OM Feb 2013

February 2013

Houston London Paris Stavanger Aberdeen Singapore Moscow Baku Perth Rio de Janeiro Lagos Luanda

World Trends and Technology for Offshore Oil and Gas Operations

For continuous news & analysiswww.offshore-mag.com

INSID

E:

Top

10dril

ling

contra

ctors

Drilling Market Review

Deepwaterspar design

Subsea capping technology

E&P offshore Asia

West Africa update

4D seismic

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http://www.offshore-mag.com

The low-hanging fruit is long gone. Every day it’s more of a challenge to increase oil and gas recovery and production from aging, under-producing fi elds and complex new ones: arctic and ultradeep subsea fi elds; tight sands, shale and thermal oil sands; HP/HT, long distance, deepwater complex pre-salt or lower tertiary formations. Whatever the need, we have the technology – rigorously proven in the world’s toughest situations – to raise your recovery factor and production to unprecedented heights. Not some day. Now.Learn more at www.MaximizeRecovery.com

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THE WORLD’S NEWSSTAND®

Previous Page | Contents | Zoom in | Zoom out | Front Cover | Search Issue | Next Page

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36

70

International EditionVolume 73, Number 2

February 2013

C O N T E N T S

Offshore (ISSN 0030-0608) is published 12 times a year, monthly by PennWell, 1421 S. Sheridan Road, Tulsa, OK 74112. Periodicals class postage paid at Tulsa, OK, and additional offices. Copyright 2013 by PennWell. (Registered in U.S. Patent Trademark Office.) All rights reserved. Permission, however, is granted for libraries and others registered with the Copyright Clearance Center, Inc. (CCC), 222 Rosewood Drive, Danvers, MA 01923, Phone (508) 750-8400, Fax (508) 750-4744 to photocopy articles for a base fee of $1 per copy of the article plus 35¢ per page. Payment should be sent directly to the CCC. Requests for bulk orders should be addressed to the Editor. Subscription prices: US $101.00 per year, Canada/Mexico $ 132.00 per year, All other countries $167.00 per year (Airmail delivery: $234.00). Worldwide digital subscriptions: $101 per year. Single copy sales: US $10.00 per issue, Canada/Mexico $12.00 per issue, All other coun-tries $14.00 per issue (Airmail delivery: $22.00. Single copy digital sales: $8 worldwide. Return Undeliverable Canadian Addresses to: P.O. Box 122, Niagara Falls, ON L2E 6S4. Back issues are available upon request. POSTMASTER send form 3579 to Offshore, P.O. Box 3200, Northbrook, IL 60065-3200. To receive this magazine in digital format, go to www.omeda.com/os.

Celebrating Over 50 Years of Trends, Tools, and Technology

DRILLING MARKET REVIEW

Drillers see future as ultra-deep............................................. 36The winnowing of the fleet and the sudden appearance of Shelf Drilling

International are part of the same trend, as the major drilling contrac-

tors divest older assets and cultivate fleets of high-spec, ultra-deep

drilling units that can command top-dollar day rates and tackle the

technical challenges of exploration and production in harsh and remote

environments. It is a process of “high-grading” that analysts expect to

continue for months to come.

Assessing the offshore drilling market .................................. 44Drilling contractors compete in regional markets with rigs of different

classes, qualities, and specifications. The first part of this three-part

series describes ownership structure and how public firms are valued

by the market. The primary factors that impact valuation are revenues,

net earnings, fleet values, and debt load.

ASIA

Operators ramp up activity offshore Asia............................... 50Economic growth in the Asia/Pacific region is driving demand for oil

and gas increasingly offshore, and international operators and national

oil and gas companies are taking action on a number of fronts to answer

that demand.

Salamander builds niche in underdeveloped Thai, Indonesian plays ............................. 54One of the fastest-growing independents in the Southeast Asia region is

London-based Salamander Energy. Since its formation in 2006, the com-

pany has built exploration and production hubs offshore and onshore

Thailand and Indonesia. Offshore spoke to COO Mike Buck for further

insights into progress to date and future plans.

WEST AFRICA

Deepwater, subsea projects propeloffshore West Africa activity................................................... 58As East Africa rapidly emerges as a frontier province with major gas dis-

coveries offshore Mozambique and Tanzania, West Africa continues to

advance plans for new and existing exploration and production projects.

GEOLOGY & GEOPHYSICS

4D seismic, seabed monitoring growing in importance ........ 62The increasing acceptance and application of 4D seismic techniques in

both exploration and production indicates that time-lapse 3D explora-

tion and reservoir monitoring are coming of age as tools to de-risk drill-

ing and to maximize the return on investment of field development.

DRILLING & COMPLETION

Production optimization: A question with many answers............................................... 66The term “production optimization” means different things to different

operators. It points to the well-known but little understood fact that the

state of optimization varies from company to company and the cures for

sub-optimal performance vary as well.

ENGINEERING, CONSTRUCTION,

& INSTALLATION

Finland yard maintains leadership in GoM spar hulls............ 70Of the 17 spar platforms in service today, 12 incorporate hulls built

at Technip’s specialized construction yard in Pori, western Finland.

Another hull is about to be delivered to Anadarko, the leading advocate

of deepwater spars, for the Lucius project in the Gulf of Mexico.

PRODUCTION OPERATIONS

Retrofit corrosion protection offers life extension................. 74With the original cathodic protection systems of many fixed and float-

ing oil and gas platforms in the North Sea reaching the end of their

designed lives, retrofit corrosion protection systems will need to be

installed over the next few years to allow operators to safely extend the

platforms’ lives. The importance of designing for reliability, integrity

and maintenance is clear, and corrosion protection is an essential part

of the solution.

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Connections made simple.Finally, a global communications provider that makes it easier to connect all the right people

in the right places.

Choosing communications solutions and services from Harris CapRock gives you simple access to the best satellite, wireless and terrestrial technologies. But more than that, our reliable, high-performance communication services keep you connected, giving you the means to improve the daily operations of your exploration and production assets, to enhance the HSE (Health, Safety and Environment) impact of your business and to improve crew morale by keeping your remote workers connected.

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International EditionVolume 73, Number 2

February 2013

D E P A R T M E N T S

SUBSEA

Industry advances subsea capping technology........................................................ 78Industry and government responses to the Deepwater Horizon blowout and subsequent oil spill

continue to evolve around the world even as the legal issues continue to be addressed in the

courts.

FLOWLINES & PIPELINES

Subsea wet insulation system applies solid silicone science.................................. 82A new engineered thermal insulation solution is being introduced to help meet the flow assur-

ance needs of subsea oil and gas operations. Formulated with silicone expertise, application

experience, and industry collaboration, the proposed advanced technology for subsea wet insula-

tion systems uses a solid silicone, unlike syntactic foams or silicone resins that contain glass

microspheres.

Expansion of Angoflex showcases Technip’s umbilical capability in Africa ........... 86In 2002, in response to increasing demand in the region, Technip and Angolan state oil company

Sonangol EP agreed to build Africa’s first umbilical manufacturing plant, known as Angoflex

Ltda. The expanded facility was commissioned in 2012, and is currently working on its first proj-

ect sourced by 100% local content, for Total’s multi-field CLOV development in block 17.

COVER: Drilling contractors are

busy upgrading their fleets with ultra-

deepwater semisubmersibles, drill-

ships, and high-specification jackups

in anticipation of increased activity

and high demand for premium assets.

Shown here is Transocean’s ultra-

deepwater drillship Discoverer Clear

Leader, which is capable of operat-

ing in water depths down to 12,000

ft. The rig, which went into service

in 2009 as the first of Transocean’s

enhanced enterprise-class drillships,

is currently working in the US Gulf of

Mexico under a contract with Chev-

ron. (Photo courtesy Transocean)

Online .................................................... 8

Comment ............................................. 10

Data ..................................................... 14

Global E&P .......................................... 16

Offshore Europe .................................. 22

Gulf of Mexico..................................... 24

Subsea Systems ................................. 26

Vessels, Rigs, & Surface Systems...... 28

Drilling & Production .......................... 30

Geosciences ........................................ 32

Offshore Automation Solutions .......... 34

Business Briefs ................................... 90

Advertisers’ Index ............................... 95

Beyond the Horizon ............................ 96

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8 Offshore February 2013 • www.offshore-mag.com

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®

Latest newsThe latest news is posted daily for the offshore oil and gas industry coveringg

ttechnology, companies, personnel moves, and products.www.offshore-mag.com

New On Demand Webcasts

➤ SEMS I and II: Compliance strategies for the new Safety and Environmental Management Systems regulations

Regulations from the Bureau of Safety and Environmental Enforcement and iincreased scrutiny from investors and the public have left companies search-iing for safer and more environmentally sound methods to extract oil and gas ffound in deep and ultra-deepwater. Skip Koshak of Shell and Charlie Williams oof the Center for Offshore Safety discuss the regulations that require offshore ooperators and contractors maintain comprehensive safety and environmental pprograms to strengthen drilling safety and reduce the risk of human error. TThey review the best practices to develop, implement, and maintain a SEMS pplan, and what to expect when SEMS II takes effect in November 2013.

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➤ Geohazard prediction in deepwater wells

In high-pressure/high-temperature environments, the lateral extent, struc-ttural position and architecture of the reservoirs become much more critical to tthe viability of a prospect, and also determine the range of safe depths where aa specifi c reservoir can be penetrated without the risk of a pressure infl ux. Dr. AAlan R. Huffman, chief technology offi cer of SIGMA³ Integrated Reservoir SSolutions, discusses how the accurate prediction of the reservoir pressures at aa specifi c penetration point can be the difference between an effi ciently man-aaged drilling operation and a potentially catastrophic pressure infl ux event.

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New maps, posters, & surveys• Gulf of Mexico Map• 2013 Deepwater Gulf of Mexico Discoveries• 2012 Worldwide Survey of Spar, DDCV, and MiniDOC Vessels• 2012 Worldwide Survey of Heavy-Lift Vessels• 2012 Worldwide Survey of FPSO Units

Download: http://www.offshore-mag.com/maps-posters.html

Browse Offshore magazineePeruse the cover issue and archives back to 1995.

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10 Offshore February 2013 • www.offshore-mag.comTo respond to articles in Offshore, or to offer articles for publication,

contact the editor by email ([email protected]).

C O M M E N T David Paganie • Houston

Qatari energy ministeroutlines challenges ahead

The Middle East holds the greatest share of global proved oil and natural gas re-serves, with a reserves-to-production ratio for oil of about 80 years and over 150 yearsfor natural gas. Nearly 33% of total world oil supply is from the region. Meanwhile, en-ergy demand in the Middle East is expected to continue to grow at a steady pace, un-derscored by expanding populations and rapid economic development (Doha, Qatar, isa prime example). Oil demand in the region grew by about 60% during the past decade,an average of 225,000 b/d per year, exceeding every region except China.

Seemingly with long-term energy security intact and a vital role to play in fuelingglobal energy demand, the region has it challenges and HE Dr. Mohammed bin SalehAl-Sada, Minister of Energy & Industry, State of Qatar, is calling on industry leaders toaddress those challenges.

“It is of paramount importance for the decision makers in the region to assess the nu-merous challenges pertaining to the energy sector as a whole and to the offshore industryin particular,” he said. “This will require coordinated efforts between major players alongthe entire energy value chain to lay the groundwork for the development of this industry.”

HE Dr. Mohammed bin Saleh Al-Sada gave the keynote address at Offshore MiddleEast Conference & Exhibition (OME) in Doha, Qatar, last month.

He noted that today, the oil and gas industry “faces the biggest need ever for newideas, new paradigms, and new innovative technologies, particularly in the offshore ar-eas to overcome the constraints of the conventional approach, if it desires to meet thefuture world demand for energy.”

In Qatar, home of the third-largest reserves of natural gas in the world, its target,according to Al-Sada, is to “maximize Qatar’s marine crude oil production while optimiz-ing operations and adopting the latest suitable technology, with a specific emphasis onefficiency, cost effectiveness, safety and the environment.”

Despite its self-imposed moratorium on the development of new hydrocarbon proj-ects, work offshore Qatar continues. Engineering work is underway at the offshoreBulHunain oil field to double production from 45,000 b/d to 90,000 b/d, and three of thelargest wellhead platforms ever built in the North field will be installed in the offshoreBarzan field to produce 1.4 bcf/d of gas for domestic consumption, by 2014.

Perhaps Qatar’s biggest offshore challenge in the medium-term is sustaining produc-tion from the North field and managing its aging offshore infrastructure. Moreover, itis understood that, through debottlenecking, it could increase its production by another10% at short notice. Emerging competition in the LNG export market could pose newchallenges in the future, but not any time soon. The next Offshore Middle East Confer-ence & Exhibition will be held in January 2015, once again in Doha.

Reviewing the drilling marketThis issue contains some key insights with regard to the offshore drilling market.

First, Senior Technical Editor Russell McCulley notes that a couple of things stand outwhen comparing rig statistics from this year’s list of the Top 10 drilling contractors andlast year’s list. He finds that the total number of rigs managed by the leading drillers fell,from 581 at the start of 2012 to 538 at the end of the year, and the number of working rigsoperated by those companies also decreased by about 10%, from 400 to 361, accordingto the research firm IHS Petrodata. The second is the debut of Shelf Drilling, the Dubai-based startup that landed a spot at number seven on the Top 10 list with last year’s $1.05 billion purchase of 37 shallow-water jackups and one swamp barge from Transocean.For more of McCulley’s analysis, turn to page 36.

In addition, Mark J. Kaiser and Brian F. Snyder of the Center for Energy Studies atLouisiana State University offer their assessment of the offshore drilling market. In thisfirst of a three-part series, the authors examine the ways in which drilling contractorscompete in regional markets with rigs of different classes, qualities, and specifications.Their analysis, which starts on page 44, finds that fleet values depend upon rig specifi-cation, market conditions, and contract backlog.

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Worldwide offshore rig count & utilization rate

January 2011 – December 2012

950

850

750

650

550

450

350

100

90

80

70

60

50

40

No

. o

f ri

gs

Fle

et u

tiliza

tion

rate

%

Jan

11

April11

July

11

Oct

11

Jan

12

April12

July

12

Oct

12

Contracted fleet utilization Total fleet Contracted Working

Sourc

e: IH

S

Asia/Pacific total reservers onstream 2008-2017

100

90

80

70

60

50

40

30

20

10

0

Vietnam

Malaysia

Thailand

Japan

Sri Lanka

Indonesia

South Korea

India

Philippines

China (Taiwan)

PapuaNew Guinea

China (PRC)

Pakistan

Brunei

New Zealand

Bangladesh

Myanmar

Australia

Source: Infield Systems Ltd.

