Petromin pipeliner

PetroMin PIPELINER

Asia's Business and Technical Pipeline magazine

jan-mar 2014

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Maintaining Pipeline Operations MCI (P) 050/01/2014 • 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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Report South Looks to Grow .......................... 06 South Asia is gas rich and as such it is quite surprising that the

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pipeline network in the region is not as developed as it perhaps should be; as far as pipelines and pipelines network development goes at least - India is the powerhouse, although Pakistan has an established network too. However, some upcoming

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projects look to set that record right.

written consent, not unreasonably withheld, of

on request, subject to a minimum quantity.

Project / Industry News

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Pipelines in the Pipeline ...................... 16

the publisher. Reprints of articles appearing in previous issues of the magazine can be provided

necessarily those of the publisher and while every attempt will be made to ensure the accuracy and authenticity of information appearing in the magazine, the publisher accepts no liability for damages caused by misinterpretation of information, expressed or implied, within the pages of the magazine. All correspondence

Technology Let it Flow ............................................. 22

regarding editorial, editorial contributions or

Pipeline single phase flow assurance has been a concern for

editorial content should be directed to the Editor.

some time, as have been the solutions with related issues.

The magazine is available at

However, multi-phase flow assurance is relatively recent,

an annual subscription rate of US$60.

with the advent of wet gas and such, and this article looks

Please refer to the subscription form or

at some of the technologies provided to maintain good flow.

contact the subscription department for further details at Fax: (65) 6222 5587, Email: khaleel@safan.com

Taking the Fight to Corrosion ........... 28 Corrosion is one of the biggest problems faced by pipeline operators. There are several inspection and repair processes, such as pigging, to combat pipeline corrosion.

This article assesses preventive methods such as coating and metalizing.

Pipeline Inspection Techniques ............. 32 2

jan-mar 2014

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jan-mar 2014 VOL.10 No. 01

Tools for Internal and External Inspection .................................................................... 39 With the need to protect the CAPEX as well as the valuable cargo within pipeline operators need to be constantly vigilant about the integrity of their pipelines. Regular and diverse inspections need to be carried out and there are a host of technology and service providers to aid this endeavour. This article outlines selected in-line and external inspection techniques and some of the proponents of these techniques.

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Regular Focus Editorial .................................................. 04 Project / Industry News ..................... 16 Calendar of Events ............................... 51 Advertisers Index .................................. 52

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Editorial

Politics Policing Pipelines…..

E

xactly twelve months ago, I was writing the editorial for the first issue of PetroMin Pipeliner for 2013.

Then I addressed the part politics played in the pipeline sector, with direct reference to issues I encountered whilst analyzing the report on South Asia that the issue carried. I vividly recall speaking about TAPI and the so-called “Peace Pipe” that was named IPI, and the influence that the US was exerting on a pipeline that was being built half a world away.

Well, lo and behold, it’s a year on, this issue is carrying a regional feature on South Asia, and I am once again blown away by the influence politics have on the pipeline sector. And guess what, it is once again about the IPI, and once again the US is a major actor in the plot. The plot’s somewhat thicker, however.

Last year I commented on how certain quarters believed that both the US and Pakistan were involved in a little gamesmanship, with political posturing evident from both parties, whilst Iran seemingly stuck in the middle. Things are a little different this time round – Iran and the US are doing the posturing and it’s Pakistan that is stuck in between.

Since 2012 the US has been pressurizing Pakistan to shelve the IPI plans, although a bilateral treaty had been signed between Pakistan and Iran, on the basis of Iran’s activity with regards to nuclear weaponry. They have also alluded to possible collaborations in the energy sector to persuade Iran but to date have not made any financial commitments.

Late last year Iran cancelled a proposed $500m loan to Pakistan, which was supposed to aid the construction of the Pakistan portion of the IPI, and further intimated that it would impose sanctions on Pakistan if Pakistan did not complete the project in the time stipulated

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in their agreement. Although the reason for this turnaround could be due to the economic turmoil Iran is facing, most believe that the principle reason is Pakistan building nuclear weapons for Saudi Arabia, a traditional nemesis of Pakistan.

It is clear that more than economic sense it politics which are shaping the future of the IPI project. In all this India seems to be the main beneficiary, as the US is promoting the TAPI project as an alternative to the IPI project, and Iran has also come forward to encourage the possibility of a pipeline connecting Iran to India, even hinting that financial help could be rendered towards this.

Despite the knowledge that energy supply and security have long been political pawns I am still amazed as to the extent to which politics can shape the destiny of international pipelines.

All in the South Asian report should prove to be not only informative but an interesting read as well.

The focus of this issue is on inspection tools. There is an article on in-line inspection which details the various technologies available in the market and another which enumerates the different types of inspection tools as well as an alternative, ECDA (External Corrosion Direct Assessment).

Multiphase flow assurance, and related issues, is one of the merging concerns of the pipeline sector and this issue carries an article outlining the different concerns and the available solutions in the market. To wrap up the issue is a brief on combating corrosion.

I hope you have a good read and that we have played a part in expanding PP your knowledge.

Publisher/Executive Editor Eddie Raj Group Editor Vishnu Pillai Email: vishnu@safan.com Online News Editor Natalia Lim Tel: 6222 3422 ext: 108 Email: natalia@safan.com Advertising Co-ordinator Mary Tel: 6222 3422 ext: 101 Email: mary@safan.com Subscription/Circulation Khaleel Tel: 6222 3422 ext: 111 Email: khaleel@safan.com Conference Co-ordinator Zaman Tel: 6222 3422 ext: 112 Email: zaman@safan.com Graphic Artist Chua Ai Hwa Email: aihwa@safan.com

Editorial Advisory Board Dr. Allen Beasley Ascope Gas Centre Prof. Andrew. C. Palmer CORE, Dept. of Civil Engineering National 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 Beller NDT Systems & Services AG Dr Andrew Ngiam INTECSEA - Worley Parsons

Vishnu Pillai Group Editor

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Report

South Looks to Grow South Asia is gas rich and as such it is quite surprising that the pipeline network in the region is not as developed as it perhaps should be; as far as pipelines and pipelines network development goes at least - India is the powerhouse, although Pakistan has an established network too. However, some upcoming projects look to set that record right.

D

espite being rich in natural gas and being major energy consumers and importers South Asia has a relatively small pipeline network. There are a number of projects in the horizon which might alleviate this situation but due to political and historical tensions in the region it’s always touch and go as to whether the projects eventually take off.

According to IHS, India's crude oil pipeline network spans just under 4,000 miles and has a total capacity of 1.9 million bbl/d.

Approximately 30 terminals, mostly on the northwest coast, take in crude oil imports. Pipelines run from these ports and producing areas (particularly from Gujarat) to major oil refineries in Gujarat, Mathura, Uttar Pradesh, and Haryana. On the eastern part of the country, pipelines run from West Bengal to the Paradip oil refinery. Refineries are generally located in coastal areas, because the majority

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of crude oil comes from tanker imports and offshore fields. Central and southern areas have few major pipelines, since the bulk of refining capacity is in the northwest and northeast.

The Indian Oil Corporation (IOC) controls and operates the oil product pipelines and supplies most of the oil products going to the domestic market. Product pipelines cluster in the north and northeast parts of India, while central and southern areas must rely on oil distributed through other means, such as cargo trucks.

IOC plans to build additional product lines to move supplies from refineries to growing demand centers, such as Jharkhand, Orissa, and Chhattisgarh.

The two most important companies operating India's large gas pipeline system are GAIL and RGTIL. GAIL, the state-owned gas transmission and marketing company, operates

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the major gas pipelines in India: the 1,740-mile Hazira-Vijaipur-Jagadishpur (HVJ) line running from Gujarat to Delhi, and the 480-mile DahejVijaipur (DVPL) line. Reliance Gas Transportation Infrastructure (RGTIL) is the biggest private investor in the gas transmission structure. RGTIL's East-West Gas Pipeline takes gas from RIL's Krishna-Godavari basin fields and pumps it to north and western Indian markets. Other players like Petronet and Assam Gas Company have significant pipeline investments servicing demand centers in northeast India.

Insufficient pipeline infrastructure constrains natural gas demand in India. The country's own pipeline network primarily services the northwest region. Reliance Gas Transport Infrastructure (owned by RIL) brought the East-West pipeline online in 2009 to link the promising D6 gas field to industrial centers in the north and west regions of the country. Smaller companies such as Petronet LNG and GSPC have considered building

their own pipelines to link production areas to the network. GAIL announced plans to extend the network with the Hazira-Bijapur-Jagdidhpur (HBJ) pipeline and a line from the D6 field to southern parts of India.

The Indian government has considered importing natural gas via pipeline through several international projects, although many of these have proved unfeasible. In 2005, negotiations between the Indian and Bangladesh governments fell through over a transnational pipeline.

In 2006, India left the Iran-Pakistan-India (IPI) pipeline project. However, the government still participates in a plan to import natural gas from Turkmenistan to India. The TurkmenistanAfghanistan-Pakistan-India (TAPI) project, also known as the Trans-Afghanistan Pipeline, has seen a decade of discussion, although major geopolitical risks and technical challenges have prevented the project from starting in earnest.

The Asian Development Bank estimates the cost of the pipeline at about $10-12 billion. However, the countries have made some progress in moving TAPI forward. The partners signed a framework agreement in 2010 and agreed on unified transit tariffs for the route in early 2012. In May 2012, India signed gas supply and purchase agreements with Turkmenistan.

In early February 2013, India's government approved a special purpose legal entity to which participating members of the pipeline would contribute investment funds.

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Currently four main projects are on the forefront of the Indian pipeline sector. India’s natural gas import demand is expected to increase in the coming years. To help meet this growing demand, a number of import schemes including both LNG and pipeline projects have either been implemented or considered.

The Mangala Development Pipeline MDP is the world’s longest continuously heated and insulated pipeline and will have access to 75% of India’s refining capacity.

Imports from Myanmar The governments of India and Myanmar signed a natural gas supply deal in 2006, but disagreement arose over whether the pipeline should go through Bangladesh. In March 2009, Myanmar signed a natural gas supply deal with China sourced from a field invested in by GAIL and ONGC, putting any India-Myanmar pipeline deal in question.

Iran-Pakistan-India Pipeline The Iran-Pakistan-India (IPI) Pipeline has been under discussion since 1994. The plan calls for a roughly 1,700-mile, 5.4-Bcf/d pipeline to run from the South Pars fields in Iran to the Indian state of Gujarat. A variety of economic, political and security

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issues have delayed a project agreement. Due to the uncertainties involving this pipeline, the Indian government’s 11th Five Year Plan does not project any gas supply from this route or the following two discussed pipelines.

Turkmenistan-Afghanistan-Pakistan-India Pipeline India has worked to join the Turkmenistan-Afghanistan-Pakistan Pipeline ((TAPI). With the inclusion of India, the project consists of a planned 1,050-mile pipeline originating in Turkmenistan’s Dauletabad natural gas fields and transporting the fuel to markets in Afghanistan, Pakistan, and India. In 2010, India signed a framework agreement for the pipeline, which is envisioned to have a capacity of 3.2 Bcf/d, but work has not yet begun on the project.

Cairn’s Crown Jewel The MDP originates from Mangala Processing Terminal (MPT) in the Mangala Field and passes through two states (Rajasthan and Gujarat), eight districts and travels up to ~670 kms before it reaches its end at the coastal location of Bhogat near Jamnagar on the western coast line of India.

About 154 km of the pipeline is in Rajasthan and the rest in Gujarat.

The MDP is a 24" crude oil pipeline which is using Skin Effect Heat Management System (SEHMS) to ensure that the crude oil remains above the Wax Appearance Temperature (WAT) of 65 Deg C, through the pipeline.

It has 8" gas line which feeds gas to all the ~36 Above Ground Installations located at every ~ 18 km distance enroute the pipeline which produces the necessary power to keep the pipeline at the required temperature.

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In addition, there is an intermediate terminal at Viramgam for storage and further pumping to the coast, including a pigging facility. There are two other pigging stations at Sanchore and Wankaner to insert ‘pigs’ (pipeline cleaning devices) that are used to clean and inspect the pipeline.

The pipeline crosses all major crude oil carrier pipe- lines in the Western part of India and thus, offers potential of blending the Rajasthan crude with these large crude carrier lines. As it terminates at a coastal location, the marine facilities are designed to load the crude oil carriers to transport the crude oil to other coastal refiners as well.

The project is divided into two phases: Phase I: From MPT to Salaya, in Gujarat, via a storage and pumping terminal at Viramgam (in the district of Ahmedabad). It includes spur lines to connect to private refiners and another spur line at Radhanpur to connect with the Indian Oil Corporation Limited’s (IOCL’s) Mundra to Panipat crude pipeline.

Since then, oil was introduced in the pipeline on 13 May 2010 and has began commercial sales to IOCL and private refiners.

Phase II: From Salaya to the Bhogat terminal on the Arabian Sea coast, and a pipeline connecting the termi- nal to the marine facilities.

