Growing on Gas - PetroMin Mediabuzpetrominonline.com/pub/ppipeliner/mags/ppl151012.pdf · 2 oct-dec...

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Asia's Business and Technical Pipeline magazine

MCI (P) 127/01/2015 • PPS636/10/2013 (025507) • ISSN 1793-1851 • Published by AP Energy Business Publications Pte Ltd 19 Kim Keat Road #04-06 Fu Tsu Building Singapore 328804 • Printed by KHL Printing Co Pte Ltd

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oct-dec 2015

Growing on Gas

3KM205x275w.email.indd 1 2/10/15 3:13 PM

TECHNICAL COMMITTEE:• Kamarul Ariffin Bin Tajul A’mar, Head Centralized Services, PETRONAS

Chemical Group Berhad• Mohd Azmi Mohd Noor, Advisor, Technical Integrity & Process Safety, HSE

Division, Exploration & Production Business, PETRONAS• Grant Vidrine, Regional VP, HSSE & Operational Assurance, Talisman Energy• Michael Costello, Technical Service Manager, Joint Venture & Affiliates,

Chevron International Pte Ltd• Phil Slowther, IMCA, Fugro Group• Dr Krishna M Bala, Director EHS, Hess Asia Pacific• David MacLaren, Technical Advisor, RAMS ASIA

PATRON

Datuk Ir. Kamarudin ZakariaHead, Group Technical Solutions

PETRONAS

The Patrons & Technical Committee Members of the 9th Reliability, Asset Management & Safety Asia Conference (RAMS Asia) cordially invite you to submit your abstract for technical presentations with the theme, “Enhancing Asset Management and Reliability with Futuristic Concepts”.

The event will highlight issues related to maintaining reliable and safe operations while optimizing productivity. The event, seeks to be the premier platform for knowledge and experience sharing in the areas of reliability, asset management and safety at the operational level.

TOPICS: QHSE, Process Safety Management and Reliability, Asset Integrity including RBI, RCM and SIL, En-hanced Safety Practices for Operations as well as installing a platform for Safety Managers, Engineers and Practitioners involved in the UPSTREAM, MIDSTREAM and DOWNSTREAM of gas power sectors.

The recent trend in the oil and gas industries has demanded we examine our usual concepts of Asset Management to search for better ways to care for aging equipment and reduced demand from our existing assets.

Abstracts on relevant topics not included above will also be taken into consideration by the programme committee. The abstract should not exceed 400 words. Abstracts should be submitted by 15 January 2016.

In line with the conference theme and objective, the program committee is careful in selecting the topics and invite speakers to present papers on their own experience and case studies to share with the conference participants. Papers of purely marketing / commercial nature will not be considered. All final papers must be written in MS WORD, to facilitate publication of selected papers in our Energy Publications. PowerPoint used for presentation will not be considered for publication.

The technical committee is in the process of selecting and inviting the industry experts for the appropriate panel sessions and presentations.

Organized by:

Call For Papers

For abstract submission, delegate registration and please contact: [email protected] / [email protected] or call us at +65 6222 3422

9th ReliAbility, ASSet MAnAgeMent & SAfety ASiA ConfeRenCe (RAMS ASiA)Theme: Enhancing Asset Management and Reliability with Futuristic Concepts

25-26 April 2016 • Kuala Lumpur, Malaysia

Abstract Submission Notification of Acceptance Final Paper Submission 15 January 2016 30 January 2016 25 March 2016

Supported by:

Published by AP Energy Business Publications Pte Ltd

ReportPetroVietnam - 40 Years Integration and Development ....................................................... 06

PV GAS Concentrates on the Development of Gas System ........................................................ 08After 25 years of establisment and development, Petrovietnam Gas Joint Stock Corporation (PV GAS) is presently a premier supplier of gas and gas products in Vietnam, contributing to the national energy security and sustainable development of Vietnam gas industry. With the continuous and safe operation of gas value chain from Cuu Long basin, Nam Con Son basin, Malay-Tho Chu basin and Song Hong basin currently, each year PVGAS provides natural gas for the production of nearly 35% of the electricity output, meeting 70% of urea demand and accounting for 70% of LPG market share nationwide.

The Great Gasby ................................................ 10Southeast Asia is gas-rich and the availability and increased demand for this commodity is being leveraged into development of pipeline networks. This report offers selected data on current and future dvelopments in the region.

Stuck in the Pipeline – Project Delays Hit Industry Outlook ................................................ 20This summary of Douglas-Westwood’s World Onshore Pipelines Market Forecast 2015-2019 aims to provide an analysis of the pipeline market. The fifth edition of the World Onshore Pipelines Market Forecast presents a comprehensive view of the historic market from 2010-2014 and the forecast period from 2015-2019. A detailed database of projects, combined with an involved, bottom-up modelling and forecasting process, result in a unique view of the market in terms of length and value.

A Pipeline Alternative to Asian LNG ............. 24As Southeast Asia pursues local solutions to meet surging gas demand, a 15-year-old effort to network the region’s pipelines gets a fresh look.

Demystifying PSM for an Enabled Workforce .............................................................................. 27There are many contributing factors challenging business operations. The lack of skilled workforces and knowledge transfer in Process Safety Management (PSM), in particular, has contributed to the current scarcity of the required knowledge and skills. If the situation continues, it could potentially compromise the operational safety and increase risk profiles of many facilities. Many companies understand the need to change their current learning and development approach. Organizations rely too often on discrete training initiatives and tend not to follow up with additional development to reinforce and sustain the skills required.

2 oct-dec 2015 Visit our websites at www.safan.com

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NewsPipelines in the Pipeline .................................... 32

Technology Two New Ways for the Pipeline Industry to Cut Costs and Complexity .............................. 36DNV GL who are very active in initiating Joint Industry Projects (JIP) have released information on two upcoming JIPs.

Monsoon Can’t Deter Remediation of Exposed Gas Pipeline on Indian Beach ......................... 40A natural gas trunk line was only shut down for three weeks, despite weather and complex repair required. This article outlines the project briefly.

Ground-Breaking Welding Operations On Cracked Live Subsea Gas Pipeline ................ 42DCN International Diving and Marine Contractors recently developed and employed a unique method that made it possible to repair a crack in a 32-inch gas pipeline three times more cheaply than by installing a bypass. Engineers from the Dutch company came up with a completely new application for an existing concept. Thanks to a number of innovative alterations, DCN was able to introduce the method in the Java Sea, where an extremely critical repair could be carried out on a live operational gas pipeline. For the client, the new method meant a saving of millions. DCN director Wim Vriens talked about this remarkable example of underwater innovation.

Composite Pipeline Repair - The Helicoid Epoxy Sleeve .................................................................... 46The Helicoid Epoxy Sleeve is an innovative, full-composite repair system for the strengthening and protection of offshore pipelines, such as risers and conductors.

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Regular FocusEditorial .............................................................. 04

News ................................................................... 32

Calendar of Events .......................................... 50

Advertisers Index ............................................. 52

Subscription Form ......................................... 32A

4 oct-dec 2015 Visit our website at www.safan.com

EditorialEditorial

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Publisher/Executive Editor Eddie Raj Group EditorVishnu PillaiTel: 6222 3422 ext: 209 Email: [email protected] Advertising Co-ordinator Mary Tel: 6222 3422 ext: 206Email: [email protected] Subscription/CirculationJaquilyn Tel: 6222 3422 ext: 201Email: [email protected] Conference Co-ordinator Zaman Tel: 6222 3422 ext: 204 Email: [email protected] Graphic Artist Chua Ai HwaEmail: [email protected]

EditoriAl AdviSory BoArd

dr. Allen Beasley Ascope Gas Centre

Prof. Andrew. C. PalmerCORE, Dept. of Civil EngineeringNational University of Singapore

dr. Nils o. Kristiansen Sarawak Shell Bhd

ir Hj Ahmad Khairiri Hj Abdul Ghani PETRONAS

Mr Adil Abas PT PGN

dr. Michael BellerNDT Systems & Services AG

dr Andrew NgiamINTECSEA - Worley Parsons

Asia Pacific Not as Badly Affected….

Although the falling oil prices have had an adverse effect on projects, causing delays and even cancella-tions, the Asian region has not really

been as badly affected as growing industries, population and economic growth have en-sured that demand for energy has increased.

According to a recent report Douglas-Westwood (DW) expects onshore pipeline capital expenditure to grow modestly, totaling $220bn over 2015-2019, an increase of 14% compared with $193bn over the preceding five-year period. The major expenditure categories of construc-tion and line pipe procurement have steady growth throughout the forecast. In contrast, Capex relating to stations (pumping, compressor and pigging) is expected to plateau or decline slightly year-on-year, as gas lines gain market share over liquids and station efficiency gains are realised internationally.

Installation activity in most regions is expected to increase, supported by contin-ued product demand growth in both new and existing population centres, new and increasing hydrocarbon supply, and a shift in energy demand preferences towards gas.

Population growth and overall energy de-mand continue to rise in non-OECD econo-mies, particularly in the Asia Pacific region. This is driving additional infrastruc¬ture requirements of which transporta¬tion of fuel and products is an important element. In a number of Asia Pacific economies the level of development for product transporta-tion infrastructure is still considered to be lagging behind existing demand, insulat-ing the construction market further from near-term demand growth perceptions and commodity prices.

Natural gas has turned out to be a savior for the pipeline sector. With an anticipated 35% increase in global energy demand between 2010 and 2040, natural gas is expected to significantly increase its share of the energy mix – growing by 65% over the same period.

Investment in new infrastructure to support LNG and unconventional gas developments will be a major factor shaping future demand for pipelines. Outside the major oil province of the Middle East, gas pipelines accounted for 62% of km installed over the past five years with this figure expected to increase to 66% for the 2015-2019 period. The re-duction in the oil price since mid-2014 has tempered the rise of gas demand to an extent, however, reducing investment in natural gas transport technologies. Less robust economic activity than expected in Asia has led to some delays in gas processing facility construction in that region, impacting our natural gas pipeline outlook. Despite this, gas installations are expected to increase by more than 20% in 2015. Furthermore, this constraining impact is anticipated to be short-term with industry fundamentals suggesting an increasing proportion of gas pipeline construction in the coming years

As I have regularly maintained, geopolitics will continue to affect projects around the world. Due to the lack of an overarching authority or jurisdiction for transnational pipelines, geopolitical complication is arguably the most difficult challenge to overcome, threatening the execution of ambitious inter-regional projects such as TAPI aiming to bring Turkmenistan gas to Pakistan and India via Afghanistan, and oth-ers. As a result, commercial interest must be the overriding driver for large transnational projects to be executed successfully as op-posed to softer geopoliti¬cal interests. This is the same for the Myanmar-China pipeline.

However, need must when the devil drives, and the need for energy infrastructure will eventually overcome politics. We thus have a lot to be positive about.

As is the norm, please allow me to take this opportunity, on behalf of all the staff at AP Energy (publishers of PetroMin Pipeliner), to wish our readers Merry Christmas and Happy New Year. May 2016 be a less arduous year than this. We look forward to engaging you once again in the upcoming year.

Group Editor


petroleum companies, especially the strategic partners of Petrovietnam who have made invalu-able contributions to the development history of Petrovietnam today.

At the Conference, President & CEO of Petrovi-etnam - Mr. Nguyen Quoc Khanh has stressed the importance of extensive international cooperation in Petrovietnam’s development strategy, while confirming science and technology is among the group’s breakthrough solutions which continu-ously contributed to the rapid and sustainable development of Petrovietnam. He conveyed the message from Petrovietnam’s Management Board that in the coming period Petrovietnam would fo-cus to develop science and technology, innova-tion, transfer of technology in searching for new resources; overcome difficulties and challenges; put research investment priority on finding solu-tions to increase oil recovery efficiency and de-velop small and marginal fields; complete the exploration and production technology to ensure

PetroVietnam - 40 YearsIntegration and Development

On 21 October 2015, H.E Deputy Prime Min-ister Hoang Trung Hai attended the Open-ing Ceremony of the 2015 Petrovietnam Conference and Exhibition 2015 with the

theme "Petrovietnam - 40 years integration and devel-opment" at Saigon Exhibition and Convention Center, Ho Chi Minh City. This is an important event to mark significant milestones through four decades of devel-opment - its emergence and contribution to Vietnam’s economy in general,to Vietnam’s oil and gas industry in particular.

Having had a speech at the opening ceremony, H.E Deputy Prime Minister Hoang Trung Hai as-sessed that the conference and exhibition 2015 has a broad coverage of in-depth discussions by lead-ers and top-notch experts on the hottest topics in today’s oil and gas technology, thus gives us a deep and timely insight into the development trends of oil and gas market of Vietnam, the region and the world. Deputy Prime Minister highly appreciated the active participation of domestic and foreign

ReportReport

H.E Deputy Prime Minister Hoang Trung Hai and delegates at the opening and ribbon-cutting ceremony for the "Petrovietnam - 40 years integration and development"

Mr. Nguyen Quoc Khanh - President & CEO of Petrovietnam gives a speech at the Opening Ceremony

oct-dec 2015 7

the safety and effectiveness, and control the pro-duction decline in existing fields; and improve the efficiency of production and business activi-ties of Petrovietnam.

The two day conference with the participation of about 500 delegates was a unique platform for petroleum and energy experts to exchange expe-rience, promote technology transfer and seek for investment and co-operation opportunities. At the conference, the CEO and leaders presented their views and visions on driving the industry further, bracing global challenges while provid-ing insights on new technologies and regional collaboration efforts for mutual benefits to de-velop the oil and gas industry in Vietnam espe-cially in this challenging time. Elements of sus-tainability, environment and smart partnerships would be further explored during the summit session. The conference brought a unique oppor-tunity to effectively discuss burning issues of oil and gas industry and provides a timely insight into Vietnam petroleum business, its scientific achievements, challenges to be faced, strengths to be enhanced and solutions to be applied.