2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

To

tal

res

erv

es

(%

)

Worldwide day rates

Year/Month Minimum Average Maximum

Drillship

2012 Jan $155,000 $432,407 $690,000

2012 Feb $155,000 $438,974 $672,000

2012 Mar $155,000 $438,541 $671,000

2012 Apr $157,000 $443,204 $671,000

2012 May $157,000 $439,230 $671,000

2012 June $50,000 $433,976 $671,000

2012 July $50,000 $438,074 $671,000

2012 Aug $50,000 $442,213 $671,000

2012 Sept $50,000 $429,391 $671,000

2012 Oct $50,000 $427,920 $672,000

2012 Nov $50,000 $443,074 $672,000

2012 Dec $50,000 $450,437 $672,000

Jackup

2012 Jan $36,000 $106,929 $339,000

2012 Feb $36,000 $107,557 $339,000

2012 Mar $36,000 $107,745 $366,000

2012 Apr $36,000 $108,062 $366,000

2012 May $36,000 $108,527 $366,000

2012 June $36,000 $110,792 $366,000

2012 July $30,000 $111,531 $366,000

2012 Aug $40,000 $111,542 $366,000

2012 Sept $40,000 $111,945 $366,000

2012 Oct $30,000 $112,419 $366,000

2012 Nov $30,000 $114,706 $366,000

2012 Dec $30,000 $116,345 $366,000

Semi

2012 Jan $30,000 $360,709 $655,000

2012 Feb $137,000 $362,236 $655,000

2012 Mar $137,000 $357,799 $655,000

2012 Apr $137,000 $361,575 $655,000

2012 May $125,000 $360,566 $655,000

2012 June $125,000 $359,528 $655,000

2012 July $69,825 $353,695 $675,000

2012 Aug $69,825 $360,211 $675,000

2012 Sept $130,000 $358,319 $675,000

2012 Oct $130,000 $358,602 $655,000

2012 Nov $130,000 $364,227 $655,000

2012 Dec $137,000 $366,625 $655,000

Source: Rigzone.com

G L O B A L D ATA


This month Infield Systems looks at planned fielddevelopments within the Asia/Pacific region; a key globalgrowth market in terms of offshore production andenergy demand over the next five years.

Seven of the top 10 field developments expectedonstream over the 2013-2017 timeframe are offshoreAustralia. The three largest developments: Jansz,Gorgon North, and Gorgon Central are expected to com-mence production before the end of 2014. Australia’sreserve additions over the forecast period are anticipatedto account for 34% of the Asia/Pacific region total.

The two largest developments outside Australia areexpected to enter production during 2013. China’s Liwan03-1 deepwater gas development, jointly operated byHusky and CNOOC, holds potential reserves of 5 tcf andis anticipated to form the cornerstone of future growth inthe region for the Canadian operator. The second largestdevelopment is expected to be the Shwe field offshoreMyanmar. The Shwe development, which includes theShwe, Shwe Phyu, and Mya discoveries, is estimated to

hold combined gas reserves between 4.79 and 8.63 tcf. Operated by Daewoo, Shwe is expected to comeonstream via a fixed production platform.

Malaysia is expected to bring onstream the second largest proportion of reserves in the region with de-velopment led by ConocoPhillips’ Gumusut-Kakap project; the third largest development outside Australiaduring the forecast period. The development saw early start up in January, ahead of the completion of theFPS. Currently tied-back to the Kikeh production facility offshore Sabah, the field’s FPS is expected to beinstalled toward the end of 2013.

Offshore Indonesia, the Gendalo Gehem joint project is at the forefront of the country’s offshoredevelopment and is globally acknowledged as one of the key deepwater fields expected to come onstreamduring the period. Operator Chevron awarded the FEED package for the development to Technip andWorley Parsons in July of 2012.

– Catarina Podevyn, Analyst, Infield Systems Ltd.

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G L O B A L E & P Jeremy Beckman • London


North AmericaExxonMobil has launched the $14-billion Hebron development,

350 km (217 mi) offshore Newfoundland. The project takes in theHebron, Ben Nevis, and West Ben Nevis oil fields, extending overfour licenses. They will be produced via a gravity base structure(GBS) platform with an integrated topsides deck and living quar-ters, strengthened to withstand sea ice and roaming icebergs. Oilproduction capacity will be up to 150,000 b/d with storage in thebase for 1.2 MMbbl. Construction of the GBS has started at the BullArm yard in Newfoundland and Labrador, and work on the topsidesshould begin later this year. First oil is scheduled for late 2017. Exx-onMobil and partners Chevron, Suncor Energy, Statoil, and NalcorEnergy aim to recover more than 700 MMbbl during the field’s 40-year lifetime.

South AmericaAnadarko is reportedly teaming with Ecopetrol to explore three

blocks in the Caribbean Sea, offshore Colombia. These include FuerteNorte and Fuerte Sur and cover a total area of 10,320 sq km (3,985 sqmi). Following seismic acquisition, drilling could start at the end of 2014.

Peru’s government has approved Pacific Rubiales’ farm-in to 49% ofthe Peruvian offshore block Z-1 license from operator BPZ Energy for$150 million. The transaction will help fund a new phase of exploration.

In the ultra-deepwater Espirito Santo basin offshore northeast Brazil,Statoil has agreed to take Vale’s 25% interest in the Petrobras-operatedBM-ES-22A concession. This comprises two blocks adjacent to theBM-ES-32 license, where Statoil is already a partner, and which con-tains the 2010 oil discovery Indra. Assuming regulatory approvals,the company expects to participate in an ongoing appraisal well onan extension of Indra into BM-ES-22A, and more exploration drillingcould follow later this year.

•••Production has started from Sapinhoá, Petrobras’ second giant

field development in the presalt Santos basin. The FPSO Cidade de

Sao Paulo, in block BM-S-9, should initially produce 15,000 b/d of oilfrom one well, eventually rising to 120,000 b/d and 176 MMcf/d of

gas from six production wells. Some of the gas will be set aside forreinjection, with the remainder exported through the subsea Lula-Sapinhoá-Mexilhão pipeline for treatment in Caraguatatuba on theSao Paulo state coast. A second FPSO, Cidade de Ilhabela, shouldenter service on Sapinhoá during the second half of 2014.

•••Petrobras has three more deepwater oil finds off Brazil. A well in

the Campos basin near the P-56 platform, serving the Marlim Sulfield, found heavy oil in a postsalt Eocene accumulation named Man-darim. Characteristics appear similar to oil produced from the mainMarlim field. A tieback to P-56 could follow.

In the Santos basin, another presalt well discovered oil in carbon-ate reservoirs in the Carcará structure in block BM-S-8. However,development appears unlikely before 2016. Finally, a fifth well onthe Sud de Tupi area has encountered oil, again in carbonate rocksbeneath the salt layer. It was due to be deepened, followed by a for-mation test.

West AfricaPlains Exploration & Production (PXP) has agreed to take a 52%

operating interest in the Mazagan exploration concession offshoreMorocco from current incumbent Pura Vida Energy. If ratified bythe government, PXP will fund 100% of activities that will likely in-clude two wells, up to a limit of $215 million. The permit is in theEssaouira basin, with prospects at Miocene and lower Cretaceouslevels. The first well, probably drilled next year, will target the 1.5-Bbbl Toubkal structure.

•••London-based Elenilto has become operator of the Senegal Off-

shore Sud Shallow Oil production-sharing contract, which spans7,920 sq km (3,058 sq mi) in the southern Senegal Casamanca basin.Analysis of existing 2D seismic suggests potential of 500-800 MMbblof oil in the main leads. Elenilto has identified two areas of interestand plans a 3D seismic survey, followed by drilling.

•••The semisubmersible Eirik Raude is drilling the first of two ex-

ploration wells offshore Liberia for African Petroleum. Bee Eater-1is on block LB-09, 9.5 km (5.9 mi) northwest of last year’s Turonianoil discovery, Narina-1. It will test a possible westerly extension ofNarina, updip of the presumed oil/water contact. The location ofthe next well has yet to be determined. African Petroleum estimatesprospective resources for the giant Bee Eater/Narina fan system at840 MMbl, with more than 2 Bbbl potentially spread among otherstructures on LB-09 and adjacent block LB-08.

•••Hess too has an oil discovery at the Turonian level to the east, off-

shore Ghana. The Pecan-1 well on the Deepwater Tano/Cape ThreePoints license encountered 245 ft (74.6 m) of net pay in two separateintervals in 8,245 ft (2,513 m) of water. It was then side tracked andsuspended. This was the company’s fifth find on the block, wheregas condensate has also been proven. Next up for Hess will be a wellon the Cob prospect, 15 mi northeast of Pecan-1.

•••ConocoPhillips expects to complete the sale of its Nigerian busi-

ness unit by mid-year to Oando for $1.79 billion. The package in-cludes a 95% operating interest in offshore license OML 131 (includ-ing the Chota field), and 20% of OPL 214, containing the Uge field.

•••Harvest Natural Resources has proven oil at presalt level offshore

Gabon. The semisub Scarabeo 3 drilled the Dussafu Tortue Marin-1well on the Dussafu license in 380 ft (116 m) of water. It intersectedtotal pay of 195 ft (59.5 m) in the Gamba formation and in stackedreservoirs in the Dentale formation. Further tests and a side trackwere due to follow.

Statoil’s farm-in concession in the Espirito Santo basin.

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G L O B A L E & P

Black SeaSterling Resources has struck gas with its

second exploration well offshore Romania.The Eugenia-1 well, operated by subsidiarycompany Midia, intersected 22 m (72 ft) ofgas-bearing late Cretaceous sandstones onthe Pelican block. More gas could be pres-ent at the Eocene level.

CGG Veritas’ Oceanic Champion has beenacquiring the first 3D seismic over the Ro-manian shallow-water Neptun block for op-

erator OMV Petrom. The program was de-signed to cover an area of 1,600 sq km (618sq mi). Previously two wells were drilled,neither yielding commercial finds.

Middle EastNorwegian operator AGR has discovered

gas in deepwater off Israel. The Aphrodite-2well, drilled in 1,107 m (5,600 ft) of water, hitthe target in lower Miocene sands. Reservescould be “significant,” according to AGR,

which has a minority 5% operating interest.The location is in block 370 on the maritimeborder with Cyprus.

•••Ganoub El Wadi Petroleum Holding Co.

(Ganope) has opened Egypt’s latest interna-tional bid round. Acreage offered includesblocks 14 and 15 in the Red Sea and blocks16-20 in the Gulf of Suez. Deadline for appli-cations is May 30.

•••Saudi Aramco has completed the floatover

installation of its largest offshore platformto date, on the Safaniya field off Saudi Ara-bia. Tie-In Platform No. 20 (Safaniya TP-20)weighed more than 6,000 metric tons (6,614tons), more than three times the company’sconventional TPs. It was built by McDer-mott in Jebel Ali, UAE. The new structure ispart of a first-phase program to upgrade thefield, and will receive power through a new47-km (29-mi), 230-kV composite submarine cable due to be installed this month.

East AfricaStatoil and ExxonMobil have achieved a

third gas discovery in deepwater block 2 off-shore Tanzania. The Lavani-2 well, designedto appraise the Lavani-1 find, was drilled bythe Ocean Rig Poseidon in 2,580 m (8,464 ft)of water. When deepened within the Palaeo-gene it encountered gas in the Saffron struc-ture. The partners will next appraise the Za-farani discovery and acquire 3D seismic towork up new targets on the block.

•••Eni and Anadarko have signed a heads of

agreement over coordinated development oftheir gas reserves off Mozambique, in theRovuma basin Area 1 and Area 4. They alsoplan to jointly build LNG facilities onshorein Cabo Delgado province, northern Mo-zambique. Anadarko’s new partner PTTEPsays Area 1 alone holds 35-65 tcf-plus of re-coverable gas, and that three consortia areperforming competitive front-end engineer-ing design contracts for installation of sub-sea production systems. These are TechnipUSA; Subsea 7 (US) and Saipem; and AllseasUSA and McDermott.

Indian Sub-ContinentEni is taking a 25% stake in ultra-deep-

water offshore Indus block G in Pakistan’sIndus basin. The partners, which includeOGDCL, PPL, and United Energy Pakistan,will draw up a study program for future ex-ploration. Nearby, Eni already holds major-ity interests in offshore Indus basins blockC and N.

•••ONGC has contracted Larsen & Toubro

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G L O B A L E & P

Heera fields off western India. They will beconnected to the Heera process complex bysubsea cables for remote operation. Workshould be completed by April 2014.

Asia/Pacifi cDockwise says it has broken its own re-

cord for a heavy-lift topsides installation,for the SHWE field development offshoreMyanmar, in the Bay of Bengal. The launchbarge HYSY229, operated under a jointventure with China’s COOEC, installedthe 30,000-ton SHP topsides on top of the22,000-ton SHP jacket via the fl oatovermethod. Dockwise’s previous record liftwas 21,000 tons. Hyundai Heavy Indus-tries built the SHWE topsides in Ulsan,South Korea.

Woodside Energy has agreed to farminto 50% of block A-6 in the Rakhine ba-sin in Myanmar’s western offshore area,with MPRL E&P remaining operator forthe current exploration period. Wood-side’s proposal included a 3D seismicsurvey, and potential future drilling.

•••CNOOC has started oil production from

two developments in the Pearl River Mouthbasin of the South China Sea. Panyu 4-2/5-1is a field adjustment project in water depthsof 100 m (328 ft), tied into existing facilities.The Liuhua 4-1 field is in 268 m (879 ft) ofwater. Here CNOOC installed a new subseaproduction system, again linked to in-placeinfrastructure.

Subject to regulatory approvals, the com-pany will have a new partner in the SouthChina Sea Yacheng gas field later this year,

after BP agreed to sell its 34.3% interest toKuwait’s KUFPEC. The location is 100 km (62 mi) south of Hainan Island.

AustralasiaChevron continues to build a pool of gas

discoveries in the Carnarvon basin off West-ern Australia, this time in the Exmouth Pla-teau area. The Pinhoe-1 well was drilled inthe WA-383-P permit, 124 mi (200 km) northof Exmouth, in 3,048 ft (929 m) of water. Itencountered roughly 197 ft (60 m) of net gaspay in Barrow and Mungaroo sands. Anoth-

er well in deeper water, in a more north-erly location – Arnhem-1 – found 149 ft(45.5 m) of gas pay in upper Mangaroosands. Both finds are farther out fromdiscoveries factored into the greater Gor-gon and Wheatstone development.

•••New Zealand Petroleum & Miner-

als has awarded new offshore permitsto three consortia. Two in the Pegasusbasin, covering blocks 12PEG1 and 12PEG2, went to Anadarko; another onblock 12GS2 in the Great South basinwent to Shell, OMV, and Mitsui; and apermit for block 12TAR9 in the Taranakibasin was issued to Todd Explorationand Cue Taranaki. �

HYSY229 near Hyundai fabrication yard,

preparing for sailaway of the SHWE platform.

