, density, rheology, flow rate and regime, maximum rate of penetration (ROP), pullback capacity, back reaming, fracture gradients, drag monitoring, drill pipe rotation speeds, BHA design, bit selection, cuttings volume, fluid volume displacement, lubricity, inhibition. • Torque and drag – friction factors, sliding limits, pick up and slack off, buckling analysis, casing wall force, fatigue endurance, yield stress, tension, rig limits. Risk and opportunity – operational risks, corporate risks, opportunities, risk sharing. The extent of factors to consider highlights the range of knowledge required to achieve an optimised fit for purpose design and a drilling methodology. In the development of this approach, Maxibor has been able to draw upon its extensive experience of installing complex pipeline projects and its network of industry specialists, which have further facilitated the build of its internal knowledge bank. This pool of knowledge can be applied to each project and provide significant confidence to clients that using HDD will be successful.

Achieving desired outcomes for clients Maxibor frequently puts forward alternative design solutions to clients to help achieve better outcomes and has applied its integrated design and drilling methodology development process to more complex projects, demonstrating the benefits of the disciplined and cooperative approach. Maxibor National Business Development Manager David Turner says by investing Maxibor’s expertise and resources to undertake additional work in the bidding stages, clients are able to complete an achievable project. An early design initiative of Maxibor on a recently completed project in Logan, Queensland was to combine two shorter bores into a 1.32 km bore, which reduced the cost to the client, provided whole of life operational economies and reduced the impact on the local vegetation and noise and dust to nearby residents. This outcome was achieved through a complete understanding of the project objectives before commencement of the detailed design and drilling methodology

Background image: Maxibor used its Vermeer 330x500 maxi rig on a 1.32 km 500 mm HDD bore for Logan City Council.


TRENCHLESS TECHNOLOGY

development activities. Mr Turner says good communication with the client and other key stakeholders is essential to ensure all HDD activity on a project is aligned with the objectives and needs of other parties. “Our clients are increasingly appreciating the extent of our knowledge and our willingness to cooperatively share that knowledge to help achieve better outcomes,” says Mr Turner. Other examples of where the use of HDD solutions could be better utilised include hilly and undulating terrain, environmentally sensitive areas, mine and tailing dam dewatering, high bushfire prone areas and cultural heritage sites. Maxibor says, generally, HDD can be considered an “obstacle avoidance technology”.

The risks of complex projects One of the major risks on the more complex HDD projects is ‘frac out’. Maxibor’s engineering design process considers fracture gradient modelling as a way of predicting the annular drilling fluid pressure compared to the ability of the formation to resist a crack or fracture forming from the annular drilling fluid pressure. There are several factors that influence this

calculation, including bore hole diameter; borehole depth of cover; drill pipe diameter; drilling fluid composition; drilling fluid flow rates; formation cohesion and plasticity; and formation ground water. Maxibor says there are two principal models that are generally applied in the HDD industry to evaluate the fracture point – the overburden density model and the DELFT model. While both models each have their place, it is important the mechanics of these complex models are fully understood since it is not a matter of simply plugging in numbers. Maxibor sees many examples where the input values into the models is done with little understanding of the mechanics of the models or how it applies to real world drilling. It has also seen many examples of “plugging numbers” to show a desired curve on a chart. At Maxibor, this is considered an unwise approach as clients and contractors are ultimately not provided with great outcomes.

Instead, Maxibor says it believes in a cooperative approach at the design stage of a project that can help impart its collective knowledge of how to mitigate HDD project risks such as frac out and get a design that will be able to be delivered. Maxibor has also compiled a comprehensive risk analysis for HDD operations that provides a point of reference to consider the risks associated with each project and identifies good practice actions that can be taken to mitigate those risks. The risk analysis is relatable to the design and drilling methodology as well as broader operational areas around labour, plant, materials and HSEQ and corporate risks and opportunities. This process makes both Maxibor and the client much more informed about the project. As a knowledge sharing business, Maxibor says it is more than happy to discuss at an early stage in a project how HDD can provide a delivery solution.

For more information contact David Turner on 0499 375 511 or visit www.maxibor.com.au

02 4966 5583 www.maxibor.com.au admin@maxibor.com.au Follow us on LinkedIn, Facebook & Twitter

» Quality and collaborative HDD design and construct services » Expertise to advise at the right time in the project delivery cycle » Gas, water and sewer, rail, road, power, telecommunications, mining, residential development and renewables » Maxi-rigs capable of long and wide diameter bores in hard rock and difficult conditions » Build a future we all look forward to.

AUSTRALIA’S LEADING HDD SPECIALIST Maxibor is using its network of experience to deliver better project outcomes to asset owners and principal contractors alike

The Australian Pipeliner | July 2020

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Primed for a sea change A potable water pipeline at Rio Tinto’s seaport facility in the Pilbara region at Cape Lambert, Western Australia, recently needed rehabilitation. To complete the challenging project, the company called on the unique and reliable Primus Line® restoration system.

Rio Tinto called in Primus Line to help rehabilitate a challenging pipeline at its iron ore seaport facility.

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Primus Line’s certified installation partner Interflow installed the flexible system in only four days.


TRENCHLESS TECHNOLOGY

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io Tinto’s port is located approximately 1,600 km north of Perth and is one of the few seaports for exporting iron ore with an annual capacity to handle 80 million t. Requiring rehabilitation was an existing HDPE DN 200 potable water pipeline, which runs along and under one of the main roads into the port. Due to its location, a dig-and-replace option was not viable as the port facility operates 24/7 and a part of the pipeline passes through areas of cultural heritage sensitivity where digging is not permitted. To counteract this problem, 1,500 m of Primus Line® DN 150 was installed instead with the lining completed in three sections. Thanks to Primus Line’s certified installation partner Interflow, the installation took only four days to complete.

A flexible yet secure option Consisting of a flexible Kevlar® reinforced liner and specifically developed end fittings, Primus Line is a flexible sliplining solution for the trenchless rehabilitation of pressure pipes. The system is self-supporting and is therefore not bonded to the host pipe, allowing an annulus to remain between the system and the host pipe.

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About Primus Line The Primus Line system has grown from a simple idea to a global asset. After intensive development work, Rädlinger primus line GmbH was founded in 2001 as a part of the Werner Rädlinger Group. Over the past two decades, the company has taken its unique system for the no-dig rehabilitation of pressure lines around the world, offering the flexible relining system and its application to many contractors and their projects. Today, the trenchless technology manufacturer has headquarters in Germany, subsidiaries in the US and Australia, and international employees working on the development, production and sales of the popular product. For more information visit www.primusline.com

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Additionally, the Primus Line system guarantees a loss-free and secure conveyance of sensitive resources such as water, with the composite pipe protecting the old pipe from the inside from abrasive particles in the water and against corrosion. Primus Line says its system is developed by experienced engineers and is suitable for various application needs, already proving itself in numerous projects in more than 40 countries worldwide. As a particularly reliable and secure system, Primus Line also satisfies the most demanding specifications relating to hygiene. The system already possesses corresponding certifications in the US, Poland, Germany, Austria, Russia, Norway, Belarus, Canada, Ukraine, Australia, Lithuania and Israel. To maximise sustainability, Primus Line uses the existing infrastructure, protects nature and the environment due to its minimal impact, requiring only a low level of machine deployment. In the development of the trenchless technology, sustainable and ecologically-minded thinking was paramount, and continues to feature at the forefront of its business principles.

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DESTINATION PIT HOST PIPE

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HOST PIPE

Trenchless rehabilitation of oil and petroleum pressure pipes • Cost savings of up to 40% compared to

other trenchless technologies Installation speeds of up to 10 metres per minute ts rojec Up to 2,500 metres per pull 20 p alled n a h t s et Small pits, minor installation footprint Mor ssfully in e Maximum capacity succ tralia! s (low wall thickness of 6 mm for PN 16) in Au • Withstands thermal expansion of the host pipe and seismic movement

• • • •

Liner: Media-specific based on TPU

Aramid Reinforcement: Seamless aramid fibre (one- or two-layer) fabric

Cover: Abrasion-resistant PE sheath

Raedlinger Primus Line Pty Ltd Mr Heiko Manzke Level 6, 8 Spring Street Sydney, NSW 2000 · Australia

Phone: 07 318 15721 heiko.manzke@primusline.com

www.primusline.com The Australian Pipeliner | July 2020

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A

ASME's crane and rigging crew in action at Sydney Airport.

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B A. ASME crew hydro testing pipeline at Sydney Airport. B.

One of the valve pits at the Sydney Airport site.


PROJECTS

ASME work takes off at Sydney Airport ASME Projects is currently completing vital fuel infrastructure upgrades for Sydney Airport in New South Wales. Although COVID-19 has temporarily put a hold on one of the two contracted projects, ASME is progressing the remaining works on schedule using its extensive experience and cutting-edge engineering systems.

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ydney Airport has been working to upgrade multiple bays at its facility in order to service larger numbers of aircrafts for arrival and departure. This process includes an upgraded refuelling capability, aircraft ground power and preconditioned air, while the structures are to be extended and additional room provided for ground services equipment. To facilitate the refuelling upgrades at the Northern Pond apron Bays 83, 84 and 85, ASME Projects has been enlisted to extend a 450NB fuel feed feedline from its existing termination point at Terminal 1 Bay 1 to a new junction pit at Bay 83. For the installation of this new pipeline, a DN 900 concrete tunnel is to be constructed running 523 m underneath the runway strip, the Bay 83 apron and the taxi lane. The on-apron fuel infrastructure upgrade also includes a 300NB fuel header line and fuel hydrant infrastructure. Originally scheduled to run concurrently with these works, ASME has also been contracted by Fulton Hogan for the fabrication and installation of jet fuel infrastructure at a separate Sydney Airport location; however, this project has been impacted by COVID-19 and is now expected to resume in 2021. ASME Projects Manager George Allen says the now-shelved project was left at about 40 per cent fabricated and was nearly at the trenching stage, while works were continuing at a good pace on the Bay 83-85 project. “We started in February and we hope to be closed out [on the first project] by the end of October,” he says. “All the apron works, and the 300 mm trunkline through the apron, has been installed and backfilled with a few different layers of concrete. We are about to put the hydrant pits in over the next 3-4 weeks and then we can close that whole apron out.” Mr Allen says the remaining works will include the assembly of another valve pit, with a 72 t pre-cast valve pit currently being fabricated by Mascot Engineering in Newcastle, which was expected on site in about September where it would be lifted into position by crane. “Then we assemble the valve pit down that

Welding the 450NB microtunnel pipeline.

end of the line and do a live tie-in to the existing jet fuel system,” he says. Mr Allen says the biggest challenge at present on the project has been the airport’s close proximity to the ocean and surrounding rivers, resulting in much of the trenching works taking place below the water line; however, despite the battling the elements at times, the team was more than capable of delivering the scope of works. “The systems in place are bulletproof and we’ve got good inspection, HSE and engineering teams. Our site supervision team is excellent and the design was probably 95 per cent complete when we started. “We are still finalising a couple of little points, mainly around design of valve pits, but they are not really hinderances, we've got a little bit of time to plan and get those over the line.” Other companies assisting with the project include Ward Civil and Engineering, Rike

Electrical and Sonix NDT with ASME saying there are 19–26 workers onsite at any one time. “The work that’s going on at the Sydney Airport upgrade is pretty cutting edge,” says Mr Allen. “We’re sitting at about 50 per cent complete on the project, but from here on it gets lighter with the work scope. We’ve still got about 340 m of microtunnel to install and we’ve set up launch frames and winches which has saved us a bit of time. “When that’s finished, we have to go through and pressure grout the microtunnel, and then we look at a final pressure test and soak test of the system.” ASME has more than 20 years of experience in oil, gas, energy and mining operations, offering design, construction, maintenance and site management services, along with the fabrication and installation of industrial piping systems, vessels and structural supports.