At the Plenary Session, the topic “Sustainable development of Vietnam’s petroleum industry” and “Innovation and new technology trend for the future petroleum industry” received great response from international petroleum scientists. The speakers have presented topics such as “Strategy for oi l and gas sector in Vietnam”, “Petrovietnam - 40 years development and new strategy”, “Scientific and technological achievements and strategy of Petrovietnam”, “Challenges and new technology opportunities in oil and gas processing”, “Benefits of integrated production modeling and l i fe of f ield (LoF) technologies experience in the development of deepwater oil and gas fields”, “Experience in the development of deepwater oil and gas fields”, “Cleaner production technologies and PP

application in the Vietnam petroleum industry”, etc. Other topics, including unlocking hydro-carbon resources from deep water areas, challenging reservoir development, unconventional hydrocarbon resources potential and development, improving efficiency of refineries and petrochemical plants, natural gas deep processing, bringing natural gas hight potential onstream, corporate govern-ance and portfolio management had been in active discussion.

At the exhibition, more than 80 Vietnam-ese and international oil and gas companies (from US, Europe, Australia, South East Asia) introduced the latest scientific and technological achievements in the petroleum industry. During the three day trade exhibition, leading com-panies of the oil and gas industry exhibited up-to-the minute tools and technologies for oil and gas exploration, production and trans-porta t ion , equ ipment fo r energy resources , metering and control, automatic process control systems, local area networks, integrated opera-tional systems for plant management, software, innovative projects for oil and gas facilities construction, wide variety of fittings, protec-tive equipment, services for oil and gas complex.

H.E Deputy Prime Minister Hoang Trung Hai and delegates visit the exhibition booth of Petrovietnam


PV GAS Concentrates on the Development of Gas System

ReportReport

With initial purpose of bringing assosiated gas from Bach Ho field which used to be burned wasterfully offshore, PV GAS was established on September 20th, 1990 with the main goals of gathering, im-

porting, transportating, storing, processing, distributing and trading gas and its products.

In April 1995, first gas from Bach Ho field was brought online with a capacity of 1 million m3 of gas/day to supply Ba Ria Power Plant.This helped to reduce huge state budget expenditures in foreign currency to import diesel oil as a traditional fuel for power plants.

With the completion of offshore gas compression platforms and an onshore gas pipeline system, PV GAS has gradually increased the pipeline capacity up to 3million m3 of gas/day in 1997, and over 5millionm3 of gas/dayin 2002 to transport additional gas sources from other fields of Cuu Long basin, such as Rang Dong field (2002), Ca Ngu Vang, and Phuong Dong fields (2008), Su Tu Vang, and Su Tu Den fields (2009), Vom Bac, Rong, and Doi Moi fields(2010), Te Giac Trang field (2011), Hai Su Den and Hai Su Trang fields (2013), Dai Hung (2015) ... to Power Plants, Fertilizer Plant and Industrial Customers in Southeast Vietnam.

By the end of 1998, Dinh Co Gas Processing Plant and Thi Vai Terminal came into operation and began to supply LPG and condensate for the Vietnam market for the first time. This marked a great significance in terms of technical, economic and social developments. Since 1999, PV Gas has met most of domestic LPG demand which has shifted to higher quality grades with competitive price to replace LPG that have been imported from abroad.

The Cuu Long gas ultilisation system has continuously developed with offshore central gas compression platform, gas pipeline systems of 2billion m3 of gas/year with total length of over 520 km from Cuu Long basin to shore, Phu My Gas Distribution Center, Dinh Co Gas Processing Plant (a design capacity of 350,000 tons of LPG and 130,000 tons of condensate/year), Thi Vai Terminal (a design capacity of over 71,000 tons of LPG, 46,000m3 of condensate).

Following up Cuu Long gas ultilisation system, PVGAS,

with foreign partners, continued to invest in the second gas system, namely Nam Con Son basin gas ultilisation system, including a pipeline system of over 400km from gas fields of Nam Con Son basin: Lan Tay, Lan Do (2003), Rong Doi, Rong Doi Tay (2006), Chim Sao, Dua (2011), and Hai Thach-Moc Tinh (2013) fields to Phu My with the design capacity of over 7billion m3 of gas/year and Nam Con Son Gas Processing Plant. In December 2002, the first gas flow from Nam Con Son basin was brought to land and transported to consumers, increasing significantly the gas outputs of PV GAS supplies.

Nam Con Son gas system associated with Cuu Long gas system created an important gas infrastructure of gas value chain in Southeast Vietnam.

To expand the Southwest Vietnam gas market, PV GAS invested in the PM3-Ca Mau gas ultilisation system with a 325 km offshore and onshore gas pipeline with a design capacity of 2billion m3 of gas/year, delivering natural gas from PM3-CAA, 46 CN field (Malay-Tho Chu basin) to Power plantsand fertilizer plant in Ca Mau province from May 2007.

In August 2015, PV GAS put the Ham Rong-Thai Binh gas ultilisation system into operation with a 25 km offshore and onshore gas pipelines and design capacity of 500million m3 of gas/year, initiating the development of gas consumption in the Northern Vietnam in the coming years.

Not just focusing on safe and effective operation of Cuu Long, Nam Con Son, PM3-Ca Mau, Ham Rong – Thai Binh Gas Projects, to meet increasing domestic gas demand, PV GAS is actively investing in new projects, such as: Block B – O Mon Gas Pipeline Project, LNG Import Projects, etc…

To increase the value of gas usage and promote new gas products, PV GAS and its member companies have continued to develop the trading and distribution systems of gas and its products in the country such as dry gas, CNG, LNG.

With the current gas pipeline systems, PV GAS is providing 10billion m3 of gas, 1.3million tons of LPG, and 60,000 tons of condensate per year. PV GAS has great confidence in its bright future with an important as a dominant representative of Vietnam gas industry.

After 25 years of establisment and development, Petrovietnam Gas Joint Stock Corporation (PV GAS) is presently a premier supplier of gas and gas products in Vietnam, contributing to the national energy security and sustainable development of Vietnam gas industry. With the continuous and safe operation of gas value chain from Cuu Long basin, Nam Con Son basin, Malay-Tho Chu basin and Song Hong basin currently, each year PVGAS provides natural gas for the production of nearly 35% of the electricity output, meeting 70% of urea demand and accounting for 70% of LPG market share nationwide.

PP

LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2016 LNG Marine Fuel Fo-rum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG

Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Ma-rine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Fo-rum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG

Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Ma-rine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Fo-rum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG

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Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Ma-rine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Fo-rum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG













Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG LNG Ma-rine Fuel Forum 2015 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine Fuel Fo-rum 2016 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG Marine Fuel Forum 2015 LNG



Marine Fuel Forum 2016 LNG Marine Fuel Forum 2016 LNG Marine

• PolicyandStrategy• PricingandConsumptionForecasts• AnOil&GasCompanyView• TheInvestmentFramework• ALegalPerspective• ABankingPerspective• Certification• Environment&Safety

• ApplicationsandEconomics• ProductionandDistributionTrends• LNGFueledOffshoreVesselDesignandEquipment• OperationalEconomics• PracticalExperience• LNG–HandlingandDistribution• LNGBunkering• LNGTechnology

PetroMin,Hydrocarbon Asia,theleadingmagazinesintheOil&GasindustryinAsia,areorganizingthe2nd LNG Marine Fuel Forum,whichwillbeheldinSingaporeon10-11May2016.

TheTechnicalCommitteehasselectedtheTHEME:“ASIAN LNG - Forging Ahead in the Marine Industry”.

“ The MPA is working on various fronts to develop LNG bunkering in the Port of Singapore…and also launched the S12million funding for players seeking to build vessels capable of using LNG as a marine fuel. A technical committee formed under Spring Singapore’s National Standardization Program is in place to develop standard procedures and technical operations for LNG bunkering operations. To ensure overall development of LNG bunkering across the globe, the MPA has also signed MOUs with the Ports of Antwerp, Zeebrugge and Rotterdam and will be looking into the harmonization of LNG bunkering procedures. ”

Dr. Parry OeiDirector Port Services and Chief Hydrographer, Maritime Port Authority of Singapore (MPA)

CONFereNCe CHAIrMAN AND TeCHNICAL COMMITTeeWong Toon Suan,MDofONEBLUE;ExecutiveAdvi-sorofILO,NationalUniversitySingapore;ConferenceChairmanelsie Tang,ConsultantofDNVGLMaritimeAdvisory(Singapore)rolv Stokkmo,ManagingDirectorofGasPartners

Denis Welch,ChairmanofOneWorldMaritimePteLtd;IMCARegionalDirectorAsiaPacificTesch Alexander,DirectorofSalesMarine&Offshore,MTUAsiaAbul Bashar Md Masum reza, Asst.PrincipalRe-searchEngineer,KeppelOffshore&MarineTechnologyCentre(KOMTech)

CONFereNCe TOPICS

The technical committee invites you to present papers in this conference. The conference will be an excellent platform for the authors and speakers to address a highly sophisticated and experienced audience.

Theabstract,whichshouldnotexceed400words,shouldbesenttousviaemail.Thecommitteememberswillreviewthewrittenpaperstoensurethatthecontentisinlinewiththeobjectiveoftheconference.Pleasenotethatpapersofapurely marketing / commercial nature will not be considered.

Forthebenefitoftheindustry,selectedpaperswillbepublishedinHydrocarbon Asia MagazineorPetroMin(inprint)andwillalsobepresentedonthewebsite.

Forabstractsubmissionandfurtherinformationpleaseemail:[email protected] / [email protected]

Organised by:

LNG Marine Fuel Forum 2016Theme: AsiAn LnG - Forging Ahead in the Marine industry 10 - 11 May 2016 • Singapore

CALL FOR PAPERs

AbstractSubmissionDeadline15 January 2016 FinalPaperSubmissionDeadline15 March 2016


The Great Gasby

ReportReport

The Association of South East Asian Nations (ASEAN) is promoting the development of a Trans-ASEAN Gas Pipeline system (TAGP) aimed at linking ASEAN's major gas production and

consumption centers by 2024. Because of Malaysia's

extensive natural gas infrastructure and its location, the country is a natural candidate to serve as a hub in the ongoing TAGP project, which currently has 1,800 miles of pipelines in operation out of a proposed 4,500 miles. The first pipeline connected Malaysia with Singapore

and was commissioned in 1991. Singapore cur-rently has two contracts to import 84 Bcf/y of gas from Malaysia. Gas pipelines between West Natuna, Indonesia, and Duyong, Malaysia were installed in 2002, and Malaysia imported more than 40 Bcf of gas from Indonesia in 2013, ac-cording to the BP Statistical Review 2014. The Trans-Thailand-Malaysia Gas Pipeline was com-missioned in 2005, which allows Malaysia to transport natural gas from the Malaysia-Thailand JDA to its domestic pipeline system.

A key component of expanding the TAGP is to transit natural gas from the massive East Natuna gas field, located in the South China Sea to Southeast Asia. The field is being developed by a joint venture consisting of Pertamina (Indonesia), ExxonMobil, Total, and PTT Exploration and Pro-duction (Thailand). Malaysia's Petronas exited the project in 2012, and the field's development has encountered several delays as a result of its remote location and high carbon dioxide levels. These challenges to East Natuna's development could also delay the TAGP, and several Southeast Asian countries are turning to LNG imports to deal with the region's gas shortages.

BruneiBrunei's small, wealthy economy is based

heavily upon proceeds from exports of crude oil and natural gas. Brunei relies on hydrocarbon

Southeast Asia is gas-rich and the availability and increased demand for this commodity is being leveraged into development of pipeline networks. This report offers selected data on current and future dvelopments in the region.

oct-dec 2015 11

revenues for nearly two-thirds of its gross domestic product and the vast majority of its merchandise exports and government revenues.

Latest UpdatesMcDermott International, Inc. has been awarded a

three-year shallow water pipeline contract by Brunei Shell Petroleum Company Sdn. Bhd. (“BSP”) to transport and install pipelines and umbilicals for the Champion and Ampa Fields offshore Brunei. Work is expected to be executed through 2017.

The full scope of work will be executed in annual work plans that are expected to be confirmed over the coming years as BSP finalizes its development

plans and budgets. The work identified for 2015 will be included in McDer-mott’s fourth quarter 2014 backlog.

The first scope of work consists of transportation and installation of more than 62 miles of pipelines including corrosion resistant alloy clad pipelines, as well as umbilicals and cables. The McDermott Derrick Barge 30 and other vessels will be mobilized to support this initial work which will include hydro testing, pre-commissioning and salvage of redundant risers.

Brunei has significant long-term plans to increase investment and pro-duction in its energy sector, and the successful installation of these new pipelines in the Champion and Ampa fields is expected to help ensure the continuity of these mature reserves. McDermott’s contribution in develop-ing these facilities plays a vital role in helping Brunei meet its energy goals.

On a less positive note, an offshore pipeline leak at AMPA 9 was detected in Septem-ber, Brunei Shell Petroleum (BSP) confirmed in a statement.

The bubbling of gas in open water, visible from a re-corded video that went viral on social media, stopped yesterday after BSP identified the pipeline and isolated the situation.

The pipeline, situated 10 kilometres off the coast of Kuala Belait, is located near AMPA DP15/24, a platform that is normally unmanned.

All 17 personnel who were working on board the platform were evacuated, as part of precautionary measures taken. The incident was first observed, then reported to the offshore installation manager.

BSP has launched an investigation to look into the cause of the incident.

“ Earlier this year we established a dedi-cated presence in Brunei and demonstrated outstanding execution delivering project certainty on the transportation and instal-lation of four jackets for the BSP Champion Waterflood B2/3 development,” said David Dickson, President and Chief Executive Officer. “BSP’s confidence in our efficient planning, seamless offshore operations and excellent safety performance is demonstrated by the award of this significant new project, which is one of BSP’s largest contracts in recent years. ”


Indonesia

Indonesia has no international oil pipelines and few domestic pipelines, making maritime trade vital. It’s a different story for Natural gas, however. Although the majority of Indonesia's natural gas exports are transported as LNG, Indonesia sends about a fourth of its gas exports to Singapore and Malaysia through two pipeline connections: one from its offshore fields in the West Natuna Sea and the other from the Grissik gas processing plant in South Sumatra. In 2014, Indonesia exported about 336 billion cubic feet per year (Bcf/y) via pipeline (30% of its total exports), with more than 230 Bcf/y sent to Singapore.

DevelopmentsLate last year it was announced that Indonesia's state-

owned gas company Perusahaan Gas Negara (PGAS) is planning to build a 1,200km undersea pipeline between the islands of Java and Kalimantan.

The gas pipeline, due to be completed in 2018, will run from Central Java to East Kalimantan province.