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O F F S H O R E E U R O P E Jeremy Beckman • London


Norway on course for rising production

A steady stream of new development proj-ects should stabilize production offshoreNorway, according to the Norwegian Petro-leum Directorate.

Currently, 16 projects are in progress andplanning is under way for at least 20 more,said NPD in its latest review of the sector. Theimpact should start to be felt next year, whenproduction should rebound after a dip in 2013,and output should then remain steady through2017. Investments in the new programs couldreach $28.5 billion this year, NPD added, ris-ing to around $34.4 billion in 2017, with muchof the outlay related to drilling by mobile rigs.

As for exploration, the 41 wells completedacross the Norwegian continental shelf lastyear brought 13 new discoveries, the mostsignificant probably being the Havis oil findin the Barents Sea. This and neighboringSkrugard helped boost bids in the region forNorway’s 22nd licensing round. NPD addedthat the new finds generated 132 MMcmoein fresh reserves, equivalent to 58% of totalNorwegian oil production in 2012.

Analysts Wood Mackenzie sounded a caution-ary note, however, claiming that last year’s explo-ration yield was way below the previous 10-yearaverage of 860 MMboe. And Norway’s explora-tion well numbers were down 20%, mainly dueto a shortage of suitable rigs, or because certaindrilling programs overran their schedules. Butup to 55 wells could be drilled this year, withsome on potentially high-impact prospects in theBarents Sea and the Utsira High region of thecentral Norwegian North Sea.

Last month Wintershall confirmed an oildiscovery in the Asha Noor structure, closeto the Edvard Grieg and Ivar Aasen fields onthe Utsira High. Reserves appear to be in the 20-40 MMbbl range.

Statoil unveils three giant developments

The governments of Norway and the UKshould both be thankful to Statoil for helpingthem prop up their economies. Either side ofChristmas, the company submitted plans forfour new mega-projects, with a total outlay ofaround $23 billion.

Most wide-ranging in scope is Aasta Han-steen in the Norwegian Sea, and the associ-ated Polarled offshore pipeline system. Thiswill be the first deepwater field developmentoff mid-Norway, based around a spar plat-form with storage in the hull for condensate,and supporting a conventional topsides withprocessing facilities. The condensate will betransferred directly to shuttle tankers.

As Aasta Hansteen is far removed from off-shore infrastructure, an associated trunkline(Polarled) will be installed taking the gas480 km (298 mi) southeast to the process-

ing plant at Nyhamna, western Norway. Thepipeline will have a capacity of 70 MMcm/d,and its diameter of 36 in. in a water depth of1,300 m (4,265 ft) will constitute a new worldrecord, Statoil claimed. A 30-km (18.6-mi), 18-in. spur line will be added between Polarledand the Kristin semisubmersible platform.This will connect the new facilities to the Aas-gard Transportation System pipeline, withtie-ins also planned for future gas field devel-opments such as Norske Shell’s Linnorm andRWE Dea’s Zidane. The Nyhamna terminal,currently dedicated to the Ormen Langefield, will be expanded.

In the North Sea, Statoil aims to recover 225MMboe from the Dagny oil and gas field. The$5.7-billion program includes construction of asteel jacket platform connected to the Sleipnercomplex for gas export, with oil transportedby shuttle tankers. Another development planshould be issued this year for the satellite gasfield Eirin, which will be linked to the platformvia a template. Assuming approvals, Dagnyshould be onstream early in 2017 and in pro-duction for a further 20 years.

The most ambitious project in termsof well engineering looks to be Mariner, aheavy oil field 150 km (93 mi) east of theShetland Isles in the UK northern NorthSea. Here Statoil plans a central production,drilling and quarters platform, supported by a steel jacket facility with 50 well slots, anda floating storage unit holding up to 850,000bbl of oil. Dragados Offshore and SNC La-valin have the construction and engineeringcontracts for the wellhead structure.

Mariner comprises two shallow, complexreservoirs in the Maureen and Lista forma-

tions, with 250 MMbbl of recoverable heavyoil (12-14° API). Early water breakthroughis expected, so the process facilities will bedesigned to handle large volumes of liquids and oil-water emulsions. All productionwells will be equipped with sand screens andelectric submersible pumps for lift purposes.Statoil aims to award a contract for a new-build cat. J drilling rig this spring. Pendingapprovals, Mariner should enter productionin 2017, and remain in service for 30 years.

Delayed Skarv finally flowingBP has finally started production from the

Skarv oil and gas field in the Norwegian Sea,providing a new hub for the area. The de-velopment plan was approved in December 2007, and start-up was originally scheduledfor late summer 2011, according to analystsScanBoss. The start would have been ear-lier had bad weather not disrupted the pull-in campaign in 2011. Capex for the projectis thought to have risen from the originallybudgeted NOK 35.6 billion ($6.46 billion) toNOK 38.5 billion ($6.98 billion).

Skarv’s giant FPSO – the hull weighs 45,000tons and the turret 4,000 tons – is connectedto 13 risers and will eventually receive produc-tion from 16 wells, 14 on Skarv and two on theIdun field. These will be spread among twodrilling centers with a total of four templates.Gas is exported through an 80-km (49.7-mi)pipeline that connects with the Gassled off-shore transportation network. The FPSO hascapacity to store 875,000 bbl of condensatewhich is offloaded to shuttle tankers. BP ex-pects production to build to 165,000 boe/d byyear-end. �

How Statoil plans to develop the Mariner field in the UK North Sea.

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3 years prior toOil spill avg: 7/mo.

Oil spillFederal DeepwaterDrilling Moratorium lifted

3-monthavg. = 6 mo.

Year prior tooil spill avg.= 6/mo.

Jan.

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July

10Sep

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Nov

. 10

Jan.

11M

ar. 1

1M

ay11

July

11Sep

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Nov

. 11

Jan.

12M

ar. 1

2M

ay12

July

12Sep

t.12

Data sourced from Bureau of Safety and Environmental Enforcement (BSEE)

and Bureau of Energy Management (BOEM), and IHS Drilling Data.

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G U L F O F M E X I C O Bruce Beaubouef • Houston


Pace of deepwater permitscontinues to rise

Greater New Orleans, Inc. and its partneringorganizations have released the thirty-fourthGulf Permit Index (GPI) to the public. This edi-tion, the fifteenth GPI+, includes data on deep-and shallow-water permit issuance taken fromthe Bureau of Safety and Environmental En-forcement (BSEE), as well as data on explora-tion and development plans taken from the Bu-reau of Ocean Energy Management (BOEM).

In September 2012, deepwater permit is-suance rose above the monthly average ob-

served in the year prior to the oil spill. Sevenpermits were issued, representing a 1-permit– or 17% – increase from the average of 6 per-mits per month. This number also matchesthe historical average of 7 permits per monthin the three years prior to the oil spill. This alsorepresents a 1-permit (17%) increase from theaverage observed over the past three months.

In October 2012, deepwater permit issu-ance also rose above the monthly average ob-served in the year prior to the oil spill. Ninepermits were issued, representing a 3-permit– or 50% – increase from the average of 6 per-mits per month. This number also representsa 2-permit – or 29% – increase from the histori-cal average of 7 permits per month in the threeyears prior to the oil spill. This also representsa 3-permit (50%) increase from the average ob-served over the past three months.

Through the month of September, threeshallow-water permits were issued. This num-ber fell below the monthly average of 7 permitsper month observed in the year prior to the oilspill. This number also represents a 12-permit– or 80% – reduction from the historical aver-age of 15 permits per month in the three yearsprior to the oil spill, and is below the averageobserved over the past three months.

Through the month of October, six shal-low-water permits were issued. This numberfell below the monthly average of 7 permitsper month observed in the year prior to theoil spill. This number also represents a 9-per-mit – or 60% – reduction from the historicalaverage of 15 permits per month in the three

years prior to the oil spill, but exceeds the av-erage observed over the past three months.

The GPI+ also shows a sharp increasein the average number of days taken to ap-prove plans. In September 2012, the averageapproval time for a plan was 113 days, com-pared to the historical average of 61 days. This number represents an 85% increaseabove historic approval times. In October 2012, the average approval time for a planwas 117 days, compared to the historical av-erage of 61 days. This number represents a92% increase above historic approval times.

Callon sells Habanero fieldinterest to Shell

Callon Petroleum Co. has closed the sale of its 11.25% working interest in the Haba-nero field in Garden Banks block 341. Thecompany sold its interest to Shell OffshoreInc., a subsidiary of Royal Dutch Shell plc,for an estimated $39.5 million.

Callon says it will use the proceeds to fundits efforts onshore in West Texas. “The sale ofour Habanero interest enables us to pay downa significant portion of our revolving bank debtand strengthen our balance sheet as we focusour efforts on the Permian basin,” said FredCallon, chairman and CEO. “This additionalfinancial flexibility will position the companyto pursue horizontal program development ofour Southern Midland assets while continuingto evaluate our Northern Midland position forfuture development operations.”

Transocean settles federalMacondo claims

In January, Transocean Deepwater Inc.agreed with the U.S. Department of Justice to resolve certain outstanding civil and po-tential criminal claims arising from the ac-cident in the Gulf of Mexico involving theDeepwater Horizon drilling rig.

Transocean has agreed to plead guilty toone misdemeanor violation of the Clean Wa-ter Act for negligent discharge of oil into theGulf of Mexico, and pay $1.4 billion in civil andcriminal fines, recoveries, and penalties, ex-cluding interest. For its part, the Department

of Justice will conclude its criminal investiga-tion of Transocean and settle its claims for civilpenalties relating to the spill.

Under the civil settlement, the Transoceandefendants must observe various court-enforce-able strictures in its drilling operations. Exam-ples of these requirements include certificationsof maintenance and repair of BOPs before eachnew drilling job, consideration of process safetyrisks, and personnel training related to oil spillsand responses to other emergencies. Thesemeasures apply to all rigs operated or owned bythe Transocean defendants in all U.S. waters andwill be in place for at least five years.

Anadarko and BP settled claims between the two companies late this past year.

Helix Energy reportsGreen Canyon discovery

Helix Energy Solutions Group has announcedthat its Wang exploration well has producedan oil discovery in the Phoenix field, located inGreen Canyon block 237.

The well, 93 mi (150 km) offshore Louisi-ana, found more than 100 ft (30.4 m) of netpay. It was drilled to TD of 18,300 ft (5,578 m)in 2,300 ft (701 m) of water. It is being com-pleted and will produce via a subsea tiebackto the Helix Producer 1 FPU in 2Q 2013.

“Preliminary data from downhole test toolsconfirmed oil in the Wang well with over 11,800psi of bottomhole pressure. We are movingahead to complete the well,” said Johnny Ed-wards, president, Energy Resource Technol-ogy GOM, a Helix subsidiary.

ERT is operator and holds a 70% workinginterest in the well. Sojitz Energy Venture Inc.owns the other 30%.

Technip to installDiscovery facilities

Technip has won a contract to install theDiscovery System’s South Timbalier block 283junction platform and related pipeline systems.Technip will perform the project management,engineering, transporting, installing, and pre-commissioning.

The pipeline will run between existing fa-cilities in South Timbalier 280 and Ewing Bank873 and the new block 283 platform. It includes15.8 km of 12-in. pipe and 13.9 km of 30-in. pipe.Water depths range from 83 to 244 m (272 to800 ft). Installation is scheduled for 2013 usingthe G1200 as the primary vessel.

“This award is the largest-diameter pipelaycontract for Technip in the Gulf of Mexico,thanks to the acquisition of Global Industries,”said David Dickson, Technip SVP, NorthAmerica. “This 30-in. pipeline will also be thelargest diameter lines installed by the G1200

vessel to date.”Williams Partners owns 60% of the Discov-

ery System and operates it. DCP MidstreamPartners owns the other 40%. �

US GoM deepwater approved new permits, Oct. 2010-Oct. 2012.

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S U B S E A S Y S T E M S Gene Kliewer • Houston


Subsea equipment orders run strong

Aker Solutions has signed a contract withMarathon Oil Norge to deliver subsea treesto the Alvheim field on the Norwegian con-tinental shelf. Contract value is undisclosed.The contract includes the delivery of foursubsea trees and associated equipment. TheAlvheim field is in the Norwegian sector ofthe North Sea, 224 km (139 mi) from Stavan-ger on the Norwegian west coast, at a waterdepth of 122 m (400 ft).

The Alvheim subsea trees will be manu-factured at Aker Solutions’ facility at Tranby,Norway. Control modules will be manufac-tured in Aberdeen, UK. The project is sched-uled for completion in the first half of 2014.

FMC Technologies Inc. has received anorder from CNR International Ltd. for sub-sea equipment for the Baobab field.

The Baobab field is in block CI-40 approxi-mately 16 mi (25 km) offshore Ivory Coast,West Africa. FMC Technologies’ scope of sup-ply includes six subsea trees, eight wellheads,three manifolds, and a subsea control systemincluding subsea distribution systems and as-sociated topside controls. The equipment isscheduled for delivery in 2014.

Fugro Survey Ltd. has ordered a newHUGIN AUV. The HUGIN 1000 is ratedto 3,000 m (9,840 ft) water depth and haslithium polymer batteries in modules thatprovide 70 hours of survey time and can beswapped out in less than two hours.

FUGRO specified the latest versions of theKongsberg EM 2040 multi-beam echo sound-er, EdgeTech sidescan sonar and sub-bottomprofiler, forward looking sonar, turbidity sen-sor, acoustic Doppler current profiler, con-ductivity temperature and depth sensor, anda camera system with LED lights.

Statoil has contracted FMC to supply fur-ther subsea equipment for the Snorre fieldin the Norwegian North Sea.

FMC will provide 10 production risersand tieback connectors, all scheduled for de-livery in 2015. Estimated value of the orderis $33 million.

Company businessKongsberg Oil & Gas Technologies AS

has agreed to acquire 100% of the shares inApply Nemo AS, a supplier of engineeringservices, products, and solutions for subseaoil and gas applications. Apply Nemo focus-es on subsea pipeline engineering and com-plex solutions, and offers experience in bothsubsea engineering and the developmentand manufacture of subsea products.

Subsea 7 has landed a new job and ex-tended an existing contract. Its Mexican jointventure got an award from Pemex valued at$140 million.

The contract covers the engineering, fabri-cation, and installation of a 16 km (10 mi) pipe,two slug catchers, and two cantilever structuresfor the Line 60 Project in the Bay of Campeche.This contract is the first award win for the jointventure.

Project management and engineering areunder way in Ciudad Del Carmen and Hous-ton. Offshore operations are to start some-time this quarter, with pipelay activities be-ing in 3Q 2013 using the Seven Borealis.