This Salaya to Bhogat pipeline extension project con- sists of three main components: 1. Extension of the pipeline with associated heating stations from Salaya to the Bhogat terminal.

2. Coastal crude oil storage terminal at Bhogat.

3. Marine export facilities, consisting of twin 24” sub- sea pipeline connecting the Bhogat terminal to the SPM (Single Point Mooring).

The SPM is located ~ 6 km off shore in the Arabian Sea and is equipped to load the AFRAMAX type tankers.

Construction work on the ~80 km Salaya to Bhogat section of the pipeline including the Bhogat terminal

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and marine facility is in progress with completion targeted for H2 CY 2012.

However, in early February 2012 it was a nounced that Cairn India Ltd has been unsuccessful in starting work on its 80km pipeline from Salaya to Bhogat in Gujarat, even as Larsen and Turbo Ltd (L&T), which was awarded the work of laying down the pipeline, has declared its intent to exit the project, amid opposition from some groups. Cairn India, which contributes to 20% of India’s domestic crude production, has invested over $3 billion in oil exploration in the Mangala field in Rajasthan, the country’s largest onshore block from where almost 90% of the company’s current crude production comes. It aims to take oil production ultimately to 240,000 barrels per day (bpd) for which it needs to complete the Salaya-Bhogat stretch in Jamnagar district, said a com- pany official familiar with developments.

The project has been stuck for the last 2 years with local politicians and farmers not allowing the company to acquire land in the area over compensation disagreements. A Cairn India spokesperson declined to comment on the issue.

When contacted, an L&T spokesperson said the company does not comment on communications with clients to a third party. The Anil Agarwalcontrolled Vedanta Group currently holds 59% of the issued share capital of Cairn India. Cairn India and Oil and Natural Gas Corp. Ltd (ONGC) have built the world’s longest continuously heated pipeline for transport of crude from Barmer in Rajasthan to Salaya in Gujarat.

Sundeep Bhandari, chairman of Cairn India’s corporate advisory board, wrote to a senior Gujarat government official on 24 January, expressing concern over the need to complete the Salaya-Bhogat stretch to raise production from 125,000 bpd to 165,000 bpd. The letter added that L&T wanted to exit the project. Bhandari expressed the company’ willingness to improve the compensation offer, according to the letter that Mint has reviewed.

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Sales arrangements are in place for 170,000 bpd with public sector units and private refiners for the current fiscal year, the company recently said in its quarterly results announcement on 24 January. Also, the company’s singlepoint mooring (SPM) system, involving an estimated investment of Rs500 crore, is near completion at Bhogat sea, but it cannot be com- missioned as the pipeline work is yet to be completed, said a government official close to the development. SPM is a loading buoy anchored offshore that serves as a mooring point and interconnect for tankers loading or offloading liquid or gas products.

According to another letter written in September 2011 to the Gujarat government by D.N. Narsimha Raju, joint secretary, ministry of petroleum and natural gas, “Early completion of the project (Salaya-Bhogat) is important to allow increase in crude oil production in the national interest and further delays will result in the pipeline project completion slipping beyond 2012...”

Myanmar-India Pipeline Myanmar has indicated that it has enough gas to fill pipelines to both India and China, while the route through Bangladesh is looking less likely. “There is enough gas there. We can sell it to both India and China,” Myanmar has indicated that it has enough gas to fill pipelines to both India and China, while the route through Bangladesh is looking less likely.

“There is enough gas there. We can sell it to both India and China,” said Myanmar ambassador to India U Kyi Thein. The in-place reserves from the Block A-1 in the Shwe field have been assessed

by American based consulting firm Ryder Scott at 2.88 Tcf to 3.56 Tcf. “Talks are on with both the countries. We are still in the negotiation stage and have not finalised with either India or China,” Mr Thein said. “Surely, we will sell gas to India,” he said. “The gas would come to India through a land route bypassing Bangladesh and linking the Kaladan River in Myanmar directly to Mizoram.”

Last week, Gas Authority of India Limited presented the detailed feasibility report prepared regarding trans- port options of gas from Myanmar to the other operators of Block A-1, concluding that a route bypassing Bangadesh was preferred.

The move comes in the context of Myanmar’s deal with China over its abundant gas supplies.

Myanmar said it signed the pact with PetroChina because no progress had been achieved in the tripartite agreement between Myanmar, Bangladesh and India for the pro- posed pipeline project, whereas the Chinese had assured that they would lay their pipeline on time.

In 2010 Bangladesh’s Sheikh Hasina government gave its approval for the construction of the 900km gas pipeline linking India and Myanmar and late last year the deal was inked between India and Myanmar.

Iran-Pakistan-India Pipeline Iran-Pakistan-India (IPI) Gas Pipeline is envisioned as harbinger of development and prosperity for South Asia. The idea of IPI Gas Pipeline was conceived in 1995 when Iran and Pakistan signed an initial agreement for construction of the pipeline linking the Iranian South.

Pars natural gas fields in the Persian Gulf with Karachi. But later on, Iran suggested the extension of pipeline to India. Towards the end of 1999, the then President of Pakistan General Pervez Musharraf visited Tehran to review the progress of the proposed pipeline. The year 2000 was eventful in terms of keen interest displayed by policy makers from all the member countries. For example, in March 2000, Pakistani secretary of petroleum visited Iran to formally agree to the pipeline project between the three countries. The Iranian government officials also visited Islamabad in April 2000 for signing the contract. Despite the lucrative nature of this mega- development project, it has remained in doldrums for the last fifteen years. For this reason many critics de- scribed it as “Dream Lines” or “Pipedreams.” However, in

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June 2010 Pakistan and Iran finalized an agreement to construct the gas pipeline without India.

Iran-Pakistan-India (IPI) Gas Pipeline is going to be 2,775-kilometre long. In Pakistan, it will traverse through Balochistan, Sindh, Khuzdarand Multan. With initial capacity of 22 billion cm annually it is expected to increase to 55 billion cm.

The pipeline will have a diameter of 48 inches (1,200 mm) and is expected to cost US$7.5 billion. Out of the total length of pipeline, its length will be 1,115-kilometer in Iranian territory. For its possible extension to India two land routes have been proposed. One is through Multan and Khuzdar and the other along the coastline of Pakistan before entering into India.

There has been another suggestion from the former prime minister of India Mr. Vajpayee to extend the pipeline from Iran beneath the Arabian Sea. However, this suggestion was not economically feasible due to high installation and maintenance costs and being prone to seismic activity.

Controversies and apprehensions have been hovering around the IPI Gas Pipeline project.

This is primarily due to trust deficit between India and Pakistan. As a matter of fact, proposal of constructing a pipeline underwater came from the Indian side. The supply of gas to India is threatened due to their deep rooted distrust with Pakistan (as the pipeline will pass through areas of Multan and Khuzdar) in Pakistan. Secondly, payment of substantial royalties to Pakistan as a transit country is also unaccept- able to many Indian policy advisors. India is no doubt an energy deficient country, and if 8% economic growth is to be maintained until 2032, it has to increase its power generating capacity by 83% (Statistics by Planning Com- mission of India). Almost 50% of India’s energy requirements are met by coal. Its economy cannot rely only on coal in the long-run as globalization and environmental protection laws and regulations are becoming stringent day by day. The carbon emission rate of India is surging at an alarming rate since the 1980s.

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As far as the construction of pipeline is concerned, it is feasible to analyze it in the backdrop of various pipeline networks in Europe. In case of South Asia, a “segmented construction” approach has been agreed upon by member states. It means that every member will construct part of the pipeline length in its territory. Iran has already done the major part of the work, that is, construction of 1,115 km from Asalouyeh to the Pakistani border. Now, 898 km are to be constructed by Pakistan on its territory before the aforesaid pipeline enters India, which will construct 740 km. However, the financing of IPI project is a big question as Iran is seen as a ‘problem child’ in the international community. Recently, the 4thround of sanctions was imposed on Iran by the UN Security Council in a bid to dissuade it from pursuing ‘nuclear ambitions.’

The economic gains which IPI promises in future are very lucrative for big oil and gas companies around the world. Despite the Iran-Libya Sanctions Act of 1996 (limiting any third country to invest not more than $20 million in any one year in Iran), a consortium was agreed upon comprising BHP (Australia), NIGC (Malaysia), Total (France), Shell (Netherlands), BP (UK) in addition to Iranian, Pakistani and Indian national gas companies.

Moreover, Gazprom (Russia’s biggest gas company) and Norwegian government showed keen interest in financing the project. It made quite big news in 2007 when World Bank’s vice president confirmed that the World Bank is willing to fund any of the gas pipelines: IPI and TAPI (TurkmenistanAfghanistan-Pakistan- India).

An overriding consideration, particularly for the Pakistani government, is the security of the pipeline. The route runs through troubled Baluchistan. The armed violence and sabotage activities by anti-state elements in the last few years in the province pose a major threat to the safety of pipelines and consistent supply of gas. Blowing up of gas pipelines in the areas of Sui and Dera Bugti by stateless elements demands a special

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levy force to safeguard the pipeline. As a result, the costs might be further raised.

IPI Gas Pipeline, to be sure, has more long term benefits than the costs to be incurred in its completion. An established positive correlation between ‘economic development’ and ‘energy use’ indicates that Pakistan’s economy will improve once the Iranian gas is supplied to its industries. Pakistan’s gas reserves are depleting and in order to fulfil the energy shortages, IPI holds a great opportunity. Besides, Balochistan as an underdeveloped province will get economic boost through employment, infrastructure development and provision of gas.

However, late last year it was announced that Iran had not only cancelled a US$500 million loan promised to Pakistan in 2012 to help fund its construction of pipeline to bring natural gas from Iran; it has also said it will demand compensation if Islamabad fails to build its side of the pipeline by the end of this year. The announcement came just days after Islamabad had agreed to speed up work on the US$7.5 billion project.

Reasons for Tehran's drastic and sudden turnabout on its decision could range from the dismal state of its own economy to understandings reached with the US last month on the future of its nuclear-development project. Complicating matters, Pakistan was reported last month to have built nuclear weapons for Saudi Arabia, Iran's archrival in the region, and that these were ready for shipping. Whatever the case, it turns the pipeline, once considered an energy lifeline for Pakistan's economy, into a liability for the cash-strapped South Asian country.

The pipeline deal stipulates that Pakistan must construct its side of the pipeline by December 2014. If the country fails to meet this deadline, it will be liable to pay fines that could run into the millions of dollars per day. Islamabad has so far failed to secure the required funding for the IP pipeline due to the threat of sanctions from the US.

There are obvious signs of frustration in Tehran.

Iran has completed its 900-kilometre section of the pipeline, from the South Pars gas field to the Pakistani border.

Iran's new stand on the pipeline has pushed Pakistan into a dilemma. There is a price the country will have to pay either way if it withdraws from the project or goes ahead. It will have to pay a penalty for abandoning the project, while it will have to arrange financing and face US sanctions in the event of starting work on the project. It will be hard for the country to arrange funds to pay the cost in either situation.

In 2012, Washington pressed Islamabad to shelve the IP pipeline as a pre-condition to holding further talks on the possibilities of cooperation in the energy sector, but the US did not make any commitment to finance the proposed $13 billion Diamer Bhasha Dam project. Washington has also dangled Islamabad other energy carrots, including the Turkmenistan-AfghanistanPakistan-India (TAPI) gas pipeline and potential projects involving the importation of liquefied natural gas in efforts to convince the country to halt the IP pipeline.

TAPI The TAPI project envisages constructing 1,680 km of pipeline with a total gas capacity of 90 mscmd.

The length of pipeline in Turkmenistan, Afghanistan and Pakistan up to the Indian border is 145 km, 735 km and 800 km, respectively.

After much political ping-pong the project seems to be headed towards more concrete footing. Gas pricing will be the key to the project that is expected to get India 38 million standard cubic metres a day (mscmd) of gas from Turkmenistan.

The supplier, Turkmenistan, has proposed that the landed cost of the gas for the buyers should be in sync with the prevailing delivered price in that country, an official source told Business Line.

Meanwhile, according to reports, Pakistan has

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proposed that there should be a common price of gas for all buyers.

To make the project attractive for India, the delivered price (or the landed cost) of Turkmenistan gas has to be lower than that of imported gas. In India, the prevailing delivered price of domestically produced gas is $4.2/mBtu and that of imported gas, about $7/mBtu. The landed cost of Turkmenistan gas in India would rise considerably after payment of transit and transportation fees, as India is at the tail end of the proposed pipeline. A transit fee is payable to the countries through which the $7.6 billion pipeline passes, while transportation charges will be levied by the consortium operating the pipeline.

Sources said that keeping all the aspects in mind, India has proposed that the pricing formula be linked to a basket of low and high sulphur fuel oil.

However, no final decision has been taken as yet.