PGAS has loaned its affiliate Kalimantan Jawa Gas (Kalija), a joint venture company, $250 million to run the gas network project.

The first stage of the project will be construction of a 207km long pipeline from the offshore Kepodang gas

field to Tambak Lorok in Central Java.

More recently it was revealed by the Indonesian government that Indonesia needs $32.42 billion for gas infrastructure.

MalaysiaMalaysia's energy industry is a critical sector of growth

for the entire economy, and it makes up almost 20% of the total gross domestic product. New tax and invest-ment incentives, starting in 2010, aim to promote oil and natural gas exploration and development in the country's deepwater and marginal fields as well as pro-mote energy efficiency measures and use of alternative energy sources. These fiscal incentives are part of the country's economic transformation program to lever-age its resources and geographic location to be one of Asia's top energy players by 2020. Another key pillar in Malaysia's energy strategy is to become a regional oil and natural gas storage, trading, and development hub that will attract technical expertise and downstream services that can compete in Asia.

Malaysia has an extensive gas pipeline net-work running through Peninsular Malaysia and pipelines that connect offshore fields in all three states to key infrastructure onshore.

Malaysia has a relatively limited oil pipeline network and relies on tankers and trucks to distribute products onshore. Malaysia's main oil pipelines connect oil

oct-dec 2015 13

fields offshore Peninsular Malaysia to onshore storage and terminal facilities. The 124-mile Tapis pipeline runs from the Tapis oil field and terminates at the Kerteh plant in Terengganu, as does the 145-mile Jerneh condensate pipe-line. The oil pipeline network for Sabah connects offshore oil fields with the onshore Labuan oil ter-minal. This network is currently expanding following the launch of development projects including the Kebabangan cluster, the Ma-likai, Gumusut/Kakap, and Kikeh oil fields. For Sarawak, there are a few other oil pipelines connecting offshore fields with the onshore Bintulu oil terminal. The majority of pipelines are operated by Pet-ronas, although ExxonMobil also operates a number of pipelines connected with its significant up-stream holdings located offshore Peninsular Malaysia.

An international oil products pipeline runs from the Dumai oil refinery in Indonesia to the Melaka oil refinery in Melaka City, Malaysia. An interconnecting oil products pipeline runs from the Melaka refinery via Shell's Port Dickson refinery to the Klang Val-ley airport and to the Klang oil distribution center.

Malaysia has one of the most extensive natural gas pipeline networks in Asia, totaling about 1,530 miles. The Peninsular Gas Utilization (PGU) project,


completed in 1998, expanded the natural gas trans-mission infrastructure on Peninsular Malaysia. The PGU system spans more than 880 miles and has the capacity to transport 2 billion cubic feet per day (Bcf/d) of natural gas. Other natural gas pipelines run from offshore gas fields to gas processing facilities at Kertih. Also, a number of pipelines link Sarawak's offshore gas fields to the Bintulu LNG facility. However, there is limited gas distribution coverage in much of the Sarawak and Sabah states.

The Sabah-Sarawak Integrated Oil and Gas Project, slated to be completed by 2015, includes the 325-mile Sabah-Sarawak Gas Pipeline (SSGP) that will transport 1 Bcf/d of gas from Sabah's offshore fields to the Petronas LNG complex for liquefaction and export. Some natural gas from the terminal is also reserved for fueling downstream industrial projects and for power generation in Sabah. The SSGP is expected to be ready for operations in conjunction with the SOGT in 2014. Other pipelines link natural gas fields located in offshore Sabah to the Labuan Gas Terminal.

MyanmarMyanmar is an important natural

gas producer in Southeast Asia, al-though its upstream hydrocarbons sector is severely underdeveloped. Financial constraints by Myanmar’s national oil company, a lack of technical capacity, opaque regula-tory policy, insufficient investment by foreign firms, and international sanctions have significantly impeded the country’s efforts to realize its oil and natural gas production potential.

On January 30, the Myanmar section of the Myanmar-China Oil Pipeline jointly invested and built by CNPC and Myanmar Oil and Gas Enterprise (MOGE) was put into trial operation, and the Port of Maday Island was officially opened.

The pipeline starts at Maday Is-land in Kyaukphyu, Rakhine State, on the west coast of Myanmar, and runs 771km through Rakhine State, Magway Region, Mandalay Region

and Shan State before entering into China at Ruili, Yun-nan Province. The pipeline is designed to transport 22 million tons of crude per annum, with the pipe diameter of 813mm.

Maday Island is located at the southeastern part of Kyaukphyu. The Port of Maday Island consists of a 300Kt crude oil terminal, a workship dock, a 650,000 cubic meter water tank, a 38km-long chan-nel, and a 1.2 million cubic meter oil tank farm. A 300Kt oil tanker has moored at the port and began to unload crude from the Middle East. The new route however, has one invaluable advantage in eyes of Chinese leaders: it bypasses the Malacca straits, whose infamous waters are infested with pirates. A 300,000 ton super tanker recently discharged its oil at the new deepwater port located on Maday Island, the first time this had happened, marking the start of new pipeline’s operation. That oil will now flow to Kunming, the capital of the southeast Chinese province of Yunnan, which borders Myanmar. The pipeline shortens the distance the oil will have to travel by sea to reach China by 700 miles. It also

oct-dec 2015 15

cuts by 30% the time this liquid black gold will take to get to the Middle Kingdom.

Parallel to the oil pipeline of Maday, another link has been functioning since 2013, from the sea port of Kyaukpyu, which is dedicated to methane. This pipeline has already transported to China four billion cubic me-ters of methane from both Burmese and Middle Eastern (Qatari) sources.

The $2.5 billion invested into the pipeline have been entirely covered by the giant state-owned oil company, China National Petroleum Company (CNPC), which owns this key infrastructure. But the project has not gained acceptance from all of the concerned parties.

PhilippinesNine natural gas pipeline projects are targeted to be

put in place in Luzon from 2017 to 2022, according to the government’s Philippine Energy Plan (PEP).

The proposed pipelines are deemed necessary for

the development of the country’s natural gas industry.

These nine projects are the Ba-tangas-Manila 1 (BatMan 1), Bat-Man 2, Bataan-Cavite (BatCave), Subic Pipeline, Clark Pipeline, Subic-Fort Bonifacio Pipeline, Sucat-Malaya, Sucat-Quirino lines and a city gas distribution network -- the EDSA-Taft Gas Pipeline, according to the PEP.

The BatMan 1 Project is consid-ered the backbone infrastructure with an estimated distance of 105 kilometers and is a high-pressure gas transmission pipeline from Batangas to Sucat.

The supply of natural gas for the BatMan 1 pipeline will come initially from the production of the Malampaya gas field and will be supplemented by LNG (liq-uefied natural gas) importation in 2020, the Energy department also said.

There is currently 529.5 km of natural gas transmission pipelines in the Philippines which transport gas from the Malampaya Gas Field to fuel three power plants: 500 MW San Lorenzo, 1,000 MW Sta Rita and 1,200 MW power plants. A total of 423 km of transmission pipeline are being proposed and will be constructed between the peri-ods from 2011 to 2020. These projects are envisioned for the island of Luzon where demand concentration for natural gas is projected to be the highest in the next 10 years. Currently, the Philippine National Oil Company is holding talks with China’s XinAo Gas, Japanese Mitsubishi Corporation, and PTT of Thailand for the development of the Batman-2 Gas Pipeline. The Batman-2 Pipeline will traverse 150 km to link Bataan to Manila. The project also includes the construction of a 35 km spur line (known as the Batcave Pipeline) to industrial areas in Rosario, Cavite province, and a distribu-tion network to serve potential gas users in the areas through which the pipeline passes.


BatMan 2, on the other hand, is a 140-kilometer high-pressure pipeline that will serve possible markets such as the Limay com-bined cycle power plant, which can be converted to natural gas-fired plant, and economic zones, notably Subic and Clark, including industries located along the route.

BatMan 2 is targeted to be in place by 2020. BatMan 1 and BatMan 2 will be connected via another infrastructure project, which is the 40-kilometer under-sea Bataan-Cavite and through the 35-kilometer Rosario, Cavite, Laguna (RoBin) line.

Four additional pipelines will be constructed, accord-ing to the PEP. These are the 40-km Subic pipeline which will be linked with the proposed BatMan (2021); the 25-km Clark pipeline to start from BatMan 2 going to Clark (2022); the 35-km Sucat-Malaya pipeline (2017) which is an underwater high pressure gas transmission pipeline from Sucat, Paranaque to service the Malaya Plant in Rizal, which is proposed to be converted into a natural gas plant; and the 15-km Sucat-Fort Bonifacio pipeline that will service the requirement of commercial establishments inside the Bonifacio Global City (2017).

Singapore

Traditionally, most of Sin-gapore’s natural gas has been imported from Indonesia and Malaysia through pipelines. Since May 2013, Singapore has started importing liquefied natural gas (LNG) to diversify and secure its energy sources SPC holds interests in three regional gas transmission pipelines. The 654-kilometre West Natuna Transportation System is the first Singapore cross border sub-sea gas pipeline carrying gas from the West Natuna Sea to Singapore. A consortium of PSC blocks in West Natuna including the Kakap PSC owns this pipeline.

The 468-kilometre Grissik-Batam-Singapore Pipeline is the second direct gas pipeline transmitting gas from Indonesia to Singapore. Gas to Singapore commenced in 2003 under a 20-year term contract between Singapore and Indonesia. The 536-kilometre Grissik-Duri Pipeline is

a trunk line that transmits gas from the Grissik gas fields to Caltex's Duri facilities under long-term contracts that commenced in 1998.

ThailandWhile Thailand is an oil and natural gas producer,

the country relies on imports to sustain its rising fuel demand. Domestic oil reserves and supply are limited in Thailand, and the country imports a significant share

oct-dec 2015 17

of its oil consumption. However, Thailand holds large proved reserves of natural gas, and natural gas produc-tion has increased substantially in the last few years. High demand growth over the past two decades led Thailand to become a net importer of natural gas.

Thailand's natural gas transmission infrastructure is extensive. PTT's transmission infrastructure stretches 2,308 miles, which includes 1,392 miles of onshore and 916 miles of subsea pipelines. In addition, the national gas pipeline system connects onshore and offshore gas fields to various gas separation plants, power plants, and industrial users.

The transmission pipeline of PTT stretches includ-ing onshore and subsea pipelines. PTT’s gas pipeline system connects with various gas pipelines in the Gulf of Thailand, LNG terminal, the pipeline grid from Yadana, Yetagun and Zawtika Myanmar at the Thai-Myanmar border with power plants, the Gas Separation Plants and industrial users. The system also contains Dew Point Control Unit and the Header which control the quality of gas from different sources

Thailand's military government plans to liberalise the country's gas pipeline business, which is monopolised by energy giant PTT, by the middle of 2015, energy policy makers said late last year.

State-controlled PTT will spin off the business by transferring the pipeline and related assets to a new entity, according to a statement from the National Energy Policy Council (NEPC), chaired by junta leader General Prayuth Chan-ocha.

The liberalisation will give other companies access to the country's gas pipelines and links to the LNG receiving terminal run by PTT.

Initially, PTT will own 100 percent of the new entity but the Finance Ministry could take a stake, Areepong Bhoocha-Oom, permanent secretary of the Energy Ministry, told reporters after meeting with the NEPC.

PTT runs onshore and offshore gas pipelines running 3,715 km (2,300 miles) and is build-ing a fourth at an estimated cost of 39 billion baht ($1.22 billion). The pipeline business has contributed about 25 percent of PTT's core earnings in the past three years, analysts said.


in the Gulf of Thailand to ensure common and uniformed heat and quality.

This pipeline system of over 511 kilometers, is a con-necting pipeline branching out from the main pipeline to connect with industries. Presently, there are a total of 450 industrial users.

PTT Plc in late-2014 revealed plans to invest more than 100 billion baht on a new gas pipeline from Rayong's Map Ta Phut to Bangkok.

The project will be its fifth pipeline to serve the con-stantly increasing demand for gas in the future, according to Chief Executive and President Pailin Chuchottaworn.

"Our four gas pipelines are operating at nearly full capacity, so we have to prepare for the new one since construction will take years," he said. Details of the new pipeline have yet to be finalised as the company is waiting for the results of the feasibility study.

The project would also need to meet the requirements of the state's power development plan (PDP). However, he said that it would probably be routed to link with pipelines carrying gas from Myanmar in order to secure gas supply in the future.

Earlier this year Bechtel announced its selection by Gulf MP Company Ltd of Thailand to manage construc-tion of pipelines that will feed gas into a network of planned new power generation facilities. Bechtel will man-age engineering, procurement and construction for 12 new gas pipelines with receiving stations.

The contract was awarded as part of Thailand’s Small Power Producer pro-gram in an effort to diversify the country’s energy mix and to support industrial en-ergy needs. The 12 new combined-cycle plants will each provide 120-130 MW of electric power to industrial users and to the Electricity Generating Authority of Thailand. They will also provide steam to local industrial users. The pipelines will vary in size between eight and 16 inches and in length between one and 11 kilometres.

VietnamOver the past few decades Vietnam has emerged as

an important oil and natural gas producer in Southeast Asia. Vietnam has boosted exploration activities, allowed for greater foreign company investment and coopera-tion in the oil and gas sectors, and introduced market reforms to support the energy industry. These measures have helped to increase oil and gas production. Also, the country's rapid economic growth, industrialization, and export market expansion have spurred domestic energy consumption.

In mid-2014 PV Gas, the gas arm of state-owned PetroVietnam, has received a $280 million loan to fund the first stage of its Nam Con Son 2 gas pipeline project, PV Gas said.

The seven-year loan was granted by a consortium of 11 Asian banks headed by Taiwanese Cathay United Bank, the company said in a statement.

In the first stage, PV Gas will invest $400 million to build 151 km of gas pipeline connecting the Thien Ung, Dai Hung fields and others in the Nam Con Son basin to the existing Bach Ho field in the Cuu Long basin.

oct-dec 2015 19

PP

The project will create infrastructure which is ex-pected to attract more investments in deep-water gas fields in the Nam Con Son basin, PV Gas said. PV Gas has not begun construction at the project yet. The company is in the process of securing capital, a PV Gas spokesperson said Thursday, without provid-ing any time frame for construction.