Meanwhile, Shell Upstream International Eu-rope has extended the terms of its underwaterservices contracts with Subsea 7 covering con-struction, inspection, repair, maintenance, and de-commissioning offshore Europe. The extensionis valued at $360 million. The extension starts in2014 and runs until 2016, with a further two-yearextension possible.

Subsea 7 will dedicate the Seven Atlantic andNormand Subsea vessels to Shell and will provideconstantly available diving and ROV support.�

Subsea Tieback opens March 5The world’s largest show

devoted to subsea produc-tion operations returns toSan Antonio, Texas, March5-7.

Offshore presents the2013 Subsea Tieback Forumand Exhibition, which is expected to set new atten-dance records as oil and gas operators and service com-panies gather to learn the latest about subsea systeminspection, maintenance and repair, subsea boosting andprocessing, well contain-ment, flowlines, risers andumbilicals, innovations, andpractical information learnedduring project execution.

Hosted by BHP Billiton and sponsored by FMC Technologies, Aker Solutions,and Helix Energy, the event opens at the Henry B. Gonzales Convention Center on Tuesday, March 5, with the opening of the exhibit hall and networking reception from5-7 p.m.

The Opening Plenary Session is at 8 a.m. on Wednesday, March 6. Mark Peters,VP of PennWell Publishing and Group Publisher of Offshore and Oil & Gas FinancialJournal will welcome attendees and be followed by event chairman Bob Writt of BHPBilliton with opening remarks.The Keynote speaker is Nigel Smith, president, Devel-opment, BHP Billiton Petroleum, and a Scene Setting presentation by Tyler Shilling ofShilling Robotics is scheduled.

Subsequent technical sessions will address topics ranging from PetrobrasAmerica’s Chinook riser response to Chevron’s look at the Jack and St. Malo sub-sea pumping system, Husky’s sub-Arctic White Rose, a complete session on wellcontainment, and ConocoPhililps on smart well completion design.The completeschedule can be found online at www.SubseaTiebackForum.com.

As before there will be a workshop by the Society for Underwater Technology, andalso workshops by ASME.These all are on March 5 before the show opens.

Deepwater, ultra-deepwater market to reach $83.2 billion this year

A new report from Visiongain predicts the global deepwater and ultra- deepwaterexploration and production market will reach a value of $83.2 billion in 2013.The sec-tor will experience strong growth over the forecast period as development of largeoffshore oil finds drives spending for ongoing projects and creates an incentive forfurther exploration.

Based on current and potential projects, the deepwater and ultra-deepwater explo-ration and production market will grow strongly over the next decade.

“The discovery of presalt oil reserves in Brazil has increased exploration activityin traditional offshore regions and frontier areas alike,”Visiongain said. “Despite thenegative publicity following Macondo, the industry is expanding at a strong pace and has the technological knowledge to operate securely and efficiently in the most chal-lenging environments.”

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V E S S E L S , R I G S , & S U R FA C E S Y S T E M S Russell McCulley • Houston


SHWE platform installed off MyanmarDockwise Ltd. has installed the production platform at the SHWE

gas development in Myanmar’s A-1 offshore block, setting a companyrecord for the heaviest float-over installation. The 30,000-ton topsideswere launched from the HYSY229 barge, which arrived at the Bay ofBengal location Dec. 8, 2012, from Hyundai Heavy Industries’ fabrica-tion yard in Ulsan, Korea. Installation of the platform, which accom-modates 200 people along with drilling and production equipment,surpassed Dockwise’s previous installation record of 21,000 tons. TheSHWE project in blocks A-1 and A-2 is operated by a consortium led byDaewoo International. The project, 70 km (43.5 mi) offshore Myanmar,will produce and process up to 500 MMcf/d of gas to China.

Island taps Ulstein for intervention vesselUlstein will deliver a newbuild multi-purpose offshore vessel to Is-

land Ventures II, a partnership between Island Offshore and EdisonChouest Offshore, under the terms of a contract that includes anoption for an additional vessel. Delivery is scheduled for May 2014.

Based on the ULSTEIN SX121 design, the vessel will be equippedfor well intervention, IRM, and SURF operations. The DP-3 vesselwill measure 130 m (427 ft) in length by 25 m (82 ft) in width and willbe capable of operating in water depths of 3000 m (9,843 ft). Equip-ment includes a vertical lay system, a 250-ton heave compensatedcrane, and room below deck for a rotating carousel with a capacityto load 2,500 tons. The vessel will have two ROVs on board and ac-commodations for 130 crew members.

McDermott on the moveMcDermott International has submitted an order with Keppel

Singmarine for construction of a high-spec, DP combination S-lay

vessel with a 2,000-ton crane. Tentatively named Derrick Lay Vessel

2000, the ship will support pipelay operations at water depths of upto 10,000 ft (3,048 m) and accommodate up to 400 people. Deliveryis expected in 2015 from Keppel Singmarine’s yard in Singapore.

McDermott also picked up a $230-million job with Pemex for deliveryof the PB-Litoral-A production platform to the Litoral Tabasco Tsimin-Xux fields in the Bay of Campeche offshore Mexico. McDermott willconduct FEED, EPCI, and commissioning of the eight-legged, 1,800-mton (1,984-ton) jacket and 4,500-m ton (4,960-ton) topsides, along withtripods, bridges and piles. Engineering will take place in McDermott’soffices in Houston and Chennai, India. McDermott’s fabrication yardin Altamira, Mexico, will have around 550 workers on the project at thepeak of construction, with installation scheduled to be completed in 2Q2015 using the Intermac 600 floatover barge and the Derrick Barge 50.

Frigstad orders semis on specFrigstad Deepwater has placed an order with China’s CIMC Raf-

fles for two ultra-deepwater semisubmersibles based on the FrigstadD90 design. The turnkey construction contracts are worth $1.3 bil-lion and include options for four more units. The rigs, to be deliv-ered in 4Q 2015 and 2Q 2016, will be capable of operation in 12,000 ft(3,658 m) of water and able to drill to a total depth of 50,000 ft (15,240m). Frigstad Offshore will manage operation of the DP-3 units.

The first Frigstad D90 was Saipem’s Scarabeo 9, which wrappedup an unsuccessful drilling campaign offshore Cuba last year. Therig has since been mobilized to West Africa.

Subsea 7 orders North Sea DSVWärtsilä has been enlisted to design a new dive support vessel

for Subsea 7, to be built at Hyundai Heavy Industries’ yard in Korea.Wärtsilä created the new VS 4725 DSV design specifically for theproject, slated for delivery in 2015. The DSV will measure 123 m(404 ft) in length, 24 m (79 ft) in width, and will be used for year-round diving operations in the North Sea.

Keppel builds Mexico jackup backlogKeppel FELS landed a $420-million contract with Mexico’s Pemex

for construction of two high-spec KFELS B class jackups. The rigs,scheduled for delivery in 1Q 2015, will be able to operate in waterdepths up to 400 ft (122 m) and drill to depths of 30,000 ft (9,144 m).Construction will take place at Keppel Offshore & Marine’s KeppelAmFELS yard in Brownsville, Texas, where two other rigs bound forMexico are being built: the Papaloapan jackup, scheduled for deliv-ery to Perforadora Central in 1Q 2013, and the Coatzacoalcos jackuprig, slated for delivery in 1Q 2014. �

The floatover topsides installation at the SHWE gas development offshore

Myanmar. (Photo courtesy Dockwise)

Island Offshore and partner Edison Chouest Offshore have ordered an

MSV based on Ulstein’s SX121 design. (Image courtesy Ulstein)

Frigstad Deepwater signed contracts worth $1.3 billion with CIMC Raffles

for two semisubs of the Frigstad D90 design. (Image courtesy Frigstad)

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D R I L L I N G & P R O D U C T I O N Dick Ghiselin • Contributing Editor


Valentine’s Day requestTraditionally, Valentine’s Day is when we remember those whom

we respect, like, or love. It’s also the season that the Offshore Ener-gy Center Hall of Fame Committee meets to review nominations forOffshore Pioneers and Pioneering Technology. This is an open invi-tation to nominate a deserving individual, or individuals, to receivethis honor, which is publicly bestowed at the annual Offshore Ener-gy Gala each September. To be eligible for nomination, the nomineeshould have distinguished himself or herself in such a way that he orshe stands out as a leader in the offshore industry. Whether throughvision, drive, business acumen, ability to search, innovate or leadthe way forward, the nominee should be someone who the industryrecognizes as a leader who revolutionized or forced change in theoffshore industry. Who comes to mind when you read these words?

There is no charge to make a nomination. To see a list of currenthonorees and receive a nominating package, please contact the Off-shore Energy Center at (281) 679-8040, email [email protected] or log on to www.oceanstaroec.com and download the forms.

Sharpened focus in offshore drillingEveryone knows the old expression, “Jack of all trades, master of

none.” Perhaps this thought motivated the leaders of Transoceanto sharpen its focus on deepwater drilling, which has long been the company’s core competency. In keeping with this idea, Transoceanrecently spun off a new independent company, Shelf Drilling, head-quartered in Dubai, UAE. With 38 shallow-water rigs in its inter-national fleet, most of the three-legged LeTourneau design, ShelfDrilling is immediately positioned to take a challenging role in shal-low water plays, typically those in about 300 ft (91 m) of water orless. The rigs are manned with experienced crews in shallow-waterenvironments and the company already has a presence in the Medi-terranean, Middle East, West Africa, and Southeast Asia. PrincipalShelf Drilling investors include Castle Harlan, CHAMP Private Eq-uity, and Lime Rock Partners.

Free to focus on their areas of greatest expertise, each companyshould be able to exploit operational efficiencies and economies ofscale that differ between the universes in which they now operate. Atthe most recent report, Transocean has pared its fleet down to 90 rigs,of which 29 are rated at greater than 7,500-ft (2,286-m) water depth,15 are rated between 4,500 ft (1,372 m) and 7,500 ft, 29 fill the gapbetween 400 ft (122 m) and 4,500 ft, 15 construct wells in 300 ft (91 m)to 400 ft of water, and two are rated for water less than 300 ft in depth.

Deepwater contractors gearing up for activity

The world’s ultra-deepwater drilling fleet is growing by leaps andbounds. Reports explain that many foreign shipyards having the capacity to build high-specification drillships and semisubmersibleshave been able to free up schedules because of a slump in tanker or-ders. According to Aol Energy, the ultra-deepwater fleet is expectedto hit 136 units momentarily.

Despite activity limitations in the US Gulf of Mexico in view ofnew, post-Macondo regulations and red tape, there appears to beplenty of deepwater drilling business elsewhere. The latest goalseems to be drilling units capable of drilling to a total depth of 40,000ft (12,192 m) in 12,000 ft (3,658 m) of water, even though to date nosuch wells have been attempted. Extended reach wells have topped40,000 ft in measured depth several times over the past few years, butthey are relatively shallow in terms of true vertical depth. Accord-ing to experts, one of the challenges has been maintaining steerabil-ity at great depths. Steering commands transmitted via mud-pulsetelemetry have been received and acknowledged at greater mea-sured depths than 43,000 ft (13,106 m). And an extended reach wellplanned to extend out under the Beaufort Sea to a distance of some

eight miles has been delayed. A purpose-built arctic drilling unit hasbeen built, along with an extended drilling pad reached from shoreby a causeway. But cost overruns and technical concerns were citedwhen BP suspended the project indefinitely last summer. The prize,a reservoir rated to produce at 40,000 b/d of oil, awaits.

Changes to UK offshoredrilling safety approach

Britain’s government has responded to a review of the UK’s offshoreoil and gas safety regime. This was conducted by an independent panel,chaired by Professor Geoffrey Maitland of Imperial College London, asa result of the Macondo blowout in the Gulf of Mexico.

The panel made various recommendations, most of which thegovernment has implemented. Among its responses are:

• The pan-industry forum established to share best practice andto develop standards for offshore well management and designshould remain in place permanently

• Operators must now conduct emergency response exercisesinvolving the Secretary of State’s Representative every threeyears, compared with five previously

• Guidance issued on how licensees on the UK continental shelfcan demonstrate the financial capability to respond to an inci-dent, prior to receiving consent to drill exploration wells.

A group comprising the Department of Energy and ClimateChange, the Health and Safety Executive, and the Maritime and Coastguard Agency, will supervise follow-through of the recommen-dations, and ensure that the offshore regime remains appropriateover the longer term.

Malcolm Webb, chief executive of industry association Oil & GasUK, welcomed the findings, adding: “The review and report furtherunderline why the EU [European Union] Commission’s proposal tointroduce a ‘one size fits all’ regulation of offshore safety was mis-guided. We are pleased to note that the movement in Europe is nowclearly away from a regulation of that nature.” �

Kulluk freeThe Arctic drilling unit Kulluk, under contract to Shell, was

retrieved from a rocky grounding and towed successfully tosafe harbor where it will undergo a thorough inspection and damage assessment. While no oil or fuel spills were detected,experts will take a cautious approach before moving the unitto a shipyard.The Kulluk incident once again fired up envi-ronmental concerns which were unfairly directed at the E&Pindustry, whereas the incident was clearly a maritime accidenthaving no tie to drilling operations.

The Ice Class floater Kulluk has been rescued from Alaska’s rocky

coastline where it lay grounded and at the mercy of winter storms.

(USCG Photo)

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G E O S C I E N C E S Gene Kliewer • Houston


Statoil to install permanentsubsea monitoring at Grane

Statoil has contracted Reef Subsea Norway to install a perma-nent reservoir monitoring system at the Grane field offshoreNorway. The full seismic subsea installation contract includesengineering, logistics and material, mobilization/demobiliza-tion, and installation of an umbilical riser, sensor array termi-nators and lead-in cables, sensor array cables, and protectionstructures. There will be almost 200 km (124 mi) of seismiccables installed and buried across 50 sq km (19 sq mi) of sea-bed in 130 m (426 ft) of water. Installation, set to occur in 2014,will employ the Polar Prince, Reef Larissa, and Reef Subsea’snew plow and dredging device. Geospace Technologies Corp.executed the definitive agreement for Geospace to provide 660km (410 mi) of seabed seismic reservoir monitoring systemsfor the Snorre and Grane fields on the Norwegian continentalshelf. The final contract value is approximately $160 millionand requires the systems to be delivered at various intervalsextending into 2015.

TGS lines up seismic vessels for offshore Europe

TGS has arranged for three vessels to work on its 3D multi-client seismic program offshore Europe this coming summer.TGS signed a letter of intent with Fugro-Geoteam to charteran eight-streamer seismic vessel starting in April and lasting anestimated five months. TGS also has signed a letters of intentwith CGGVeritas Services to charter a 12-streamer seismicvessel and Dolphin Geophysical AS to charter the newbuild16-streamer M/V Sanco Swift.