For more information visit www.asmeprojects.com.au The Australian Pipeliner | July 2020

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PROJECTS

Vacuworx helps lift water reliability in NSW The construction of the new St Helena pipeline project in northern New South Wales is benefiting from the safety and efficiency the Vacuworx RC series provides.

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he St Helena pipeline project will see the construction of a 13,200 m pipeline delivered in two stages: Stage 1 running from Dorroughby to the Clunes Cross Connection, and Stage 2 continuing from the Clunes Cross Connection to Friday Hut Road. The $36 million pipeline will help ensure continued water supply for customers in the area and, in response to an increased demand for bulk water supply in coastal regions, Ross County Council begun Stage 1 construction in May 2020.

Improving safety and efficiency The Stage 1 construction contract was awarded to Ledonne Constructions in February 2020 and they have now commenced work. As part of the project, the existing 300 mm diameter pipeline, which has reached the end of its service life, will be replaced with a new 660 mm diameter watermain. In an effort to improve safety and efficiency, Ledonne Constructions are using two Vacuworx RC 20 lifters to assist with loading and unloading the trucks transporting the pipes to the site from the holding yard, as well as to lay the pipe in the ground. Ledonne Construction Manager Shaun Zimmerman is no stranger to vacuum lifting and the advantages gained from using them on a job site. “We’re glad to be working with Vacuworx again!” says Mr Zimmerman. “You can’t beat them when it comes to safety and efficiency. Basically, it becomes a one-man operation. You eliminate the need for three or four workers to have their hands at risk of being crushed or injured from putting slings under and around pipes.” “We’re using one lifter to load and transport the pipes from the yard and one lifter onsite to unload and transport the pipes up and down some very steep terrain. Without the vacuum lifters it would become a safety nightmare in this environment.” The RC series is designed to handle materials from 10 to 25 t in conjunction with largercapacity host carriers and are perfect for large scale infrastructure projects such as this. Vacuum lifting provides a safer methodology for moving pipe, eliminating the risk of injury to workers

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From left: Ashley Chen (Vacuworx), Malcolm Collins (Vacuworx), Shaun Zimmerman (Ledonne Constructions).

Stage 1 of the St Helena pipeline works.

while increasing overall efficiency. “We can have a truck loaded within half an hour with the RC 20, where it would normally take around three hours plus additional workers without a Vacuworx lifter,” says Mr Zimmerman. Vacuworx Australia manufactures, sells, leases, rents and services vacuum lifting systems for the energy, construction, infrastructure and utility

industries. Its vacuum lifting systems handle all forms of pipe, plate and slabs including steel, plastic, concrete and cast-iron pipe, steel plate, steel piling, pre-cast slabs and concrete road barriers. Lifters can be attached to excavators, wheel or track loaders, cranes, pipelayers and forklifts, and can be customised to accommodate a variety of applications and lifting needs.

For information email australia@vacuworx.com or visit www.vacuworx.com The Australian Pipeliner | July 2020


INSPECTION AND MAINTENANCE

Savcor Products Australia salvages unpiggable pipelines The definition of an unpiggable pipeline is somewhat of a moving target in the pigging industry. Because of new technologies, stronger or alternative materials and the growing cumulative knowledge of the industry, many lines that are or were once considered unpiggable are in fact piggable in at least some way, and Savcor Products Australia has experienced this firsthand.

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ome of the most common reasons a pipeline might be considered unpiggable include the bend radius or curves being too sharp, meaning pigs cannot navigate the tight turns; improver valves being used that obstruct the line; pipeline diameter changing; temperatures outside the range of standard pigs; incompatible chemicals that destroy traditional pigs; and many more. However, thanks to modern pigs and the use of line modifications – which can sometimes be temporary in nature – many of these issues can now be addressed and overcome. Incompatible valves can be temporarily removed and replaced by spool pieces if a pig manufacturer determines there is no viable pig design that can pass through a particular valve. Reduced or enlarged internal diameters (ID) at valves are often not a problem for foam pigs as they can easily compress at least 25 per cent – or even more under extreme duress – and they can be modified to span gaps in valves larger than the mainline pipe ID. It is also due to this flexibility that foam models can effectively clean pipelines with reasonable diameter changes. One line size difference, such as 10–8 inch (254–203 mm) is easily accomplished by most models and without much extra consideration. Larger jumps are possible, such as 30–24 inch (762–609 mm) with specially modified full-bodied pigs, but pressure and volume limitations of the line or equipment may be an issue.

One of Savcor Products Australia's pigging products after completing a water flush pig run.

Savcor Products Australia offers modern pigging solutions that can address and overcome challenges on pipelines deemed “unpiggable”.

A variety of materials

strong enough to move the material in front of the pig. At a certain point, resistance to forward motion becomes more than the pig and hydraulics of the operation can overcome, which is especially a problem in smaller and longer lines. “However, with careful consideration, a proper pig selection and a progressive pigging plan, debris can be removed slowly, little by little, avoiding plugs and reducing the differential pressure needed to move the pig,” says Savcor Products Australia.

Polyurethane has long been the standard material for most pigs since at least the 1950s due to its flexibility and durability, but today cups and discs are also available in alternative materials such as ethylene propylene diene monomer, viton, silicone and others. Increased temperature resistance and a different set of chemical compatibility options are also available in cups and discs, with all these options on offer at Savcor Products Australia. However, often lines are still not cleaned until they are well overdue. Sometimes these lines can be mostly obstructed by deposits or debris and removal of all the debris is often impossible as the pumping pressure behind the pig must be

For more information visit www.savcorproducts.com.au

Products for the Pipeline Industry www.savcorproducts.com.au Call: 1800 SAVCOR

Cathodic Protection Materials:

Pipeline Fittings & Equipment:

Cortec VpCI Preservation Materials

Surge Protectors

Sacrificial anodes (Zn, Mg, Al)

Borin Permanent & Portable electrodes

Corrosometer resistance probes

Loresco Coke Backfill

Gypsum bentonite backfill

APS Flange Insulation Kits

Dehn & Sohne IEC Certified Spark Gap Arresters

Radolid Nuts Protectors

Pipeline pigs and equipment including: Foam, Poly Coated & Wire Brush Pigs Monolithic Insulating Joints Hot Tapping Equipment

Wachs Pipe Cutting and Beveling Pipe Seals, Pipe Clamps, Leak Repair APS Casing Spacers Impressed Current & Sacrificial Anodes

Trusted Supplier of Cathodic Protection & Prevention materials in Australia. Melbourne

T: 03 9764 2651 E: melbourne@savcor.com.au

Sydney

T: 02 9807 4542 E: sydney@savcor.com.au

Brisbane

T: 07 5549 2248 E: brisbane@savcor.com.au

The Australian Pipeliner | July 2020

Perth

T: 08 6240 3900 E: perth@savcor.com.au

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INSPECTION AND MAINTENANCE

An alternative solution for high-quality data in low-pressure gas pipelines Pipelines come in all shapes and sizes, but they can also display a variety of operating conditions. One not-so-popular operating condition is low pressure, meaning a gas pipeline operates at pressures l ower than “normal” and often does not allow for standard ILI, so a solution must be found.

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here are a few golden rules when addressing challenging pipelines, including: 1. What goes in must come out 2. The inline inspection (ILI) must be worth it. ‘Worth it’ is not only meant from a high-quality data collection standpoint, which of course is arguably the sole purpose of an inspection, but also at a cost that makes sense – demonstrating how creating a solution for a low-pressure gas pipelines must take into consideration many factors. In 2019, the ROSEN Group was challenged to create one of these unique solutions. The goal was to complete a full internal and external metal loss inspection of a 16 inch (406 mm), 17 km onshore gas pipeline; however, this unique asset posed its challenges, one being the low operating pressure of 3 bar, while a “normal” standard for operating pressure is between 30 and 35 bar. Additionally, temporary launcher and receiver traps were required, as none were present.

The solution When creating an inspection solution for any pipeline, it is always best to make sure the full picture is understood, meaning solution experts collect all data available on the pipeline before making a suggestion. In this case, things to be considered were propulsion methodology, such as how the tool would best move through the pipeline at speeds to guarantee high-quality data collection, technology choice and subsequent tool modification. In this case, ROSEN experts chose nitrogen as the propulsion element. The conventional way of using nitrogen as a propellant is to use a nitrogen-pumping spread. This method requires a huge amount of nitrogen liquid, which then needs to be converted to gas; the gas, in turn, is then used to create the pressure needed for tool propulsion. This is a massive expense, which is why ROSEN experts initiated a feasibility study for using a so-called nitrogen membrane instead.

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Tool selection guideline for low pressure gas pipelines.

This membrane is a generating unit that can separate oxygen from air and produce a continuous supply of N2 gas, ensuring a dependable supply of nitrogen without needing to rely on liquid nitrogen, therefore cutting operational cost significantly. With the propulsion problem solved, the technology and tool challenge were to follow. Although the N2 membrane does allow for increased pressure, it also has its limitations. The pressure would not rise to 30 bar, which is the pressure standard tools need to perform best. Looking at the ROSEN technology portfolio, it was clear magnetic flux leakage (MFL) would be the best technology for the job. Widely known and used technology in ILI, MFL is robust and dependable, and is applied in both gas and liquid lines. The technology choice was clear, but an additional concern would be the tool itself. It needed to be optimised to carry the MFL unit through the pipeline and still collect high-quality data. In the case of low-pressure pipelines, a dominant challenge is to overcome speed excursions, which normally occur during inspection runs because of passing bends, wall thickness variances, welds or the presence of debris. In this case, the system was adapted by using the following elements: • low-friction wheeled magnetizer yokes • enhanced cup design for reduced and The Australian Pipeliner | July 2020

A gas pipeline operating at pressures lower than normal often does not allow for a traditional ILI.

• • •

constant friction customized yoke support system friction reducing odometer unit ultra-compact and lightweight design.

Outcome The solution resulted in successful findings that met POF standards, and the data obtained from this inspection has helped the operator to decide on the next steps for further integrity management of the pipeline. This operation has achieved the main objective of completing the ILI with a cost-effective measure without compromising data quality.

For more information visit www.rosen-group.com


INSPECTION AND MAINTENANCE

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New testing system shows off Pipe Tek wares Pipe Tek is continuing its upward trajectory as one of Australia’s leading pipeline testing firms with the opening of its new inline inspection demonstration piping system.

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fficially coming online at its Brisbane location in May 2020, Pipe Tek’s new demonstration piping system gives the company a platform to showcase the capabilities of the top of the line inspection tools it has at its disposal. Pipe Tek is the exclusive provider of Enduro Pipeline Services’ extensive range of pipeline inspection technologies in Australasia, supplying these tools along with expert services to the region’s oil and gas industry.