PV Gas will also invest $125 million in the first stage to upgrade the pipeline system in the Bach Ho field to enable it to receive about 7.5 billion cubic meters/year of natural gas and 300,000 cu m/year of condensate from Thien Ung and Dai Hung, Vietsov-petro, a joint venture between PetroVietnam (51%) and Russia's Zarubezhneft (49%) said in March 2014.

In early May 2014, PV Gas awarded Vietsovpetro contracts to build the 151 km pipeline and upgrade the pipeline system in the Bach Ho field.

All gas from the Bach Ho pipeline system will then be transported via the existing Nam Con Son 1 pipeline to supply customers in Vietnam's south, PV Gas said.

Vietsovpetro made a commercial discovery at the Thien Ung field in block 04-3 in 2009. The field is expected to start production in 2016, Zarubezhneft said.

However, PetroVietnam Director General Do Van Hau said in May that PetroVietnam hoped to speed up construction of the pipeline to allow first gas from the Thien Ung field to be pumped in the third quarter of 2015.

He asked PV Gas and other relevant parties to strive to finish the pipeline in the first stage as planned, PetroVietnam said.

The producing Dai Hung oil and gas field is located in block 05-1A and is equally owned by PetroVietnam and its upstream arm PVEP.

The proposed $1.3 billion Nam Con Son 2 pipeline will be capable of transporting about 7 billion cubic meters/year of natural gas from several gas fields in the Nam Con Son basin. The project will comprise 325 km of pipeline offshore and 30 km on land. It will run parallel to the Nam Con Son-1 pipeline project, which was completed in 2003 and has a

capacity of around 19 million cu m/day, according to PetroVietnam.

PV Gas also plans to raise $1.3 billion in charter capi-tal in the next three years, to fund the construction of 550km in new gas pipelines and related facilities across Vietnam, it was announced early this year.

Additionally, Vietnam and Laos will conduct a feasi-bility study on a project building a bonded warehouse and two oil and gas pipelines running from Vietnam's central province of Quang Binh's Hon La Island to the Lao province of Khammouane.

According to a report from VOV, a contract signing ceremony was held in Vietnam on October 22nd between PetroLao, Energy Commodities Company from Slovakia, and the Association of Vietnam Investors in Laos (AVIL).

The projects include the building of a bonded ware-house, with a capacity of 300,000-500,000 cubic metres for temporary import and re-export to Laos, a seaport system to handle 50,000 ton vessels, and a 290-kilometre long oil pipeline from Hon La, Vietnam to the Kham-moune province in Laos.

As scheduled, the project will start in the fourth quar-ter of 2015 and take approximately 30 months. It is expected to be put into operation by the end of 2017.

ReferencesBechtelBrunei TimesBusiness WireChina Petroleum Engineering Co.,Ltd CIA World FactbookCNPCEIAEnergy Market Authority of SingaporeEnergyglobal.comForbesIEAMyanmar TimesNikkei Asian ReviewPlattsPTTPLCSPCThai PBSThe Jakarta PostThe Philippine StarTheodora.com


Stuck in the Pipeline – Project Delays Hit Industry Outlook

ReportReport

The substantial fall in oil prices since July 2014 has weakened the onshore pipeline market, causing project delays and a focus on reduc-ing costs for pipeline owners. Despite this,

the delays we have observed to date have a different complexion to other oilfield sectors – deepwater capital projects or drilling programmes for example – and have been limited in large part to the North America region. In general, the onshore pipeline market itself is well-cushioned from short-term commodity price fluctuations with projects typically responsive to long-term demand and supply trends, both within and between regions. Other geopolitical factors tend to be of greater relative importance than for other sec-tors, which has played its part in limiting the impact of the downturn, so far.

Douglas-Westwood (DW) expects onshore pipeline capital expenditure to grow modestly, totaling $220bn over 2015-2019, an increase of 14% compared with $193bn over the preceding five-year period. The major expenditure categories of construction and line pipe procurement have steady growth throughout the forecast. In contrast, Capex relating to stations (pumping, compressor and pigging) is expected to plateau or decline slightly year-on-year, as gas lines gain market share over liquids and station efficiency gains are realised internationally.

Installation activity in most regions is expected to increase, supported by continued product demand growth in both new and existing population centres, new and increasing hydrocarbon supply, and a shift in energy demand preferences towards gas.

Demand Shifting to Non-OECD Regions Population growth and overall energy demand con-

tinue to rise in non-OECD economies, particularly in the Asia Pacific region. This is driving additional infrastructure requirements of which transportation of fuel and products is an important element. In a number of Asia Pacific economies the level of de-velopment for product transportation infrastructure is still considered to be lagging behind existing demand, insulating the construction market further from near-term demand growth perceptions and commodity prices.

This summary of Douglas-Westwood’s World Onshore Pipelines Market Forecast 2015-2019 aims to provide an analysis of the pipeline market. The fifth edition of the World Onshore Pipelines Market Forecast presents a comprehensive view of the historic market from 2010-2014 and the forecast period from 2015-2019. A detailed database of projects, combined with an involved, bottom-up modelling and forecasting process, result in a unique view of the market in terms of length and value.

oct-dec 2015 21

A continuation of robust growth in non-OECD markets is expected to see Asia overtake North America as the largest regional market by Capex in 2015, although the volume of pipeline installations will remain higher in North America throughout the forecast period.

North America will suffer the greatest impact as a result of the decline in commodity prices. Drilling activity in the unconventional plays has reduced significantly since mid-2014 and production is also declining, including in the Bakken where pipeline infrastructure remains under-developed. Driven in part by a higher crude price beyond 2015, pipe installation demand is set to increase steadily in this region from 2016 onwards. In contrast, West-ern Europe Capex is in decline, a trend expected to continue over the next five years.

A significant increase in expenditure in other regions, particularly those with fastest economic growth, is likely to provide opportunities for indig-

enous and international players alike as infrastructure develops towards an established network of pipe-lines carrying both raw hydrocarbons and finished products. This includes Africa, Latin America and the Middle East.

Pipeline activity in the Middle East is currently growing at a faster rate than in any other region, a trend expected to remain over the next five years. Driving the market expansion is rising energy demand both within and in neighbouring regions, especially Asia, alongside strong growth in domestic hydro-carbon production. Iraq, Saudi Arabia and the UAE in particular have followed a strategy of increasing production in recent months with a positive impact in the near-term on pipe installations. The lack of political stability and security in many areas, in-cluding Iraq, Syria and Yemen, is still a key threat to pipeline projects, however. As the level of uncer-tainty increases, there is potential for further project disruptions. The removal of US and EU sanctions on Iran is likewise anticipated to boost activity in that economy although the majority of lines included in the DW forecast are export lines to the north and east of the country.

Key Trends Impacting the Nature of Pipeline Construction

With an anticipated 35% increase in global energy demand between 2010 and 2040, natural gas is expected to significantly increase its share of the energy mix – growing by 65% over the same pe-riod. This trend, observable in our previous edition of this report, is progressing as expected, driven in large part by non-OECD demand growth and technology advancements, including in liquefied natural gas.

Investment in new infrastructure to support LNG and unconventional gas developments will be a major factor shaping future demand for pipelines. Outside the major oil province of the Middle East, gas pipe-lines accounted for 62% of km installed over the past five years with this figure expected to increase to 66% for the 2015-2019 period. The reduction


in the oil price since mid-2014 has tempered the rise of gas demand to an extent, however, reducing investment in natural gas transport technologies. Less robust economic activity than expected in Asia has led to some delays in gas processing facility construction in that region, impacting our natural gas pipeline outlook. Despite this, gas installations are expected to increase by more than 20% in 2015. Furthermore, this constraining impact is anticipated to be short-term with industry fundamentals sug-gesting an increasing proportion of gas pipeline construction in the coming years.

While gas pipelines increase in volume, installa-tion of liquid lines is expected to contract by 15% in 2015, primarily as a result of a reduction in US demand associated with additional unconventional liquid production. US crude production reached a peak of 9.6 mmbbl/d in April 2015 but has been in steady decline since according to the Energy Information Administration (EIA) Short-Term Energy Outlook (September 2015), a trend expected to continue into 2016. Eastern Europe & FSU and Latin America are both expected to continue to invest in liquid pipelines in 2015, despite the lower price environment. Approximately 105,000 km of liquid pipelines are expected to be installed between 2015 and 2019.

The specifications of the pipelines themselves have trended towards large diameter lines over the past three years. This trend is expected to continue to 2016, reflecting a high volume of major pipe-line projects driven by historically high product demand growth in Asia and major additions to the pipeline networks in Eastern Europe & FSU and North America. In 2017 and beyond, smaller diameter pipelines are expected to gain relative market share driven in part by maturing networks within population centres of non-OECD countries and a return of US onshore production growth, requiring further development of smaller-scale midstream infrastructure within shale plays. This is likely to impact technology development for both construction and maintenance contractors.

We have seen lower steel prices and greater manufacturing capacity become available. Lower levels of near-term activity among tubular goods providers have released manufacturing capacity for line pipes. Lower than expected economic growth in Asia and reduced activity in North American unconventional production is expected to support this scenario in the short-term. There remains a low risk of delayed pipeline projects due to constrained capacity in the later years of the forecast which may reduce overall expenditure.

Geopolitics and Environmental ConcernsGeopolitics continues to challenge a wide

range of projects around the world. Due to the lack of an overarching authority or jurisdiction for transnational pipelines, geopolitical compli-cation is arguably the most difficult challenge to overcome, threatening the execution of ambitious inter-regional projects such as TAPI aiming to bring Turkmenistan gas to Pakistan and India via Afghanistan, and others. As a result, commercial interest must be the overriding driver for large transnational projects to be executed successfully as opposed to softer geopolitical interests.

The ongoing conflict between the Ukrainian Government and rebels with Russian sympathies in Eastern Ukraine has led to extensive sanctions on the Russian economy, imposed by North America and European governments. While this has limited some construction and maintenance activity in the immediate vicinity of the conflict, continued violence has led to increased political focus on alternative sources for European gas. This may provide upside to our forecast in the Middle East, North Africa and North America regions.

Environmental concerns remain a vital challenge for major pipeline projects with public opposition causing significant delays in the approval proc-ess. This trend is most often observed in highly regulated regions such as North America with the well publicised example of Keystone XL in the US.

oct-dec 2015 23

PP

Relative Stability, Despite Project DelaysWhile lower commodity prices threaten pipeline

construction projects, particularly in the US and Ca-nadian markets, global expenditure will continue to climb in 2015 and 2016 as sanctioned projects are delivered and international growth outweighs the contraction in North America. DW expects almost 309,000km of line pipe to be installed between 2015 and 2019, an increase of 11% compared to the previ-ous five-year period. The relative consistency of annual expenditure in the global pipeline market (relative to other sectors of the upstream and midstream oil and gas industry) and high volume will facilitate oppor-tunities for the supply chain around the world as the infrastructure network continues to grow.

This periodical thanks Matt Loffman of Douglas-Westwood for providing this article for publication. Matt has led a range of commercial due diligence and market intelligence studies focusing on inter-national drilling, pipeline services and downstream facility sectors. His previous experience includes posts as a consultant to the United Nations and to the Embassy of the Kingdom of Spain. In the past year, Matt has headed up global market studies relating to inline inspection services, cryogenic pumps, line pipe manufacturing and heat tracing equipment, amongst others. Matt is a graduate of the London School of Economics, a fluent Arabic speaker, and a member of the Society of Petroleum Engineers and of the Society for Underwater Technology.


A Pipeline Alternative to Asian LNG

ReportReport

Unprecedented growth in global liquefied natural gas (LNG) supply is adding 150 billion cubic metres (bcm) of LNG capacity that is already under construction or set to start in

the next four years. But prospects for further natural gas demand and, in particular, LNG growth in key regions, have never been so uncertain.

The pricing picture is in full swing, too, with an av-erage gap in 2013 between US and Asian gas prices of USD 12 per million British thermal units. This gap is responsible not only for the flurry of planned LNG projects targeting mostly Asia, but also for renewed Asian attempts to develop innovative and cost-cutting approaches to gas delivery.

Since the 1990s, the economic development of na-tions in the Association of Southeast Asian Nations (ASEAN) has led to a thirst for energy. The IEA expects more than 80% growth in regional energy demand through 2035 compared with 2011, as the economy triples and population expands by almost one-quarter. Coal will supply much of the new energy, but gas will also play a role, with 100 bcm in new demand lifting consumption to 250 bcm.

Early on in planning for the demand surge, ASEAN expected to rely on pipeline supplies. New output for distribution was, and still is, expected from the East Natuna gas field in the sea between Indone-sia, Malaysia and Singapore. So energy ministers announced the Trans-ASEAN Gas Pipeline (TAGP) system in 1999 to connect existing pipelines for

a fully integrated network that would also deliver supply from East Natuna. The region has extensive pipelines that in many cases cross borders – but such links are only binational. Aimed at enhancing security of supply and greater economic co-operation within the region, the TAGP is to connect gas reserves in the Gulf of Thailand, Indonesia, Myanmar and the Philippines to the rest of the region.

But over the past four years, LNG developed quickly as countries in the region built terminals, while the TAGP project lost steam. However, these terminals suffer from the inefficiencies of the global LNG mar-ket and are sometimes too large for smaller domestic demand centres. A 400 megawatt gas-fired plant needs about 0.4 bcm per year to run 5 000 hours per year – about four LNG cargoes per year.

New Relevance for A Regional NetworkWithin this context, a new IEA report, The Asian Quest for LNG in a Globalising Market, finds that the TAGP project could still be a valuable solution. The network could provide flexibility and diversity of supplies within the region, based on both LNG and the development of East Natuna with the TAGP as backbone. For example, the TAGP could facili-tate swapping gas within the region for an optimal allocation, through time or cargo swaps of LNG or via additional LNG imports through terminals in neighbouring countries.

The TAGP, however, faces several significant challenges:• overcoming technical issues such as different gas

As Southeast Asia pursues local solutions to meet surging gas demand, a 15-year-old effort to network the region’s pipelines gets a fresh look.

oct-dec 2015 25

quality and obstacles to developing East Natuna• reconciling differences in market structures and

pricing among countries• moving from the existing bilateral cross-border

pipelines system to an integrated and harmonised system

• harmonising regulation such as third-party access rules and regulatory authorities.