After the last technical working group meeting it was decided to appoint a transaction advisor. The Asian Development Bank (ADB) is expected to appoint a transaction advisor for the pipeline project

by April. The advisor would facilitate formation of a consortium company and selection of the consortium leader for execution of the TAPI project.

Plans for Growth India will by 2017 have a natural gas pipeline grid of 30,000-km connecting consumption centres to source of fuel, Oil Minister S Jaipal Reddy said in April 2012.

"We have a country wide network of 12,000 km of gas pipeline (and another) 12,000 km of pipelines are under construction," he said speaking at the 15th Foundation Day of Petronet LNG Ltd. "With another 7,000 km of pipelines under bidding by the (oil regulator) Petroleum and Natural Gas Regulatory Board (PNGRB), we are looking at the emergence of a National Gas Grid of nearly 30,000 km in length by 2017, with a capacity of 875 million standard

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cubic meters per day (mmscmd), to take natural gas to different markets across the length and breadth of India," he said.

Currently, the gas pipelines have a capacity to transport 230 mmscmd of gas. Stating that natural gas sector in India was on the verge of a takeoff, Reddy said natural gas is the fuel of choice since it is an efficient fuel for power generation, a cheaper feedstock for industries, a cleaner alternative fuel for vehicles and leads to an improvement in the quality of life.

Considering its versatility and a smaller carbon footprint, the government has launched a drive to popularise the use of natural gas in the country.

"Today, about 51 cities and towns are covered under the City Gas Distribution (CGD) as a part of which piped natural gas for cooking and CNG for the transport sector are being supplied," he said, adding PNGRB has plans to roll out CGD networks in over 300 geographical areas in the country.

With domestic gas produced is limited, India's dependence on imported liquefied natural gas (LNG) is projected to grow.

"To cater to the increase in imported LNG, we are in the process of increasing our current LNG handling capacity of 13.5 million tonnes per annum to more than three times by 2017," Reddy added.

To cater to the huge expansion in the gas market, India is also pursuing trans-national gas pipelines such as the 1800 km long Turkmenistan-Afghanistan-Pakistan-India (TAPI) Gas Pipeline.

"In spite of the security hazards and a high threat perception, we are pursuing this ambitious project.

After more than 18 months of hard negotiations, the four participating countries are close to initialising the Gas Sale Purchase Agreement (GSPA)," he said without elaborating.

Late last year it was announced that Iran is focusing on exporting natural gas to India along a

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deep-sea route — the move coinciding with the cancellation of a loan to Islamabad to build the Pakistani section of the Iran-Pakistan gas pipeline and the signing of the Geneva nuclear accord that could help relax sanctions against Tehran.

“Negotiations were held with three Indian companies for [their] purchase of gas from Iran, and general agreements have been reached,” said Ali Amirani, director of marketing at the National Iranian Gas Exports Company (NIGEC), as quoted by the Tasnim news agency.

He added that India’s South Asia Gas Enterprise Pvt. Ltd. (SAGE) had conducted feasibility studies for the multi-billion-dollar undersea pipeline, which could carry gas from Iran’s giant South Pars gas field to India’s west coast. Mr. Amirani said the project cost estimated by the company was $4-5 billion.

Once operational, it could channel 31 million cubic meters of gas per day.

“We are in regular touch with the Iranians and at this moment they are the only country, among energy rich nations of the Persian Gulf, which has the surplus gas to export to India,” said Subodh Kumar Jain, Director SAGE, in a telephonic conversation with The Hindu. He added that there were no technical hurdles to build the deep sea pipeline, and the project, which was financially viable, could be completed in 4-5 years, once the sanctions against Iran are lifted. “There could be several options but one of them could be bringing Iranian gas to the port of Chabahar from where it could either be transferred directly along the seabed or via Oman, which could also become a beneficiary”.

Implications Despite the slow development, in relation to cross-border pipeline projects in other parts of the world, it is apparent that progress is being made. Most of the delays are caused by political and social tension in the region which causes the members of the region to resort to one-upmanship and political posturing, but in the end it is clear that practicality will prevail.

References Asia Pulse Asia Times Associated Press BBC Business Standard Census of India CIA World Factbook Economist Intelligence Unit Energy Economist FACTS Global Energy Financial Times GAIL Global Insight IEE Japan IHS Energy Indian Chamber of Commerce Indian Ministry of Coal and Mines Indian Ministry of New and Renewable Energy Indian Ministry of Petroleum and Natural Gas International Energy Agency (IEA) Lloyd's List Intelligence Nuclear Association Oil India Limited Petroleum Economist Petroleum Intelligence Weekly PFC Energy PIRA Platts Energy Reliance Industries Ltd. Reuters The Hindu Times of India U.S. Energy Information Administration World Gas Intelligence World Socialist Web Site

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jan-mar 2014

15

Project / Industry News

Pipelines in the Pipeline Technip Wins Jangkrik Subsea Package in Indonesia It was announced in early March that Technip has been awarded a major subsea contract by Eni Muara Bakau B.V. (Eni) the Operator of the Muara Bakau PSC, for the Jangkrik project located in the Muara Bakau PSC working area, approximately 70 kilometers off the coast of Makassar Strait, Indonesia, at water depth ranging from 200 to 430 meters.

The contract covers the engineering, procurement, commissioning and installation of: - 36 kilometers of flexible risers and flowlines with diameters ranging from 4" to 14", - 195 kilometers of pipeline with diameter ranging from 4" to 24", - subsea equipment which includes mid-water arch and flowline end termination.

Technip will also carry out the installation of 51 kilometers of umbilicals, five manifolds and seven SSIV subsea structures and associated flying leads.

Finally, the project also includes the engineering, procurement and construction of an onshore receiving facility including pig traps, metering systems and utilities.

The project is scheduled to be completed in the first quarter of 2017.

The flexible pipes will be manufactured at Technip’s Asiaflex Products plant in Tanjung Langsat, Johor, Malaysia. Technip’s S-Lay and heavy-lift vessel, G1201 and its multipurpose installation and construction vessel, the Deep Orient, will be used for the installation.

Lim Kwee Keong, Senior Vice President of

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Technip in Asia Pacific stated: "We are delighted to support Eni in bringing the Jangkrik project onstream. This contract is an excellent example of Technip’s capability to propose competitive solutions for large and complex projects which combine onshore and subsea scopes. It confirms the relevance of our strategy of vertical integration to provide best-in-class solutions to our clients' projects."

Technip Awarded Contract in Brunei It was announced in late February that Technip has been awarded a significant contract by Total E&P Borneo B.V., covering engineering, procurement, supply, construction and commissioning (EPSCC). This project aims at the modification of the onshore facilities as well as the construction of a new onshore pipeline, in order to transport Maharaja Lela & Jamalulalam South (MLJS) gas to the Brunei Liquefied Natural Gas (BLNG) plant.

The onshore modification work includes: • de-bottlenecking of the processing plant to enable handling up to 5 million cubic meters per day (annual average) from the greater MLJ field, • associated assistance in start-up and performance test.

Technip’s operating center in Kuala Lumpur, Malaysia will execute the contract with support from the office of the Group based in Brunei.

The project is scheduled for completion in the second half of 2015.

Lim Kwee Keong, Senior Vice President of Technip in Asia Pacific, stated: “Following the front-end engineering design that we have completed in 2012, Technip was keen

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C & C Technologies leads the way in survey and positioning technology for the oil and gas industry From pioneering AUV technology to providing uprecedented levels of excellence in surveying, C & C has created a “new vision” for the oil and gas industry. Our fleet of AUVs (C-Surveyor® II, III, IV, V) has set new standards by reaching depths to 4,500 meters in ultra-deep waters across the globe. We have also integrated C-Nav® (globally corrected GNSS service) into our services in pursuit of breakthrough technology for our clients. We produce the most reliable, accurate and timely data to help our clients make sound decisions, while also providing expert data interpretation. With more than 600 employees globally, we provide marine construction survey services, high-resolution multichannel geophysical surveys and geotechnical laboratory testing to bring you a complete package of services for your next project.

Singapore Tel : (+65) 6295 9738 Thailand Tel : (+66) 3807 2028

www.cctechnol.com

on undertaking the EPSCC contract. Vital for the brownfield tie-in of the MLJS project, our familiarity with the onshore facilities has made the difference and gave us leverage in this much sought-after development.”

McDermott Awarded EPCI & Commissioning Contract in the Arabian Gulf McDermott International, Inc. announced in late November that one of its subsidiaries was awarded an Engineering, Procurement, Construction and Installation (EPCI) project for a customer in the Arabian Gulf. The value is approximately US$ 200 million and will be included in McDermott’s fourth quarter 2013 backlog.

The contract includes the fabrication, transportation and installation of offshore facilities including two production deck modules and ten observation platforms. The scope also includes works for two subsea pipeline installations, three submarine power cables and two fiber optic cables.

“Engineering work will be undertaken by the Dubai and Al Khobar offices, with construction and transportation from its Jebel Ali fabrication facility,” said Stewart Mitchell, Senior Vice President and General Manager, Middle East & Atlantic. “This project is a continuation of work we have previously completed for the same Client in the same field. Knowledge and experience gained over the years will give us a greater insight into the field characteristics and project execution requirements. We are pleased that our Client has shown continued confidence in McDermott with this award.”

Installation will be carried out using vessels from its global fleet which are expected to mobilize in the end of the second quarter of 2014. Project completion, including hookup

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and commissioning, is expected during the first quarter of 2015.

KONGSBERG Chosen as Engineering and Technology Supplier for the New Petrofac Derrick Pipelayer Vessel KONGSBERG has been appointed as the supplier and integrator of all electrical, telecom and integrated control systems for the new Petrofac JSD 6000 deepwater derrick lay vessel. The contract has a value of over NOK 230 Million and is one of the most extensive ‘Full Picture’ contracts that Kongsberg Maritime has secured to date.

The vessel is to be built at the Shanghai Zhenhua Heavy Industry Co., Ltd (ZPMC) yard in China for Petrofac UK. The contract was awarded by ZPMC to Kongsberg Maritime Engineering (KME), a wholly owned subsidiary of Kongsberg Maritime.

The full contract includes supply and integration of the electrical, telecom and integrated control systems, project management, interface management and engineering services at all stages. In addition, a significant technology scope of supply includes generators, switchboards, automation, navigation & DP systems, radio and satellite communications, networking and on board entertainment, safety technology and monitoring systems such as the advanced helideck monitoring system.

Pipes from Khartsyzsk Pipe are used for the Central Asia-China gas pipeline Metinvest Group's Khartsyzsk Pipe (Donetsk Region, Ukraine) manufactured over one million tons of large diameter pipes for construction of the Central Asia-China gas pipeline.

Khartsyzsk Pipe is a supplier of large diameter pipes for all participants of the transnational Central Asia-China gas pipeline project.

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Over one million pipes have been shipped for the Uzbekistan-China and Kazakhstan-China sections and the Beineu Bozoi-Shymkent gas pipeline.

Khartsyzsk Pipe's pipes will also be used for the construction of the 'C' branch of the Central Asia-China gas pipeline. This branch goes over the territory of Uzbekistan, Kazakhstan and Turkmenistan, and is designed to increase the transit of gas from Central Asia to China. It extends for 1,840 km. The design capacity of the 'C' branch will be 25 billion m3 of gas per year.

It is scheduled to be commissioned in 2014.

For construction of the 'C' branch, Khartsyzsk Pipe supplied single-seam 1,219 mm diameter pipes from high strength X80 grade steel with external anti-corrosion and internal epoxy coatings. The pipes were manufactured according to customer technical requirements based on the international standards API Spec 5L (level PSL 2), CSA Z 245.21 and API RP 5L2.

"This is yet another example of Khartsyzsk Pipe delivering an important order in good quality and on time. The compliance of our products with all modern requirements has been recognized at an international level. At the same time, we understand that the exploration of hard-to-reach deposits in the future will require fundamentally new pipes that would be resistant to severe temperature fluctuations, high working pressure and the corrosion on transported media. The experts of Khartsyzsk Pipe are keeping their eye on innovations in the production of welded pipes and are ready to put them into production within the shortest possible period of time according to customer requirements," said Pavel Uzbek, Khartsyzsk Pipe's general director.

Vallourec Awarded Offshore Contract by Total for ML-South Project in Brunei Vallourec has been awarded a $100 mil-

lion contract for the supply of premium pipes with VAM® 21 connections for the offshore ML-South Project, operated by Total’s affiliate Total E&P Borneo in Brunei. After a successful exploration campaign started in 2007, Total has a drilling program starting with 6 development wells from 2015. ML-South is located in Block B offshore Brunei and is an extension of the producing Maharaja Lela Jamalulalam field with water depth of approximately 65 meters, and is expected to hold important gas and condensate reserves.

The development wells will be producing at depth greater than 5,000m, in a highly corrosive environment and sustaining High Pressure/ High Temperature (HP/HT). These conditions position the project at a new field development frontier.