TGS will not be the only one acquiring seismic data offshoreEurope this year. The Dolphin Group says Dolphin Geophysi-

cal has won several contracts for seismic work in the North Sea.Dolphin has awards for both 3D and 4D projects that will usethree of its vessels for as long as a year.

Elsewhere in EuropeA first 3D seismic campaign over the shallow-water sector

of the Neptun block in the Romanian Black Sea started in January.CGG Veritas’ Oceanic Champion vessel is performing the 60-dayprogram, which will cover an area of 1,600 sq km (618 sq mi). Thevessel is deploying eight 6-km (3.7-mi) long streamers over a 100-m (328-ft) width. Exploration in the shallow water part of Neptunstarted before 2005. To date two wells have been drilled (neitherled to commercial discoveries), and 2D seismic has been acquired.OMV Petrom operates this part of the block. ExxonMobil farmedinto 50% of the deeper water portion in 2008. Here the partners areshooting the largest 3D seismic program to date over the BlackSea, OMV Petrom claims, covering roughly 6,000 sq km (2,317sq mi).

In the Norwegian Barents Sea, SeaBird Exploration and Search-

er Seismic Pty. are working together on a multi-client 12,000-km (7,456-mi) Snøspurv 2D high-resolution seismic survey overBjarmeland Platform. Work is expected to start next spring and takefour months to complete. The platform area consists of play typesalready proven in other parts of the Barents Sea. It will specificallytarget the prospective Triassic/Jurassic sections to the south andwest, and the Carboniferous/Permian and Triassic section in thenorthern part of the survey area. No exploration wells have beendrilled on the Bjarmeland Platform, which covers an area of almost35,000 sq km (13,513 sq mi). The survey results should also providethe necessary link for regional interpretation into the southeasternBarents frontier region, due to open soon for exploration. Data willbe available for participating companies from 3Q 2013.

Shell arranged CSEM servicesShell International Exploration & Production B.V. has signed

a three-year global frame agreement with Electromagnetic Geoser-

vices ASA for controlled-source electromagnetic 3D services. Elec-tromagnetic Geoservices ASA has signed two letters of intent for atotal of 10 weeks of 3D electromagnetic data acquisition offshoreAsia. The work will be done with the EM Leader following its comple-tion of a contract for Shell in Malaysia. �

New Zealand Petroleum & Minerals has closed Block Of-fer 2012 and awarded 10 exploration permits, five of themoffshore.The work associated with exploration on the permitsis valued at $82 million, and could reach $776 million if the permits run the full five years. Offshore permit winners are as follows:

1. 54858 on block 12PEG1 in Pegasus basin to AnadarkoNew Zealand Co.

2. 54861 on block 12PEG2 in Pegasus basin to AnadarkoNew Zealand Co.

3. 54863 on block 12GS2 in Great South basin to Shell GSBLtd., OMV New Zealand Ltd., and Mitsui E&P Australia PtyLtd.

4. 54865 on block 12TAR9 in Taranaki basin to Todd Explora-tion Ltd. and Cue Taranaki Pty Ltd.

5. 54857 on block 12TAR8 in Taranaki basin to NZOG Canter-bury Ltd.

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Owner-operators and the control system end users must

develop risk management strategies for automation

technologies that align with operational philosophy,

corporate directives, and risk management guidelines.

O F F S H O R E A U T O M AT I O N S O L U T I O N S


Peter ReynoldsARC Advisory Group

Both owner-operators and suppliers face many complex issuesregarding when and how to migrate obsolete control systems andtechnology. An estimated $65 billion worth of obsolete technology isstill in use today, much of it in the upstream and downstream oil andgas industries. Since many of these systems are still performing wellbeyond original life expectancy, this introduces appreciable risk forowner-operators. This risk increases for control systems installed offshore, where environmental conditions can result in prematurefailures and increased reliability problems for electronic devices,and where the consequences of failure can be far more costly thanthose on land-based exploration and production assets.

Some of the general issues driving distributed control system(DCS) migration relate to the unavailability of automation systemcomponents. However, a shortage of the skills required to supportobsolete systems is another major issue. Owner-operators must de-cide how to justify and manage the business risk, while suppliers must develop solutions that simplify the process, enabling owner-operators to migrate successfully from the obsolete systems andthus ensure business continuity.

A half-day workshop at the 2012 ARC World Industry Forum inOrlando, Florida, brought together over 100 end users, suppliers,system integrators, and engineering contractors to discuss issues,needs, and wants associated with migrating control systems. One ofthe biggest challenges, according to workshop participants, is justi-fying a control system migration. While plant engineers may havea good handle on determining equipment reliability and predictingend of life, it’s more difficult to do this with control systems. Thisis one reason why it is challenging to convince management of theneed to replace old technology or migrate to new control systemtechnology.

One of the problems with systems in particular is that while as-sets like pumps, pipes, conveyer systems, and other mechanical de-vices may all be designed to be repaired or replaced as components,automation systems generally must be replaced in their entirety.

Some common practices used to justify migrations reflect internalpractices that might be executed during a migration project. Othersrepresent “open season” for many of the technology suppliers, engi-neering contractors, and system integrators:

• Develop a financial assessment of the cost of not migrating• Improve the rigor of control systems reliability data to include

actual failure events• Develop a technology maturity model across industry. Some fa-

cilities are late adopters, while others keep up with technology.• Benchmark against other companies that are running obsolete

systems• Supplier evaluations are 70% technical and 30% commercial.

Drive value by creating long-term contracts and user/supplierrelationships

• While not typically used to justify migrations, the practice ofstandardization can help lower total cost of ownership. Take the

time to perform a solid market assessment before beginningyour migration.

Migration approaches vary not just from industry to industry, butfrom company to company. Generally, operators of facilities such asrefineries, which never “sleep,” prefer to conduct migrations whileprocesses are up and running – a method known as the hot cutoverapproach – since their turnarounds are done at long, typically five-yearintervals. On the other hand, discussions with users who have experi-ence on offshore platforms – which also never sleep – indicate that, onthese facilities, any significant control system migration activities wouldonly be undertaken during infrequent major maintenance turnarounds.

One leading integrated refiner/petrochemical/specialty chemicalcompany performs approximately 85% of its migrations using thehot cutover approach and 15% using the off-line cutover approach.A leading global system integrator found that hot cutovers tend tobe more cost effective. Some users also indicated that, regardlessof their migration planning, hurricanes and other events forced un-planned migrations.

While migration strategy is a key factor in vendor selection, mostmigrations are done on a per-site basis. One global chemical com-pany is now minimizing the number of vendors, and standardizingto support lower total cost of ownership. Another major integrated

energy company looks to the automation supplier to manage thehardware inventory, and to help the company decide when systemcomponents should be replaced.

Many end users say it is important to manage a technology road-map with suppliers on an ongoing basis. Having all sites near obsoles-cence at the same time would be extremely detrimental to operations.

Supplier evaluation techniques that work well in the early stag-es of a migration project include developing a weighted scorecardagainst all criteria using KT International or Six Sigma methods. Workshop participants noted that a wide range of definition andweighting for each criterion are often used based on differences andpriorities of organizations. Developing a functional specification upfront could prove invaluable for any project.

Owner-operators and the control system end users must developrisk management strategies for automation technologies that alignwith operational philosophy, corporate directives, and risk manage-ment guidelines. This will ensure that investment decisions for plantautomation are made at the highest level in the organization, andthat the project team will have appropriate corporate-level support.

Suppliers and end users must also jointly develop long-range strategies for migrating obsolete automation technologies. This will help ensure that obsolete equipment is sustained until a migrationproject can be planned and executed.

The migration project planning should include end users, suppli-ers, and any third-party engineering and procurement contractor orsystem integrator firms involved. The keys to a successful migrationproject are to have the right mix of resources and to involve chancemanagement experts at an early stage.

Ultimately, the owner-operator must balance the risks of failureand lost opportunities against new capabilities, standardization, andpotential new opportunities. �

DCS migration success rests with suppliers and users alike

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D R I L L I N G M A R K E T R E V I E W

Drillers see future in ultra-deep

Strong market leaves room for older assets

Acouple of things stand out when com-paring rig statistics from this year’slist of the Top 10 drilling contractorsand last year’s list. First, the totalnumber of rigs managed by the lead-

ing drillers fell, from 581 at the start of 2012to 538 at the end of the year, and the numberof working rigs operated by those compa-nies also decreased by about 10%, from 400to 361, according to the research firm IHSPetrodata. The second is the debut of Shelf Drilling, the Dubai-based startup that land-ed a spot at number seven on the Top 10 listwith last year’s $1.05 billion purchase of 37shallow-water jackups and one swamp bargefrom Transocean.

The winnowing of the fleet and the sud-den appearance of Shelf are part of thesame trend, as the major drilling contrac-tors divest older assets and cultivate fleets ofhigh-spec, ultra-deep drilling units that cancommand top-dollar day rates and tackle the technical challenges of exploration and pro-duction in harsh and remote environments.

It’s a process of “high-grading” that analystsexpect to continue for months to come.

“Several established drillers have saidthe future lies in newer and higher-spec as-sets,” says Brad Handler, managing directorof equity research for oilfield services anddrilling at Jefferies & Co. “It allows themto distinguish themselves in a competitivemarket,” where a number of new drillingservices companies have captured marketshare from the big drillers. “They’re high-grading their fleets with newbuilds and thedivestment of older assets.”

The Transocean-Shelf deal, finalized in4Q 2012, was the most prominent in a yearmarked less by headline-grabbing mergersand high-stake deals than by quieter, one- andtwo-off transactions. The divestment of Trans-

ocean’s lower-spec jackups, most of whichhave been in service since the late 1970s andearly 1980s, is “a good example of the majorcontractors rationalizing their fleets” as wellas a measure of the perceived strength ofthe jackup market going forward, says TomKellock, an offshore rig consultant with IHS.Companies like Shelf—led by a team domi-nated by former Transocean executives – “feelthat these middle-aged jackups still have somelife ahead of them,” he says.

Analysts expect to see more divestment ofolder rigs in coming months, if not a pack-age deal as attention-getting as Shelf’s. In December 2012, Noble Corp. announcedthe $79 million sale of two standard jackups,the 300 ft (92 m) water depth capable Noble

Lewis Dugger and the 150 ft (46 m) depth ca-pable Noble Don Walker, to private companiesin Mexico and Nigeria, respectively. Noblehas five ultra-deepwater drillships and sixhigh-spec jackups under construction, withdelivery slated to begin this year; by 2015, the company expects to derive 40% of its rev-

Russell McCulleySenior Technical Editor

Transocean is building four new ultra-deepwater DP drillships, like the as-yet-unnamed model depicted in this rendering, which will be leased to Shell

under four 10-year contracts worth a total of $7.6 billion.The rigs will be built at the Daewoo Shipbuilding and Marine Engineering yard in South Korea,

with delivery of the first scheduled for 2015. (Image courtesy Transocean)

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enue from ultra-deepwater drilling, up from24% in 2011, and to reduce its proportion ofincome from standard jackups to 23%, from33%.

“There’s a sense that we will see a prettysteady retirement of these older assets,” saysHandler. “What’s interesting is, that sense ofobsolescence is being forestalled by pocketsof interest in places such as India, Mexico,and Southeast Asia, where we’re seeing abroadening of demand for standard jackups.”

The utilization rate for high-spec jackups,which Handler describes as those less than15 years old and capable of operation indepths of 350 ft (107 m) or more, stands at98%; after peaking at near full utilization in2005, before a number of newbuilds hit themarket, the global utilization rate for stan-dard jackups has been “hovering at around90% for a year and a half,” he says.

“We see a bifurcation, for sure, betweenstandard and premium jackups,” Handler

comments. “But utilization is neverthelesspretty strong on the standard side. That’sbeen a little bit of a surprise for us.”

Building boomWith no deals on the scale of the 2011

Ensco-Pride International merger on thehorizon, the leading drilling contractors arelooking for growth in ambitious newbuildprograms with a focus on standardization.Transocean has two ultra-deepwater drill-ships – the Deepwater Asgard and Deepwater

Invictus – and three high-spec jackups un-der construction, and in September 2012 announced that it would build four DSMEultra-deepwater drillships on the back of four 10-year contracts with Shell worth $7.6 billion. Construction on the first of the fourdrillships is to begin later this year.

“Our asset strategy is straightforward,”Transocean CEO Steven Newman told ana-lysts in a November 2012 conference call.“We have a clear objective to gradually re-duce our exposure to lower-specifi cation,less-differentiated assets, and increase ourexposure to high-specification assets, bothjackups and floaters…We also anticipatecontinued progress in the sale of individualnon-core assets, both floaters and our re-maining standard jackups.”

As of mid-December 2012, the Top 10 off-shore drilling contractors had a total of 66mobile offshore drilling units under construc-tion, according to IHS Petrodata. Seadrill,with 22 units currently in the yards, leads inthe number of rigs under construction.

In late July 2012, Ensco took delivery ofENSCO 8506, the seventh and final rig in its8500 series of DP-2 semisubmersibles. Therig is contracted with Anadarko for work inthe US Gulf of Mexico. The company alsoexercised one of two options with SamsungHeavy Industries for ENSCO DS-9, a DP-3drillship based on the Samsung GF12000design to be delivered in 4Q 2014. Like EN-

SCO DS-8, scheduled for delivery 3Q 2014,ENSCO DS-7 will have a 1,250-ton hoistingsystem and, while initially configured to op-erate in 10,000-ft (3,048-m) water depths, israted for up to 12,000 ft (3,658 m) depths.

Ensco’s strategy of fleet standardizationis manifest in the uniform design of the EN-

SCO 8500 series and in the core elementsof the new drillship designs. The approachaims to improve reliability and uptime per-formance, and to improve safety by enablingmore streamlined training, maintenance andrepair. “Ensco is big on standardization, butthe designs allow alteration,” says Enscosenior VP of marketing Kevin Robert. “It’slike auto manufacturing, where subsequentmodels may look identical but have advanc-es under the hood. We leverage off our exist-ing fleet, but also tailor to client needs.

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“Operators are demanding more paral-lel capability—to get more work out of thesame asset,” he continues. “DP floaters arereally good for them, because they can sup-port exploratory drilling, production drill-ing, construction, workovers.”

Rates stabilizeHigh demand helped push day rates up

throughout the course of 2011, says Han-

dler. “But the leading-edge day rates” – therates included in contracts signed monthsbefore rigs are available – “have kind ofstalled,” he says. “They’ve been holding at around $600,000 a day for ultra-deepwaterfloaters, and that hasn’t really changed in sixmonths or so.”