All of these issues limit the access of buyers, sell-ers or both from non-neighbouring countries to the imagined single network. In other words, many fun-damental issues limit third-party access and hence the move to an efficient integrated network.

Overcoming The Challenges to LinkageThe East Natuna field has been difficult to de-

velop, despite its substantial 1 300 bcm of natural gas. Located in a basin in Indonesia’s most northern territory in the South China Sea, it is far from the consuming areas. Another difficulty is the very high carbon dioxide (CO2) content of the gas, which would compound technical issues in aligning gas quality across the TAGP. In Singapore, for example, imported natural gas must comply with Gas Network Code specifications before it can be injected into the transmission system. The minimum methane level in Singapore is set at 80% of the volume, with CO2 no higher than 5%. But in Thailand, natural gas from onshore fields in the north-eastern part on average contains 76% methane and 13% CO2, while that from offshore fields in Myanmar contains 72.4% methane, 6.2% CO2 and 16% nitrogen.

The quality issue also applies to LNG. TAGP-facilitated swaps of LNG between terminals or between LNG and pipeline gas offer an opportunity to harmonise qualities system-wide. Without becoming an obstacle to new LNG supplies, quality could be managed at the import terminals before the gas is injected into the TAGP.

National Systems Impede RegionalisationPerhaps the greatest challenge for the TAGP is the

different market structures found among the ten ASEAN member countries. For example, besides national monopolies in several nations, Thailand and Indonesia have vertically integrated compa-nies, while Singapore is on a firm course towards

Singapore’s OpportunitySingapore is trying to establish Asia’s first natural gas hub, which would depend heavily on LNG supplies. But as an ASEAN member, the country is also involved in the TAGP project. Developing both LNG and the pipeline network could prove synergistic rather than competitive: the TAGP could link Singapore with gas fields and LNG regasi-fication terminals region-wide, enhancing supply security and diversity while increas-ing the hub’s liquidity. Further, a hub that provides a reliable, single-price reference for all TAGP transactions could end different cross-border price regimes, a key obstacle to the project’s success.

Over the longer term, Asia could have multiple trading hubs to capture differences among intraregional markets. Asia has no spot price, unlike Europe and North America, and the IEA is focused on the obstacles and opportunities for Asia-Pacific economies to establish natu-ral gas trading hubs that allow gas prices to reflect local and regional demand and supply.

But most of ASEAN is far from fulfilling what the IEA sees as necessary to establish a regional hub: hands-off government approach, separate transport and commercial activities, sufficient network capacity and non-discriminatory ac-cess, wholesale price deregulation, a competitive number of market participants, and involvement of financial institutions. Without improvement in these areas, the TAGP cannot realise the syn-ergies possible from a trading hub in Singapore or elsewhere.


deregulation with the unbundling of transport and commercial activities. Most countries do not provide efficient and transparent third-party access, even if there is regulation supporting this principle. Fulfill-ing the TAGP aim of a single network would involve harmonisation of regulatory oversight.

Other limitations to development are national poli-cies that favour domestic energy use before considering exports – policies that limit the most efficient allocation of gas within the region. The most common form of favouring domestic energy users is through subsidies, which many countries in the region use to protect gas consumers from higher international market prices, a trend likely to worsen as countries become increasingly reliant on imports.

Connecting these diverse markets through a single pipeline network would enable access to the various countries. But the distinctions among national market structures would limit that access, as the parties’ interests and risks vary. The absence of third-party access to the transmission grid in some countries would hinder the creation of an integrated network in which gas would flow to where the highest prices are paid, which would create additional challenges for the countries with artificially low prices.

Network Offers Option to Crowded MarketOver the medium term, gas markets of non-OECD

Asian countries will play a key role in attracting ad-ditional LNG supplies, according to an IEA report. For Southeast Asia, LNG will always be necessary, as it brings flexibility and matches some countries’ island geography.

However, ASEAN countries will be turning to a crowded market, as demand expands elsewhere, too. By 2019, total Asian LNG imports will near 150 bcm, more than Japan’s current world-leading deliveries. China will overtake Korea to rank as the second-largest overall gas importer behind Europe, relying on LNG as well as pipeline gas to maintain a diversified sup-ply mix and feed its gas-hungry coastal region, which

remains distant from pipeline or most domestic sup-plies. In India, LNG is the only likely source of imports over the medium term as pipeline projects remain a far-away dream.

As such, the requirements for ASEAN to develop import and transport infrastructure will be sig-nificant, and the competition for product high. As most Southeast Asian countries are interlinked bilaterally by pipeline, increasing these connections by reinvigorating the TAGP project can diversify delivery, buttressing the energy security crucial to the region’s economy.

This periodical thanks International Energy Agency for providing this article for publication. This article is by former IEA Senior Gas Analyst Anne-Sophie Corbeau and originally appeared in IEA Energy: The Journal of the International Energy Agency. Anne-Sophie Corbeau has left the IEA, joining the King Abdullah Petroleum Studies and Research Center as a gas expert. She previously worked at Cambridge Energy Research Associates and in Peugeot’s fuel cell and hydrogen department.

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oct-dec 2015 27

Demystifying PSM for an Enabled Workforce

ReportReport

Across the globe, demographic change contin-ues to pose a serious challenge to business continuity. A number of confluent factors contribute to this: rapidly aging workforces

and a retirement boom in developed economies; the lack of skilled workforces within process and extractive industries; increasingly stringent local employment requirements; and an increased reli-ance on contractors to perform specialized tasks. Such change has increased operational risk, as demonstrated by a review of recent major incidents. Human error was shown to be a major contributing factor to incidents.

Complicating matters further, many members of the process and extractive industries firmly believe that one has to be an engineer to understand the technologies and how they operate. As a conse-quence, only those with the appropriate educa-tion and/or technical qualifications are trained in advanced technologies relevant to the process and extractive industries and their applications. Some of these highly trained, experienced people are often reluctant to share their knowledge or experience concerning specific processes and the associated

risks of those processes within the organization. This lack of knowledge transfer has contributed to the current scarcity of required knowledge and skills, thereby compromising the operational safety of and augmenting risk profiles of many facilities.

While many companies understand the need to change their current learning and development ap-proach, the lack of a structured approach is hindering the developmental process. Organizations rely too often on discrete training initiatives and tend not to follow up with additional training to reinforce and sustain the skills required. As a result, money is often spent by an organization without actually getting appropriate returns – a skilled workforce. Learning and development need to be a strategic imperative that is given a priority similar to a company’s other strategic business goals. This focus on learning and development is particularly critical in the area of Process Safety Management, in order to minimize the risk of catastrophic incidents.

A structured approach to learning and develop-ment will help improve organizational performance by identifying and developing the skills, behaviors

There are many contributing factors challenging business operations. The lack of skilled workforces and knowledge transfer in Process Safety Management (PSM), in particular, has contributed to the current scarcity of the required knowledge and skills. If the situation continues, it could potentially compromise the operational safety and increase risk profiles of many facilities. Many companies understand the need to change their current learning and development approach. Organizations rely too often on discrete training initiatives and tend not to follow up with additional development to reinforce and sustain the skills required. This paper demonstrates the importance of enabling the workforce to effectively implement Process Safety Management, by way of a structured learning and development approach, in order to ensure that business and operational continuity are maintained.


and competencies needed to support the company’s business objectives. Improved organizational per-formance can be achieved by institutionalizing a learning and development function that focuses on professional development and building foundational knowledge and skills, particularly in the area of process safety. This assumes particular significance in light of the recent spate of process incidents, as well as the potentially catastrophic impacts a process safety incident can have upon workers, local com-munities and the company’s bottom line.

Why Process Safety Management is Critical The heart of Process Safety Management (PSM) is

about recognizing the hazards and associated risks within an organization. Most people consider PSM to be a safety requirement rather than an operations requirement. In fact, PSM impacts both the safety of the organization and its operations. An effective PSM system allows operations to run smoothly, contributes to increased productivity and efficiency, and thus extracts more value from the assets. But, if PSM is not implemented with rigor and discipline, it enhances risk and negatively impacts the productivity and efficiency of an organization. PSM contributes to the protection of assets, directly and indirectly.

An interesting example of risk can be found with a pressure cooker that we use at home. In order to cook, we add some water, rice or vegetables to the pot, and then start heating. The pressure builds up and the steam helps to cook the contents faster. Over a period of time, the gasket in the pressure cooker starts to wear down and when that happens, steam starts leaking. This contributes to increased time and energy required to cook the same amount of food. And further, the leakage of steam contributes to the risk of injury. What can happen in the workplace is similar to what happens with pressure cookers, but multiplied exponentially in terms of intensity and impact.

Demystifying PSM Organizations and individuals spend too much

time and effort developing standards and proce-

dures. And when an incident occurs, it results in more procedures, and more documentation. As illustrated in Figure1, organizations tend to focus their time and resources on managing operations, incidents and emergencies, when in fact, it’s more important to recognize risk and the conditions in which a potential risk could occur.

Recognizing potential risks requires an under-standing of the hazards of materials, equipment design basis and process design basis. This risk determination provides a fundamental basis to dif-ferentiate potential risks by level of severity and by likelihood of occurrence, and then allocate resources accordingly based on these two factors. If the risk is higher, then there is an obvious need to have more layers of protection and detailed plans in place. This risk assessment helps ensure that time, money and resources are spent based on the level of risk and that the appropriate return on investment is realized.

Individual risk perception varies significantly depending upon what the individual has experi-enced in the past. An organization is comprised of many individuals, each with varying perceptions of risk. Accordingly, an employee who has worked in hazardous environments, with little or no prior repercussions, may be daring and take significant

oct-dec 2015 29

risks while working. Another person, who has ex-perienced significant incidents and has not been exposed to hazardous environments, may be afraid to work in a particular area. The risk matrix should be appropriate to the nature of the risks and based on the acceptable level of risk from the collective organization and its leadership, taking into account legal considerations. This helps build risk awareness that is consistent across the organization and uses practical tools and examples that employees can relate to on a day-day basis.

A comprehensive Process Hazards Analysis (PHA) and its results should drive the design and implemen-tation of the balance of the process safety require-ments—standard operating procedure and safe work practices; mechanical integrity and quality assurance; training of personnel including contractors; incident management, changes in technology, facilities and personnel; and emergency management. Over the years, DuPont has realized the importance of engag-ing people down the line, including operators/techni-cians in PHA, to create a better understanding and appreciation of risks and “why” they are expected to perform their actions in a particular way. By engaging the workforce, a sense of ownership and an element of pride are created that is a win-win both for the employee and the business.

Building a Business Case for PSM A strong business case can be built for the im-

plementation of or improvement of a PSM system.

The business case combines financial, functional and emotional elements (Figure 2).

The Financial Case For the financial case, an analysis of process safety

incidents can be quite revealing in terms of the po-tential financial impacts of not implementing PSM. To quantify risk and potential monetary implications, one should look at the potential direct and indirect consequences of an incident or an event rather than only the direct results of an incident that has occurred.

The Functional Case The functional component of the business case

addresses the need for a structured framework for managing process safety. A structured framework facilitates decision making on a daily basis and reduces the degree of uncertainty in taking appro-priate actions without fear of reprisal. For example, employees are often confused about their priorities due to the mixed signals they sometimes receive from their line managers versus the safety manager. Workers understand the importance of continuing production, but when something goes wrong, such as an equipment malfunction, employees may feel as though they will be blamed for any stoppage.

The Emotional Case The emotional element of the business case has

become top of mind in recent times. Many CEOs have remarked that what keeps them awake at night is think-ing about the potential impact of a single incident that could cause injury to 10-20 people and/or destroy the facility and consequentially the business itself. And CEOs obviously do not want their legacy tied to a catastrophic incident that occurs during their tenure.

Enabling the Workforce to Effectively Implement PSM

In order to ensure the effective implementation of PSM, it is important to ensure that all levels of the or-ganization understand the consequences of following or not following prescribed PSM requirements and the impact these consequences can have on the business – injury, reputation, and cost. And it is equally important that employees receive the critical training, coaching and mentoring to build skills and competencies in order to avoid negative consequences.


A structured process is essential to build the skills and competencies required to effectively implement PSM. As illustrated in Figure 3 the organization must assess the learning and development needs.

Mapping the critical functions and PSM critical skills required by the organization is a good starting point (Figure 4).

It is important to consider the following elements when compiling the inventory of skills: complexity of the skills, skill maturity period, availability of resources with existing PSM skills and attrition rate. This exercise should provide an overall view of the size of the chal-lenge ahead for companies.

While it is not possible, or necessary, to make eve-ryone a PSM expert, developing a PSM competency model, one that is customized to the organization and to the particular sites will help address employee needs. The competency model should take into account the various roles and the levels of awareness, knowledge, skill and expertise required to implement and maintain PSM (Figure 5).

It is not practical to build skills and competencies overnight especially in the area of PSM. So the com-petency model should be used develop an overall roadmap that extends to a 3-5 year horizon for building the skills and competencies required.

Finally, the learning and development curriculum is then designed based upon these three inputs: inventory of critical functions and skills, competency building roadmap and the level of competencies required for the overall organization. It should be strongly emphasized that this process, and the corresponding curriculum, is NOT about training! Training contributes to about 10% of the development process. The learning and devel-opment curriculum may start with training, but must include frequent reinforcement and refreshing in the form of coaching and mentoring on the job –where the bulk of the learning occurs.

This structured approach to learning and develop-ment creates the opportunity to develop people, and more importantly, creates a pool of future talent.

oct-dec 2015 31

PHA is one area in which the skill development period is quite long and hence, the planning process will help to introduce sufficient new talent early enough to ensure adequate resources are available.

It is important to develop metrics that will evaluate the effectiveness of the organization’s learning and development program. This can be done through a combination of leading and lagging metrics. For example, the number of overdue PHAs that result due to lack of availability of competent resources could be a leading indicator.

Conclusion This paper demonstrates the importance of enabling

the workforce to effectively implement PSM. In order

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to build the capability and improve the productivity of an organization, individual employee skills and capabilities must be developed and prioritized as a key business imperative. A structured learning and development process helps ensure that business and operational continuity are maintained. The im-plementation of a structured learning and develop-ment process will also motivate, engage and build the skills of employees, and should result in a safer, more productive organization.