It highlights Total’s expertise in operating in very complex environments and consolidates Vallourec’s leadership position in supplying premium OCTG (Oil Country Tubular Goods) solutions to the oil & gas industry.

Didier Hornet, Managing Director of Vallourec’s Oil & Gas Activities, said: "We are honored to have been selected by Total for this complex offshore project. This contract recognizes Vallourec’s ability to provide the most advanced premium tubular solutions and services in the most challenging environments. We will work alongside Total to develop the local contribution to this project."

Vallourec will equip the wells with premium pipes the majority of which in high alloyed, corrosion-resistant grades, threaded with its latest premium connection VAM® 21. Casing and tubing will be manufactured in Vallourec’s European & Indonesian plants. The pipes are expected to be delivered to Total E&P Borneo for drilling operations scheduled to start in the second half of 2015. jan-mar 2014

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Iran Cancels Pakistan Gas Pipeline Loan Deputy Oil Minister Ali Majedi says Iran has no obligation to finance the Pakistani side of the project and also doesn't have the money. Majedi’s comments were posted on the oil ministry's website, shana.ir.

"Pakistani officials were told in recent talks that, given the sanctions, Iran is not able to finance construction of the pipeline (in Pakistan) and has no obligation to do so," he said.

He said Tehran will demand compensation if Islamabad fails to take Iranian gas by end of next year.

Under a valid contract, Pakistan is required to finish construction of the pipeline on its territory by the end of 2014.

"If a contractor is chosen today and pipeline construction begins today, it will take four years to complete it. Should Pakistan fail to take gas by the end of next year, Iran will demand compensation under the terms of the contract," he said.

Pakistan has welcomed an Iranian offer to approach third parties, including European companies, to finance the project.

The Iran-Pakistan pipeline is designed to help Pakistan overcome its mushrooming energy needs.

Pakistanis experience frequent blackouts.

Iran has already invested over $2 billion to construct the Iranian side of the pipeline. But there are serious doubts about how Pakistan could finance the $2 billion needed to construct the pipeline, which also faces US opposition

India-Pakistan-Iran pipeline remains the most viable option Despite the Foreign Office emphasising that

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India was looking for an undersea route to source gas from Iran, bypassing Pakistan in the process, reliable sources here maintained that the India-Pakistan-Iran (IPI) “Peace Pipeline” still remained on the drawing board and was the most viable option.

Following talks between Iranian Foreign Minister Mohammad Javad Zarif and External Affairs Minister Salman Khurshid last week, official sources suggested that one important subject, which was also discussed with the Oman Foreign Minister the same day, was the revival of an undersea pipeline project.

Official sources suggested that this pipeline, which would bypass Pakistan, was now technically feasible after the success of the North Sea undersea pipeline.

If Iran was looking at the cheapest way to get gas to customers, it would prefer European customers. But what Iran had in mind was providing spillover benefits of the surface pipeline to the region it passes through, especially the Makran Plateau common to both Pakistan and Iran and where poverty has fuelled subversive tendencies.

And, the sources suggested that the future of the IPI pipeline was entwined with the Chah-bahar port as Iran was keen to ensure that this town and the surrounding region of Sistan-Baluchistan Province also gained from the availability of gas.

The benefits will cross the border as development of industry due to availability of energy would give more employment opportunities to Pakistani youth. Interestingly, this is India’s approach too.

Its officials began two days of talks with their Pakistani counterparts here on Wednesday on exporting electricity.

Just 72 km from the Pakistani port of Gwadar being built with Chinese help, the first phase of developing the Chah-bahar port is nearly

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over. The Union Cabinet has already earmarked $100 millions for the development of the port in anticipation of Iran agreeing to involve India in developing the port as well as utilising a northbound route that enters into Afghanistan and Central Asia.

India and Iran have held several rounds of talks on sharing operations and developing the port.

After the latest conversation between the Iranian and Indian Foreign Ministers, official sources said Tehran will get back before Nauroz holidays (Persian New Year) with answers to queries raised. But the next government will have to work on several other fronts before Iran agrees to give India access to a port that faces the open sea unlike the bigger Iranian port of Bandar Abbas which is in the Persian Gulf.

don’t know how to work together,” acknowledged PP an official.

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Iranian Foreign Minister as well as other interlocutors have indicated that Iran is in no hurry to get the money back, held up due to sanctions by the US and the European Union. It would want this money, even if it accumulates further, to be utilised as export credit for some big ticket joint venture projects, possibly even a refinery at Chahbahar which is just 900 km away from Gujrat's Mundhra Port.

The biggest problem is despite deep energy and civilisational links, India and Iran are unfamiliar with each other’s processes and systems of doing business in other areas. “India does business with the West and so does Iran. But they are unfamiliar with the business situation in the other country. They jan-mar 2014

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Technology

Let it Flow Pipeline single phase flow assurance has been a concern for some time, as have been the solutions with related issues. However, multi-phase flow assurance is relatively recent, with the advent of wet gas and such, and this article looks at some of the technologies provided to maintain good flow.

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s the search for oil and gas moves farther offshore into deeper and more hostile environments, ensuring a reliable flow of product has become increasingly challenging. High pressures, cold temperatures and corrosive chemicals combine to increase viscosity and deposition, restricting flow – all while placing enormous demands on lines, risers and equipment.

Flow assurance is the analysis of thermal, hydraulic and production chemistry issues during the flow of fluids through pipelines and processes in the oil and gas industry. These issues arise during the design, operation and maintenance of gas/oil supply systems, which are often in deep water or challenging environments.

The term ‘Flow Assurance’ covers broadly the same meaning as the term ‘multiphase transport technology’: Design tools, methods, equipment, knowledge and professional skills needed to ensure the safe, uninterrupted transport of reservoir fluids from the reservoir to processing facilities.

The purpose of the flow assurance exercise is to predict the behaviour of a produced fluid as it travels

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along a pipeline or process and to highlight issues which could impact on safety, integrity, production capacity and availability. The issues identified are used as design parameters for pipe sizing, liquid handling capacity and materials selection. Strategies can then be developed to handle the formation of solids and emulsions ranging from mechanical removal (pigging), physical design (insulation), operating philosophy and chemical inhibition.

Flow assurance is extremely diverse, encompassing many discrete and specialized subjects and bridging across the full gamut of engineering disciplines. Besides n e t wo r k m o deling and transient multiphase simulation, flow assurance involves effectively handling many solid deposits, such as, gas hydrates, asphaltene, wax, scale, and naphthenates. Flow assurance is the most critical task during deep water energy production because of the high pressures and low temperature (~4 degree Celsius) involved.

The financial loss from production interruption or asset damage due to flow assurance mishap can be astronomical. What compounds the flow assurance task even further is that these solid deposits can

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interact with each other and can cause catastrophic blockage formation in pipelines and result in flow assurance failure.

Flow assurance is the analysis of thermal, hydraulic and production chemistry issues during the flow of fluids through pipelines and processes in the oil and gas industry. These issues arise during the design, operation and maintenance of gas/oil supply systems, which are often in deep water or challenging environments.

The efficient operation of pipelines transporting liquid or gaseous hydrocarbons is crucial. Any upset to the internal pipe surface can significantly impact both pipeline throughput and energy requirements for maintaining design flow rates. Maintaining a clean pipeline will help to maximize flow, will increase system longevity, will enhance system reliability while lowering associated safety risks and will, ultimately improve bottom line profitability for pipeline owners and operators.

monitor flow assurance for their pipelines. These include feasibility studies, FEED, simulation software, chemical inhibitors and monitoring systems.

The following are some of the technical support provided by technology providers.

DNV DNV GL provides expert advice across all of the following aspects of flow assurance: • Prevention of blockages from hydrates, waxes, asphaltenes and the impact of emulsions • Transient multiphase simulations for pipeline sizing and operating envelopes • Independent screening and selection of oilfield chemicals • HIPPS and flare/vent modelling providing protection from excessive pressures and high flows • Surge analysis and slugcatcher sizing

Throughout the operational life of pipelines, it is common to encounter deposits, including a build up of sand, scale, wax, asphaltenes, black powder, hydrates and e m u l s i o n s wh i ch c a n create flow restrictions, bore reductions, higher back pressures and accelerated corrosion.

Technical Support There are various types of technical support available for pipeline operators who want to

• Thermal behaviour of flowlines including pipeline insulation and active heating.

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This could be applied to: • New or extended subsea pipelines • New or extended offshore developments • Change of pipeline use Troubleshooting operational pipelines • Subsea tiebacks.

Tools

OLGA from SPT Group is the market leading simulator for transient multiphase flow of oil, water and gas in wells and pipelines.

Many aspects of multiphase flow, such as slugging, are dynamic phenomena and require the transient capability of OLGA to allow their prediction.

HYSYS is a simulation package from AspenTech that can be used for plant design, performance monitoring, troubleshooting, operational improvement and asset management. HYSYS includes a databank of over 18,000 components and all the industry standard equations of state.

PIPESYS from Neotechnology Consultants Ltd is an extension to HYSYS which gives the capability to model single and multiphase flow in pipelines and can be used to calculate pressure, temperature and hold-up profiles.

WaxPro is a steady state thermodynamic simulation tool developed by the Tulsa University Paraffin Deposition joint industry project. It is used in the investigation of wax deposition and wax prevention techniques in single and multiphase pipelines.

Multiflash from Infochem can perform multiphase equilibrium calculations between a number of phases of different types. The phases that can be modelled include gases, liquids and solids such as hydrates, waxes and asphaltenes.

Halliburton Halliburton Pipeline and Process Services provides a wide range of specialized pipeline cleaning solu-

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tions designed to address a number of flow assurance problems. Services include the following: • Routine Pigging • Progressive Pigging • Mechanical Pigging • Thermal Cleaning • Hot Oiling • Debris Pick Up Gel Pigging • Scale Removal • Wax Removal • Hydrate Removal • Black Powder Removal • Pre-Inspection Cleaning (for ILI) • De-Oiling • Change of Service Cleaning • Pipeline Decommissioning Cleaning SureStream® Flow Assurance Services To resolve the most challenging flow assurance problems, Halliburton has developed an integrated flow assurance service. With sound practical experience and combined knowledge, our specialists can be deployed to offer advice on an extensive range of parameters to prevent both flow assurance problems and system upsets arising. Where problems have already occurred, we can investigate, remediate and can continue to maintain those customer hydrocarbon systems where hydrates, wax, scales, asphaltenes and solid deposits have become an issue. These problems would be addressed through our range of Assessment & Consultation Remediation and Maintenance Services. As an integrated offering, the depth and breadth of the capability and expertise of SureStream® Flow Assurance Services is unequalled in the field.

Fluor Fluor has designed some of the world’s largest and longest offshore pipelines, successfully designing pipelines and flowlines to carry oil, gas, multi-phase production, gas condensate, and liquefied natural gas (LNG). Fluor provides engineering, procurement

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and project management, as well as operation and maintenance services, on subsea and deep water projects around the world. Engineering design expertise includes: • Shallow to ultra-deep water • Configurations of pipe-in-pipe, bundles, heated pipelines, wet insulated and single pipelines • Short tiebacks to long step-outs, complicated subsea architecture and export pipelines • Upheaval / lateral buckling analysis Fluor Offshore Solutions has an experienced staff in deep water riser design including: • Top tension risers • Steel catenary risers • Riser towers • Hybrid risers • Flexible risers • Vortex Induced Vibration (VIV) analysis • Installation analysis • Sage profile analysis of the profile and span length of a large diameter offshore pipeline Flow Assurance • PIPEPHASE® / PIPESIM® steady-state, multiphase flow simulation software for analyzing normal operations • OLGA® / PVTsim flow assurance and fluid characterization simulators for addressing transient operational issues • Fluent® / CFX® / ANSYS® / Abaqus® for FEA analysis of complex localized flow and heat transfer, and solidification / melting • Consideration of new and emerging technologies, such as low dosage hydrate inhibitors and subsea processing • OLGA simulation of the operation to clear accumulated liquid in a steep uphill section of a subsea flowline.

Schlumberger Successful production system design and operations requires a detailed understanding of

multiphase flow behavior. Flow modeling and simulation provides valuable insights into flow behavior, including the physics describing flow through the entire production systems, from reservoir pore to process facility.

The OLGA dynamic multiphase flow simulator models time-dependent behaviors, or transient flow, to maximize production potential. Transient modeling is an essential component for feasibility studies and field development design. Dynamic simulation is essential in deepwater and is used extensively in both offshore and onshore developments to investigate transient behavior in pipelines and wellbores.

Transient simulation with the OLGA simulator provides an added dimension to steady-state analyses by predicting system dynamics such as time-varying changes in flow rates, fluid compositions, temperature, solids deposition and operational changes.

From wellbore dynamics for any well completion to pipeline systems with all types of process equipment, the OLGA simulator provides an accurate prediction of key operational conditions involving transient flow.