Standing out from the competition The new piping system – also known as a testing loop – is made of 10 inch (254 mm) carbon steel and has three different wall thicknesses. In order to provide clients with a full range of scenarios, the system also contains 1.5D bends, 45° angles and a flanged joint. Pipe Tek clients will be invited to attend demonstrations at the new facility to view the impressive capabilities of the Enduro Magnetic Flux leakage (MFl) – Digitel flux logger (Dfl) tool that uses axial MFl data to provide an assessment of metal loss occurring within a pipeline. Five different data sets – for conducting metal loss, deformation, and inertial surveys, along with internal/external discrimination and residual field data – are taken in a single pass of this next generation inspection tool. The tool

B A. The new system contains 1.5D bends, 45° angles and a flanged joint. B.

Pipe Tek’s new ILI demonstration piping system.

uses some of the most advanced design, data storage and packaging techniques presently available, evidenced by the diverse data sets being taken and limited physical size and weight of the tools themselves, typically less in length and weight than most offered on the market.

Brisbane-based specialists All inline inspection tools will be operated and calibrated by Pipe Tek’s fully certified Australian personnel, guaranteeing only the best in service and industry knowledge, with all tools serviced and calibrated in Brisbane.

Pipe Tek continues to offer cost-effective pigging solutions to ensure pipeline operators can maintain an efficient, safe and debris-free pipeline that runs online at its intended maximum efficiency. The company prides itself on its efficiency and dedication to safety, with the ability to acquire field reports for clients within 24 hours of conducting inspection and deliver final reports within 30 days. Pipe Tek has pigged, cleaned, dried, tested and certified pipelines up to 70 inches (1,778 mm) in diameter, completed works all around Australia and is expanding its reputation as one of the most trusted names in pipeline inspection.

For more information visit www.pipetek.com.au The Australian Pipeliner | July 2020

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INSPECTION AND MAINTENANCE

Iplex launches easy-to-use product To ensure the long life and high performance of sewage transport systems, asset owners must be able to properly perform inspection and maintenance operations. The EZIpit® range now includes the recently released EZIpit 1000, which provides this complete solution for gravity sewer pipelines. Nicole Sumich.

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urrently, the EZIpit range has three products available: the EZIpit 425 Maintenance Shaft (MS), EZIpit 600 Maintenance Chamber (MC) and the recently WSAA appraised EZIpit 1000 Maintenance Hole (MH). Iplex General Manager Nicole Sumich says the 1,000 mm size is required for access by a maintenance person, commonly known as a manhole, while other smaller sizes are placed at intervals between maintenance holes as inspection points which allow access from the surface. “We say it is the perfect pipeline pit because the components are lightweight, modular, fast and easy to install in any application whether it be a new system or a rehabilitation application,” says Ms Sumich. The EZIPit 1000.

Standing out from the crowd The EZIpit is derived from a proven European model developed by Iplex’s technology partner Wavin – a global leader in water solutions. The two companies have been at the forefront of innovative firsts in pipeline solutions for many years, led by Iplex Product Manager Michael Lancuba. Ms Sumich says its EZIpit range has a competitive advantage by making sewer inspection and maintenance much easier by being lightweight, modular and quick to install. “The EZIpit 1000 is available with or without a ladder and enables quick access for inspection cleaning and maintenance activities,” she says. “Made from inert polypropylene, the EZIpits deliver watertight units which are chemically resistant to aggressive gases and abrasion. The EZIpit therefore provides superior in-ground performance, reducing operational pipeline costs and providing years of corrosion free service.” Additionally, the EZIpit system has a higher safety standard compared to conventional systems as it can be assembled and backfilled with the sewer pipe simultaneously – reducing both labour costs and the risks associated with open excavation.

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The EZIpit was first used in Australia by Sydney Water in March 2005 for backlog sewer projects in the Blue Mountains area. Since then, the system’s benefits have been recognised and used by contractors throughout Victoria, Queensland and New South Wales, as well as across Europe where the system is well established and used extensively. Ms Sumich says its system offers benefits not only to contractors and asset owners, but to the wider community by minimising disruption through the quick speed and installation and reducing costs with minimal maintenance and operational cost over its lifetime.

A long history of innovation “We’ve been in business for over 80 years and have a long history of product innovation, having brought numerous new technologies to market, driving the industry forward,” says Ms Sumich. “When you think about what our products hold and transport, water; we are ensuring that Australians receive and manage water safely. Our health and wellbeing is underpinned by The Australian Pipeliner | July 2020

functioning sewer systems, access to clean waterways and efficiently moving water after heavy rainfall events. “Some of the challenges we face are cities with growing populations, ageing water assets, increasing network failure rates from leaking sewer systems and limited capital available. “The EZIpit is just one innovative solution we have brought to the market and [we are] excited to announce that there are more to come this year.” Iplex has a long-standing interest in innovation and Ms Sumich says it is constantly looking for new ways to improve and futureproof wastewater and stormwater applications to maintain the health and wellbeing of the growing Australian population. “At Iplex, we partner with our customers and communities to provide safe, secure and innovative water solutions.”

For more information visit www.iplex.com.au


INTRODUCING ® EZIPIT 1000 (MH) THE PERFECT ANSWER TO ALL OF YOUR DESIGN AND INSTALLATION CHALLENGES The perfect plastic pipeline pit. Having received its WSAA Appraisal, the highly sought-after EZIpit® 1000 Maintenance Hole (MH) is now available for purchase from Iplex Pipelines. Available with or without the ladder, the recently launched EZIpit® 1000 (MH) enables safe access for inspection, cleaning and maintenance activities, providing greater flexibility for your pipeline projects.

The EZIpit® is your easy-to-assemble, modular solution providing years of corrosion free service. With the launch of our latest and largest maintenance structure, the EZIpit® 1000 (MH), combined with our incumbent EZIpit® 425 (MS) and EZIpit® 600 (MC) systems, provides complete design and construction flexibility for any sewer project.

EZIpit® 425 Maintenance Shaft (MS)

EZIpit® 425 Maintenance Shaft (MS)

EZIpit® 425 Maintenance Shaft (MS)

THE EZIPIT® RANGE MAKES SEWER INSPECTION AND MAINTENANCE SO MUCH EASIER Civil 13 10 86 • info@iplexpipelines.com.au • iplex.com.au/ezipit-mh


WELDING

Reducing costs with contemporary technologies In the current era of low oil and gas prices, pipeline operators are increasingly being challenged to complete projects ahead of schedule and within approved budgets. With this push for heightened fiscal responsibility in mind, one midstream operator achieved major cost reductions by employing a WeldFit 3-way hot tap tee, available in Australasia through Tremco Pipeline Equipment, on a pipeline tie-in project.

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he hot tapping process has been performed on distribution and transmission pipelines for many decades. However, by evaluating more modern methodologies associated with this practice, operators can often find value by selecting the appropriate approach and product for the application. Recently, a pipeline tie-in project within Pennsylvania’s Marcellus shale formation in the US was able to able to achieve a project cost saving of 14 per cent for its customers for its customers through the use of a WeldFit three-way hot tap tee. The operator, one of the largest midstream energy companies in the US, needed a cost-effective solution for adding a 30 inch (762 mm) branch connection to an existing 30 inch (762 mm) pipeline to tie into a compressor station. In late 2019, WeldFit was approached by this operator to offer a solution for its project. WeldFit recommended using a three-way hot tap tee as an efficient way to perform the tie-in while allowing the pipeline to remain online during service.

Traditional hot tap tee comparison A commonly used method for adding tie-in connections to existing pipelines features the use of a traditional hot tap tee, which requires burying a sacrificial valve after completion of the hot tap. By contrast, using a three-way tee allows the pipeline to easily be expanded without the need for a sacrificial valve buried below grade at the tie-in point. WeldFit says in the three-way tee, the tie-in connection is made using a temporary hot tap valve mounted on top of the tee. Prior to performing the hot tap, the new branch tie-in line is welded into place on the three-way tee, which is welded to the existing pipeline. A permanent valve is installed above grade on the new expansion line and the hot tap is then performed, allowing product to flow through the newly created branch tie-in line. Lastly, the temporary hot tap valve is removed and a piggable plug is securely set in the flange. “An added benefit of utilising a three-way tee in lieu of a traditional hot tap tee is that the branch tie-in pipeline can be laid above ground for ease of access in the future,” says WeldFit.

Saving time and money The three-way tee is an integral part of an efficient hot tapping operation and accomplishes three primary objectives, being to safely direct the flow of fluids to an expansion or lateral line, eliminating the traditional requirement to bury a sacrificial valve and allowing the branch tie-in pipeline and a

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Weldfit installed the three-way tee for its customers, allowing for a 14 per cent project cost saving.


WELDING

permanent valve to be placed above ground. Using a three-way tee also reduces field labour costs and engineering management time associated with the work typically required to install and bury a sacrificial valve, in addition to reducing indirect costs such as transportation and inventory holding.

Positioned for the future WeldFit says for this customer, opting to install the three-way tee was clearly the best decision for this branch tie-in project when compared to using a traditional hot tap tee that would have buried the sacrificial valve. “Using the more efficient three-way tee solution offers multiple savings that can be quantified through shorter project schedules and ease of future access when maintenance and/or expansions are required,” says WeldFit. “At a time resource optimisation is of paramount importance, knowing that your pipeline service partner is experienced enough to recommend the best solutions for the job can make the decision-making process much easier.” Tremco Pipeline Equipment supplies WeldFit products and equipment to the pipeline industry in Australia, Papua New Guinea and the Pacific Islands.

A three-way hot tapping system was used on a pipeline tie-in project in the Marcellus shale.

For more information visit www.tremcopipeline.com.au

Our 3-Way Tee Eliminates Sacrificial Valve Costs. G et the full story.

Download WeldFit’s case study online. www.weldfit3-waytee.info For more information contact Tremco Pipeline Equipment: tremcopipeline.com.au PH: +07. 3344 . 1066

Authorized Partner

The right fitting, on time, when you need it. Our commitment is to be responsive and reliable on every project, every time. MATERIAL GRADES from A234 WPB to WPHY-70 SIZES from 4 in to 42 in diameter; up to 2,220 psi SURELOC® completion plug, secured with segment rings, comes standard PROPRIETARY extrusion fabrication process assures the highest quality and extended durability for your pipeline.

WeldFit Corporation www.weldfit.com

® Registered Trademark, WeldFit Corporation in the United States and other countries. |

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Trademark, WeldFit Corporation in the United States and other countries. | © Copyright 2020 all right reserved WeldFit Corporation.

The Australian Pipeliner | July 2020

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HYDROGEN

Hydrogen: A simple molecule but a complex business by Peter Milne, Freelance Energy and Resources Journalist

It seems Australia is awash with hydrogen buzz. A specialised product few cared about a decade ago is now touted as a replacement for LNG exports and metallurgical coal in steelmaking, a long-term store of renewable energy, and a provider of green fertiliser and climate-friendly fuel for heavy transport.