This periodical thanks Mr. Srinivasan Ramab-hadran, Global Practice Leader for Process Safety Management, DuPont Sustainable Solutions for providing this article for publication.


delivered on time and within budget, we have a strong base for consolidating our position in the region.

“Our track record is estab-lished for providing safety critical isolation services that enable urgent maintenance work to be completed, within schedule and with minimal outage to production.

“There is huge potential to introduce our Remote Tecno Plug isolation technology to the broader Asian and Australian onshore market building on the success we have enjoyed in Malaysia.”

Technip Awarded an Important Flexible Pipe Contract for Layang Development

Technip has been awarded an important subsea con-tract by JX Nippon Oil and Gas Exploration (Malaysia) Ltd in the Layang field, Block SK10, offshore Sarawak, Malaysia at a water depth of 85 meters.

The contract covers the engineering, procurement, fabrication, installation and commissioning of three flexible pipes totaling 9.9 kilometers. The flexible pipes consist of two production risers and flowlines and one gas export riser and flowline, connecting shallow water platforms to a new FPSO.

The Group will leverage its unique subsea integrated approach, as Technip’s operating center in Kuala Lumpur, Malaysia, will execute the contract, while the flexible flowlines will be produced in Asiaflex

Pipelines in the PipelineSTATS Group Plugs Gap in Malaysian Pipeline Isolation Market

Pipeline technology special-ist STATS Group has seen a sharp upswing in demand for its Remote Tecno Plug isolation technology in Malaysia.

In the last nine months STATS has completed seven pressurised pipeline isolation projects on behalf of a major oil explora-tion company facilitating the safe and efficient replacement of 17 valves.

The onshore and offshore projects, which have been com-pleted on the Malaysian Penin-sular and in Sarawak, deployed STATS’ DNV GL type approved Remote Tecno Plugs ranging in size from 24” to 32”.

Established 17 years ago, STATS Group work in all major oil and gas producing regions across the globe and have extended their original North Sea operations to encompass bases in Canada, USA and the Middle East.

The company believes its success in the Malaysian market will act as a springboard for further contract wins in Asian and Australia and will strengthen their commitment to the region by establishing an opera-tional base in Labuan and a technical support and sales office in Kuala Lumpur.

Ron James, sales director, said: “This has been our busiest period in Malaysia and with all projects

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oct-dec 2015 33

Products, Technip’s manufacturing facility in Tanjung Langsat, Johor, Malaysia.

The installation campaign will use the Group’s mul-tipurpose vessel, the Deep Orient and the project is scheduled to be completed in the second half of 2016.

KK Lim, President of Technip in Asia Pacific, com-mented, "We are delighted to work with JX Nippon Oil and Gas Exploration and its main partner Petro-nas Carigali Sdn Bhd (PCSB) on this project which is awarded under the “Flexible Pipes Framework Agree-ment” signed with PCSB last year. It demonstrates the competitiveness of our flexible pipe technology for shallow water developments and the advantages of our unique subsea integrated approach as a one stop solution for cost-effective field developments”.

Alam Maritim Wins PETRONAS Malaysia Pipeline Job

Alam Maritim Resources Berhad has received a letter of award from Malaysia’s national oil company Petronas for a pipeline extension project in Malaysia.

Namely, Alam Maritim will provide engineering, procurement, construction, installation and commis-sioning (EPCIC) services for a 10-inch X 1km pipeline for the Terengganu Crude Oil Terminal. Terengganu condensate is produced offshore in South China Sea, East of Peninsular Malaysia.

According to Alam Maritim’s Bursa Malaysia filing on Tuesday, the contract value is approximately RM26 million ($6.1M). The effective date of the contract is October 8, 2015.

Physical execution is expected in March 2016, while the work is expected to be completed by the end of June 2016.

Jemena Wins Bid to Build $570M Gas Pipeline in Australia

Australia's Northern Territory government in mid-November chose Jemena, a company owned by State Grid Corp of China and Singapore Power, to build an

A$800 million ($567 million) pipeline to the country's east coast gas markets.

Jemena beat rival bids from APA Group, DUET Group, and a Chinese consortium PCP Australia, which included state-owned China National Petroleum Corp.

The 622-kilometre (386-mile) pipeline will run between Tennant Creek in the Northern Territory and Mount Isa in Queensland, Chief Minister Adam Giles said in a statement.

The Northern Territory is estimated to hold more than 200 trillion cubic feet (Tcf) of gas resources on-shore, which it says would be enough gas to power Australia for more than 200 years, and has more than 30 Tcf of gas offshore.

PETRONAS Awards Two Multi-Year Contracts to APS

APS Malaysia (APSM) was awarded two multi-year contracts for the production and installation of the InField Liner® technology worth in excess of 150 million USD for the rehabilitation of various 6”, 8” and 10” subsea crude oil gathering and high pressure gas and condensate lines, varying in lengths from 700 meters up to 3500 meters at the end of November.

InField Liner® is a flexible Kevlar reinforced liner

installed in existing subsea pipelines, once installed the liner then acts as a corrosion barrier, providing protec-


The Lao government and private businesses have worked with the Vietnamese side to develop the project, which is estimated to require between US$300 and US$500 million of investment.

The 290 km pipeline will transfer oil from Hon La seaport in Vietnam's Quang Binh province to Kham-muan province.

Dr Khammany said the project developers are plan-ning to construct a refinery to refine the crude oil in Laos. Both refined and crude oil will be transfered through the pipeline system.

He said officials in charge are currently contacting countries which have crude oil in preparation for the project. Russian investors are interested in joining the venture in refining crude oil in Laos.

It was reported previously that the Lao and Vietnam-ese governments agreed to establish a subsidiary of the Lao Petro Company, a Lao project developer, in Vietnam to manage the project.

The project's warehouse in Laos to store the oil will be built in Nhommalath district, Khammuan province, about 30km from the Laos-Vietnam border.

Land allocation that will be used to build the ware-house at the Hon La seaport was also agreed upon.

The bonded warehouse at Hon La seaport is expected to be capable of storing 300,000 to 500,000 cubic metres of fuel products. Another 100,000-200,000 cubic metre warehouse will also be set up in Kham-muan province, according to Tuoi Tre News.

A bonded warehouse is a building in which duti-able goods may be stored, manipulated, or undergo manuf acturing operations without payment of duty.

Construction of the pipeline and warehouse facili-ties is expected to be completed in 2018, according to Tuoi Tre News, which cited a report presented at a ceremony last year when Lao Petro Company signed

tion against aggressive service conditions and extending the use of the pipeline beyond its original design life.

The liner system has been independently tested by a third party to meet oil and gas industry standards API 17J (2008), 15S 2006; DVGW G 469-2010; DIN 53536 (1992) and ASTM F1545-97, D4060, D1599-99. It can extend the lifetime of existing pipelines by up to 30 years.

InField Liner® was successfully piloted at PETRONAS Carigali Sdn Bhd’s (PCSB) Samarang field in September 2013 and a commercial trial deployed at West Lutong field in November 2014.

On the back of the recent successful internal ap-plication of this highly innovative technology and the subsequent large contracts award to APS, PETRONAS has further granted APS a global 20-year exclusive license to apply the technology for other oil and gas operators.

Through this exclusive licensing agreement, APS will manufacture and market worldwide the InField Liner®, PETRONAS’ proprietary subsea pipeline rehabilitation system with internal liners. The agree-ment was formalized at a signing ceremony held at the Malaysian Petroleum Club, KLCC, PETRONAS Twin Towers.

Action Set to Begin for Laos-Vietnam Oil PipelineImplementation is set to take place to carry out

the planned oil pipeline project, which will involve the building of an oil pipeline s ystem connecting a seaport in central Vietnam to the Lao central province of Khammuan, the Minister of Energy and Mines said.

Dr Khammany Inthirath told local media that con-struction of the project is expected to begin soon. It was reported previously that construction was expected to begin within this year.

He spoke at a press conference during his attend-ance at the three-day meeting between the government cabinet, Vientiane Mayor and provincial governors.

oct-dec 2015 35

a contract that tasked Slovakia's Energy Commodities to complete a feasibility report on the project.

The project is expected to cut the cost of transport for oil products and ensure energy security for Laos.

It will also boost bilateral trade between Laos and Vietnam, as well as stabilise and develop the Lao energy industry.

Iran in Talks for $4.5-billion Undersea Gas Pipe-line to Gujarat

Iran is discussing a plan to lay a $4.5 billion subsea pipeline to export natural gas to India, but the proposal of another pipeline between the two countries through Pakistan is off the table due to waning Indian interest, National Iranian Gas Export Company's managing director Alireza Kameli said.

"We are negotiating with our counterpart SAGE company on behalf of Indian gas consumers to dis-cuss about laying the sea pipeline from Iran to India," said Kameli.

New-Delhi-based SAGE, or South Asia Gas Enterprise, is the leader of a private consortium that has been marshalling support for an undersea pipeline between Iran and India for years and is pinning hopes on the waiver of sanctions imposed by the Western nations on Iran to help expedite the project.

The proposed Iran-India subsea pipeline, with a carrying capacity of about 31 million cubic metres of gas a day, can be constructed in about two years after the policy, financing and purchase.

"These are all geopolitically sensitive projects, but now the time has come because Iran sanctions are going away," said Subodh Kumar. Jain, director at SAGE, has appointed SBI Cap as its financial adviser for the project.

Jain said he is hoping to tie up finances for the project next year and build the pipeline in about five years.

SAGE's pipeline will be a common carrier with an expected transit fee of about $2.25 per unit.

MPG Pipeline Names Dan Murphy Quality Assurance Manager

MPG Pipeline Contractors, a leading North American pipeline contractor, has named Dan Murphy as quality assurance manager in its Houston office.

Murphy will enhance and implement a compre-hensive quality assurance program to manage qual-ity control, ensure traceability of components and materials and organize construction turnover through commissioning and startup functions.

“Dan’s expertise in building and implementing quality assurance programs for oil and gas industry clients makes him an invaluable asset for our MPG team,” said Jimmy Fontenot, president, MPG Pipeline Contractors. “An even more effective quality assur-ance program will not only improve the quality of MPG products and services but will also strengthen the value of our company operations and enhance customer satisfaction.”

Murphy joins MPG with more than 30 years’ expe-rience in operations, quality assurance, engineering and project management. Most recently, he worked as the compliance and quality manager for TransCanada Pipelines Ltd.

Murphy holds a Bachelor of Science in electrical electronics engineering and a Master of business ad-ministration from the University of Houston, as well as a Master of Science in quality assurance from Southern Polytechnic State University in Marietta, Georgia.

“MPG has a two-tiered approach for long-term success including proactive improvements and strategic growth,” said Fontenot. “MPG’s quality assur-ance program is atypical in the pipeline industry and the proactive implementa-tion will benefit MPG’s customers while

exceeding industry regulations.” PP


Two New Ways for the Pipeline Industry to Cut Costs and Complexity

TechnologyTechnology

Pipeline development projects are becoming increasingly complex, spanning longer and deeper terrains. Pipelines must operate at higher pressures and temperatures, in harsher

environments and to stricter regulatory requirements. Projects must also be feasible in a cost-constrained market. DNV GL is inviting industry players to take part in two Joint Industry Projects (JIP) to help the industry work more efficiently while maintaining safety.

The first JIP will reduce uncer-tainty in tensile testing results and the associated costs of inac-curacies and delays, while the second will help operators save time and money in adapting to new industry requirements.

Gaining Confidence in Tensile Testing Results

Tensile test results are a ma-jor contributing component to pipeline design and operation, as the pipeline’s strength must be suitable for containing the internal pressure of the liquid or gas. The issue of inconsistent yield strength results from tensile testing of line pipe has been

identified by Federal regulators in the US. This JIP will study the standardization of tensile testing parameters and calibration specimens.

Inaccurate yield strength measurements can have significant negative implications for a pipeline project, ranging from schedule disruptions and commercial disputes to unanticipated costs and potential regula-

tory challenges. Current industry standards allow a wide range of tensile testing parameters, creat-ing variability and uncertainty in the test results.

The Standardization of Flat-tened-strap Tensile Testing of Line Pipe JIP will investigate dif-ferent tensile testing variables that affect results, including material properties, sample flattening and preparation practices, testing equipment and testing procedures. The objective is to establish testing parameters and procedures to reduce the variability in yield strength results for large diam-eter line pipe. The results will be applicable to both onshore and offshore pipelines.

DNV GL who are very active in initiating Joint Industry Projects (JIP) have released information on two upcoming JIPs.

oct-dec 2015 37

Standardization of Flattened-Strap Tensile Testing Of Line Pipe

Flattened transverse test specimens are typically used to measure the tensile properties, including yield strength, of large diameter line pipe. The maximum allowable operating pressure (MAOP) of a pipeline is based on the specified minimum yield strength (SMYS), which is verified by tensile testing. However, the absence of standardized sample flattening procedures and wide ranges of testing parameters in the applicable industry standards has been known to produce significant variability in measured yield strength. The negative implications of inaccuracies in yield strength measurement have often resulted in project disruptions, commercial disputes, unanticipated cost, and potential regulatory challenges. This JIP seeks to minimize the variability in tensile testing so that results are more reproducible and indicative of line pipe performance.

In a 2009 Advisory Bulletin issued by Federal Regulators in the US, the potential for low and variable yield strength line pipe was identified. A previous JIP by DNV GL was conducted to study the variability in yield strength test results measured using flattened-strap specimens however, the effects of tensile testing equipment were not included.

ObjectivesVariables that affect the measured yield strength using

flattened-strap specimens, including those introduced by material properties, sample flattening and preparation practices, testing equipment, and testing procedures will be studied in this JIP. The objective of this JIP is to establish testing parameters and procedures that minimize variability in yield strength results for large diameter line pipe.

The deliverable for this project will include testing requirements suitable for use by pipeline operating com-panies during the purchase of new line pipe and during testing and analysis of existing line pipe. Additionally, the participation by NIST personnel and Earl Ruth will ensure that the deliverable for this project will be suitable for con-sideration by industry standards committees for inclusion in current or future standards or recommended practices.

Scope of WorkThe scope of this project will include the development

of a calibration sample, designed by NIST, to test tensile testing machine compliance or stiffness, which has been shown to influence test results. The calibration sample will allow for better quantification of the variability in flattened-strap tensile test results due to machine variability.