Key flow simulation applications The OLGA simulator enables key flow simulation applications, including • liquids handling • sizing separators and slug catchers • managing solids (e.g., hydrates and wax) • simulating key operational procedures including start-up, shut-down, and pigging • modeling for contingency planning (kill mud density and kill flow rates for blowout control) • assessing environmental risk in complex deep water drilling environments.

From early conceptual and planning phases to full field production operations and contingency

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planning, the OLGA simulator helps you to determine the best design, operational procedures, optimization, and risk mitigation strategy.

Weatherford Flow assurance chemicals supplied by Weatherford include pipeline drag reducers used to increase crude oil or refined products flow through existing pipelines, pipeline hydro-test and dewatering chemicals, and pipeline cleaning chemicals.

Bio-Clear™ 242D - Synergistic blend of glutaraldehyde and quaternary ammonium compounds that effectively kills microorganisms, including sulfate reducing bacteria and algal slime forming bacteria. Highly potent to remove established bio-film and inhibit re-growth over a broad pH and temperature range.

Bio-Clear™ 250 - 50% active glutaraldehyde based biocide effective against many types of microorganisms, including sulfate reducing bacteria and algal slime forming bacteria.

Recommended dosage is 0.1 gal/1,000 gal of water (0.1 l/m3).

E-Gel - Cationic, high-molecular weight polyacrylamide copolymer that viscosifies ethylene glycol to create gel sealing plugs and viscous slugs for dehydration and isolation purposes. Can be added continuously while pumping or pre-mixed at a concentration range of 0.5 to 3.0% by volume of glycol used.

Floro Dye 649™ - 40 to 42% active liquid fluorescein dye used as a tracer in pipeline hydro-test fluids to help determine the location of leaks.

Dosage levels range from 15 to 30 ppm.

GO FLOW™ 125 - Dispersion of ultra-high molecular weight polymer in a nonaqueous base for use as a drag reducing agent in a wide

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range of refined products and fuels to increase pipeline throughput by decreasing pressure losses. Typical loading rate is 3 to 30 ppm depending on refined fuel characteristics and pipeline configuration.

GO FLOW™ 126 - Dispersion of ultra-high molecular weight polymer in a nonaqueous base for use as a drag reducing agent in a wide range of crude oils to increase pipeline throughput by decreasing pressure losses. Typical loading rate is 5 to 50 ppm depending on crude oil characteristics and pipeline configuration.

Conclusion Some of the most severe operational hazards are associated with the transportation of fluids. When oil, water, and gas simultaneously flow in a well or pipeline, many potential problems can arise. These problems include flow instabilities and solids formation that can block the flowpath, or erosion and corrosion can result in pipeline ruptures. With the immense financial implications caused by faulty pipelines it is imperative that flow assurance of operational pipelines be monitored and proper flow be ensured.

References 3M DNV Halliburton Fluor Institute for Energy Technology Omnisens PetroMin Schlumberger Teledyne Weatherford Wikipedia Wood Group

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Technology

Taking the Fight to Corrosion Corrosion is one of the biggest problems faced by pipeline operators.

There are several inspection and repair processes, such as pigging, to combat pipeline corrosion. This article assesses preventive methods such as coating and metalizing.

C

orrosion presents by far the biggest threat to integrity of facilities: onshore and offshore; surface and sub-surface. Corrosion induced failures can, not only cause downtime, shutdown and affect the production, but in many cases present major health, safety and environmental threats. Corrosion protection can be achieved by changing either the material or the operating environment. Material changes can include upgrading to corrosion resistant alloys or changing from metallic to non-metallic materials.

Environmental changes can be induced by introduction of oilfield chemicals, application of coating or by electrochemical means.

management policy and strategy and includes a clear set of corrosion management system requirements that can, and should, be considered normative.

They are based on the elements of a simple management model:

It is widely recognised within the oil and gas industry that effective management of corrosion will contribute towards the maintenance of asset integrity and achieve the following benefits: • compliance with statutory and corporate safety, health and environmental requirements; • reduction in safety and environmental hazard from leaks and structural failures; • reduction in unplanned maintenance, reducing costs; • reduction in deferment costs; • optimisation of mitigation, monitoring and inspection costs, and • improvement in the working environment with associated benefits.

Corrosion management has been defined as the part of the overall management system that develops, implements, reviews and maintains the corrosion

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Corrosion inhibitors historically used in the oil field can be grouped into several common types or mechanistic classes: passivating, vapor phase, cathodic, anodic, film forming, neutralizing, and reactive. The common material of construction in oil and gas production is carbon or low-alloy steel, so the primary aim is steel inhibition; other metals can also benefit from many of these inhibitors. Inorganic inhibitors, such as sodium arsenite (Na2HAsO3) and sodium ferrocyanide, were used in early days to inhibit carbon dioxide (CO2) corrosion in oil wells, but the treatment frequency and effectiveness were not satisfactory. This led to the development of many organic chemical formulations that frequently incorporated film-forming amines and their salts.

In the mid-1940s, long-chain polar compounds were shown to have inhibitive properties. This discovery dramatically altered the inhibitor practices on primary production oil wells and gas wells. It permitted operation of wells that, because of the corrosivity and volume of water produced along with the hydrocarbons, would not have been used due to economics. Perhaps entire reservoirs would have been abandoned because of the high cost of corrosion. Inhibitors also allowed the injection and production of high volumes of corrosive water resulting from the secondary-recovery concept of waterflooding. Tertiary recovery floods, such as CO2, steam, polymer, and in situ combustion floods, would usually be uneconomical without the application of corrosion inhibitors. At first, it was thought that organic compounds inhibit corrosion by adsorbing at the metal-solution interface. Three types of adsorption could be possible with organic inhibitors: p- bond orbital adsorption, electrostatic adsorption, and chemisorption. A more simplistic view of this mechanism of corrosion inhibitors can be described as controlled precipitation of the inhibitor from its environment (water and hydrocarbons) onto metal surfaces. A more recent view of the mechanism of oil/gas field corrosion inhibitors invokes the incorporation of the inhibitor into a thin corrosion-product film. This film

then becomes more resistant to the flow of ions and electrons, so the corrosion reaction is slowed.

Over the years, many improvements in inhibitor technology have been made in formulation and methods of applying inhibitors. The methods of evaluating the performance during their use have also advanced considerably.

Effective Coating vs Effective Metalizing Two popular forms of corrosion inhibition are through coating and metalizing. There is constant debate as to which is the better option and attempted one-upmanship by each camp. However, there has been, and I dare say never will be, a clear consensus as to which is the better option. It really depends on preferences, needs and priorities. Each of these methods has its strengths and drawbacks. However, managed correctly both can be effective.

Guidelines for Effective Coating As a coating maintenance program is being compiled, many factors need to be considered -budget, of course, plus local codes, government regulations and industry standards. In putting together such a program, here is a list of considerations. A solid, well-thought-out program can add years to the life of an asset’s coatings, protecting a company’s investment and extending the maintenance budget.

Every coating maintenance program is different.

Factors include the age of the asset and its existing coating, the fluid it transports, its locations, the overall environments in which it exists, above or below ground… certainly, a lot of variables. In this regard, it may be a good idea to break the project into zones and identify the individual requirements.

Factors include: • Chemical • Abrasion resistance • Impact resistance

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• • • • • •

In-service temperature resistance VOC requirements Cathodic protection compatibility Insulated or non-insulated. pH and Moisture Environment Mold or Mildew Issues

Work with a qualified coatings supplier to select the right coating for your project. Factors to consider include: • Film Thickness Requirements • Edge Retentive Requirements • Ease of Application • Surface Preparation Requirements • Application Temperature Capabilities • Return To Service Capabilities • Availability of New Technology These are areas of a project that are defined as “any area that cannot be prepared, coated and inspected according to the specifications.” If failure in any of these areas is a concern and if they can truly not be part of the coatings maintenance program, overall replacement may be the best option.

While this may carry a higher initial cost, consider the risk of future failures that could cause system shutdown, or, worse, result in property damage and potential litigation.

Work with a contractor who has experience in coating maintenance programs. Ask for credentials and references. Your chosen contractor should be willing to work with you to develop a specification and provide other value-added suggestions if necessary. Other things to consider are a contractor’s • record keeping procedures • safety program and compliance with federal and state health and safety regulations • experienced, field-tested personnel who can add value to the project through years of know-how • agreement to accept an independent inspector’s

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critiques, revisions and final sign-off throughout the project.

A third-party inspector should be selected as early in the process as possible. This company or individual should be an integral part of the process and completely understand the tasks at hand. A good resource is the Society for Protective Coatings’(SSPC) Qualification No. 5, the Standard Procedure for Evaluating the Qualifications of Coating and Lining Inspection Companies.

After specifications are developed and coating selection has taken place, it’s a good idea to involve everyone who will be involved in the project to understand the overall scope of the project. This is the time for questions to be raised to ensure that everyone involved understands deliverables and what is expected at project completion. The inspector should provide an overall project checklist that the contractor and coatings supplier can work from throughout the project to avoid any surprises at key inspection points and project completion.

Constant communication should take place as the project moves forward. Regular meetings, with field reports to the owner, will help provide assurance that the project is moving forward as planned.

Record the project’s progress, its completion and the coating system performance history on a regular basis. Digital photography and storage allow a maintenance engineer to keep a comprehensive history of the asset. Equip your inspectors with digital cameras and make certain that critical or selected “test” areas are recorded at regular intervals over the lifespan of a maintenance project.

The time to think about the next coatings system maintenance project is when the current one is completed. It’s still fresh in your mind, as well of that of the contractor and supplier.

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Get everyone together to discuss the project at length – what worked as planned, any surprises that needed to be addressed – and put together a plan for the future. It will ease the overall planning and budgeting process when the time comes for maintenance.

Through the selection of the metal to be sprayed, multiple types of protection can be attained. For example, Inconel can provide a seawater / erosionresistant coating for marine applications, while other wear-resistant coatings can be achieved with aluminum or nickel-based coatings.

Metalizing – What and Why Metalizing is a substitute for painting structural steel that protects steel for decades longer than paint alone. This is a proven process, which has been used around the world for 90 years. Steel of every shape and size may be metalized either in-shop before construction or on-site instead of less effective repainting. Metalizing is the most versatile and effective coating for protecting steel structures, such as bridges, available today.

The Verdict

The metalizing process always begins with proper surface preparation. Next, aluminum wire or zinc wire is continuously melted in an electric arc spray or gas flame spray gun. Clean, compressed air strips droplets of molten metal from the wire depositing these particles onto the steel forming the protective coating. This sprayed metal coating is both a barrier coating and a galvanic coating in one. A single metalized coating protects steel for 30 years or longer depending upon the application, coating thickness and sealing.

Micrograph studies substantiate that the metalizing process is the only thermal spray application that has no porosity. The ABS has issued certifications for zinc and aluminum applications performed by specialist machines.

Aluminum and zinc-form anodic coating protects against corrosion for many years. Aluminum ensures a heat-resistant coating that can withstand cyclic heat application of up to 600°C. By using arc spray instead of the flame spray process, the application rate is vastly increased, as is the quality of the coating.

As mentioned earlier, each of these methods and technologies has its merits and limitations.

Certainly, metalizing is purportedly more environmental-friendly, longer lasting and easier to maintain in the long run; however, due to a much larger initial capital outlay when compared to coating, it remains a much more expensive option for owners who need not require such a long shelf life. As the saying goes, different strokes for different folks, and it is critical that the most suitable corrosion management techniques be used in order to extend asset life and thus protect the asset owner’s bottomline.

References NACE Energy Institute Sherwn-Williams MTM Metalizing metalizing.com Energy Institution

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Technology

Pipeline Inspection Techniques

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vast network of pipelines transports large volumes of energy products over long distances from production wells to processing and consumption sites. Historically, pipelines have proven to be a relatively safe transportation mode. As with any infrastructure, the integrity can be affected by time dependent degradation and abrupt damage from outside forces. The pipeline industry relies on nondestructive testing (NDT) methods to detect and characterize the degradation and damage. To quickly and economically survey the large portions of the infrastructure, autonomous in-line inspection tools, commonly referred to as pigs, examine the pipe from the inside as they are propelled by the product flow.

Inspection tool developers are challenged to implement sensitive measurement technology on a platform that must survive the pipeline environment. Inspection tools must meet measurement specifications for long distances at high speeds, while negotiating tight bends that induce substantial forces, obstructions that protrude into the pipe, debris that forces the sensors from the pipe and other inspection dilemmas.

Furthermore, the reliability of the inspection system must be high since the pipeline anomalies are typically localized events, not general degradation. One inspection technology, magnetic flux leakage, can be implemented to overcome the physical barriers while adequately detecting and characterizing corrosion anomalies. Other technologies address other classes of anomalies such stress corrosion cracking, mechanical damage, seam weld anomalies and more precise corrosion assessment. Some pipelines, referred to as unpigable, have excessive physical or operational

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barriers that prevent the use of available pigs.