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ydrogen is a simple molecule with an overwhelming number of new business opportunities that have one thing in common – the need to slash carbon emissions. Many make the call to electrify everything, backed by a power grid dominated by renewable energy. The trouble is that not everything can be electrified. Electricity is expensive to store for extended periods or transport long distances, while batteries can store much less energy for a given weight than liquid fuels. Electricity cannot produce the high temperatures required for some industrial processes such as steelmaking. There is also the need for a cleaner way to meet the current annual demand for 70 million t of hydrogen that is predominantly used in oil refining and to produce ammonia and methanol. Presently, about 75 per cent of hydrogen is made from gas, and most of the rest from coal. A tonne of hydrogen made from natural gas produces 10 t of carbon dioxide and almost twice that if made from coal. Greenhouse gases from hydrogen production are equal to the combined emissions of the UK and Indonesia. If global warming was not a concern, there would be no driver to expand the application of hydrogen. At every stage of the hydrogen value chain – production, storage, transport and use – there is a myriad of technical and commercial options. From computing operating systems in the 1980s Windows became dominant, MacOS a profitable niche player and Amiga disappeared completely. The same array of fates awaits the hydrogen business cases talked about now. Time, technical progress, regulation and the market will determine the winners and losers. The production of hydrogen without carbon emissions comes down to two main choices. The current steam methane reforming technology that splits methane into hydrogen

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and carbon dioxide can be combined with carbon capture and storage (CCS) to produce emissions-free blue hydrogen. The alternative is green hydrogen made in electrolysers powered by renewable energy that produce hydrogen and oxygen from water. Other processes are under development. Perthbased Hazer Group has a technology to produce hydrogen from natural gas but also make high-quality graphite instead of emitting carbon dioxide. A demonstration plant will start next year using biogas from a sewerage treatment works in Perth’s south. In the Latrobe Valley, a pilot plant is under development to test the shipment to Japan of hydrogen made from brown coal and is considering carbon offset for the CO2 emitted. The winning technology will be the cheapest technology. Currently, blue hydrogen is less expensive than green hydrogen, but the future will be determined by the rate at which technology can drive prices down. The future cost of blue hydrogen depends on the price of gas and CCS. As an established technology, steam methane reforming has less potential to achieve substantial improvements. The expected continued decline in the cost of power from wind and solar energy will help the competitiveness of green hydrogen. The big unknown is the cost of electrolysers and their efficiency that currently sits between 60 and 80 per cent. While little improvement is expected on the more established alkaline electrolysis process, the newer polymer electrolyte membrane technology is expected to improve rapidly over the next few years, according to the National Hydrogen Roadmap. When it comes to commercialisation, green hydrogen has the advantage of being more scalable, with the number of solar panels, wind turbines and electrolysers matched to the investment and production required, once produced hydrogen can be used here in Australia or exported. The Australian Pipeliner | July 2020

Export challenges and domestic uses The clear prize that ignited Australian interest in hydrogen was a commitment by Japan to making the new fuel a vital part of its cleaner energy mix. Minister for Energy and Emissions Reduction Angus Taylor recently said the government was driving towards a hydrogen cost of $2/kg. “Getting costs down will be key to establishing Australia as a world leader in the hydrogen sector through both domestic uses … to exporting Australian-made hydrogen to our key trading partners, like Japan and Korea,” says Mr Taylor. Unfortunately, transporting hydrogen overseas is not straight forward. Hydrogen is often compared to LNG in that it can be cooled to a liquid for transport. The difference is methane becomes a liquid at –160°C in a process consuming about 10 per cent of the gas; but hydrogen must be cooled to –253°C with a loss of 25 to 35 per cent of the fuel. The alternative is to incorporate the hydrogen into a larger molecule, such as ammonia, that is liquid at –33°C or so-called liquid organic hydrogen carriers that have similar properties to oil products. The rationale behind exporting hydrogen to Japan is that as it is smaller and cloudier than Australia, it could not produce enough renewable energy itself to feed its need for hydrogen. This business case was recently questioned by Sydney-based Bloomberg New Energy Finance Head of Industrial Decarbonisation Kobad Bhavnagri. BloombergNEF estimated that while Australia could land green hydrogen into Japan for US$2.81/kg (AU$4.09/kg) by 2050, with onshore wind Japan would be able to produce hydrogen for US$1.60/kg (AU $2.33/kg). Australia was uncompetitive as 70 per cent of the cost was for shipping, wiping out its advantage of cheaper renewable energy. Bhavnagri says countries requiring energy imports are likely to view hydrogen by ship as the worst option. “This challenges the narrative that Australia can become a hydrogen exporting superpower,” he says. “Instead, Australia could have a competitive advantage using hydrogen onshore, to produce


HYDROGEN

and export value-added products like green steel, fertilisers, ammonia and alumina, instead of just raw commodities.” Whether Australian hydrogen is used here or overseas, there is a dizzying array of potential uses in addition to Bhavnagri’s industrial examples. Number one is heavy or long-distance transport where compressed hydrogen in a tank has a quicker refuelling process and higher energy density than lithiumion batteries. While vehicles would most likely use a hydrogen fuel cell that essentially replaces the lithium battery in current electric cars, hydrogen-based fuels such as synthetic methane, methanol and ammonia could power heavier transport. In particular, there are few low emission alternatives for rail, shipping and aviation. Hydrogen trains, already operating in Germany, can work on long distance or lessused routes where electrification is uneconomic. Hydrogen can be the feedstock for a synthetic jet fuel or power marine engines in the form of ammonia. Small streams of hydrogen can also be mixed into natural gas distribution systems to achieve partial decarbonisation.

This is a relatively simple way to build local demand for hydrogen as it scales up. ATCO has built a clean energy innovation hub in WA to test the use of blended natural gas and green hydrogen produced onsite with common household appliances. However, so-called green steel, where hydrogen powers the furnace instead of metallurgical coal could be the killerapplication for hydrogen in Australia. BloombergNEF’s Bhavnagri says an international transition to green steel would decimate demand for metallurgical coal, one of Australia’s most valuable exports. However, if that green steel is built here it could utilise Australia’s vast sun, wind and iron ore resources to offset the loss of coal income and jobs. The Grattan Institute recently concluded the coal mining areas of Central Queensland and the Hunter Valley have the right combination of workforce and renewable energy potential to turn Pilbara iron ore into steel. However, the northwest was regarded as too expensive to operate a labour-intensive steel mill. Making ammonia in Australia from green hydrogen has attracted interest from some of the world’s biggest industrial companies.

The Australian Pipeliner | July 2020

In May, BP announced a feasibility study into an export scale project near Geraldton in WA targeting a 20,000 t/a pilot plant that could expand to a 1 million t/year giant consuming 1.5 GW of power. Norwegian fertiliser manufacturer Yara is looking to produce 28,000 t/a to replace five per cent of the hydrogen used in its Pilbara ammonia plant as a first step towards decarbonisation. The International Energy Agency noted last year that while hydrogen has had false starts in the past this time could be different. In the past hydrogen had surged wave of enthusiasm for hydrogen fuel cells for transport. “What is new today is both the breadth of possibilities for hydrogen use being discussed and the depth of political enthusiasm for those possibilities around the world,” the IEA says in its Future of Hydrogen report. For businesses involved in hydrogen, the coming decade will be one of experimentation and learning. Money will be lost at times and some companies will retire hurt. However, with hydrogen the favoured solution for so many decarbonising opportunities, the rewards for the winners will be vast.

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Jemena paves the way for lower emissions Jemena has called for a national green certification program for renewable gases like hydrogen and biomethane, saying the accreditation system would enable customers to purchase verified and approved zero emission gas alike to what is already possible for renewable electricity.

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Adobe Stock © malp


HYDROGEN

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n May this year, Jemena put forward the notion of a renewable gas certification as part of the company’s submission to the Australian Renewable Energy Agency (ARENA) Bioenergy Roadmap. Submissions to the ARENA roadmap closed in early June, with a final report on the sector due to be released from Federal Minister for Energy and Emissions Reduction Angus Taylor later in 2020. Jemena Executive General Manager Gas Distribution Dr Jennifer Purdie says Australia had the potential to be a world leader in zero emissions gas, pointing to Jemena’s projects as an example. “Several green hydrogen gas trials have commenced for domestic and international markets across the nation, including our own Western Sydney Green Gas project, in which the first electrolyser in New South Wales will be installed later this year,” says Dr Purdie. “This technology utilises solar and wind power to create carbon neutral hydrogen gas, which is stored in the Jemena Gas Network, making it accessible to homes, business and the vehicle industry.” Dr Purdie says as Australia looks to recover from the economic impacts of COVID-19, a

stronger focus on renewable gas could unlock regional jobs, business growth, enhance energy security, and be injected into the network with no impact to customer appliances. “In addition to employment opportunities, there are clear benefits for customers who want green energy. Achieving this will kick start projects that can go to market quickly, which will be important as we get back on our feet following the coronavirus pandemic.”

Bioenergy roadmap Dr Purdie says Australia has the capacity to unlock its bioenergy sector, which is already well established in Europe and is a proven ‘here and now’ fuel source that can help Australia address the energy trilemma of affordability, reliability and sustainability. Bioenergy is derived from plants, animals and the subsequent by-products and residues created through agriculture, farming, wastes and remains. When converted into biomethane, the energy source can provide reliable and responsive carbon neutral energy. “We estimate that there are approximately 30 PJ of biomethane gas in close proximity to the Jemena Gas Network alone, enough to

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supply all current NSW natural gas residential customers and support the NSW Government’s drive towards zero emissions by 2050,” says Dr Purdie. “The energy industry can work collaboratively with the bioenergy and hydrogen sectors to sore natural gas, and renewably-generated gases in existing infrastructure. The Jemena Gas Network for example, can act like a giant battery and bring renewable gas to more than 1.4 million customers for cooking, heating and hot water.” Dr Purdie says Jemena’s submission to ARENA had been signed and supported by other members of the sector, representing thousands of large and small businesses across Australia. “In our submission, we have committed to leading the development of a certification system to recognise biomethane as a renewable and net zero emission energy source,” she says.

For more information visit www.jemena.com.au

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The Australian Pipeliner | July 2020

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The Model FLT93F FlexSwitch from FCI.

Continuous flow verification for heavy-duty processes Engineers challenged by demanding high-temperature, high-pressure processes requiring the continuous verification of flow and/or control of air, gases and liquids will find the advanced FLT93F FlexSwitch from Fluid Components International (FCI) – available through AMS Instrumentation & Calibration – offers a precision, rugged and reliable solution with full global approvals to maintain a safe work environment.