Additionally, individual, controlled studies will be performed to quantify the variability of test results due to specific parameter changes. Examples of parameters which may be studied include:• Extensometer type and placement• Type of grips and specimen alignment

• Strain rate or cross-head speed• Degree of sample flatness• Extensometer gauge length as compared to sample

gauge length• Effect of test specimen shape

Alternate studies may be performed based on the in-terest of the JIP participants. Depending on the number of participants, the scope may be expanded to include additional areas of interest.

Finally, a limited round-robin study will be performed to quantify the variability of flattened-strap tensile test results across the industry. Participants chosen for the round-robin will be accredited to ISO/IEC 17025, General Requirements for the Competence of Testing and Calibra-tion Laboratories, by an accreditation body who is an In-ternational Laboratory Accreditation Cooperation Mutual Recognition Arrangement (ILAC MRA) member. The use of accredited laboratories will allow for the project results to be reviewed by industry standards organization(s) for potential revisions to the standards.

BenefitsStandardization of test procedures can minimize

variability in yield strength results and their associated liabilities. As a result, improved test methods establish-ing accurate yield strength determination will minimize unanticipated pipeline project delays and costs associated with new and existing pipelines. Furthermore, reduced variability in test results will allow pipe manufacturers and third party test labs to provide test results that more closely reflect the actual distribution of pipe yield strength and are indicative of line pipe performance.

The project is expected to start in the fourth quarter of 2015 and be complete within 18 months.

Project Team MembersDNV GL is pleased to announce collaboration with the

following on this JIP:

The National Institute of Standards and Technology (NIST), Material Measurement Laboratory (MML) Founded in 1901, NIST is a non-regulatory federal agency within the U.S. Department of Commerce. NIST's mission is to promote U.S. innovation and industrial competitiveness by advancing measurement science, standards, and technology in ways that enhance economic security and improve our quality of life.

The Material Measurement Laboratory (MML) serves as the national reference laboratory for measurements in the chemical, biological and material sciences through activi-ties ranging from fundamental and applied research, to the development and dissemination of certified reference materials, critically evaluated data, and other programs and tools to assure the quality of measurement results.


“The project will ensure that the tensile testing results are both more reproduceable and indicative of line pipe performance. It will reduce the uncertainty of the results and give pipeline operating companies the confidence they need when purchasing new line pipe as well as during the testing and analysis of existing pipe, ultimately saving time and cost,” says Melissa Gould, Senior Engineer, DNV GL - Oil & Gas.

The JIP will be carried out in conjunction with recognized parties such as the US National Institute of Standards and Technology (NIST) Material Measure-ment Laboratory (MML) and the former chair of the ASTM (American Society for Testing and Materials) Committee E28, Earl Ruth. The project is expected to last for 18 months and the results will be suitable for incorporation into standards and recommended practices, as applicable.

Standardized Approach to Meet New Requirements for Girth Weld Repairs

The requirements for girth weld repairs in the 21st Edition of API-1104 are much more comprehensive than those in the 20th Edition. The changes place more requirements on repair welding which, for a typical pipeline operator, will necessitate the qualifi-cation of a comprehensive suite of repair welding procedures. The JIP will include the development and qualification of these procedures and industry best practice. The offshore and onshore pipeline industry is adapting to the updated requirements for repair welding in the Twenty-First Edition of the API Standard 1104, “Welding of Pipelines and Related Facilities”. The updates place more requirements on the qualification of repair welding procedures and welders.

The JIP on the Development of Industry Best Practice for Girth Weld Repairs will, in cooperation with pipeline engineering specialists Kiefner/Applus RTD, address the technical aspects of girth weld repairs and the practi-cal aspects of repair welder qualification during the construction of new pipelines. The project is expected to be concluded within 18 months and will result in procedures and guidelines to help the industry meet the new API 1104 requirements.

Development of industry best practices for girth weld repairs

The requirements for girth weld repairs in the Twenty-first Edition of API 1104 are much more comprehensive than those in the Twentieth Edition. The half-page section in the Twentieth Edition is now ten pages long in the Twenty-first Edition. The changes place more requirements on repair welding practices that, for a typical pipeline operating company, will necessitate the qualification of a comprehensive suite of repair welding procedures. The proposed JIP will include the development and qualification of these procedures to the requirements of the Twenty-first Edition of API 1104 on a cost sharing basis.

In a recent Advisory Bulletin pertaining to pipeline construction quality issues, repair of pipeline girth welds was identified as an area of concern by Federal Regulators in the US. API 1104 was subsequently revised for the Twenty-first Edition to provide stricter requirements and more guidance for repair welds. The revisions provide more detail in terms of what constitutes a repair (including types of repairs), what level of authorization is required for various types of repairs, how to qualify repair welding procedures, and how to qualify repair welders. While the Twenty-first Edition of API 1104 was published over a year ago, it has not yet been incorporated by reference into Federal regulations in the US. As a result, many pipeline operators have not yet adopted the more-comprehensive requirements for girth weld repairs in the Twenty-first Edition.

Repair welds are often made under more challeng-ing conditions than production welds, which can potentially reduce the quality of completed welds. Factors that make repair welds more challenging to make include excavation geometries (produced

oct-dec 2015 39

PP

by hand grinding), particularly for the root region of through-wall repairs, restraint provided by surround-ing weld metal (higher levels of residual stress), and thermal severity (faster weld cooling rates) caused by surrounding weld metal.

Scope of WorkThe objective of this project is to develop indus-

try best practice for repair of pipeline girth welds during new construction activities. The scope of this project will include the development and qualification of a comprehensive suite of repair welding procedures in accordance with Section 10 of the recently-released Twenty-first Edition of API 1104 – Welding of Pipelines and Related Fa-cilities – that covers a wide range of applications. A guideline for selecting an appropriate procedure for a given application will also be developed. The scope will also include the development of guid-ance pertaining to other technical aspects of girth weld repair and repair welder qualification (e.g., preheating requirements, inspection requirements, time delay prior to inspection, minimum-required and maximum-allowable repair length, practical limits on wall thickness, etc.) that will be used to develop a generic company specification for repair of pipeline girth welds during new construction.

The primary deliverables of this project will be as follows:• A compendium of repair welding procedures quali-

fied in accordance with the requirements of Section 10 in the recently-released Twenty-first Edition of API 1104 that covers a wide range of applications

• A guideline that can be used to select the appropri-ate repair procedure for a given application

• A guidance document to address the technical as-pects of girth weld repair and the practical aspects of repair welder qualification

Repair procedures for each type of repair listed in Section 10 will be qualified for each of the material

groupings listed in Section 5.4.2.2 of API 1104 in ad-dition to repair procedures for Grades API 5L X65 and X70. This effort will focus on repair of manual welds made using shielded-metal arc welding (SMAW) and cellulosic-coated electrodes. Repair procedures for mechanized gas-metal arc welds (GMAW) for materials grades from API 5L X52 through X70 will also be qualified. The following repair options will be explored:• Repair with cellulosic-coated electrodes for specific

applications with guidance on mitigating the risk of hydrogen induced cracking

• Repair with conventional low-hydrogen electrodes• Through wall repairs using combination processes

(cellulosic-coated electrodes for the root and hot passes followed by low-hydrogen electrodes for the remainder of the passes)

Depending on the number of participants in the JIP, the scope may be expanded to include additional areas of interest such as:• Repair using low-hydrogen vertical down electrodes• Repair using gas metal arc welding and/or flux- cored

arc welding• Repair using gas tungsten arc welding• Repair of sleeve fillet and branch groove welds• Repair of higher-strength materials (e.g. X80)• Repair of welds made between line pipe and fittings

(e.g. elbows, bend, flanges, etc.)• Repair procedures for specific material property

requirements including toughness and hardness

BenefitsDevelopment and qualification of repair welding

procedures in accordance with Section 10 of the recently-released Twenty-first Edition of API 1104 fulfils an industry need and a JIP allows this to be done on a cost-sharing basis. The development and use of industry best practices for repair of pipeline girth welds during new construction has the potential to reduce cost and will increase safety, reliability, and quality of completed pipelines.

“Repair welds are often made under more challenging condi-tions than production welds, which can potentially reduce the quality of the completed welds,” says Brad Etheridge, Senior Engi-neer, DNV GL – Oil & Gas. “The project fulfils an industry need Bradley Charles Etheridge

to meet new requirements and has the potential to reduce cost and complexity, increase safety and reliability, and deliver better quality pipelines.”

This periodical thanks DNV GL. for providing this article for publication.


Monsoon Can’t Deter Remediation of Exposed Gas Pipeline on Indian Beach


Abeach in a highly populated tourist area is hardly an ideal work site. But when a 42-inch gas pipeline laid parallel to the sea-shore shifted and became exposed on the

beach near Ubhrat, India, crews had to overcome several unique chal-lenges posed by the surrounding land-scape and notable environmental forces to ensure a safe in-tervention. Rough seas due to mon-soon, cyclonic storm, high tides, and sour gas notwi ths tand-ing, the urgency of the repair left little room for error.

Th i s p a r t i c u l a r

trunk line was completed in 1996. By 2015, the pipeline had shifted approximately 25 m (82 ft.) from its original position and could be seen moving considerably with the tide. In addition, the rising sea level exposed the pipeline in the beach area. This caused a very tense situation around the beach and within the surrounding community, as the au-thorities immediately put the beach under constant observation over the threat of rupture and possible

explosion – and kept it safe until a new pipeline could be commissioned.

In order to carry out the remediation while limiting the amount of downtime and protecting the environ-

ment, the pipeline operator, its engineer-ing consultant, and the main contractor worked with global pipeline solutions pro-vider T.D. Williamson (TDW) to develop a safe remediation.

To accommodate for the unique nature of the work site conditions, the TDW team created a customized solution that included hot tap-

ping and then isolating the line using double block and bleed methodology, including the STOPPLE® II plugging system. The solution used a double STOPPLE isolation unit at one end and single unit at the other. According to George Easo, TDW project manager, this enabled the repair work to be carried out quickly. As a result, production from the pipeline was shut down for only 21 days, allowing the operator to maintain its reputation for safe operation in the community.

A natural gas trunk line was only shut down for three weeks, despite weather and complex repair required. This article outlines the project briefly.

oct-dec 2015 41

TDW Plugging SystemsUtilizes proven TDW STOPPLE® technology

to provide the safety of inserting two plugging heads through a single fitting. TDW STOPPLE® plugging machines serve as a temporary block valve to isolate a section of line during scheduled maintenance, retro-fitting, new construction, alterations and unplanned emergencies without interrupting service. Introduced in the early 1950's, STOPPLE® plugging technology remains the most reliable and widely used method of isolating a section of pipeline.

The remediation also helped prevent a potential environmental incident. As predicted, the weakest portion of the line – the insulation joint (IJ) that isolates the offshore and onshore sections – inevitably ruptured in the midst of the hot tapping process.

“We already had our double block and bleed iso-lation system installed and pressure-tested, on the upstream location,” Easo recalls. “This helped the operator isolate the leaking section at short notice to facilitate the venting, cold cutting, welding of new section, charging, and commissioning.”

Under tight deadlines and harsh environmental conditions, the TDW crew began the challenging task of welding. This involved preheating the fittings at an elevated temperature before welding, in preparation for tie-in of a new section of pipeline. TDW facilitated the replacement of a 1.2 km (0.75 mi) section of pipe on the beach using application-specific hot tapping and line isolation systems, including 42-inch NACE-qualified STOPPLE fittings.

The section replacement was complete July 31, 2015, the line was purged, and gas was charged into the new section. Once the operator verified the safety and integrity of the pipeline, the well was made op-erational that same day.

“The timeline for completion of the job set by the operator was critical due to the health of the damaged section,” notes Easo. “T.D. Williamson worked closely with the engineering consultant, contractor, and the operator to successfully complete the project on the planned date.”

This periodical thanks T.D.Williamson. for providing this article for publication.

PP


Ground-Breaking Welding Operations On Cracked Live Subsea Gas Pipeline


At the end of last year, DCN was awarded the largest EPIC contract in the company's his-tory. The Indonesian state-owned company PGN (Perushaan Gas Negara), specialists

in the transport and distribution of gas, awarded DCN the order to seal a tear in a seven-year-old gas pipeline located on the bed of the Java Sea. The crack had been discovered in 2013, and temporarily sealed using a Plidco clamp. The gas that flows through the pipeline is delivered to the Indonesian capital city of Jakarta. Switching to another pipeline was not possible, so one of the requirements imposed by PGN was that through-out the repair, the gas supply had to be continued without interruption. In other words, the pipeline had to remain fully pressurised, or the 29 million residents of Greater Jakarta would have experienced considerable, long-term problems.

Hyperbaric CentreTo be able to meet this requirement, DCN proposed

carrying out the welding work underwater, in dry conditions, through the use of what is known as a habitat. A habitat is a sealed working space that

offers divers a safe and protected working environ-ment, while on the sea bed. Others viewed the proposed alternatives with considerable scepticism, and instead opted for a far more costly and complex alternative that involved installing a bypass.

"DCN was the only company that met the require-ments imposed by PGN, with its repair proposal,"

DCN International Diving and Marine Contractors recently developed and employed a unique method that made it possible to repair a crack in a 32-inch gas pipeline three times more cheaply than by installing a bypass. Engineers from the Dutch company came up with a completely new application for an existing concept. Thanks to a number of innovative alterations, DCN was able to introduce the method in the Java Sea, where an extremely critical repair could be carried out on a live operational gas pipeline. For the client, the new method meant a saving of millions. DCN director Wim Vriens talked about this remarkable example of underwater innovation.

In Bergen op Zoom there is a full hyperbaric test center.

oct-dec 2015 43

explained Wim Vriens. Because gas supplied to Jakarta is entirely dependent on this one pipeline, PGN demanded precise preparation of all work, including facilitation of simulated test conditions. As Vriens continued: "The fact that we are the only diving company in the world that have our own complete hyperbaric centre was therefore a deci-sive factor in the awarding of the order. During the summer, here in Bergen op Zoom, we carried out a series of dry runs and tests. We endlessly simu-lated all the elementary welding tasks necessary to ensure the long-term success of the repair at our own location. The tests were in fact carried out by the same divers who would eventually be required to carry out the work at a depth of 27 metres in the Java Sea, under considerable pressure. After the extensive testing programme, all the risks had been identified, minimised and managed."