Crawler technologies are being implemented that overcome these barriers, sometimes with alternative inspection methods. After internal inspection, the details of the anomalies are commonly quantified after excavation using more classical NDT methods. In-the-ditch sizing methods for corrosion and cracking are used to quantify pigging results.

Application of Inspection Methods to Pipelines In-line inspection equipment is commonly used to examine a large portion of the long distance transmission pipeline system that transports energy products from well gathering points to local distribution companies. A piece of equipment that is inserted into a pipeline and driven by product flow is called a ‘pig’. Using this term as a base, a set of terms have evolved. Pigs that are equipped with sensors and data recording devises are called ‘intelligent pigs’. Pipelines that cannot be inspected using intelligent pigs are deemed ‘unpigable’. But many factors affect the passage of a pig through a pipeline, or the ‘pigability’.

The concept of pigability pipeline extends well beyond the basic need for a long round hole with a means to enter and exit. An accurate assessment of pigability includes consideration of pipeline length, attributes, pressure, flow rate, deformation, cleanliness, and other factors as well as the availability of inspection technology.

All factors must be considered when assessing the appropriateness of inline inspection (ILI) to assess specific pipeline threats.

In terms of implementing an integrity management plan (IMP), the first step is the evaluation of potential threats that exist in the pipeline or segment being considered and their credibility. Once the credible

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threats are established, the appropriate integrity assessment method(s) are then selected. Where instrumented non-destructive ILI tools are deemed appropriate, several preliminary aspects must then be considered. Otherwise, alternative integrity assessment methods that may include pressure testing and direct assessment will be required.

Each inspection technology implementation must be examined to determine suitability of both assessment of threats and passage of pipeline attributes.

Some pipelines may constitute a single source of supply to a locale that cannot be easily interrupted even for scheduled ILI or other maintenance operations. If an interruption does occur, alternative (and often very expensive) supply sources such as truck is required to maintain service. Even where suitable permanent launchers/ receivers (or some temporary configurations) are available, pipeline operating characteristics may need to be modified to conduct a successful ILI integrity assessment.

Such operating parameter modifications can impact gas delivery and may not be acceptable. Also, more detailed piggability assessment should be performed to ensure free passage of ILI tools.

The length of the pipeline or segment to be assessed is also an important initial consideration. It is rarely practical to run product driven ILI tools in short segments of pipeline that might include a short high consequence area (HCA), crossovers between pipelines, and short length laterals. Equipping such pipelines or segments for periodic ILI tool operation would be expensive unless the equipment was also used for other pipeline operational purposes such as liquid removal. Furthermore, the required flow conditions for proper ILI operation may be difficult to achieve in short segments. Costs for gas driven ILI tools are typically compared on an approximate cost/mile basis that includes the ILI vendor’s fixed mobilization charge. A typical cost/ mile

analysis shows that gas driven ILI run lengths should exceed about 50 kilometers (30 miles) to approach the least unit cost.

Other types of instrumented ILI tools (i.e., wireline ILI tools) are more appropriate for shorter lengths of pipe. Another initial consideration is the particular instrumented ILI technology that is capable of assessing the established threats and the suitability of that technology in pipelines.

Each of the available ILI technologies has its strengths and limitations for anomaly detection.

Inspection technologies for each of these conditions are at various stages of development. Many of the inspection technologies are product specific and may not applicable in gas or liquid pipelines in all cases.

Pipeline operating pressure and flow conditions can dictate if it is feasible to satisfactorily operate an ILI tool. For gas natural pipelines, low pressure (25-40 bar, 400-600 psi) and flow conditions may not be sufficient to efficiently drive a pig. A minimum gas pressure is needed to assure stable ILI operation since higher pressures create a higher density fluid column behind and in front of the pig thus minimizing speed variations and surges. The effects of low pressures can be more extreme in hilly terrain since the gas column would not effectively restrain the tool thus permitting velocity variations. Instrumented ILI tools should be operated within their recommended velocity ranges to achieve optimum inspection results. For example, magnetic flux leakage (MFL) tools speeds are typically 13 m/s and inspection results can degrade when an ILI tool when operated out of the recommended range, especially where excessive velocities occur.

Typical pipeline operating parameters may require modification to control flow rates and product pressures thereby optimizing ILI inspection

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results. In some pipelines, the pressure increases needed to assure satisfactory ILI operations may be precluded by pressure limiting restrictions.

This may include pressure regulator adjustments, compressor station operation modifications, and flow throttling with valves. ILI tools equipped with gas bypass technology are now being applied to provide improved inspection velocities in a wider range of flow conditions.

Solutions & Solution Providers 3P Services 3P Services offers in-line inspection (ILI) services for both onshore and offshore pipelines. Various inspection techniques are applied on-board "intelligent pigs", which measure different integrity parameters while being pumped through the pipeline together with the product. Pipelines are inspected for metal loss (such as internal and external corrosion), mechanical deformations and other features without interrupting the transportation process.

In-line pipeline inspection tools 3P Services has a well-proven range of in-line pipeline tools covering the following categories: • Magnetic flux leakage (MFL) high-resolution tools from 3in in diameter and larger; this is the classical tool to locate both internal and external metal loss such as corrosion • Direct magnetic response (DMR) tools to inspect for internal local metal loss in pipelines of 2in in diameter and larger, regardless of the wall thickness • GEO (high-resolution and multi-channel geometric) tools to identify discontinuities of the internal geometry (including dents and ovalities) of pipelines of 2in in diameter and larger • XYZ mapping available on any of the tool types • Buckle detectors for real-time geometric inspection during offshore pipe lay

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• Bi-directional offshore riser inspection • HandyScan: external MFL scanner equipment, sales and support; test heads from 2in and larger; tank floor scanners for bottom, wall and roof Inspection technology for difficult pipelines 3P concentrates on applying its inspection technologies in pipelines that are considered to be difficult or impossible to pig. Our unique modular design philosophy means that we tailor-make the inspection tools that we will use in nearly every inspection project. Some examples of these special applications include the following: • Bi-directional tools for pump-in/pump-out operation in single-access pipeline situations • GEO tools that negotiate, determine and measure mitred bends • MFL tools that can negotiate short radius elbows, for example 4in pipeline and 1.5D90° bends • DMR tools to inspect small-diameter pipelines with heavy walls • WAX tools to measure thickness of paraffin or other sedimentation • Multi-diameter lines • Lines with difficult and mitred bends • Difficult flow conditions Specialised inspection equipment All specialised inspection equipment is of genuine 3P Services’ origin. The development of all components, including hard and software, is carried out under one roof at 3P Services in Germany.

Marine-terminal loading and unloading pipelines "Unpiggable" pipelines include various types of marine terminal pipelines, which are often referred to as tanker-loading lines, tanker-unloading lines, jetty lines and submarine pipelines. As marine terminal operators rely on techniques that offer only partial inspection and qualitative

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condition assessment, often pipelines have never been pigged and much less inspected.

• Quality of pipeline repairs • Presence of water

A typical marine terminal pipeline connects a shore-based installation, such as a refinery or tank farm, to a subsea pipeline end manifold (PLEM).

The PLEM usually lies in water around 25m to 40m deep and is connected to a buoy by a flexible hose or hoses. Floating flexible hoses complete the connection to the tanker.

RoVisual is optimized for pipelines with transparent products and can be mounted on ROSEN cleaning tools ranging from size 16” to 56”.

As typical marine terminal pipelines have not being made for pigging, there is no access to the subsea end of the line to either insert or retrieve a pig. There is very often limited opportunity to get access even to the shore end of the pipeline as space can be very tight. While PLEM/SPM installations do have similar characteristics, each system and installation contains unique configurations.

The PLEM can connect to the shore with a single pipeline – or several. Diameters can vary and dualdiameter pipelines are occasionally encountered.

RoLeak is designed for robust and easy use, supported by intelligent software to automatically evaluate measurement results with the least possible effort for the pipeline operator.

Leak Detection Tool (RoLeak) ROSEN’s ultrasonic leak detection technology is the ideal inspection solution for liquid pipelines.

ROSEN ROSEN offers a complete range of services for highresolution and quality defect identification utilizing Geometry, MFL, UT, EMAT, EC and AE technology.

The Optical Inspection tool (RoVisual) is a unique ROSEN innovation that integrates a high quality camera with its own lighting support into a robust pipeline cleaning tool. RoVisual provides dramatic visualization of the inside of pipeline, capturing and recording the information on-board for review later.

With RoVisual the pipeline operator can investigate the pipeline for many key properties, including: • Pipeline damage (e.g. dents) • Cleanliness (e.g. degree of dust contamination) • Condition of pipeline fittings • (e.g.open valves, valve seals, guiding bars)

The Key Benefits : • Simple detection and location of small leaks in liquid pipelines • Easy launching and receiving • Tool accommodates various pipeline conditions • Automated data analysis of repeated inspection runs

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Combined ILI Technology Combined ILI technology provides accurate and efficient inspection results, making an invaluable contribution to pipeline integrity management.

ROSEN’s in-house development, design and manufacturing ensure robust, reliable inspection equipment that is modular and compatible through the entire inspection range. Specific integrity threats can be identified through the wide range of options available. Technologies can be combined on a single tool to tailor the inspection capabilities to specific inspection goals.

The tool's main unit is used for corrosion detection. It uses odometers, acceleration and orientation sensors, ancillary systems as well as the data processing and storage electronics.

The main body can be combined with various technologies and/or add-ons to create a tool with capabilities specific to the extended multiinspection challenge.

Shaw Pipeline Services A division of ShawCor, Shaw Pipeline Services provides reliable pipeline weld inspection services to the oil and gas industry. Shaw Pipeline Services' pipeline inspection techniques and procedures provide high-resolution weld evaluation using state of the art automated ultrasonic testing equipment.

Shaw Pipeline Services' ultrasonic testing equipment provides weld evaluation and defect sizing assessment for automatic, semi-automatic and manual welding processes.

Their pipeline inspection capability benefits from decades of experience in the pipeline industry.

Their procedures meet standard inspection specifications for Workmanship Acceptance Criteria or Alternative Acceptance Criteria based on the Engineering Critical Assessment (ECA) method.

They ensure that welding repairs are kept to a minimum by providing welders with quick and

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accurate process control feedback derived from ultrasonic inspection data.

Shaw Pipeline Services' "total weld inspection" philosophy incorporates the use of focused probe technology, augmented by Time Of Flight Diffraction (TOFD) techniques, to accurately locate and size flaws within a weld. In dynamic offshore environments, Shaw Pipeline Services continues to meet the ever-changing demands of its customers by successfully adapting its inspection techniques to increasingly challenging technical applications through hardware and software enhancements.

AUT Pipeline Inspection Technology and Applications Shaw Pipeline Services inspects onshore and offshore pipeline facilities where welding processes such as GMAW, SAW and Manual Stick are utilized. Shaw Pipeline Services also specializes in the inspection of risers, Steel Catenary Risers (SCR), flowlines, speciality fabrications and clad material systems. We have developed the largest, most experienced technican pool in the industry with over 130 AUT personnel, including 30 SCR qualified operators.

Their automated ultrasonic weld inspection equipment is readily adaptable for all fabrication scenarios including single, double and quad joint facilities, offshore S-Lay and J-Lay configurations.

Shaw Pipeline Services maintains sophisticated training facilities based in Houston and Great Yarmouth. These facilities are utilised for SPS personnel, client and contractor training.

Automated Ultrasonic Girth Weld Inspection (AUT) Shaw Pipeline Services was established in 1990 to deliver AUT services for the pipeline industry and is now regarded as the leading company in its field.

Led by a carefully planned growth strategy, Shaw Pipeline Services has successfully

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through the acquisition of the leading US pipeline inspection company, Edwards Pipeline Services. Growth continues to be a central strategy as we focus on the dynamic needs of our customers in a technically challenging environment.

TDW

expanded its equipment fleet to serve the global market.

Shaw Pipeline Services completed its first AUT weld inspection project in 1991, servicing a 270km, 48in pipeline for TransCanada Pipeline. In 1994 it introduced AUT technology in the Gulf of Mexico on the offshore Mars project.

In 1997 the division implemented its global expansion strategy with the acquisition of the UKbased QED. This enabled the division to strengthen its presence in the Eastern Hemisphere The same year Shaw Pipeline Services introduced AUT into Saudi Arabia on the Shaybah project. In 1998 its AUT technology was introduced to Latin America on the Gasbol project, to the North Sea on the Ketch Corvette projects, and to the Far East on the West Natuna project. In 1999 its AUT technology was introduced to the US land sector on the Alliance project.

As the new millennium rolled in, Shaw Pipeline Services further expanded its service capabilities

TDW delivers customized inline inspection services specifically engineered to optimize system performance with a minimum of downtime.

TDW inline inspection technologies are fully engineered to ensure pipeline integrity in even the harshest environments and provide the most accurate data available, usually in just one run.

Active Speed Control Technology - When a tool moves too quickly though a pipeline, data quality can suffer. Active Speed Control Technology is specifically designed to pair with MFL inspection technology for use in high velocity gas lines.