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he insertion-style FLT93F FlexSwitch for flow, level and temperature monitoring and control represents a true technological breakthrough in thermal measurement technology. FCI is the only thermal manufacturer providing temperature compensation to ensure set point accuracy for process temperatures that vary up to 37.7°C, which ensures performance users can count on. The SIL-2 rated FLT93F FlexSwitch is designed for fast response performance of an

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extensive list of critical air/gas flow application tasks that meet the needs of a wide range of process and manufacturing industries. Highly accurate, the FLT93F is ideal for use in ventilation air flow, purge gas assurance, gas analysers and sampling systems, inert gas tank blanketing, hydrocarbon gas flows, high-pressure relief valve monitoring and much more. Featuring FCI’s advanced thermal sensing technology, the Model FLT93F combines a highly accurate, all-welded stainless steel sensing The Australian Pipeliner | July 2020

element with an advanced, user-friendly FlexSwitch control circuit. One standardised, field configurable FlexSwitch control circuit satisfies virtually any combination of flow, level and temperature application requirements. The dependable FLT93F FlexSwitch offers a fast response time as low as 0.5 seconds and is suitable for small process connections in lines available in standard lengths from 30 to 457 mm, as well as in custom-specified lengths. This instrument is easily field configurable or factory


TOOLS AND MACHINERY

The FLT93F FlexSwitch is highly accurate in continuous air/gas flow verification applications and in liquids too. pre-set, providing unparalleled flexibility, accuracy and stability for all multi-process sensing and switching requirements. The FLT93F FlexSwitch is highly accurate in continuous air/gas flow verification applications and in liquids too. Air/gas service accuracy is: ±0.5 per cent reading or ±0.06 nmps –whichever is higher. In liquids, accuracy is ±0.5 per cent reading or ±0.012 mps – again, whichever is higher. For temperature service, accuracy is ±1°C with repeatability of ±0.6°C. The versatile FLT93F FlexSwitch operates over a wide setpoint range. In air/gas, the setpoint range is 0.08 to 37 smps at standard conditions of 21.1°C and 1.013 bar(g). The

setpoint range in water-based liquids is: 0.003 to 0.9 mps, and in hydrocarbon-based liquids it is 0.003 to 1.5 mps. The FLT93F is available with either integral electronics or remote electronics for use in hazardous areas where the transmitter electronics must be separated from the instrument. The standard transmitter features dual SPDT or single DPDT relays that are field configurable and 6-amp resistive at 115 Vac, 240 Vac or 24 Vdc. The standard enclosure for the FLT93F FlexSwitch comes in aluminium, which is power coated, with a single 1 inch NPT conduit port and the weather-resistant enclosure is rated NEMA 4X/IP67, Ex approved and suitable for outdoor use. The options available are either a stainless steel enclosure or a dual-conduit port aluminium enclosure with 0.5 inch NPT or M20 metric conduit ports. Global agency approvals and compliances for the Model FLT93F FlexSwitch include: FM, FMc, ATEX, IECEx, EAC/TR CU, Inmetro. CE mark. PED and CRN. It also meets EC directives for EMC and LVD. The probe complies with Canadian Electrical

The Australian Pipeliner | July 2020

code requirements of ANSI/ISA 12.27.01-2011 as a single seal device. The Model FLT93F FlexSwitch is available for service up to –73 to +260°C and pressures up to 240 bar(g). FCI’s range of products is available in Australia and New Zealand through AMS.

About AMS AMS Instrumentation and Calibration represents some of the world’s leading instrumentation and calibration equipment manufacturers, supplying products to industry, government departments and public utilities. The company has operated for more than 40 years and represents a wide range of manufacturers including FCI, Trimec Flow Products, Lauris Technologies, ECD and Interface. For more information visit www.ams-ic.com.au

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TOOLS AND MACHINERY

Schillers’ Vermeer RTX1250.

Equipment and service combine for winning formula For companies like Schillers Town & Country Electrical, having reliable equipment and a supplier to provide aftersales support to regional areas is important to keep operations running. When it came time to upgrade an old trenching machine and expand its fleet with a new smaller trencher, these two factors played a key role in the company investing in a RTX1250 Ride-on Trencher and a RTX450 Ride-on Trencher from Vermeer.

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ocated in Wagga Wagga in regional New South Wales and servicing the Riverina region, Schillers Town & Country Electrical has been installing pipelines for about 10 years. The company installs tanks and troughs for stock water systems and polypipelines, and over the past three to four years has been taking on bigger jobs where more than 100 km of trenching is required.

the machine, rather than me being on it all the time. The increase in horsepower from my previous machine means that I’ve managed to get the trenching jobs done quicker. “I’ve found Kevin to be very good throughout the process, and ever since I’ve had the machine. Overall, Vermeer’s customer support has been excellent – it’s what I need when something goes wrong and I need that support straightaway.”

Updating old equipment

Putting the equipment to work

Getting customer support when needed

With its previous machine working up many hours of use, Schillers Town & Country Electrical Owner Bernard Schiller says the company decided the time was right to invest in a new trencher. “At the time I was looking at bringing a second-hand machine over from the US. I had also looked at prices of other brands,” says Mr Schiller. “Then Kevin Gilbert from Vermeer in Albury managed to get in contact with me at the right time. I caught up with him and looked further into what they offered and decided to go with a Vermeer machine because it was the best equipment that I could buy to fit in with my setup. “The conditions out here can be very hot and the RTX1250 has a very good cooling system, and I’m confident in putting someone else on

Not long after purchasing the RTX1250, Mr Schiller purchased a second smaller Vermeer trencher, the RTX450. “I had been thinking about trading in a smaller machine for a second-hand machine. I spoke to Kevin about it a number of times and decided it’s an important part of our operation to have a smaller machine as well, so we decided to purchase a new one,” says Mr Schiller. Mr Schiller says both machines are still quite new and the team is getting used to them, but he has so far found them to be great additions to his fleet. “For me to be successful in this industry I need the best gear that I can buy, and as far as I’m concerned, I’ve got it.”

Mr Schiller says he is very happy with the customer service he has received from Vermeer since purchasing the RTX1250 and knowing that someone will be able to help with the machines at short notice is invaluable. “I feel confident knowing that Vermeer is there to support me if something goes wrong, and the fact that the machines are under warranty is important for me,” Mr Schiller says. “In the past I haven’t had that support, which I desperately needed, and now that I do it’s taken a lot of pressure off me knowing that they’re there, a phone call away, or a day away, to do something to the machine if need be. “I look forward to building more of a relationship with Vermeer.”

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Since receiving the RTX1250, Mr Schiller has been using it on a project to install stock water systems on big rural properties. “We’re working with Darling Irrigation on the project. Solar bores are being put in and then we’re installing the infrastructure, running polypipeline from those bores to tanks and troughs,” says Mr Schiller.

For more information visit www.vermeer.com.au The Australian Pipeliner | July 2020


More than rental vehicles As one of the world’s leading fleet management, leasing and rental companies with the widest range of commercial vehicles, our competitive solutions can support your business with flexible short-term hire needs. Trust ORIX Rental to keep your business moving.

More Than Fleet Call us to discuss our comprehensive range of vehicles and pricing Ingleburn, NSW | Laverton, VIC | Rocklea, QLD | Eagle Farm, QLD | Emerald, QLD | Garbutt, QLD Moranbah, QLD | Wingfield, SA | Kewdale, WA Produced by ORIX Australia Corporation Limited, ABN 79 002 992 681. It is intended to provide general information about our products and services, current at the time of publication but could change without notice. Standard delivery times apply. The contents do not constitute financial or taxation advice and should not be relied upon as such. Images for illustration purpose only and may show items that are over and above the standard specification. Credit criteria and conditions apply. All vehicles are covered with comprehensive insurance with an excess of $2,000. Terms and conditions apply. Third party rentals subject to third party terms and conditions. The modest delivery fee will vary depending on pick up time/location. *Daily rate, All rates exclude GST.

orix.com.au | 1300 366 749 | info@orix.com.au


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PSSS becomes Australian Dealer for SPC Coatings PSSS announced it is the new dealer throughout Australia for Speciality Polymer Coatings’ range of polymer coatings and accessories.

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peciality Polymer Coatings, Inc. (SPC) Vice President Matt Alliston announced the appointment, saying Piping Speciality Supply Service (PSSS) was chosen for its proven ability sell SPC’s specialist products through its technical expertise and essential promotional infrastructure in Australasia. SPC formulates, manufactures and distributes an industry-leading series of 100 per cent solid multi component liquid (MCL) epoxies and polyurethane coatings containing no VOCs. These materials have been formulated to provide customers with the benefit of a single coat application and the ability to provide a film thickness of greater than 50 mils / 1,250 µm without sagging or compromising flexibility. The company also has broad line coating systems that are used extensively in the pipeline industry, as linings for tanks, whether for acids, alkaline, sewage, potable water, crude oil and a myriad of various petrochemical services, as well as various other steel structures, marine docks and ship applications. SPC says its innovative formulations can provide protection from corrosion along with chemical and abrasive resistance up to elevated temperatures of 180⁰C, with its internal tank linings also suitable for a multitude of services. PSSS Managing Director John Wilton says his interest in SPC begun with its proven track record of polymer coatings and accessories, as it has been supplying and developing PSSS’ range for more than 28 years. “This partnership grew from an existing client’s need for polymer coatings and we are looking forward to bringing this range to all of our existing customers and to our ever-growing client base,” says Mr Wilton. “I also believe these products will complement our existing range of piping products.”

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About PSSS PSSS is the Australian agent for Pigs Unlimited, Hy-Ram, HTL and Sawyer Manufacturing – now adding SPC to its growing list. The team pride themselves on a commitment to providing both high-quality products and services to clients, as well as competitive pricing. PSSS says it is consistently on the look out for new and innovative solutions to offer its clients, with the ability to assist with pipe handling, pipeline equipment and machinery, HDPE tooling and welding, pipeline pigs and pigging equipment, welding clamps and more. For information visit www.psssa.com.au or call 1300 794 096 A. SPC’s polymer coatings and accessories can be used on a range of applications in the pipeline industry. B.

PSSS is now the Australian supplier of SPC’s polymer coatings and accessories, used on this pipeline. The Australian Pipeliner | July 2020


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ORIX talks instant asset write-offs and small business Although businesses of all sizes are feeling the economic effects of COVID-19, small businesses are being hit the hardest. ORIX is helping clients understand the Federal Government’s instant asset write-off scheme and providing a cost-effective way for them acquire vehicles for their company.

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Vehicles available from ORIX for rent and lease.


COMPANY NEWS

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n March 2020, the Federal Government introduced a $17.6 billion economic stimulus package to help Australian businesses navigate these unprecedented times. The package includes an expansion of the original instant asset write-off scheme with increased thresholds for eligible assets and businesses. According to the Australian Taxation Office (ATO), the instant asset write-off scheme allows eligible businesses to, “immediately write off the cost of each asset that costs less than the threshold” and “claim a tax deduction for the business portion of the purchase cost in the year the asset is first used or installed ready for use. (Some exclusions and limits apply.)” From 12 March 2020 until 31 December 2020, the threshold for the cost of a new or second-hand asset has been raised from less than $30,000 to less than $150,000, while the annual turnover threshold for eligible businesses was raised from less than $50 million to less than $500 million – a change that now covers most Australian businesses. “Small businesses are obviously being impacted the most,” says ORIX National Manager of Small and Medium Enterprise Pasquale Petrucci. “Their cash flow and balance sheets are under pressure at the moment.” Mr Petrucci says his team had received many vehicle applications and inquiries recently, largely driven the then-impending end of the financial year, to take advantage of the expanded instant asset write-off.

Any money saved on tax can then be put to operational use – such as wages, rent or maintenance costs.” From 1 July, the threshold reduced to $1,000 for businesses with turnover of less than $10 million. If you don’t want to pay for the assets upfront but still want to take advantage of the instant asset write off, you may want to explore chattel mortgages. “A chattel mortgage is one of the few finance options available that allows you to take legal ownership of equipment from the time of purchase, so you may be eligible for the instant asset write-off,” says Mr Petrucci. With a chattel mortgage, you own the asset legally while you pay back the mortgage over an agreed contract period. ORIX offers flexible repayment periods from one to five years, and the ability to increase the size of the balloon payment to reduce monthly payments. “When you add in the fleet discounts ORIX can secure nationwide, along with our competitive finance rates, it can be a costeffective way to purchase your vehicles,” says Mr Petrucci. “We know how busy it is when you’re running a small business, so we do everything possible to save our customers time – you can add in optional service cards to make it simpler to track fuel and other running costs, with the added benefit of one consolidated monthly invoice covering all expenses. “In addition, ORIX’s OneView online portal provides our customers with access to a range of reports and vehicle management data.”