LogisticsThe implementation of the project itself also called

for a carefully planned logistic organisation. The first containers of equipment were shipped to Singapore at the start of July, including the complete saturation diving system and the habitat with suction anchors (piles). The final batch of welding equipment and the pre-heat induction cables developed and pro-duced specially for the project were finally sent out by airfreight at the end of July. Applying power to these cables after wrapping them around the pipe-

line, generates the necessary heat to preheat the pipeline to 70 degrees, before a start can be made on the actual welding work. The hyperbaric centre at DCN clearly played a central role in developing these unique cables.

Four sets In Singapore, all the equipment was then placed

on the afterdeck of the vessel Normand Baltic, chartered for the work by DCN. The Norwegian DP2 vessel subsequently sailed to the island of Batam at the start of September, to collect the sleeves that were also specially produced for this project. The sleeves are the definitive outer coating that had to be welded tightly around the pipeline, as a sort of second skin.

In line with the specifications, four sets of sleeves were produced; one set for test welding, one for simu-lating handling in the habitat, one for welding onto the cracked torn pipeline and one spare set. The same requirements applied to the gas containment clamps that first had to be placed over the existing Plidco clamp on the pipeline.

InstallationIn preparation for the offshore work 30 kilometres off

the coast, a multi beam survey of the entire environment was first carried out. After studying the recordings, a start was made on installing the 5 six-metre long piles in the seabed made up of silt and clay.

The Norwegian DP2 dive vessel 'Normand Baltic’.

The habitat on the aft deck of the 'Normand Baltic’.


The first pile was used as a trial, in order to de-termine the required suction force, and to calculate

the theoretical load-bearing capacity. The habitat subsequently had to be placed on the remaining four piles. To ensure installation of the piles within a tolerance of just 20 cm, a complete location-finding system was placed on the pipeline, using acoustic, underwater beacons.

These made it possible to produce a three-dimen-sional chart of the underwater situation. Safety was the first priority; we had to avoid coming into contact with the pipeline so as not the cause the crack to spread further. The placement of the habitat with its diving bell, which would serve as a safe haven throughout the project for the nine saturation divers, went without a hitch. "This was certainly one of the most critical moments of the project, and we were greatly relieved when the habitat was put in place right first time," admitted Wim Vriens.

Following the hermetic sealing and purging of the habitat to lower the water level, the first gas contain-ment barrier – a sort of safety clamp – was mounted on the pipeline, followed by the lower and upper sleeve. The divers were then able to start on the demanding welding process while the gas continued to be pumped through the pipeline. Over a period of ten days, weld-ing was carried out uninterrupted, while the welded layers underwent continuous ultrasonic testing. Finally, the repaired section of the pipeline was fitted with an anti-corrosion wrapping.

The habitat hoisted by the heave compensated crane aboard the 'Normand Baltic.

The Diving Bell which served as a ‘safe haven’ for the nine saturation divers.

Installation habitat.

oct-dec 2015 45

PP

The entire repair project was successfully con-cluded by mid-October, well within the agreed timeframe, on budget, without any additional work being required and without a single personal injury.

Repair works in habitat at a depth of 27 meters.

A remarkable performance that was closely moni-tored by the entire subsea world.

Wim Vriens concluded: "What DCN has demon-strated with this project is the company's innovative attitude that enables us to tackle complex projects with simple solutions. In coming up with those solutions, we are clearly willing to think out of the box. Thanks to this creative approach, we are able to break out of existing patterns, and deal with problems and dilemmas in an entirely new way. We come up with solutions that others set aside as unworkable. This project is incontrovertible proof of that ability."

This periodical thanks DCN International Diving and Marine Contractors for providing this article for publication.

Artist Impression of habitat installed over the pipeline.


Composite Pipeline Repair - The Helicoid Epoxy Sleeve


Further to the detection of Neoprene Rubber Coating (NRC) damage on 3 risers located at the SMP-A, Samarang offshore platform in Malaysia, an effective repair system was

deemed necessary. As such, Merit Technologies Sdn Bhd(Merit) were requested to undertake the project on the following risers: 6” R2 (PL-122),6” R3 (PL120),8” R4 (PL121). The specific damage area was approximately between +2.50 m and -2.50 m with reference to the Mean Sea Level (MSL) for both 6” and 8” risers.

Due to the location of the damage, which was found to be concentrated at the splash-zone area, a quick and efficient response was needed to ensure no further corrosion and damage occurred. This project highlights the costly issues presented by pipeline damage occurring in the splash-zone area, which shows a higher propensity for damage due to the constant shift between saltwater and air, as pre-sented by the wave action of the water. Furthermore, small-scale debris or vessel impact may contribute to damage or the external corrosion of the pipe.

If left unattended, these factors may contribute to the wall thickness of the risers to fall below the Minimum Allowable Wall Thickness and thus be classified as critical. This may place the riser’s con-tinued operations at jeopardy, along with bringing a multitude of potential Health & Safety hazards.

Installation without ShutdownAfter close consultation with Merit, it was con-

cluded that the solution was the Helicoid Epoxy Sleeve repair system.

The primary requirement and challenge for the repair was to ensure that no shutdowns occurred within the installation period of the repair system, thereby eliminating any costs associated with a stop in production. This was a challenge that Merit had overcome successfully in a multitude of past projects.

The concept of “Epoxy-filled metal sleeves” or “Epoxy Clamps” was first conceived in the 80’s by British gas, utilizing an oversized metal sleeve, whereby the annulus is filled with an epoxy resin. These split metal sleeves are required to be either bolted together or welded, which is strictly forbid-den on “live” pipelines, and thus would require a shutdown. It was decided that this particular repair system was not applicable for this particular problem.

These Epoxy Clamps come with their own dis-advantages and shortcomings. They are generally purpose-built, which entails a lengthy and costly design, engineering and fabrication/delivery period. They are also metal-based, and are therefore subject to corrosion themselves.

The adept engineers and technical staff at Merit, who possess years of experience in pipeline repair with Epoxy-filled metal sleeves, realized that there may be an innovative new method of offshore pipe-line repair systems, which provides similar levels

The Helicoid Epoxy Sleeve is an innovative, full-composite repair system for the strengthening and protection of offshore pipelines, such as risers and conductors.

oct-dec 2015 47

of protection and strengthening whilst circumventing many of the issues possessed by Epoxy Clamps.

Thus, the Helicoid Epoxy Sleeve was invented.

Prior to installation of the Helicoid Epoxy Sleeve, Merit first had to conduct service preparation using their own “Helicoid Surface Preparation System”, consisting of semi-automated hydro-blasting equipment capable of achieving optimum surface cleanliness on our risers, ensuring a strong bond between the riser’s surface and the epoxy grout.

The Helicoid Epoxy Sleeve is an innovative, full-composite repair system for the strengthening and protection of offshore pipelines, such as risers and conductors.

The system consists of carbon-fiber reinforced, mechanically interlocking strips composed of PE or HDPE, to be helically-wound along the damaged section of the riser.

The 100mm wide PE strip has male and female locks, ensuring a strong, rigid pipe that will hold.

An annulus of approximately 40mm between the pipe and the inner section of the sleeve allows for a cementitious grout to be pumped using the “Tremie method”, creating a pressure-containment and load-bearing system. Two polyamide endcaps ensure that the grout is kept contained within the annulus.

All aspects of the Helicoid Epoxy Sleeve system are able to be installed with a minimum amount of personnel, as well as the complete omission of divers, which in turn allowed Petronas Carigali to reap cost-savings of RM6.8 million. In total, four (4) project technicians and two (2) scaffolders were required on site for the whole duration of the installation job.

The Final OutcomeThe project deliverables were three successful instal-

lations of the Helicoid Epoxy Sleeve on the aforemen-tioned risers, which were reviewed and verified by the project team.

Polyamide Endcap Closeup

The 3 completed Helicoid Epoxy Sleeves


The overall scope of work consisted of:• Surface preparation by means of high pressure

hydro-blasting • Installation of Helicoid Epoxy Sleeve • Injection of load-bearing Epoxy Grout HC 68

During installation, Merit faced certain issues and constraints, which they were able to resolve and learn from, ensuring constant improvements to their instal-lation and operating procedures, as well providing potential grounds for further development.

A major constraint faced by Merit was the rela-tively small area that made up their workspace. They will circumvent this issue in the future by

ensuring more compact and efficient equipment through constant research and development.

Other issues beyond Merit’s control came in the form of adverse weather and oceanic activities such as high wave and swell.

Starting from the initial proposal stage, through to installation and completion, Merit was in constant communications with the project team and ensured constant collaboration to get the job done.

This periodical thanks PETRONAS for providing this article for publication.

PP

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Single 1⁄4 page insertion 7766-ads Package 3,68012 ads Package 6,342NOTE:: Dimensions 11cm x 8.5cm

July - September 2016 ____________________________


Special Feature – HSE

Technology – Composites and Coating

October - December 2016 ____________________________

Country / Regional Report – Pacific Rim

Special Feature – Tank Storage

Technology – Corrosion Control


Reliability, Asset Management & Safety (RAMS) Asia Conference • Dynamic Positioning Asia Conference • Downstream Business Engineering and Technology Forum • Mobile Offshore Drilling Units Conference • Offshore Pipeline Technology Asia Conference *

PETROMIN, HYDROCARBON ASIA & PETROMIN PIPELINEREvents Organised by

If you require any further information, please feel free to contact Zaman / Jaquilyn at 6222 3422 or email us at [email protected] / [email protected].

*Conferences are subjected to change. Please visit www.safan.com/tech-events for updates on conferences.


Barrel............................................bblThousand.barrels...........................MbMillion.barrels................................MMbBarrels.per.day..............................b/dThousand.barrels.per.day..............Mb/dMillion.barrels.per.day...................MMb/dMetric.ton......................................tonneThousand.tonnes...........................Mt

Conventions used within this magazineMillion.tonnes................................MMtTonnes.per.day..............................t/dTonnes.per.year.............................t/y,.tpaThousand.tonnes.per.year..............Mt/yMillion.tonnes.per.year..................MMt/yTonnes.of.oil.equivalent.................toeThousand.tonnes.of.oil.equivalent..MtoeMillion.tonnes.of.oil.equivalent.......MMtoe

Cubic.feet......................................cfThousand.cubic.feet......................McfMillion.cubic.feet...........................MMcfBillion.cubic.feet............................BcfTrillion.cubic.feet...........................TcfCubic.feet.per.day..........................cfdMillion.cubic.feet.per.day...............MMcfdBillion.cubic.feet.per.day................BcfdBritish.Thermal.Unit.......................Btu

Watt...............................................WKiloWatt.........................................kWMegaWatt......................................MWGigaWatt........................................GWWatt-hour......................................WhKiloWatt-hour.................................kWhMegaWatt-hour..............................MWhGigaWatt-hour...............................GWh

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AP ENERGY BUSINESS PUBLICATIONS

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advertising index

Advertiser PageNo

advertising index

2nd LNG Marine Fuel Forum 2016 9

9th Reliability, Asset Management and Safety (RAMS) 1

Asia Conference 2016

Bredero Shaw (Asia) Pte Ltd OBC

DMI International, Inc. 13

Kongsberg Maritime Pte Ltd IFC

Petrovietnam GAS 8

Vietnam Oil and Gas Group (PVN) 6-7

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APR-JUNE 2015

Petrovietnam Ensuring National Energy Security .... 10

Offshore Pipeline Management

Sunrise at Hai Thach Field, Vietnam

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Advertisements

Bleed : 211mm x 281mmTrim Size : 205mm x 275 mmNote: Keepalltypedmaterial 8mmwithintrimsize.

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For circulation details and other information, visit our website www.safan.comFor all advertising requirements and your business advertisement schedule please contact: Tel: (65) 6222 3422; Fax: (65) 6222 5587 Email: [email protected]


PetroMin Pipeliner magazine advertisement rates:(all rates are expressed in US$) All ads in 4C, US$

Insertions 1 x Rate 2 x Rate 4 x Rate OBC $4,700 $4,470 S4,010 Inside Front cover $4,300 $4,090 $3,670 Inside Back cover $3,900 $3,710 $3,330 Full page $3,600 $3,425 $3,075 Half page $2,550 $2,425 $2,175 Third Page $1,850 $1,760 $1,580 Quarter page $1,250 $1,190 $1,070

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apr-june 2015

Offshore Pipeline Management

Sunrise at Hai Thach Field, Vietnam

January-March 2016 _____________________________

Country / Regional Report – South Asia

Technology – Materials Technology

Special Feature – Onshore Pipelines

April -June 2016 _________________________________

Country / Regional Report – Pacific Rim

Technology – Trenchless Laying

Special Feature – Deepwater Pipelines

The only magazine covering pipelines exclusively in Asia. As more new pipelines are being built in Asia than anywhere else in the world, there is a growing need for information in order to do business in the area. PetroMin Pipeliner is your window to the Asian pipeline market with news,

interviews, technical articles and more.

July - September 2016 ____________________________

Country / Regional Report – Far East

Technology – Composite Developments

Special Feature – Corrosion Control

October-December 2016 _________________________


Technology – Pipelaying

Special Feature – Offshore Pipelines

Note:TheaboveEditorialScheduleispreliminaryandissubjecttochangeinlinewithpipelineeventsin2016.Eacheditionwillalsoincludedetailedprojectreports,up-to-datenewsandtechnicalinformation.Pleasecontactustodayforthelatestdetails.

Substantialin-depthtechnicalarticlesfromspecialisedcompaniesandprofessionalsalliedtothepipelineindustryareinvited.

NOW OFFERING ONE SOURCE OF PROTECTION FOR YOUR MOST CRITICAL ASSETS.

Two of the world’s largest pipe coating providers, Bredero Shaw and Socotherm, have joined forces as a part of Shawcor’s Pipeline Performance team. By integrating our resources, world-class facilities, experienced technical teams and innovative technologies, we’re primed to offer end-to-end coating solutions that protect the assets of any project and pipe source—anywhere in the world.

To see how Shawcor’s fi eld joint and mainline coating systems can enhance reliability and e� ciency for your operation, visit Shawcorsuccess.com/pipeline. To speak to a representative, please call +1 281 886 2350.

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SHAW-9495_Shawcor Pipeline Performance-OCT2015-Petromin_v1.indd 1 9/3/15 12:32 PM

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