Deformation Technology - Engineered with sensors designed to ride directly on the internal pipe surface rather than behind a cup for increased sensitivity. High resolution data from these tools can be analyzed for induced dent strain and can precisely measure expanded pipe locations.

GMFL Technology - Provides accurate detection and sizing of internal and external metal loss and other ferrous anomalies. Engineered to negotiate reductions and reduce tool drag for more consistent velocities.

Inline Inspection Support Services - With inline inspection support services from TDW you can survey and optimize pipeline performance, troubleshoot potential problems and make downtime a thing of the past.

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KALIPER® 360 Technology - Specifically engineered for use in newly constructed pipelines and for pipelines currently in the active service of moving liquid, gas, chemical or other linetransportable products.

MFL Technology - Provides accurate detection and sizing of internal and external metal loss and other ferrous anomalies.

interpretation of the data logged provides useful information, enabling operators to make informed decisions about the integrity of their pipeline.

Applications of the SAAM tool include: • 3D out-of-straightness measurement • Locate internal debris (e.g. paraffin wax) • Locate internal bore restrictions (e.g. dents) • Locate internal corrosion • Log process data (pressure, temperature) • Diagnose and optimize pigging

Pull-Through Inspection Service - A cost effective, operationally-sound method for providing assessment of short, hard-to-pig pipeline segments.

SpirALL® Magnetic Flux Leakage Technology - Provides the most accurate long seam assessment possible without adding significant tool length.

XYZ Mapping - Allows operators to determine the precise centerline trajectory of a pipeline in latitude, longitude and elevation.

I n t e ra c t ive R e p o r t i n g S o f t wa r e - Designed with inline inspection services customers in mind, easy-touse Interactive Report software from TDW enables users to view potential problem areas and identify critical anomalies.

Weatherford Weatherford P&SS provides pipeline inspection services using SAAM, the Original Smart Utility Pig. The SAAM (Smart Acquisition Analysis Module) technology is a revolutionary inspection system, and provides a versatile, cost-effective solution to pipeline operators.

The SAAM unit is installed completely within a utility pig, and measures and records the pig’s behavior through a pipeline. Post-survey

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The SAAM tool can be used in a regular direct assessment and maintenance role, as well as in one-off troubleshooting applications.

• SAAM is a registered trademark in the United Kingdom.

References 3P Services PetroMin Pipeliner ROSEN Shaw Pipeline Services TDW Weatherford

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Technology

Tools for Internal and External Inspection With the need to protect the CAPEX as well as the valuable cargo within pipeline operators need to be constantly vigilant about the integrity of their pipelines. Regular and diverse inspections need to be carried out and there are a host of technology and service providers to aid this endeavour. This article outlines selected in-line and external inspection techniques and some of the proponents of these techniques.

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any pipeline operators are currently facing the consequences of an aging grid, making pipeline inspection increasingly important. Large parts of pipe networks can be inspected using in-line inspection (ILI) tools, also known as intelligent pigs. For pipelines that cannot be inspected internally, alternative techniques, such as external corrosion direct assessment (ECDA), can determine pipeline condition.

In-Line Inspection The pipeline industry has, for many years, used scrubbing and scraping devices to clean the inside of their piping systems. These devices – called “pigs” – reduce build-up of waxes and other contaminants along the pipe’s interior.

Sophisticated and sensitive in-line inspection (ILI) tools travel through the pipe and measure and record irregularities that may represent corrosion, cracks, laminations, deformations (dents, gouges, etc.), or other defects. As they run inside the pipe in a manner similar to the scrubbing and scraping devices known as pigs, these in-line inspection tools are often referred to as smart pigs.”

Smart pigs are inserted into the pipeline at a location, such as a valve or pump station, that has a special configuration of pipes and valves

where the tool can be loaded into a receiver, the receiver can be closed and sealed, and the flow of the pipeline product can be directed to launch the tool into the main line of the pipeline. A similar setup is located downstream, where the tool is directed out of the main line into a receiver, the tool is removed, and the recorded data retrieved for analysis and reporting.

Magnetic Flux Tools There are two types of tools commonly used for inspections of hazardous liquid pipelines based on magnetic flux measurements.

A Magnetic Flux Leakage (MFL) tool is an electronic tool that identifies and measures metal loss (corrosion, gouges, etc.) through the use of a temporarily applied magnetic field. As it passes through the pipe this tool induces a magnetic flux into the pipe wall between the north and south magnetic poles of onboard magnets. A homogeneous steel wall – one without defects – creates a homogeneous distribution of magnetic flux. Anomalies (i.e., metal loss (or gain) associated with the steel wall) result in a change in distribution of the magnetic flux, which, in a magnetically saturated pipe wall, leaks out of the pipe wall. Sensors onboard the tool detect and measure the amount and distribution of the flux leakage. The flux leakage signals are

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processed, and resulting data is stored onboard the MFL tool for later analysis and reporting.

A Transverse MFL/Transverse Flux Inspection tool (TFI) identifies and measures metal loss through the use of a temporarily-applied magnetic field that is oriented circumferentially, wrapping completely around the circumference of the pipe. It uses the same principal as other MFL tools except that the orientation of the magnetic field is different (turned 90 degrees). The TFI tool is used to determine the location and extent of longitudinally-oriented corrosion. This makes TFI useful for detecting seamrelated corrosion. Cracks and other defects can be detected also, though not with the same level of reliability. A TFI tool may be able to detect axial pipe wall defects – such as cracks, lack of fusion in the longitudinal weld seam, and stress corrosion cracking – that are not detectable with conventional MFL and ultrasonic tools.

Ultrasonic Tools There are two types of tools commonly used for inspections of hazardous liquid pipelines based on ultrasonic measurements.

Compression Wave Ultrasonic Testing (UT) tools measure pipe wall thickness and metal loss. The first commercial application of UT technology in ILI tools used compression waves. These tools are equipped with transducers that emit ultrasonic signals perpendicular to the surface of the pipe. An echo is received from both the internal and external surfaces of the pipe and, by timing these return signals and comparing them to the speed of ultrasound

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in pipe steel, the wall thickness can be determined.

Of particular importance to successful deployment of a UT tool is pipe cleanliness, specifically the removal of paraffin build-up within the pipe. This is especially important for crude oil lines. The use of a cleaning pig is recommended prior to use of UT tools.

Shear Wave Ultrasonic Testing (also known as Circumferential Ultrasonic Testing, or C-UT) is the nondestructive examination technique that most reliably detects longitudinal cracks, longitudinal weld defects, and crack-like defects (such as stress corrosion cracking). Because most cracklike defects are perpendicular to the main stress component (i.e., the hoop stress), UT pulses are injected in a circumferential direction to obtain maximum acoustic response.

Shear Wave UT is categorized as a liquid coupled tool. It uses shear waves generated in the pipe wall by the angular transmission of UT pulses through a liquid coupling medium (oil, water, etc). The angle of incidence is adjusted such that a propagation angle of 45 degrees is obtained in pipeline steel. This technique is appropriate for longitudinal crack inspection.

Baker Hughes The Baker Hughes VECTRA™ high-resolution magnetic flux leakage (MFL) in-line inspection

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service reduces integrity management program cost by minimizing verification digs and maintaining full product throughput during inspection.

This technology includes tri-axial sensors, gas bypass with active speed control, and an onboard inertial measurement unit (IMU).

The Baker Hughes V-LINE™ tethered MFL pipeline inspection service allows operators to verify the integrity of the pipeline and meet regulations at reduced cost even if there’s only a single point of access. The bidirectional capability eliminates pig launchers and receivers—and multiple cuts of the pipeline—reducing overall project operations time and money.

The V-LINE inspection service, which can now inspect up to 2.5 miles of pipeline, can validate direct assessments with one excavation in a readily accessible, less costly location.

The high-resolution MFL service offers a solution for pipelines that are unpiggable with traditional inline techniques. Real-time data allows completion of an on-site analysis so operators immediately know the pipeline’s condition even

in high-consequence or hard-to-access areas: tank farms and terminals, station dead legs and laterals, production and plant piping, airport fuel systems, electrical conduits, natural gas storage fields, and river or road crossings.

Rosen Based on 25 years of experience in ILI technology, ROSEN has developed a unique tool for characterizing and sizing dents. RoGeo•Xt incorporates high-resolution technology combining a touch-less electronic measuring system with the conventional calliper arm tools. This dynamic compensation technology provides highly accurate results both under dynamic and static conditions.

The tool is based on an innovative concept: it combines a traditional mechanical caliper arm with an electronic distance measurement system, thereby optimizing measurement accuracy and providing 100% circumferential coverage. Traditional mechanical caliper tool designs generate position signals on the basis of the movements of a mechanical arm. Since increased tool speeds mean that the mechanical arm can lose contact with the inner pipe wall while abrupt changes in the inter-

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nal surface may lead to inaccurate measurements, this puts severe limitations on inspection speed.

RoGeo•Xt overcomes these difficulties thanks to its ‘mechatronic’ design.

ROSEN's combined MFL / UT corrosion detection tool RoCorrMFL / UT employs twin inspection technologies to achieve enhanced performance in defect detection and sizing. Ultrasoni c t e ch n o l o g y (UT) can detect and accurately size defects where magnetic flux leakage (MFL) has limitations (such as large areas of uniformly-corroded metal loss and laminations).

Conversely, MFL can detect and size defects where UT has limitations (i.e. small corrosion pits and internal defects covered by wax or other deposits). With the combined MFL / UT tool, the strengths of both inspection methods provide the most comprehensive detection and sizing results in the market from a single run.

Weatherford MFL technology operates on a simple principle—where there is

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metal loss (i.e., corrision) the magnetic field leaks from the metal. The MFL tool detects this leakage field. MFL tools have a proven track record for the detection of metal loss on the outer and inner surface of the pipewall, as well as detecting general and pitting corrosion, corrosion in or near the girthweld, and construction defects within the girthweld.

We a t h e r f o r d builds on this proven technology with its MFL high-resolution tool. High- resolution translates into more reliable and accurate identification and characterization of pipeline anomalies, thus better data on the pipelines integrity status.

The software, anomaly database and analysis report (generated by the analysis center) are then compiled to form a comprehensive final report to document the integrity of the pipeline.

TFI technology incorporates a magnetic flux technique to detect and characterize narrow axially oriented anoma-

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lies by inducing a circumferential field path, rather than a longitudinal one. This method is sensitive to defects not normally detected by conventional magnetics, such as narrow axial external corrosion, cracks in long seam welds (SCC), gouges, axial notches in dents—as well as large individual cracks or large colonies of stress corrosion cracking (SSC).

Both of these tools have a proven track record, minimizing the need for expensive client-initiated verification excavations—important considerations when building a superior pipeline integrity management program. They are both well suited for use in any type of product line, whether oil, refined product, gas, water or condensate. They can be used onshore or offshore and are available in many different diameters.

The Weatherford proprietary visualization and analysis software package, providing a detailed database of anomalies, pipeline features, and geometry anomalies—allows data to be viewed in various formats.

Ultrasonic Tools There are two types of tools commonly used for inspections of hazardous liquid pipelines based on ultrasonic measurements.

Compression Wave Ultrasonic Testing (UT) tools measure pipe wall thickness and metal loss. The first commercial application of UT technology in ILI tools used compression waves. These tools are equipped with transducers that emit ultrasonic signals perpendicular to the surface of the pipe.

An echo is received from both the internal and external surfaces of the pipe and, by timing these return signals and comparing them to the speed of ultrasound in pipe steel, the wall thickness can be determined. Of particular importance to successful deployment of a UT tool is pipe cleanliness, specifically the removal of paraffin build-up within the pipe. This is especially important for crude oil lines. The use of a cleaning pig is recommended prior to use of UT tools.

Shear Wave Ultrasonic Testing (also known as Circumferential Ultrasonic Testing, or C-UT) is the nondestructive examination technique that most reliably detects longitudinal cracks, longitudinal weld defects, and crack-like defects (such as stress corrosion cracking).

Because most cracklike defects are perpendicular to the main stress component (i.e., the hoop stress), UT pulses are injected in a circumferential direction to obtain maximum acoustic response.

Shear Wave UT is categorized as a liquid coupled tool. It uses shear waves generated in the pipe wall by the angular transmission of UT pulses through a liquid coupling medium (oil, water, etc). The angle of incidence is adjusted such that a propagation angle of 45 degrees is obtained in pipeline steel. This technique is appropriate for longitudinal crack inspection.

Quest Integrity Group Quest Integrity Group’s InVista is a lightweight, hand-held ultrasonic in-line inspection tool (in-

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telligent pig) capable of detecting pipeline wall loss and corrosion in unpiggable or difficult-toinspect pipelines. The advantages of ultrasonic inspection over MFL are listed below. The pipeline geometry inspection data captured by the InVista tool is exceptionally powerful when combined with our LifeQuest™Pipeline fitness-for-service capabilities, providing an integrated solution set for the pipeline industry.