One reason is that contracts for premiumrigs are being signed well in advance of de-livery, locking in rates. “And the current rate

structure gives (drillers) good returns onnewbuild assets,” Handler says. “For now,there seems to be a happy balance betweensuppliers and customers. But I think if de-mand remains strong, we could see ratesclimb in six to nine months.”

In a year-end 2012 report, analysts at Inter-national Strategy & Investments (ISI) backedoff an earlier forecast of day rate increases in2013 despite a tight rig market. According to

Top 10 Offshore Drilling Contractors by Number of Rigs Managed (Total Rigs includes rigs under construction) As of Dec. 19, 2012

Total Under Rest ofCompany Rigs Working Construction US GOM Latin Am NW Europe W Africa Middle East Asia/Pacifi c World

Transocean 99 62 9 16 9 20 14 5 21 5

Noble 76 49 11 11 20 9 5 14 2 4

Ensco 74 57 6 18 14 8 4 10 13 1

Seadrill 64 37 22 2 5 0 7 5 22 1

Diamond Offshore 44 29 4 7 18 4 2 0 7 2

Hercules Offshore 41 19 2 31 0 0 1 5 2 0

Shelf Drilling 37 29 0 0 0 0 6 11 18 2

Rowan 35 24 4 7 2 6 0 11 4 1

China Oilfield Services Ltd 34 30 1 0 2 3 0 4 24 0

Maersk 34 25 7 1 10 9 2 0 3 2

Total 538 361 66 93 80 59 41 65 116 18

Notes: Rig types included: Arctic, drill barges (but not inland barges), drillships, jackups, semisubmersibles, submersibles, and tender-asists. Seadrill numbers do not include rigs owned and managed by North Atlantic Drilling but do include the tender-assists that will be part of the joint venture with SapuraKencana. Noble includes Kulluk Arctic rig which is owned by Shell . Shelf Drilling has not yet taken over full management of all the rigs shown here.

All data as of Dec. 19, 2012. Data courtesty IHS.

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its authors, “Going forward, we continue toforecast strong growth in deepwater activitythrough 2014 but believe that the modest up-side in day rates we were forecasting in 2013may not materialize based on several recentfixtures below our expectations as well as theincreasing desire by contractors to lock morerigs up on term contracts.”

Global ultra-deepwater fleet utilizationstood at 99% at the end of 2012, ISI reported,with Transocean’s GSF Explorer ready stacked

in Southeast Asia. Deepwater utilization de-clined slightly to 86% in the fourth quarter.ISI noted a handful of contracts with day ratesthat exceeded expectations, particularly thenewbuild ultra-deepwater drillships Ocean Rig

Athena, which landed a three-year contractat $650,000 per day, and the Pacifi c Khamsin,which will go to work for Chevron under a two-year contract at $660,000 a day. Both vesselswill be deployed offshore West Africa. But “forevery Khamsin contract that exceeds expecta-

tions with a shorter-term deal, there are otherrigs taking longer-term contracts at rates 10-15% below our modeled expectations,” ISI said.“As more long-term opportunities develop, weexpect more contractors to take advantageof these opportunities, particularly for lowerspec rigs that can be locked up through 2015.”

While demand for midwater assets re-mains strong in the North Sea, new rigs en-tering service in 2014 and the move towardlonger-term contracts could keep day ratesfor the sector flat in 2013, ISI said. Some rigsare expected to be released from Brazil incoming months, which could cause “a sup-ply overhang on surrounding markets inLatin America, the Mediterranean, and WestAfrica” if oil prices do not increase.

Global jackup utilization in late 2012 washovering around 85%, the report said, withday rates bolstered by strong demand inthe North Sea and the US Gulf of Mexico. “With availability in 2013 dwindling, theGulf of Mexico remains the most dynamicjackup market as operators are now movingaggressively to procure rigs for the regionnext year, which is driving backlog higherand likely setting the stage for further rate increases in 2013,” ISI said. Increasing de-mand for jackups in Mexico and an expected long-term overhaul of Pemex’s fleet havehelped drive recent deals in the region – “amarket worth highlighting,” the report said.

Global opportunitiesOverall, 2013 is shaping up to be an en-

couraging year in most all markets. Thereare regional challenges – escalating costs atAustralia’s LNG projects, political pressurein Brazil, heightened regulatory scrutiny inthe US – but the economic picture for drill-ers has improved considerably since theglobal financial crisis and Macondo.

“The Gulf of Mexico feels very strong,”says Handler. “We hear what may be an op-timistic outlook of getting to 50 deepwater rigs in the region in the next few years,” upfrom the current mid-thirties. “I think thatmay be optimistic, but there’s no doubt thatit’s a very strong market.”

Handler expects a “slow evolution” in WestAfrica but notes the nascent presalt oppor-tunities in deepwater offshore Angola as an“interesting” proposition for drillers. Trans-ocean’s Newman singled out the region ina November speech when the topic turnedto promising markets. “The customers haveseen the recent successes that companies likeCobalt have experienced with their well testsand their exploration activity, and there’s a lotof enthusiasm building for a presalt provincein West Africa as well,” he enthused. “So wesee opportunities around the world that giveus a lot of confidence in the strength and thelength of the ultra-deepwater market.”

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In Brazil, state operator Petrobras last year backed off earlier production targets,rolled out a $14-billion divestment plan andcanceled an order for five Ocean Rig drill-ships, citing the need for fewer wells thanthe company had previously stated. Someobservers have welcomed the changes as steps toward greater transparency and ac-countability.

“In 2013, I think we will see the start of therevised Petrobras strategy,” Ensco’s Robertsays. “They are very intent on exploitingthese resources and delivering on time.”

Despite personnel and equipment con-straints, “Brazil is working. I see it as astable place in 2013, with a big focus on pre-salt,” Robert adds. “Brazil is a very interest-ing market, a very large market, and a placewhere opportunities will continue to exist.”

Globally, the delivery of high-spec jackupsand ultra-deepwater rigs over the next few years may hasten the bifurcation trend ana-

lysts see in day rates and demand. But fornow, relative political and economic stabilityin oil producing regions promise a period ofmodest growth, predictability, and new op-

portunities for drilling contractors that ex-tend well beyond the Golden Triangle.

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The Largest Publicly Traded Drilling Contractors in 2011

Enterprise Fleet 2011valuea valuea revenue

Firm ($billion) ($billion) ($billion) Jackups Semis Drillships Total Headquarters

Transocean 25.4 32.1 9.1 68 50 23 141 U.S.

Seadrill 27.1 15.6 4.0 21 12 6 39 Norway

Diamond Offshore 8.9 8.7 3.3 13 32 3 48 U.S.

Ensco 16.7 14.5 2.8 42 18 5 65 U.S.

Noble 13.3 11.7 2.7 45 14 13 72 U.S.

Saipem 26c 4.5 1.0b 7 7 2 16 Italy

Rowan 4.5 5.7 0.9 31 0 0 31 U.S.

Songa Offshore 1.7 1.9 0.7 0 5 0 5 Norway

Ocean Rig 3.6 3.0 0.7 0 2 4 6 Norway

Atwood Oceanics 3.2 2.7 0.6 6 6 1 13 U.S.

Aban 2.9 2.4 0.6 15 0 3 18 India

Hercules Offshore 1.3 1.1 0.5b 33 0 0 33 U.S.

Vantage 1.5 1.7 0.3 4 0 4 8 U.S.

Japan Drilling 0.4 1.2 0.3 4 2 0 6 Japan

Total 110.5 106.8 26.4 289 148 64 501

% of world fleet 54% 66% 60% 58%

Note: (a) Enterprise and fleet value evaluated on December 21, 2011. (b) Only includes offshore drilling revenues. (c) Most of Saipem’s enterprise value is associated with non-offshore drilling activities and is not included in the total.Source: Jefferies and Company, Inc., 2012; financial reports; RigLogix, 2011.



Assessing the offshore

drilling market

Fleet values depend

upon rig specification,

market conditions,

and contract backlog

Mark J. KaiserBrian F. Snyder

Center for Energy StudiesLouisiana State University

Drilling contractors compete in re-gional markets with rigs of differentclasses, qualities, and specifi cations.The first part of this three-part seriesdescribes ownership structure and

how public firms are valued by the market.The primary factors that impact valuationare revenues, net earnings, fleet values, anddebt load.

OwnershipDrilling contractors are corporate entities

that may be owned by investors or a govern-ment. Investor-owned drilling contractorsmay be publicly traded or privately held.Publicly traded corporations have a largenumber of shareholders and their reportingrequirements are regulated by the stock ex-changes where they are listed, whereas pri-vate firms are owned by a small number ofshareholders and are not required to reportfinancial or operational data. State-owneddrilling contractors may be entirely ownedby a state, or a fraction of the shares may betraded on a financial exchange. The owner-ship structure of the firm impacts businessstrategies, governance, access to debt, andtransparency.

Public firmsThe 14 largest publicly traded drilling con-

tractors realized $26.4 billion in revenues in2011 from an inventory of 501 drilling rigs(289 jackups, 148 semis, and 64 drillships)and generated more than half of the indus-try’s total revenue. Total fleet value is estimat-ed at $107 billion, and collectively, the compa-nies had an enterprise value of $111 billion.

Transocean was the largest contractor interms of fleet size and revenue, and owned141 rigs, or 16% of the total fl eet, including22% of the total floater fleet. In September2012, Transocean agreed to sell 38 shallow-

The Largest State-Owned Drilling Contractors in 2011

PubliclyFirm Nation/Market Jackups Semis Drillships Total traded

China Oilfield Services Ltd. China 27 6 0 33 Yes

National Drilling UAE 13 0 0 13 No

ONGC India 8 0 2 10 Yes

Petrobras Brazil 6 4 0 10 Yes

Socar Azerbaijan 6 3 0 9 No

Egyptian Drilling Egypt 7 0 0 7 No

Gulf Drilling International Qatar 6 0 0 6 No

CNPC China 4 0 0 4 Yes

Gazflot Russia 2 2 0 4 No

NIDC Iran 4 0 0 4 No

Arabian Drilling Saudi Arabia 4 0 0 4 No

PV Drilling Vietnam 4 0 0 4 No

Sheng Li China 4 0 0 4 No

VietSovPetro Vietnam 3 0 0 3 No

Caspian Drilling Azerbaijan 0 2 0 2 No

Saudi Aramco Saudia Arabia 2 0 0 2 No

ArcticMorNefteGazRazvedka Russia 2 0 0 2 No

Petrobaltic Poland 2 0 0 2 Yes

PDVSA Venezuala 2 0 0 2 No

KNOC Korea 0 1 0 1 No

Pemex Mexico 1 0 0 1 Yes

Total 107 18 2 127

% of world fleet 20% 8% 2% 15%

Source: RigLogix, 2011.

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water drilling rigs to Shelf Drilling Interna-tional Holdings Ltd. for $1.05 billion as part of its strategy to unload older rigs and focus on the high-end market. Seadrill was the largest fi rm by enterprise value, with only half the revenue and one-third the fl eet size of Transocean. After the 2010 Macondo oil spill, Transocean’s share price declined be-cause of uncertainty associated with its fu-ture liability. Seadrill, Diamond, Ensco and Noble together own 209 rigs, including 88 fl oaters, and account for 24% of the total fl eet and 27% of the fl oater fl eet.

Transocean, Seadrill, Diamond, Ensco, and Noble are signifi cantly larger than their near-est competitors, and each had revenues of over $2 billion in 2011 with enterprise values of $9 billion or more. These fi ve fi rms are cat-egorized as “large-cap” and the nine smaller fi rms as “mid-market” players. Large-cap fi rms operate large diverse fl eets in a number of geographic regions, while mid-market fi rms operate smaller fl eets and are more likely to specialize by rig class and geographic region.

All large cap fi rms except Seadrill are headquartered in the United States, as are the mid–market fi rms Hercules, Rowan, Atwood, and Vantage. Seadrill, Songa, and Ocean Rig are headquartered in Norway. Most fi rms are incorporated in offshore fi -nancial centers for tax purposes. Common centers of incorporation include Switzer-land, Cyprus, and the Cayman Islands.

State-owned fi rmsChina Oilfi eld Services Ltd. (COSL) is the

largest state-owned drilling contractor and owns as many rigs as National Drilling (UAE), ONGC (India), and Petrobras (Brazil) com-bined. In total, state-owned fi rms own 127 drilling rigs, or about 15% of the world fl eet, and control about 20% of the jackup market. Most state-owned fi rms are jackup-oriented, but COSL, Petrobras and Socar own semisub-mersibles, and ONGC owns two drillships.

State-owned drilling contractors work almost exclusively in their home countries and are typically important players in their home mar-kets. They may be a subsidiary of a national oil company (e.g. COSL is owned by CNOOC) or the NOC may directly own and operate the drilling fl eet. The largest state-owned drilling contractors are publicly traded fi rms in which the government is the majority shareholder (Petrobras, CNOOC, ONGC); most other state-owned contractors are not publicly traded and are small players similar to small private fi rms.

Private fi rmsPrivate fi rms own about a third of the

world’s deepwater rig fl eet, and play an im-portant role in the fl oater markets in the North Sea and Brazil. Maersk Drilling, Stena Drilling, Dolphin, Schahin, and Odfjeld are

the largest private contractors and control about 20% of the private fl eet. Maersk Drill-ing is a subsidiary of A.P Moller-Maersk and Dolphin is a subsidiary of Fred Olsen Energy.

The only privately held fi rm frequently op-erating in the US GoM is Spartan Offshore, which is owned by a private equity fi rm and operates four low-spec jackups. About 50 fi rms own fewer than three rigs, and are ei-ther privately held or traded on the over the counter market.

Market share The number of contracted days across all

regional markets is used to measure market share. Over the past decade, jackups have been contracted between 250,000–350,000 days and fl oaters 150,000–275,000 days per year. Publicly traded fi rms dominate the market because of their larger fl eet sizes, but state-owned contractors are important in

the jackup market, constituting about 20% of days on contract, and in the fl oater market, private fi rms share of contracted days has historically ranged from 10 to 20%.

ValuationPublicly traded drilling contractors are

continuously valued by the market. The pri-mary factors that impact valuation are cur-rent and projected revenues, net earnings, fl eet values, and debt levels. Factors that are more diffi cult to observe and quantify that also impact market valuation include insur-ance liabilities and customer relationships.

RevenueEnterprise value is correlated with fi rm

revenue and earnings. Revenue and earnings is determined by fl eet composition (rig type, quality, age) and geographic distribution, uti-lization, day rates, and operating cost.

Source: Data from RigLogix, 2011.

Contracted days in the world drilling market

by company ownership, 2000-2010.