Considerations

The finer details

Mr Petrucci says before you make any asset purchase decisions, it’s important to talk to your accountant or financial adviser. “The instant asset write-off could help some businesses withstand and recover from the effects of COVID-19,” Mr Petrucci says. By potentially lowering your tax bill at the end of this financial year, it may provide some flexibility with cash flow while the environment is still uncertain. “Let’s say a business was already planning to add three vehicles to their fleet across the next six months,” he says. “This might make it most tax-effective to bring the purchases forward.

There are exclusions and limits to using the instant asset write-off for a business vehicle, including but not limited to the current ATO’s car limit of $57,581 for simplified depreciation. Visit the ATO for some detailed examples on how this works. It is also important to contact your accountant or tax adviser for more information on your business’ specific circumstances. You can add new vehicles to your fleet before the expanded instant asset write-off ends on 31 December 2020 – without having to visit a dealership.

You can research, compare and purchase hundreds of vehicles for your business online with VOOM. Get in touch with the ORIX small business team by calling 1300 134 385 or emailing info@voom.com.au. For more information visit www.orix.com.au The Australian Pipeliner | July 2020

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APGA NEWS AND EVENTS

APGA’s response to COVID-19 by Karen Polglaze, Communications Manager, APGA

Compelled into digital mode due to closing borders, forced quarantine and a locked-down community, APGA experienced an unexpected bonanza in running virtual events. Karen Polglaze

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n 13 March, APGA Chief Executive Officer Steve Davies advised members that APGA had decided to cancel face-to-face events until 31 May due to restrictions introduced to reduce the spread of COVID-19. In an indication of how fast the sand was shifting under everyone’s feet, on 12 March all secretariat staff were working in the office and Steve sent a message to members saying we were pushing ahead with our events, although preparing for lower numbers. But by the next day, we were going fully virtual. APGA has been running technical webinars since early 2019, attracting from 50 to 100 participants once a month. Although we had the technical capacity to have virtual meetings, we still largely either travelled to meetings or had teleconferences. How archaic that seems now. It’s quite a step from running webinars to devising a diverse range of virtual events, and there wasn’t much time. The world was shutting down as the pandemic ripped through cities and countries across the globe. With most people working from home to reduce the risk of transmission, that meant dwindling interaction with workmates and decreasing possibilities for colleagues across the industry to maintain vital connections. APGA is all about connections. Networking, sharing experiences and information, learning from others – all these opportunities were abruptly reduced to almost zero. We knew we could provide a range of alternatives. We just had to learn how to do it. A lot. And fast. Our first virtual event was, oddly, a Zoom meeting. Everyone is all over Zoom now, but our collective experience of it then was quite low. The Pipeline Operators Group (POG) Meeting, one of two this committee holds every year, was scheduled for 1 April and was to discuss pandemic management plans, so it was vital that it went ahead.

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It is hard to remember now, but everyone was new to Zoom and the idea of running a meeting with upwards of 40 people in the virtual room was fairly daunting. It seems such a small thing after months crammed with Zoom and Teams meetings, but at the time it was very important: if we couldn’t run a meeting, how would anyone trust us to run any other online event? With some last-minute practice in muting and unmuting people and learning where to find raised hands, the meeting was launched. And it was a huge success, probably more due to the skill of Chair Ryan Phipps (First Gas) than to the digital platform but, notably, there was a huge level of support from attendees for the experience. So much so, the POG may be squeezing in an extra meeting annually in future. Buoyed by the positive response, we bravely launched into our next event devised on the back of an envelope: the APGA President and CEO Catch-Up and Virtual Drinks. This was to be about 30 minutes of CEO Steve Davies and President Tony O’Sullivan giving an update on issues of concern to the Board and the association as well as answering questions from the floor. The second half was a semi-organised chat between Steve, Tony, Steve Dobbie and the attendees. We had 90 registered attendees, and not too many less than that in the room, and the chatting had to be by text. Nevertheless, everyone seemed to have a good time, even though the technology didn’t deliver the easiest networking experience. Our virtual events just seemed to grow a life of their own after that. The APGA Women’s Leadership Development form had previously held half of its discussion forums face-to-face, but this year’s two cohorts went fully digital from the start. The Third Pipeline Corridor (Land Use Change) Forum segued easily into the online format, bringing together pipeline owner/ operators and technical regulators, planning The Australian Pipeliner | July 2020

authorities, planning consultants, state government officials and developers to discuss topics relating to corridor encroachment management, including engagement with planning authorities and developers and the expectations of regulators. The #Better Together workshop, designed to invite users of pipeline services to talk to owner/operators about their experiences and ways to improve pipeline information reporting to the market was a little more tricky. A key element of the workshop at conception had been putting all these people in the same room to help everyone understand all the different perspectives at play. Suddenly, the pandemic had undermined the key plank of the workshops: having people meet face-to-face and imagine themselves in the other person’s shoes. It was important everyone had a chance to be heard, at length if required, and it was originally hoped that between 30 and 40 people would participate. A plan was developed to move the single facilitated workshop online and split it into four: essentially four repeated workshops with different people. And it proved to be a significant success with the smaller groups allowing a much larger flow of information. Inspired by the success of the President and CEO Catch-up, another type of event was stitched together while we worked hard behind the scenes to come up with something, anything, to recreate at least a shadow of the major value of APGA in-person events: the networking. This time, Steve was going to try his hand at interviewing. What could go wrong when the interviewer was a person who was usually on the other side of the microphone? Our first APGA Interview was with Ben Wilson, CEO of Australian Gas Infrastructure Group. There was no doubting the enthusiasm of the audience: we had 143 registered attendees. And it turned out to be compelling viewing – another tick on the board.


APGA NEWS AND EVENTS

Our greatest success so far was the POG Webinar Series 2020. This replaced the day-long POG Seminar which had been scheduled to be held on 2 April. We split the seminar program into five separate webinars to run over five weeks for 90 minutes each. We had two keen sponsors, Denso and Rosen and, for the first time, we charged a registration fee. And the response was amazing. A total of 181 people registered for the webinar series, which is more than double the number we usually get for the face-to-face event. We had chairs and presenters from around the country and across the Tasman and the presentations were riveting. The event increased the knowledge transfer the seminar is valued for, and the five webinars are now all available as recordings, so the transfer can continue. Our next event was another catch-up, this time with Steve and APGA Director John

Stuart-Robertson. The Catch-Up was followed by a Virtual Drinks event with a new twist we hoped would recreate some of the serendipity that comes from chance encounters at APGA events, as well as providing an opportunity to catch up with colleagues and meet new pipeliners. Judging from the enthusiasm of the participants in the randomised speed networking we tested, it was another great success, and an experience I’m sure we’ll be repeating in the weeks ahead. By the time you read this, we’ll be bringing you the HS&E Webinar Series (sponsored by Nacap and LocusView) which will have a different format to the POG Webinar Series, but one that will be equally interesting and enjoyable. It has become apparent we were merely scratching the surface with our Technical Webinars and that Zoom has great

potential for us, especially in the areas of knowledge transfer and communicating more information to members. While we cannot wait to get back to face-to-face events, it is clear that more virtual events will feature in APGA’s services into the future. The decision to postpone the 2020 APGA Annual Convention and Exhibition until 2021 in Brisbane is presenting us with another challenge and we’re plunging into planning for a Virtual Convention for 2020. We expect to work out the program fairly quickly as our early and ongoing research into digital alternatives included the possibility that we would have to replace some, or even all, of the 2020 Convention with a virtual version. We’ve learned a lot over the past few months, and we intend to make 2020 a Convention to remember for the right reasons, even if they are all digital.

Connect with The Australian Pipeliner on Join the growing network of pipeliners that connect through social media. LinkedIn has become a place to network, discuss industry developments, and look for the latest job opportunities. Don’t miss your opportunity to stay closely connected to your colleagues and build your career through social networking.

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The Australian Pipeliner | July 2020

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Pexels © bongkarn thanyakij

POG Webinar Series thrives online Due to restrictions brought about by COVID-19, APGA developed the virtual webinar series as an alternative to its annual POG Seminar, which would have been in its 18th year. Despite the change in delivery, the series still carried the original theme of Pipeline operations and maintenance: Solving the challenges.

R

unning each Wednesday from 22 April to 20 May, the Pipeline Operators Group (POG) Webinar Series allowed APGA to continue its annual seminar albeit in a different format — delivered virtually through Zoom. The topics covered over the five weeks gave an insight into the issues currently facing pipeline operations and maintenance. With industry leaders presenting individual papers, the series promotes industry-wide discussion to assist pipelines in further enhancing asset management, benefitting both the industry and the public. Attended by all types of industry personnel including managers, supervisors, engineers and field operators of high-pressure oil and gas pipelines through to service and supply businesses, technical auditors and regulators, the series saw hundreds of participants attending from their personal devices each week. To mimic the in-person seminars, a question feature was enabled in the video where participants could type questions for the speakers to answer in real time in addition to a virtual chat function where participants could interact and network between themselves, which has always been a highlight of APGA functions.

Weekly program The series commenced with its first instalment on 22 April, featuring a presentation from GPA Engineering Lead

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Mechanical Engineer Josh Wickham, before Future Fuels CRC Research and Innovation Manager Klaas van Alphen took the virtual stage to discuss his group’s ongoing work. Mr Wickham explored hydrogen’s impact on pipelines and examined its potential as political and industrial entities look to facilitate its growth, while Mr Alphen discussed Future Fuels CRC’s operation-based research that has been taking place. The following week, corrosion was the hot topic with First Gas Technical Assurance Manager Mick Ellem presenting a paper to shed some light on corrosion growth assessment and how to make sense of it. After Mr Ellem concluded his presentation, SEA Gas Senior Pipeline Engineer Michael Jarosz took the baton of the corrosion conversation and discussed AC corrosion in low resistivity soils. On 6 May, it was Jemena Gas Engineering Manager Mike Peoples and APA Group Senior Reliability Engineer Bert Pereira’s turn behind the virtual lectern. Mr Peoples provided attendees with a brief recap of the Northern Gas Pipeline (NGP) project – which commenced in 2016 – hailing it as Jemena’s “biggest project to date” before delving it to the achievements and challenges. Following Mr Peoples, Mr Pereira focused his presentation on the improved maintenance and reliability practices at APA, emphasising the importance of the company’s risk-based inspections and criticality workshops that are in place to ensure its assets and equipment remains up to date. The Australian Pipeliner | July 2020

The fourth instalment of the series featured more presentations from Jemena personnel, with Manager Network Operations Phil Colvin and General Manager Asset Management and Gas Markets Sean Ward discussing the threat of fire to infrastructure and the company’s response. After such a damaging bush fire season, the important information presented and shared in the webinar was indicative of why the POG gatherings are such a vital tool for APGA members. The final webinar began on 20 May with a presentation from Santos Process Safety Engineer Katie Gilbar and Santos Pipeline Operation Engineer Laura Fois, who discussed how to support a strong process safety culture through visible risk management of Santos’ pipeline assets. Following this discussion, Australian Gas Infrastructure Group HS&E Manager Louise Watson presented a paper on implementing a process safety framework in collaboration with HSE to create a positive HSE experience. The 20 May webinar was the final of the five-week webinar series that was clearly a fantastic success and a worthwhile alternative to the annual in-person event. For those who missed the series, all webinars were recorded with the recordings now available on the APGA website.