Ultrasonic inline inspection technology has numerous benefits over magnetic flux leakage (MFL) tools. Some of these benefits are listed below: • Lightweight, hand-held intelligent pig reduces safety and operational risk • Lower pressure differential requirements and bi-directional capability minimize line disruptions • Unique design reduces wear, impact and debris collection • Ultrasonic inline technology measurement delivers accurate, repeatable results • Linear ultrasonic sizing minimizes verification digs and improves excavation and repair confidence • Permanent line modifications not required • Efficient pipeline inspections minimize offline status • Onsite turnaround and rapid pipeline geometry inspection data analysis allows real-time operating decisions • Ultrasonic inline inspection technology does not permanently magnetize pipe like magnetic flux leakage tools, thereby eliminating demagnetization repairs

External Corrosion Direct Assessment (ECDA) Monitoring the integrity of buried onshore ferrous pipeline is a key concern for many manufacturers and process industries, primarily because these structures are out of sight. Therefore, it is crucial to have a comprehensive system in

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place that allows continuous evaluation of the structure’s condition.

External Corrosion Direct Assessment (ECDA) is a structured process used to evaluate buried onshore ferrous pipeline integrity. The ECDA goal is to enhance safety by managing the risk of pipeline corrosion failures while minimizing the cost required for excavations and repairs. ECDA may also be used when more established methods such as in-line inspection (ILI) and pressure testing are not possible or not practical. NACE Standard Recommended Practice on Pipeline External Corrosion Direct Assessment Methodology (RP0502-2002) describes the ECDA process as allowing “...the prediction of susceptible areas where corrosion activity has occurred, is occurring or may occur.”

Although ECDA field assessment techniques are well established, specialized field equipment and staff experienced in the collection, recording, and analysis of data are necessary to obtain reliable and meaningful results. Corrosion Service quickly embraced the new ECDA techniques and both our field and professional staff are well versed in their application. We are equipped with state-ofthe-art equipment for surveys and the collection of data which is then analyzed by professional engineers with many years of pipeline corrosion prevention experience.

The ECDA Process This four step process consists of: 1) Pre-Assessment; 2) Indirect Inspection; 3) Direct Examination; and 4) Post Assessment, which can be summarized as follows: 1. The “Pre-Assessment” step involves the collection and evaluation of historical data and pipeline characteristics. Based on this information, the feasibility of an ECDA application is determined and once affirmed, the pipeline is divided into regions with similar exposure and areas where the same

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indirect inspection tools may be used.

2. The “Indirect Inspection” step uses a combination of 2 or more above ground survey techniques such as close interval potential survey (CIPS), alternating current voltage gradient (ACVG), direct current voltage gradient (DCVG), AC attenuation for the identification of areas with corrosion activities or coating faults. The data is evaluated via systematic analysis and high-risk areas are identified for excavation.

3. The “Direct Examination” step covers the selection of sites to be excavated and the physical identification of defects requiring repair or replacement.

4. The “Post Assessment” step evaluates the previous 3 steps of the ECDA process and establishes a future assessment schedule Corrosion Service Corrosion Service has developed an integrated indirect inspection technique merging both the CIPS and DCVG measurements. This integrated technique allows data acquisition of both CIPS and DCVG simultaneously. Higher efficiency and lower survey costs are achieved by merging both techniques.

DCVG Survey with “Indication” of Suspect Coating Holiday Corrpro Corrpro is a world class provider of External Corrosion Direct Assessment (ECDA) related surveys and data analysis. Our Pipeline Services Division includes numerous personnel with more than 20 years experience in pipeline testing and integrity assessments. For more than 10 years, we have been one of the largest providers of these types of services in the United States.

Corrpro's ECDA services include:

Integrated CIPS/DCVG Survey Results

• Pre-Assessment • Indirect Examination • CIS potential surveys • DCVG surveys • Electromagnetic surveys • ACVG surveys • Soil studies • Resistivity surveys • Depth of cover • Sub-Meter GPS locating • Direct Examination • Excavate and inspect • Coating evaluation • Corrosion measurements

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45

• MIC investigations • Pipe strength calculations • Root cause analysis • Corrosion rate estimates • Post Assessment MATCOR MATCOR’s Direct Assessment process can be broken down into the following four components: • Pre-Assessment: Pipeline data review • Indirect Examination: Diagnostic testing evaluating cathodic protection (CP) on pipeline and surrounding corrosive environment • Direct Examination: Pipe exposure and physical examination • Post Assessment: Integrity modeling risk based analysis utilizing all data collected, to determine severity of corrosion Direct Assessment provides the information that is needed to determine the integrity of the pipeline, or it may be used in conjunction with or as an enhancement to the findings of other available technologies, such as smart pigging. Direct Assessment is one of the more valuable tools a pipeline operator has available to enhance the safety of his operations.

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Mears Group, Inc With Mears engineers, technicians, and construction personnel and equipment, they provide turnkey External Corrosion Direct Assessment services to the pipeline and gas distribution industry. Direct Assessment is an approved method for evaluating pipelines in HCA’s for Integrity Management as directed by PHMSA and the state regulatory commissions, along with ILI and Hydrotest.

ECDA or external corrosion direct assessment is a four step process including pre-assessment engineering, indirect field testing, construction bell hole digs and pipe evaluation and reporting, and a post assessment report outlining future evaluation requirements.

Mears are familiar with industry documents, including the pipeline integrity rules recently added to 49CFR192, the NACE Standard Recommended Practice 0502 and American Society of Mechanical Engineers B31.8S. Mears has performed ECDA tasks in accordance with a variety of integrity management protocols adopted by pipeline operators, such as those developed by Northeast Gas Association, Gas Technical Institute (GTI), and Pipeline Research Council International (PRCI) among others.

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Mears assists clients in development of ECDA Standards and protocols that are appropriate for their pipeline systems. The four-steps of the ECDA program are available in combination or individually to accommodate specific needs.

VELOSI VELOSI offers pipeline operators a comprehensive approach to all four stages of the ECDA process.

Their techniques are based on in-depth knowledge of the industry’s best practices and an extensive corrosion database. In all of their operations, the goal is to deliver the highest levels of confidence achievable with the fewest number of digs (for a more thorough understanding of your pipeline’s integrity). VAIL- Pipeline is software developed inhouse for ECDA.

system is being properly monitored for any damage or defects that might affect its capability to function safely and properly, as intended.

Conclusion Each of the inspection tools described above has advantages and disadvantages when it comes to measuring pipe for defects that could affect integrity.

In selecting the tools most suitable for inspections, pipeline operators must know the type, thickness and material of the pipe being measured; the types of defects that the pipe might be subject to (e.g., internal corrosion, external corrosion, weld cracks, stress corrosion cracks); and the risk presented by the pipe section being measured. It must also be kept in mind that all tools have their limitations, as the Pegasus pipeline reminded us, and much depends on the people analyzing the data and planning repairs, a process that can take many months.

References

Operators have the flexibility to either choose only those service areas of specific interest to them, or to utilize VELOSI’s expertise for the entire process. These ECDA services execute the complex requirements identified in NACE RP 0502, simplifying the entire process and yielding results that help to ensure pipeline safety and prolong asset life.

By using VELOSI’s ECDA services, operators can be assured that you are conforming to the requirements set forth in the NACE RP 0502, as well as having the confidence that comes with knowing that your

Alpha Pipeline Integrity Services, Inc. Baker Hughes Corrosion Service Corrpro DNV GL MATCOR Mears Group, Inc Quest Integrity Group Rosen U.S. Department of Transportation VELOSI Weatherford

PP

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calendar

2014

of events

MARCH 2014 IndoCBM 2014 26 – 27 March 2014 (Jakarta Convention Center, Indonesia) Tel: +62 21 8378 3757 Fax: +62 21 8378 1126 Email: indocbm.committee@i-eec. com Website: www.IndoCBM2014.i-eec. com

APRIL 2014 5 Annual FPSO th

6 - 9 April 2014 (Marina Bay Sands, Singapore) Email: register@ibcasia.com.sg Tel: (65) 6508 2401 Fax: (65) 6508 2407 Website: www.fpsoconference. com/asia

6th Annual Offshore Drilling 6 - 9 April 2014 (Marina Bay Sands, Singapore) Email: register@ibcasia.com.sg Tel: (65) 6508 2401 Fax: (65) 6508 2407 Website: www.offshoredrillingasia. com

6th Annual Offshore Support Vessels 7 - 9 April 2014 (Marina Bay Sands, Singapore) Email: register@ibcasia.com.sg Tel: (65) 6508 2401

Fax: (65) 6508 2407 Website: osvconference.com/singapore

JUNE 2014 SUBSEA Asia 2014 11 June 2014 (Conference) 12 - 13 June 2014 (Exhibition) (Kuala Lumpur Convention Centre, Malaysia) Contact Person: Mr Lim Cha Cheng Tel: (60) 3 4041 0311 Fax: (60) 3 4043 7241 Email: lcc@mesallworld.com Website: www.subseaasia.org

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Downstream Business Engineering and Technology 2014 (DBET 2014) 10 - 11 June 2014 (Kuala Lumpur, Malaysia) Tel: (65) 6222 3422 Fax: (65) 6222 5587 Email: natalialim@safan.com / zaman@safan.com Website: www.safan.com

4th Dynamic Positioning Asia Conference 2014 23 - 24 June 2014 (Resorts World Sentosa Convention Center, Singapore) Tel: (65) 6222 3422 Fax: (65) 6222 5587 Email: natalialim@safan.com / zaman@safan.com

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july 2014 World National Oil Companies Congress Asia 1 – 4 July 2014 (JW Marriott, Bangkok, Thailand) Contact Person: Paul Gilbertson Tel: (44) 20 7092 1245 Fax: (44) 20 7242 1508 Email: paul.gilbertson@terrapinn. com Website: www.terrapinn.com/ conference/world-national-oilcompanies-congress-asia

october 2014 8th Reliability, Asset Management and Safety Asia Conference 2014 (RAMS Asia 2014) 14 - 15 October 2014 (Kuala Lumpur, Malaysia) Tel: (65) 6222 3422 Fax: (65) 6222 5587 Email: natalialim@safan.com / zaman@safan.com Website: www.safan.com

DECEMBER 2014 OSEA 2014 2 – 5 December 2014 (Marina Bay Sands, Singapore) Contact: Chua Buck Cheng Tel: (65) 6233 6638 Fax: (65) 6233 6633 Email: osea@sesallworld.com Website: www.osea-asia.com

Calendar of Events This information is supplied ‘as is’. While every attempt has been made to ensure the accuracy of such information, the publisher does not accept responsibility for any loss or damage attributable to errors or omissions.

Organisers are advised to check the information and to notify the magazine

of any such errors or omissions. If e-mail is available, please also provide readers. To have e-mail address. This listing is a free service to your conference or exhibition listed please post, fax or e-mail details to Mary at mary@safan.com.

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51

advertising index Advertiser

ADVERTISING SALES OFFICES

Page No

Bredero Shaw (Asia) Pte Ltd

OBC

AP ENERGY BUSINESS PUBLICATIONS PTE LTD

C & C Technologies (Asia Pacific) Pte Ltd

17

19 Kim Keat Road #04-06 Fu Tsu Building

Check-6, Inc.

5

Singapore 328804 Tel: 65-6222 3422 Fax: 65-6222 5587 E-mail: mary@safan.com

DMI International, Inc. INACOATING 2014

21 IBC

Kongsberg Maritime Pte Ltd

SUBSEA ASIA 2014 TD Williamson, Inc.

9 27 1

Wasco Coatings Malaysia Sdn Bhd

IFC

The closing date for placing advertisements is not less than TWO WEEKS before the date of publication. Please contact our nearest advertising office for more details.

This index is provided as an additional service. The publisher does not assume any liability for errors or omission.

Conventions used within this magazine Barrel............................................bbl Thousand barrels...........................Mb Million barrels................................MMb Barrels per day..............................b/d Thousand barrels per day..............Mb/d Million barrels per day ..................MMb/d Metric ton......................................tonne Thousand tonnes...........................Mt

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Million tonnes................................MMt Tonnes per day..............................t/d Tonnes per year.............................t/y, tpa Thousand tonnes per year..............Mt/y Million tonnes per year..................MMt/y Tonnes of oil equivalent.................toe Thousand tonnes of oil equivalent..Mtoe Million tonnes of oil equivalent.......MMtoe

Cubic feet......................................cf Thousand cubic feet......................Mcf Million cubic feet...........................MMcf Billion cubic feet............................Bcf Trillion cubic feet...........................Tcf Cubic feet per day..........................cfd Million cubic feet per day...............MMcfd Billion cubic feet per day................Bcfd British Thermal Unit.......................Btu

Watt...............................................W KiloWatt.........................................kW MegaWatt......................................MW GigaWatt........................................GW Watt-hour......................................Wh KiloWatt-hour.................................kWh MegaWatt-hour..............................MWh GigaWatt-hour...............................GWh

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