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35

30

25

20

15

10

5

01

y = 3.0715x + 2.8412R2 = 0.71364

Seadrill

Transocean

Diamond

ENSCO

Noble

Rowan

Vantage Songa

Aban & Atwood

2011 revenue ($billion)

En

terp

ris

e v

alu

e (

$b

illi

on

)

20 3 4 5 6 7 8 9 10

Source: Data from Jefferies and Company, Inc., 2012.

Relationship between enterprise value and revenue

for leading drilling contractors on Dec. 31, 2011.

35

30

25

20

15

10

5

00

y = 0.2164x – 0.1151R2 = 0.87978

Seadrill

Transocean

Diamond

Hercules

ENSCO

Noble

Rowan

Vantage,Japan Drilling,

Ocean Rig& Songa

Saipem

AbanAtwood

Fleet size (# of rigs)F

lee

t va

lue

($

bil

lio

n)

20 40 60 80 100 120 140 160


Relationship between fleet size

and fleet value on Dec. 31, 2011.

Transocean and Diamond are the only two large-cap contractorsthat fall below the industry average in both revenue and earnings.Transocean’s $5-billion market discount suggests the market valua-tion of its liabilities associated with Macondo. In January 2013, someof this uncertainty was resolved when Transocean agreed to pay$1.4 billion to settle all federal civil and criminal claims related tothe oil spill, but pending claims remain. Diamond falls below theindustry line due in part to its older fleet, despite relatively strongrevenues. Seadrill, Ensco, and Noble have higher enterprise valuesthan the industry average, with the premium for Seadrill being par-ticularly large due to its focus on high-specification units which havereceived high utilization and day rates in recent years. Ensco andNoble also have higher-spec and globally diversified fleets, whichcontributes to their higher valuation.

Fleet valueFleet value is closely correlated with fleet size and is a significant

predictor of enterprise value. Fleet value is defined as the net assetvalue of the firm’s rig portfolio, and depends upon rig specifications,market conditions and the backlog of contracts held by the firm.Fleet sizes vary over time with newbuild programs and retirements,and can vary dramatically with merger and acquisition activity. Alarge asset base implies a platform for sustainable revenues and cor-relates to the diversity of the product line.

For most firms, enterprise value as a percentage of fleet value variedbetween 80% to 120%, between 2010 and 2012. Rowan’s valuation fell onthe low end of the spectrum, between 60% and 90% of fleet value, duein part to its jackup specialization and large proportion of its operationsin the low-day rate Persian Gulf and US GoM. By contrast, Seadrill’senterprise value was over 200% of net asset value reflecting its high-specfleet and focus on Southeast Asia and the North Sea, where utilizationrates are high and day rates command a price premium.

DebtThe cost to construct offshore drilling rigs is substantial, and the

capital requirements to maintain a fleet requires a strong and stablecash flow. As a result, contract drillers often show negative free cashflow during periods of construction or major fleet enhancement.Seadrill and Songa were active in the newbuild and secondhandmarkets between 2008 and 2011, and illustrate the range of financ-ing alternatives.

In 2008, Songa’s debt-to-market capitalization was relatively high

because the company had used debt to finance the purchase of rigs,and had limited cash flow at the time. Its 2008 earnings were approx-imately $200 million compared to a total debt of $1 billion. Songa’sdebt load declined as the company used earnings to pay off debt,and by late 2010, Songa’s debt had declined to approximately $500million and its debt-to-market capitalization was 30%. In 2011, Songa entered into a new credit facility to finance the construction of newrigs, increasing its debt-to-market capitalization ratio to 45%.

By contrast, Seadrill’s debt as a proportion of market capitaliza-tion remained relatively stable from 2008-2011, ranging between 60%to 70%, even as the firm’s debt load grew from $6 billion in 2008 to$10 billion in 2011. Instead of using cash to pay off debt, Seadrillhas spent cash on acquisitions and newbuilds. Strong current andprojected future earnings have allowed the firm to maintain a highmarket capitalization and a modest debt ratio load. Next part, wereview operator specialization and newbuild strategies. �

Editor’s note: This article is the first in a three-part series by Mark Kaiser and

Brian Snyder on the offshore contract drilling market.

35

30

25

20

15

10

5

00

y = 0.9216x + 1.5399R2 = 0.8007

Seadrill

Transocean

Diamond

ENSCO

Noble

Rowan

Songa,Hercules

& Vantage

Atwood

Fleet value ($billion)

En

terp

ris

eva

lue

($

bil

lio

n)

5 10 15 20 25 30 35


Relationship between enterprise value

and fleet value on Dec. 31, 2011.

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LH29-1-1 discovery well

Husky interests

Hainan

Block 63/05

Wenchang

oil field Block 29/26

South China Sea

Philippines

Taiwan

East China Sea

Block 04/35

Hong Kong

Shanghai

0 Miles 186

0 Km 300

VIETNAM

CHINA

LW3-1-1discovery well

LW3-1-3appraisal well

LW3-1-2appraisal well

LW3-1-4appraisal well LH34-2-1

discovery well


A S I A

Operators ramp up activity offshore Asia

Economic growth in the Asia/Pacific region is driving demandfor oil and gas increasingly offshore, and international opera-tors and national oil and gas companies are taking action on anumber of fronts to answer that demand.

According to Infield Systems Ltd., total capex in the regionis expected to exceed $90 billion during 2011-2015, a 55% increasefrom the previous five-year period.

The following highlights some of the more notable proposed andongoing oil and gas development projects offshore Asia.

ChinaChina National Offshore Oil Co. (CNOOC) is active on several

fronts. The Chinese national oil company reports that productionhas commenced on the Panyu 4-2/5-1 oil fi eld adjustment projectand the Liuhua 4-1 oil field, located in the Pearl River Mouth basinof South China Sea.

The Panyu 4-2/5-1 oil field has an average water depth of about100 m (328 ft). The adjustment project was designed to access exist-ing facilities in order to develop Panyu 4-2/5-1 more effectively. Theadjustment project was expected to reach peak production in 2014.

CNOOC holds 75.5% interest and serves as operator of the Panyu4-2/5-1 oil field. Its partner, Burlington Resources China, holds theremaining 24.5% interest.

The Liuhua 4-1 oil field has an average water depth of about 268 m(879 ft). In view of the features of the field, CNOOC built a new sub-sea production system that also makes use of surrounding facilitiesfor field development. This project is expected to hit peak produc-tion in 2013. Liuhua 4-1 is an independent oil field in which CNOOCholds 100% interest and is the operator.

In addition to these developments, CNOOC also reports that oilhas begin to flow on the Weizhou 11-2 and Weizhou 6-9/6-10 fieldsin the South China Sea’s Beibu Gulf. Weizhou 11-2, in 35 m (115 ft)of water, has four producing wells and is expected to peak at 3,960b/d this year. Weizhou 6-9/6-10, in 32.5 m (107 ft) water depth, hasnine producing wells and is expected to peak at 5,870 b/d this year.CNOOC holds 100% interest in both fields.

Elsewhere, CNOOC reports success on two wells at Qinghuang-dao 29-2 East in Bohai Bay. The tract is in the north central BohaiBay in 27 m (89 ft) water depth. The E4 well encountered a total of218.4 m (717 ft) of oil pay, with 133.7 m (439 ft) in a single zone. Ittested at 6,600 b/d of oil and 4.5 MMcf/d of natural gas. No furtherinformation was available at press time regarding the second well.

On still another front, Husky Energy says construction of the Li-wan gas project in the South China Sea is roughly 75% complete. Thecentral platform jacket has been launched and secured to the seabedin readiness for installation of the topsides next spring.

VietnamSignificant development activities are taking place offshore Vietnam.

PanPacific Petroleum (PPP) recently announced that the Silver Sillagoprospect will be drilled as the remaining commitment well in block07/03 offshore southern Vietnam. Subject to finalization of the rig con-tract, the well should be drilled in mid-2013. The partners are assess-ing whether additional appraisal drilling is needed to resolve resource

uncertainties over the Cá Rồng Ðỏ oil and gas/condensate discovery.In offshore block 121 (PPP interest 15%, subject to completion of farm-

in), a rig will be sought to drill the large Ca Voi prospect in 2Q 2013. Op-erator Origin Energy has requested an extension to the first explorationphase from PetroVietnam to accommodate the revised spud date.

Elsewhere, production is building at the Te Giac Trang (TGT) fieldoffshore Vietnam, in the Nam Con Son basin. Production is in therange of 50-56,000 b/d, according to SOCO International. The field isoperated by the Hoang Long Joint Operating Co., a partnership formedbetween PetroVietnam (41%), Soco International (28.5%), PTT Explora-tion and Production (28.5%), and OPECO Vietnam (2%).

Five wells are onstream at the H4-WHP TGT southern platform,which entered service this past summer. The field’s daily rate fluc-tuations reflect well intervention activities. A one-day “high rate” flowtest was conducted on the TGT FPSO at 60,789 b/d, SOCO adds. Noissues were evident in either reservoir performance or FPSO oper-ability.

At TGT’s northern platform, H1-WHP, the PetroVietnam jackupPVD-II has been working on a four-well, infield development drillingprogram that included two infill wells, an appraisal well, and onedevelopment well.

The TGT-15P and TGT-16P infill wells on the H1.1 fault block andthe TGT-8X appraisal well on the H2N fault block were batch drilledinto the reservoir section. All are now onstream.

MalaysiaIn Malaysia, Petronas has reported two major gas discoveries off-

shore Sarawak. The Kuang North-2 exploration well in block SK316penetrated a 636-m (2,087-ft) gas column. The well was drilled to aTD of 3,223 m (10,574 ft). Preliminary assessments indicate gas-in-place for the Kuang North field is about 2.3 tcf.

The Tukau Timur Deep-1 well was drilled to a depth of 4,830 m(15,846 ft) and discovered 12 gas-bearing reservoirs with total netgas sand of 183 m (600 ft). This is the first completed high-pres-

Bruce BeaubouefManaging Editor

Husky Energy is advancing plans for three significant gas discoveries in

block 29/26 of the South China Sea, including the Liwan 3-1, Liuhua 34-2,

and Liuhua 29-1 gas fields. (Map courtesy Husky Energy)

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A S I A

sure/high-temperature well in Sarawak andis also the deepest vertical well to be drilledby Petronas.

Preliminary assessments indicate the totalgas-in-place for Tukau Timur field is about 2.1tcf. Petronas Carigali operates block SK307with 50% interest and Sarawak Shell Berhadholds the remaining 50%.

Petronas has also awarded a production-sharing contract for block SB311 offshoreSabah to the ConocoPhillips Sabah Gas Ltd./Shell Energy Asia Ltd./Petronas Carigali SdnBhd partnership.

The partners are committed to drill twowildcats, acquire new 2D seismic, and repro-cess existing 3D seismic on the block. The1,046-sq km (404-sq mi) block is in centralSabah basin and has water depths of 50 to100 m (164 to 328 ft). ConocoPhillips will bethe operator with 40% interest while Petro-nas and Shell will each hold 30%.

In the North Malay basin, Petronas Cari-gali Sdn Bhd and Hess Exploration and Pro-duction Malaysia B.V. have signed contractsto move forward with the North Malay Basingas development project. Petronas says $5.2billion will be invested in the project over thenext five years to commercialize 1.7 tcf of gasreserves. Hess will have a 50% working inter-est and become operator of the project.

First production is forecast to commencein 2013 at a net rate of approximately 40MMcf/d and increase in 2015 to an estimat-ed 125 MMcf/d.

Meanwhile, Shell and Petronas are teamingup on EOR projects offshore Malaysia. Thetwo companies recently signed two new pro-duction-sharing contracts for enhanced oil re-covery projects offshore Sarawak and Sabah.

Under the new contracts, Shell Malaysia’supstream companies and partner Petro-nas will further develop six oil fields in theBaram Delta offshore Sarawak, and three oilfields in the North Sabah development areaoffshore Sabah.

The deal combines the remaining periodsof the earlier PSCs which would have expiredin 2018 (Baram Delta Operations) and 2019(North Sabah) with license extension to 2040,and with the addition of the EOR componentfor integrated PSCs with new terms.

ThailandThe number of E&P projects is also on the

rise offshore Thailand. In the Gulf of Thailand,PTT Exploration and Production plc (PTTEP)has started production from the Greater BongkotSouth (GBS) gas and condensate field. Its part-ners in the development are Total and BG Group.

The GBS field is in blocks B16 and B17,200 km (124 mi) east of Songkhla. This latestdevelopment comprises a new central process-ing platform, a living quarter platform, and 13wellhead platforms. According to Total, the pro-

cessing platform has a capacity of 350 MMcf /dof gas and 15,000 b/d of condensate.

Gas heads via a new spur line to the PTT-operated grid while condensate is exported tothe existing FSO vessel at the Greater Bong-kot North field, 80 km (49.7 mi) to the north.

In addition to the state-owned PTTEP, sever-al private contractors and E&P firms are look-ing to develop oil and gas offshore Thailand.Salamander Energy has started oil produc-tion through the Bualuang Bravo platform inthe Gulf of Thailand. The jackup Atwood Mako

drilled and completed the horizontal BB-04Hdevelopment well from the platform on the Bua-luang field. After clean-up operations, the wellshould produce at its planned rate of 1,500 b/d.The rig is currently drilling the second develop-ment well from the platform BB-10H.

The Bualuang field is presently producingmore than 8,300 b/d. As the developmentprogram progresses, with 15 more wells tobe added, next year output is expected to in-crease to 11,000-14,000 b/d.

PhilippinesOff the Philippines, operators and develop-

ers are moving to develop several new proj-ects. Total E&P Philippines has agreed tofarm into 75% of offshore block SC56 in the

(Above) The Malampaya Deepwater Gas-to-Pow-

er project is in its third phase and encompasses

installation of a depletion compression platform

linked by a bridge to the existing shallow-water

platform. (Photo courtesy PNOC Exploration

Co.) (Below) Offshore Thailand, the jackup

Atwood Mako has drilled and completed the

horizontal BB-04H development well from the

platform on the Bualuang field for Salamander

Energy. After clean-up operations, the well

should produce at its planned rate of 1,500 b/d.

(Photo courtesy Atwood Oceanics)

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Sulu Sea, held by Kuala Lumpur-based MitraEnergy (Philippines SC-56). The block cov-ers an area of roughly 4,300 sq km (1,660 sqmi), in water depths ranging from 200-3,000 m(656-9,842 ft). Mitra will retain a 25% interestin SC56.

The Philippines Department of Energy isalso facilitating project requests on the regula-tory front. The department has extended forone year an existing permit for explorationSub-Phase 4 in SC55. Operator BHP Billitonrequested the extension in order to secure anappropriate ultra-deepwater rig with specializedwell control equipment it wants for safe drillingon the proposed Cinco prospect.