For more information visit www.apga.org.au


APGA NEWS AND EVENTS

An interview with a twist In a move to the digital sphere of events, APGA has commenced an interview series – referring to the virtual discussions as “a traditional current affairs interview with a twist”.

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ith the alternative format allowing vast numbers of participants to join from their personal devices and abide by all social distancing requirements, the APGA Interview provided a platform for important energy views to be discussed in regard to the changing landscape Australia – and the world – is experiencing. Taking to the virtual stage was APGA CEO Steve Davies in the host’s chair, asking Australian Gas Infrastructure Group (AGIG) CEO Ben Wilson about the industry at large and some of AGIG’s current projects. Mr Wilson discussed a range of energy topics, including the burgeoning focus on hydrogen in the industry, contending government incentives were necessary to facilitating the use of green gas. “We need some stimulus to stimulate demand for green gas, whether it’s hydrogen or biogas, because that stimulus is not there today, and the prices are premium,” says Mr Wilson. “If you’re going to get people to pay a premium, then you need to stimulate the demand.” Mr Wilson says gas networks are the best place for such an incentive, because there is only a price issue rather than a technical issue as well, and they can blend in. “We can all take green hydrogen today in our gas blend, the only issue is the price and we need something to shift the line on that.” Mr Wilson says there is an incentive for whichever state in Australia acted first on this kind of stimulus as it would result in that location attracting major projects.

AGIG initiatives AGIG itself is undertaking several hydrogen initiatives around the country at present, including its construction of a 1.25 MW electrolyser at its Hydrogen Park SA project in South Australia. Mr Wilson says it is important people accepted the premise that the economy needed to be decarbonised and Australia had an opportunity to be at the forefront of the international hydrogen industry. Outside of hydrogen, Mr Wilson says it’s also important not to forget the conventional gas initiatives that are ongoing in Australia, signalling that a number of infrastructure projects could be ready to progress once the

AGIG CEO Ben Wilson says Australia needs a green gas stimulus.

threat of COVID-19 is reduced. “We’re looking at transmission projects, storage projects and midstream projects across Australia and so are a lot of the other pipeliners too,” he says. “As we come out of this crisis, stuff which is shovel ready, which can create jobs and growth,

there surely will be more political support for that than there was before. “We should find ourselves pushing at opens for some of this, and if that’s combined with a lower east cost gas price due to what’s happening in the world, we could be in for some good times.”

For more information visit www.agig.com.au The Australian Pipeliner | July 2020

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Preamble

Body.

Adobe Stock © merla

Second edition delivers as promised The second edition of the APGA Interview series – delivered through Zoom – took place in late June, with APGA CEO Steve Davies interviewing APA Group’s Darren Rogers.

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n 25 June, Mr Davies returned to the interviewer’s chair with APA Group Executive Operations Darren Rogers in place as interviewee to discuss how APA is responding to the COVID-19 pandemic. In his position, Mr Rogers is responsible for the safe operations, maintenance, asset management and in-year revenue responsibility of APA’s portfolio of transmission, power, networks and midstream infrastructure assets. Included in this portfolio is more than 15,000 km of transmission pipelines, 750 MW of solar and wind farms, gas storage and processing and distribution assets. During the interview, Mr Rogers discussed the changes to APA’s operations and his

opinion on what recovery will look like for the company after COVID-19.

An essential service APA’s services have been deemed essential throughout the pandemic, with its critical facilities and essential field sites able to remain operational during the pandemic, ensuring its assets stay safe and services to its customers continued. With its robust crisis management capability, APA ensures it has a cross-functional team monitoring advice on the ongoing COVID-19 situation and managing issues as they arise while simultaneously planning ahead. The company ensures it is following all government advice, including a progressive

For more information visit www.apa.com.au

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The Australian Pipeliner | July 2020

move to remote working and other social distancing protocols to provide for the health and wellbeing of all personnel while also ensuring the operational resilience of its energy infrastructure and services. With much learned about the company’s response to the pandemic and its operational adjustments, APGA plans to continue this informative and successful series with more interviews to be scheduled and announced shortly. APA owns and operates around $21 billion worth of energy infrastructure assets with gas transmission pipelines in every state and territory in mainland Australia. The company delivers approximately half the country’s gas usage.


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APGA MEMBERSHIP

Australian Pipelines and Gas Association Membership CONSTRUCTION CONTRACTOR Alltype Engineering Clough Coe Drilling Pty Ltd Comdain Infrastructure Enscope Pty Ltd Ferretti International (Aust) Global Engineering & Construction Pty Ltd HDI Lucas HH Civil Pty Ltd Maxibor Australia McConnell Dowell Constructors (Aust) Pty Ltd Michels Corporation Mitchell Water Australia Pty Ltd Moody Civil & Pipe Pty Ltd MPC Kinetic Nacap Pty Ltd National Australian Pipelines P and G Welding Pty Ltd Pipecraft Pipeline Plant Hire Pty Ltd Quanta Services Australia Pty Ltd The Newham Group Trushape Engineering Pty Ltd Valmec Limited CONSULTANT ACIL Allen Consulting Aerodyne UAV Australia Pty Ltd Australian Workplace Training Group Pty Ltd Cardno CNC Project Management DNV GL Australia Pty Limited Energy Matrix Group Pty Ltd EnergyQuest Pty Ltd JLL Infrastructure Advisory Pty Ltd Kleinfelder Australia Pty Ltd Land Access & Management Services Pty Ltd Metcalfe Engineering Consultants Pipeline Engineering Consultants Plant & Platform Consultants Ltd Powered Quest Integrity AUS Pty Limited Rhead Group Pty Ltd Sage Consulting Solutions Pty Ltd Stockton Drilling Services Sustech Engineering Pty Ltd TMS Consulting Twycross and Partners Pty Ltd Veris

ENGINEERING/PROJECT MANAGER A J Stack Solutions Pty Ltd AFS Projects Pty Ltd Atteris Pty Ltd Fyfe GHD Pty Ltd GPA Engineering Pty Ltd Momentum Engineering OSD SPIE Plexal Worley GOVERNMENT DEPARTMENTS/ REGULATORS Department for Energy and Mining Department of Natural Resources and Mines Energy Safe Victoria Water Corporation INDUSTRY ASSOCIATION Pipeline Research Council International, Inc PIPELINE OWNER/OPERATOR AGL Energy Limited APA Group Arrow Energy Pty Ltd AusNet Services Australian Energy Market Operator Australian Gas Infrastructure Group Beach Energy Limited Brookfield Infrastructure Group Caltex Australia Petroleum Pty Ltd Energy Infrastructure Management Pty Ltd Enwave Australia Pty Ltd Epic Energy SA Pty Ltd Esperance Pipeline Company Esso Australia Pty Ltd First Gas Ltd Gas Pipelines Victoria Pty Ltd Halfwave AS Jemena Mobil Oil Australia Pty Ltd Origin Energy Limited Papuan Oil Search Limited Power and Water Corporation Qenos Pty Ltd QGC Refining NZ Santos SEA Gas South Australian Water Corporation

Tasmanian Gas Pipeline Pty Ltd Viva Energy Australia Ltd WestSide Corporation Woodside Energy Ltd SERVICE PROVIDER ABB Australia Pty Ltd APTS Pty Ltd ASME Projects Avmin Pty Ltd AXS Pty Ltd Baker Hughes, a GE company Brooks Hire Service Pty Ltd Brownline Australia Pty Ltd Bureau Veritas Asset Integrity and Reliability Services Pty Ltd Contract Resources Ltd Corrosion Control Engineering Pty Ltd DSQ Pty Ltd EnerMech Pty Ltd ERIAS Group Pty Ltd Flowtran Pty Ltd Gameco Pty Ltd Great Southern Press Pty Ltd ITI International LandPartners Pty Ltd LocusView LW Survey Australia Pty Ltd Mipela GeoSolutions NDT Global Pty Ltd Neil Mansell Transport Pty Ltd Nixon Communications Pty Ltd Oceaneering Australia Pty Ltd ORIX Commercial Peter Norman Personnel Pty Ltd PIPE TEK Pty Ltd Piping Specialty Supply Service Pty Ltd QIC Protective Coatings (Aust) Pty Ltd Qube Energy Pty Ltd Rider Hunt International (RHI) ROSEN Australia Pty Ltd RTC Contracting Pty Ltd Shipman King STATS Group T D Williamson Australia Pty Ltd TEAM Truck Hire Australia Pty Ltd Wasco Energy Group Zinfra SUPPLIER OF EQUIPMENT OR MATERIALS Adtech FRP Pty Ltd Aegis Pty Ltd

Anode Engineering Pty Ltd Anti Corrosion Technology Pty Ltd AtlasGas Pty Ltd Australian Pipeline Valve Australian Portable Camps Bao Australia Pty Ltd Composite Pipe Systems Denso (Australia) Pty Ltd Edgen Murray Australia Pty Ltd EDMI Gas Pty Ltd Fast Fusion, LLC Gasco Pty Ltd GF Piping Systems Hard Metal Industries Hawk Measurement Systems Heath Pipeline Services Pty Ltd Herrenknecht AG Inductabend Pty Ltd iPipe Services Iplex Pipelines Australia Pty Ltd Jindal Saw Limited Laurini Officine Meccaniche Srl Lincoln Electric Company (Australia) Pty Ltd McElroy Australia Ozzie's Pipeline Padder Inc PAC PGG Wrightson Turf Pipeline Machinery International LP PipeServ Polyfabrics Australasia Pty Ltd PSAH Pty Ltd Richmond Roadside Products Pty Ltd Savcor Products Australia Pty Ltd Shawcor (Singapore) Pte Ltd SICK Pty Ltd Solar Turbines Australia Specialty Polymer Coatings Inc. System Control Engineering The Hills Rockslinger TIB Chemicals AG Tremco Pipeline Equipment Pty Ltd Tubi Pty Ltd Universal Corrosion Coatings Pty Ltd Vac-Ex Australia Vacuworx Australia Vermeer Equipment Holdings Pty Ltd Viega Pty Ltd Vinidex Pty Ltd Welspun Corp Limited Worldpoly Pty Ltd Worldwide Group

APGA New Membership Approvals

Government Department/Regulator

CORPORATE MEMBERS

Service Provider

Manufacturer of Equipment or Material Specialty Polymer Coatings, Inc Roadside Products Pty Ltd

Rider Hunt International (RHI) Shipman King Pty Ltd LocusView

Supplier of Equipment or Materials

INDIVIDUAL MEMBERS

Vac-Ex Australia The Hills Rockslinger

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ENERGY DISTRIBUTOR ATCO Gas Australia

Water Corporation

David Nichols Arron Smith

The Australian Pipeliner | July 2020


APGA MEMBERSHIP

APGA would particularly like to acknowledge the generous support of its Owner Members • •

APA Group Australian Gas Infrastructure Group

• •

Epic Energy SA Pty Ltd Jemena

• •

SEA Gas Tasmanian Gas Pipeline Pty Ltd

APGA would also like to acknowledge the strong support of its Lead Members • • • • • • •

AGL Energy Limited Energy Infrastructure Management Pty Ltd Esso Australia Pty Ltd Fyfe HDI Lucas McConnell Dowell Constructors (Aust) Pty Ltd MPC Kinetic

• • • • • •

Nacap Pty Ltd OSD QGC Quanta Services Australia Pty Ltd Solar Turbines Australia Worley

Honorary Life Members • • • • • •

Ken Barker David Curry Keith Fitzgerald* Leigh Fletcher D C Gore* Robert Gration

• • • • • •

Max Kimber Andy Lukas Tony Marletta Mick McCormack Stuart McDonald Jim McDonald*

• • • •

Allan Newham Stephen Ohl Mark Twycross Phil Venton *deceased

Individual Members • • • • • • • • •

Dean Barker John Blain Bevan Boocock Grant Bowley Ken Cameron Chris Carter Andrew Cook Mark Cooper Geoff Cope

• • • • • • • • •

John de Robillard Stephen Dykes Yuyu Fang John Fleming Kenneth Flowers Tony Forde Gretchen Gagel Chris Gatehouse Lynndon Harnell

• • • • • • • •

Chris Harvey Graeme Hogarth Justine Hyams Jeff Jones Ashley Kellett Steven Liddell John Lott Cameron MacDiarmid

• • • • • • • • •

Jason Mansfield Bruce McDonough Peter McLennan Mick Murphy David Nichols John Piper Steve Polglase David Pollock Brett Reay

• • • • • •

Arron Smith Jasper Tieland Michael Wallace Andrew Wood Howard Wright Ken Wyllie

Craig de Laine Edwin De Prinse Jason de Ross Ross Demby Carlo DiCarlo Edrees Faizi Daniel Faulkner Matt Felvus John Ferguson Mike Flynn Tom Forde Mark Fothergill Paul Frederick Jarrod Gilby Calvin Gordon David Handsaker

• • • • • • • • • • • • • • • •

Peter Harcus Geoff Harrison Chris Hewson Ian Israelsohn Brett Johnstone Stuart Kamper Hugo Kuhn Trent Leach Benjy Lee Keith Lenghaus Stephen Livens Paul May Matt McFarlane Stephen McKenzie John Messent Paul Miller

• • •

Stephen Mudge Ashley Muldrew Matthew O'Connell Brian O'Sullivan Neil Parry Bob Paton Michael Peoples Jan Peric Janusz Podgorski Tawake Rakai Jim Reaman Josh Row Craig Sheather Reynard Smith James Smith

• • • • • • • • • • •

Andrew Staniford Colin Symonds Soheil Taherian Farrah Tan-Savva Warwick Tidswell Mark Turner Cees van Oord Sean Ward Louise Watson Rob Wheals Robert White

Employee Members • • • • • • • • • • • • • • • •

Awais Ashraf Eric Bardy Geoff Barton Paul Beukelman Tony Bird Tom Bohacik Liz Brierley Peter Bucki Mark Bumpstead Ivan Byak Annette Cahill Geoff Callar Francis Carroll Philip Colvin Jeff Cooke Colin Cool

• • • • • • • • • • • • • • • •

The Australian Pipeliner | July 2020

• • • • • • • • • • • •

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APGA MEMBERSHIP

FULL MEMBERSHIP

(1)

OWNER MEMBER(2)(3)

LEAD MEMBER(4)

CORPORATE MEMBER

Category Applied for (please tick)

ORGANISATION NAME: ABN: POSTAL ADDRESS: SUBURB: STATE: POSTCODE: STREET ADDRESS: SUBURB: STATE: POSTCODE: PHONE: FAX: WEBSITE: APPOINTED REPRESENTATIVE (5) NAME: POSITION: PHONE: FAX: MOBILE: EMAIL: ORGANISATION CHIEF EXECUTIVE (if different from above): NAME: TITLE: APGA POINT OF CONTACT – for distribution of APGA information within your organisation (if different from Appointed Representative) NAME: POSITION: POSTAL ADDRESS: SUBURB: STATE: POSTCODE: PHONE: FAX: MOBILE: EMAIL: ACCOUNTS DEPARTMENT CONTACT: EMAIL: NUMBER OF EMPLOYEES IN ORGANISATION:

1-5

6-25

26-50

>51

ORGANISATION’S INTEREST IN THE PIPELINE INDUSTRY (Must tick ONE ONLY. If more than one applies, please tick the one most applicable to your business):

Adviser/Consultant

Construction Contractor

Energy Distributor

Engineering/Project Manager

Pipeline Owner/Operator

Service Provider

Manufacturer/Distributor of Equipment or Materials

Government Department/Regulator

Other Industry Association (Please Specify)

SECTOR Please indicate which of the following industry sectors you are primarily working in (please tick ONLY ONE box)

Gas

Water

Oil

Slurry

We hereby apply for Full Membership of the Australian Pipelines and Gas Association in the Category and Interest Group indicated above and agree to abide by the Association’s Constitution and any By-laws set from time to time. We attach our payment for the appropriate portion of the first year’s subscription.

SIGNED: DATE: NOTE

(1)

Upon payment of the relevant fees, an organisation may hold more than one category of full membership.

(2)

The appointed representative of an Owner Member should be the Chief Executive.

(3)

All Owner Members are entitled to nominate up to ten Employee Members without additional subscription.

(4)

All Lead members are entitled to nominate up to three Employee Members without additional subscription.

(5)

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All correspondence will be sent to the appointed representative, who will hold the member’s voting rights. A member’s appointed representative may be changed at any time by advising the Association’s Secretary in writing.

The Australian Pipeliner | July 2020


APGA MEMBERSHIP

INDIVIDUAL MEMBERSHIP/EMPLOYEE MEMBERSHIP

INDIVIDUAL MEMBERSHIP(1)

EMPLOYEE MEMBERSHIP

APPLICANT’S NAME: ORGANISATION: POSITION: POSTAL ADDRESS: SUBURB: STATE: POSTCODE: STREET ADDRESS: SUBURB: STATE: POSTCODE: PHONE: FAX: MOBILE: EMAIL: I NDIVIDUAL MEMBERSHIP APPLICATION: I hereby apply for Individual Membership of the Australian Pipelines and Gas Association and agree to abide by the Company’s Constitution and any By-laws set from time to time. Payment for the appropriate portion of the first year’s subscription is attached. NOTE (1): Open to any individual consultant with an interest in the pipeline or gas industries. This membership category is designed to accommodate the one-man consultants working within the pipeline and gas industries and will not be open to consulting organisations consisting of more than one person. Employees of a company will not be accepted as an Individual Member of the Australian Pipelines and Gas Association unless the company employing that person is a Full Member of APGA. E MPLOYEE MEMBERSHIP APPLICATION: (Open to employees of full members of APGA) I hereby apply for Employee Membership of the Australian Pipelines and Gas Association and agree to abide by the Association’s Constitution and any By-laws set from time to time. Payment for the appropriate portion of the first year’s subscription is attached. SIGNED: DATE: SUBSCRIPTION RATES (2019/2020 Membership year 1 July 2019 to 30 June 2020)

AUSTRALIA Membership year 1 July 2019 to 30 June 2020

OWNER Applicable to owners only – fee upon application

LEAD $11,780 (incl. GST)

CORPORATE 1-5 Employees 6-25 Employees 26-50 Employees >51 Employees (incl. GST)

AUD AUD AUD AUD

INDIVIDUAL $630 (incl. GST)

$2,360 $3,160 $3,980 $5,100

EMPLOYEE $230 (incl. GST)

New members joining after 1 October 2019, please contact APGA to discuss the appropriate pro-rate subscription rate. (All applications received after 15 May 2020 will be issued with an invoice for the 2020/2021 membership year).

ALL PRICES QUOTED FOR AUSTRALIAN MEMBERS INCLUDE 10% GST.

INTERNATIONAL Membership year 1 July 2019 to 30 June 2020

OWNER Applicable to owners only – fee upon application

LEAD AUD $10,710

CORPORATE 1-5 Employees 6-25 Employees 26-50 Employes >51 Employees (incl. GST)

AUD AUD AUD AUD

INDIVIDUAL AUD $580

$2,140 $2,880 $3,620 $4,640

EMPLOYEE AUD $220

New members joining after 1 October 2019, please contact APGA to discuss the appropriate pro-rate subscription rate. (All applications received after 15 May 2020 will be issued with an invoice for the 2020/2021 membership year).

ALL PRICES ARE IN AUSTRALIAN DOLLARS. A TAX INVOICE WILL BE ISSUED.

PAYMENT

EFT Bank Westpac Banking Corporation, Swift/ABA/Routing# WPACAU2S. IBAN No. 032729162756. BSB: 032-729. Account No: 16-2756.

I enclose my cheque made payable to The Australian Pipelines and Gas Association, or APGA.

Please debit my credit card (please tick)

Amex

Visa

MasterCard

Credit card processing fee applies.

CARD NUMBER:

EXPIRY DATE:

TOTAL AMOUNT AUD$

CARDHOLDER’S NAME: SIGNATURE: Please return completed form with payment to: AUSTRALIAN PIPELINES AND GAS ASSOCIATION (ABN: 29 098 754 324) PO BOX 5416, KINGSTON ACT 2604 | PHONE: 02 6273 0577 | FAX: 02 6273 0588 EMAIL: apga@apga.org.au | WEBSITE: www.apga.org.au The Australian Pipeliner | July 2020

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ADVERTISERS AND FEATURES

Advertisers' index AMS Instrumentation & Calibration ASME Projects Corrosion Control Engineering Denso (Australia) ERIAS Group Inductabend Iplex Pipelines Australia kwik-ZIP Maxibor Australia McConnell Dowell McElroy Manufacturing Orix Australia Corporation PIPE TEK

47 9 13 7 23 45 38 27 29 1 43 49 5

Pipeline Plant Hire Pipeline Specialty Supply Service Peter Norman Personnel Prime Drilling Radlinger Primus Line ROSEN Group Savcor Products Australia STATS Group Tremco Pipeline Equipment Vacuworx Australia Vermeer Equipment Worldwide Machinery

15 51 14 16 31 19 35 21 41 25 OBC IFC

Features and deadlines 2020–21 OCTOBER 2020

MARCH 2021

MAY 2021

JULY 2021

FEATURES

Women in pipelines and gas Pipeline construction projects and equipment Corrosion and cathodic protection Pigging and ILI Social licence to operate

Upstream Vacuum lifters NDT Pipeline cleaning Environment and land issues

Land issues Integrity and maintenance Construction equipment Coatings and linings Safety PE pipelines

Offshore Trenchless technology Rehabilitation and repair Unpiggable pipelines Hydrogen Valves and actuators

REGIONAL FOCUS

Queensland

Western Australia

South Australia

Papua New Guinea

DISTRIBUTION

APGA functions.

APGA functions

APGA functions OzWater APPEA Oil and Gas Conference

APGA functions

DEADLINE

14 August 2020

15 January 2021

2 April 2021

TBC Features and deadlines are subject to change.

APGA 2021 Members’ Directory is coming soon – book now to secure enhanced exposure for your company in the new year

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The annual APGA Members’ Directory contains product and service information for all APGA member companies. All company listings are made available on the Pipeliner website, and the print copy is distributed to more than 2,500+ pipeline industry professionals. Directory advertisers are entitled to premium listing benefits. Contact our sales team today to take advantage of this great opportunity to enhance your company’s exposure in the new calendar year.

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For more information call 03 9248 5100 or email advertising@gs-press.com.au

The Australian Pipeliner | July 2020


APGA Virtual Convention & Exhibition 2020

LIVE –19 to 23 OCTOBER 2020

NEW DECADE: NEW PERSPECTIVE For more information www.apga.org.au


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