After the extension, Sub-Phase 4 and onecommitted well will be drilled by Aug. 5, 2013.Sub-Phase 5 calls for another well to be drilledby Aug. 5, 2014. The working interests in Ser-vice Contract 55 are Otto Energy throughwholly owned subsidiary NorAsian Energy Ltd,33.18%; BHP Billiton Petroleum (Philippines)Corp., 60%; and Trans-Asia Oil and Energy De-velopment Corp., 6.82%.

The department has also extended by ninemonths the Otto Energy Ltd. Exploration Sub-Phase 3 on service contract 69. Otto says theextension is to allow sufficient time to completedetailed evaluation and grading of prospects.Further, recent 3D seismic confirms three po-tential targets in Lampos, Lampos South, andManagua East areas of the service contract.Otto Energy Investments Ltd. holds 79%, Fron-tier Gasfields Pty Ltd holds 15%, and Trans-AsiaOil and Energy Development Corp. has 6%.

Elsewhere, the Fluor Corp. Offshore Solu-tions unit has participated in the MalampayaDeepwater Gas-to-Power project contract sign-ing. Joint venture partners in Service Contract38 are Shell Philippines Exploration, ChevronMalampaya, and Philippine National Oil Co.The venture operates the Malampaya projectfor the Philippine Department of Energy.

Malampaya is in its third phase and encom-passes installation of a depletion compressionplatform linked by a bridge to the existing shal-low water platform. Fluor is responsible for thetopsides and substructure. The project is underway with expected completion in late 2015.

The Phase 3 project is led by the PhilippineDepartment of Energy, supported by projectoperator Shell and its joint venture partners,Chevron Malampaya LLC and the PhilippineNational Oil Co.-Exploration Corp (PNOC-EC).

Keppel Subic Shipyard has a contract fromShell Philippines Exploration to build a depletioncompression platform (DCP) for the Malampayagas field development.

The DCP will be bridge-linked to the exist-ing shallow-water production platform nearPalawan Island, under Phase 3. It will maintaincurrent availability and deliverability of naturalgas from the Malampaya field by regulatinggas export pressure and flow rates. �

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A S I A

Salamander builds niche

in underdeveloped Thai, Indonesian plays

Jeremy BeckmanEditor, Europe

One of the fastest-growing indepen-dents in the Southeast Asia region isLondon-based Salamander Energy.Since its formation in 2006, the com-pany has built exploration and pro-

duction hubs offshore and onshore Thailandand Indonesia, with offices in Singapore,Bangkok and Jakarta.

Much of its offshore oil comes from theBualuang field in the B8/38 license Gulf ofThailand, where the company recently addeda second wellhead platform. Ongoing develop-ment drilling, using the jackup rig Atwood Mako,should drive output to 14,000 b/d. Later thisyear, Salamander plans to explore for furtherreserves in the area by drilling six exploratorywells on the adjoining G4/50 license.

In the North Kutei basin offshore Indone-sia, the company operates the Bontang andSE Sangatta production-sharing contracts.The main Kutei basin has been prolific foroil and gas, but the northern part had gen-erally been assumed to lack a sand system.In 2010, however, Salamander opened a newplay in the area with its Angklung gas dis-covery, and recently started a three-well ex-ploration program targeting over 400 MM-Boe of prospective resources.

Offshore spoke to chief operating officerMike Buck for further insights into progressto date and future plans.

Offshore: Salamander has developed rela-tionships and contacts at various levels acrossthe Southeast Asia region. How did it happen,and is this level of a contact unusual for anE&P independent of Salamander’s size?

Buck: I think it is partly as a result of thedirectors having worked in Southeast Asia viatheir previous roles. More importantly, I thinkit comes through being regionally focused. Asa pure Southeast Asian play, our managementis not splitting its time between three regionsin different parts of the world and that cer-tainly helps to develop strong relationships. Ithink people within the region know we arecommitted to making Southeast Asia workand can see the track record we have built ofdelivering developments on time and budget,which makes them want to get to know us.

Offshore: Would you say Salamander hasbeen more active than others offshore Thai-land in trying to maximize production fromits assets, in this case in the Greater Bualu-ang Area (GBA)?

Buck: The west of the Gulf of Thailand isrelatively under-explored and so far there areonly a handful of development projects. Wehave been actively investing in the Bualuangfield to both grow production and reduce oper-ating costs. We installed a new platform (Bravo)in 4Q 2012 and are in the early stages of a 16-well development drilling program that will seeproduction grow by at least 50% in 2013. Weare in the process of building new power andprocessing modules to load onto the platformat the end of 2013 that will enable us to replacethe current FPSO with a floating storage andoffloading unit (FSO), which will lower operat-ing costs by around 30% per annum.

Offshore: Is the Bualuang field complexto image or produce? Historically, were re-serves this size offshore Thailand ignoredby foreign investors?

Buck: Exploration in the Gulf of Thailandhas traditionally focused on the large Pattanibasin to the east of our acreage position, whereChevron is the main producer. Exploration inthe western basins has been much lighter todate and this immaturity means the block sizesin the west tend to be larger. All Gulf of Thailandbasins have similar play elements, although thePattani is much deeper and so more gas-prone.

Typical Gulf of Thailand traps are complex,fault block structures with stacked thin payzones. Early vertical wells often failed or foundminimal pay, and accurate structural mappingusing 3D seismic is essential. Bualuang, on theother hand, is a relatively simple fault-boundedstructure with one thick reservoir sand andtwo thinner pay zones. It is extremely wellimaged by Salamander’s 3D seismic data, sowells can be targeted with precision. The pri-mary challenge for efficient production is toensure a balance of oil production rate withwater cut that maximizes the commercial re-coverability of reserves.

Offshore: How have the Bualuang pro-duction wells performed to date? Has therebeen any need for supplementary measuresto stimulate flow?

Buck: We have drilled around 14 wells now,excluding workovers and side tracks, so wehave a very good model and can accurately pre-dict well performance. One of the keys to thesuccess has been drilling horizontal wells. Wehave a very good quality reservoir and watermanagement is a key issue. Through drillinghorizontal wells and using electric submersiblepumps to regulate fluid flow, we are able to max-imize recovery and delay water breakthrough.All slots on the Alpha platform are now fullyused – the 12 available slots provide 10 produc-tion wells and two water disposal wells.

As for development drilling from the Bua-luang Bravo platform, this has gone well so

The bridge-linked Bualang Alpha and Bravo platforms in the Gulf of Thailand.

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A S I A

far and the initial wells have performed as ex-pected. The Bravo platform is an unmannedstructure with 16 drilling slots and weighs2,100 tons [1,905 metric tons]. It is roughlytwice the size of the Alpha platform. Bravowas designed and built by Thai Nippon Steel,which constructs a lot of platforms for opera-tors in the Gulf of Thailand. There are no pro-cessing facilities on either platform at presentand we have an FPSO at the field. Later thisyear, we will load processing facilities ontothe Bravo platform as well as replacing theFPSO with an FSO. The Bravo platform haspipework already installed that will allow sat-ellite discoveries to be tied into the Bualuangprocessing and oil export facilities.

Offshore: Are any of the new developmentwells the Atwood Mako is drilling complex inany way?

Buck: The bridge-linked Alpha and Bravoplatforms are centrally located on the Bualu-ang field. This is highly efficient from a facili-ties standpoint but does require all the produc-tion wells to be deviated to their targets. Themain reservoir in Bualuang is only 1,100 m[3,609 ft] below the surface and so some of thewells are quite long reach with drilled depthsof up to 3,000 m [9,842 ft]. Long reach horizon-tal drilling technology is tried and trusted in

the industry, if rather new to the Gulf of Thai-land, and to date, Salamander is having greatsuccess in drilling the production wells on theBualuang field. To maximize recovery, we drillhorizontal wells very close to the top of thereservoir and the skill is in locating these wellsin the right place to maximize reservoir qual-ity and stand off from the oil/water contact.

Offshore: Bualuang is said to be under atax and fiscal regime that rewards produc-tivity – how does it compare with other re-gimes in the region?

Buck: Thai fiscal terms are very attrac-tive and Thai barrels are some of the mostvaluable in the region.

Offshore: Can you provide an update onSalamander’s exploration drilling plans forthe B/38 and surrounding G4/50 licenses?

Buck: Exploration in our offshore acreageis now focused on maturing the G4/50 pros-pect inventory, and we eagerly anticipate thestart of a minimum six-well drilling campaignin 2013 targeting prospects which have goodchances of success and are quick to drill. Wehave completed initial interpretation of 5,000sq km [1,930 sq mi] of 3D seismic acrossthe license, and preliminary mapping of thedata has identified over 20 prospects. These

lie within the 20-80 MMbbl oil range, withchances of success expected to be around30% once the prospects are matured. A num-ber of these prospects are drill-ready and willbe among the 2013 planned wells.

Well costs are anticipated to be about $6 million each, depending on depth. Discover-ies can be brought onstream rapidly, usingexisting facilities where possible.

Offshore: What is the situation concerningseismic coverage and interpretation over theBontang and Southeast Sangatta licenses?

Buck: There are over 28 leads and pros-pects mapped across the Bontang and SE San-gatta production-sharing contracts. South Ke-capi is the first well in a potentially high impactprogram, and will be followed by the NorthKendang and Bedug wells in a campaign thatwill test combined mean prospective resourceof 1.4 tcf of gas and 189 MMbbl of oil.

Offshore: The 2010 Angklung discovery dem-onstrated distinctive seismic response of gas-bearing sandstones in this area, and that thesecould be mapped using 3D seismic data. Whatwas the difficulty in terms of imaging, and howdid you or your contractor overcome this?

Buck: The seismic response of the maingas sand at Angklung was very clear and pro-

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A S I A

vided excellent calibration to help optimize theprocessing of the 3D data sets. Similar seismicresponses have been identified on many of theprospects mapped in Bontang and SoutheastSangatta. As with any seismic data set, it is ex-tremely important to ensure careful control ofseismic velocities during processing. Salaman-der has put great effort into this aspect of thework and processes the data with prestack mi-gration in both the time and depth domains toimage as clearly as possible the traps and theirgeology. The multiple stacked potential of theprospects has presented some difficulties in im-aging as the deeper targets can have their seismicresponse masked by high amplitude response inthe shallower targets above. Where this occurs,careful interpretation of the seismic is required;incorporating detailed mapping with geologicalmodeling to ensure a coherent and consistentassessment is made, allowing reserves and riskpotential to be properly evaluated.

Offshore: Has the discovery of a sand systemled to others exploring in the North Kutei basin?

Buck: There is not much other explorationin the North Kutei at present, but other peopleare chasing similar plays further to the south.

Historically, exploration of the Kutei basinhas shown it to be predominantly a gas prov-ince yielding around 70% gas reserves and 30%oil. Discoveries in the northern Kutei to datetend to conform to the overall gas/oil percent-ages. However, the presence of active oil seepsonshore adjacent to the Southeast Sangattablock and seabed oil seeps detected on thesea surface by multiple pass satellite survey-ing indicate that the Miocene section of theNorth Kutei basin is more oil-prone than theshallower, gas-prone Pliocene. The Kendangstructure has a very well defined seabed seepassociated with its bounding fault which sup-ports the argument for a significant oil play inthe area. However, with the gas markets be-ing so strong in the area due to the presence ofthe Bontang LNG plant and the surroundingindustrial infrastructure, realizable gas pricesare also high and gas is more valuable than inmany other parts of the world.

Offshore: The 3D data review over the twolicenses identified over 28 leads and pros-pects. Do they appear complex to drill – isthat the reason for the planned side track onSouth Kecapi-1?

Buck: The wells are not overly compli-cated, requiring relatively minor amountsof steering to ensure the stacked targetsare penetrated at the desired locations. Theprospects lie in water depths between 350 and 550 m [1,148-1,904 ft] and so requirea floating rig, but the sea state in this shel-tered part of the Makassar Strait is benignyear round and presents no particular chal-lenge to operations. The side track of South

Kecapi is necessary as one of the Pliocenechannel targets of the first well shows po-tential to be substantially thickened and per-haps independently trapped down dip of theoriginal hole. The side track is therefore re-quired to evaluate this down dip thickening.

The majority of the targets defined are inthe Pliocene and Upper Miocene sections.

We have the equipment at site to test thewells. We will also use pressure-testing logsto determine fluid type and potential hydro-

carbon column height so not every pay zonewould have to be drillstem tested.

Offshore: Salamander exited Vietnam lastyear after an unsuccessful drilling campaignoff the north coast. Is it looking at other off-shore opportunities elsewhere in SoutheastAsia?

Buck: We are always looking at new op-portunities but most of them would be on-shore or in shallow water. �

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W E S T A F R I C A

Deepwater, subsea projects propel

offshore West Africa activity

As East Africa rapidly emerges as a frontier province with majorgas discoveries offshore Mozambique and Tanzania, West Af-rica continues to advance plans for new and existing explora-tion and production projects.

A recent Infield Systems Ltd. report estimated that morethan 220 fields are expected to start production in the next five years.According to the energy analyst, the largest proportionate growth inreserve additions will occur offshore Cameroon, Congo (Brazzaville),Equatorial Guinea, and Ghana.

Total is expected to remain the dominant major operator, but InfieldSystems also expects continued strong development from Chevron,ExxonMobil, and Shell. However, independents such as Tullow Oil,Hess Corp., Afren, and Noble Energy are finding success in the region.

The following is an overview of activity offshore West Africa.

GhanaDeepwater Ghana continues to deliver for operators. Tullow Oil and

its partners have submitted a plan of development for the Tweneboa,Enyenra, and Ntomme (TEN) fields to Ghana’s Ministry of Energy.The development is designed to allow reserves from these fields andother nearby discoveries to be tied back to an FPSO.

The Deepwater Tano block is operated by Tullow Oil (49.95% workinginterest) along with Anadarko (18% working interest), Kosmos Energy(18% working interest), Sabre Oil & Gas Holdings Ltd. (4.05% workinginterest), and the Ghana National Petroleum Corp. (10% carried interest).

Tullow Oil’s latest exploration well in the license reached its planneddepth with mixed results. Okure-1 encountered non-reservoir qualityformations at the main target levels below the TEN cluster fields. Thewell also encountered a gross 17-m (56-ft) interval of low net-to-grossoil-bearing Turonian-age sandstones within an overlying secondary tar-get. Light oil (40° API) was recovered from this interval. Analysis ofwireline logs and pressure data indicates the structure is not connectedto other discoveries in the license area.

The company has started to drill the Sapele-1 exploratory welladjacent to the Jubilee field.

Following the start-up of two Jubilee field Phase 1A wells and success-ful acid stimulations, oil production is about 110,000 b/d. Total well pro-duction deliverability is now more than 120,000 b/d. Three more Phase1A producer wells are expected to be completed before mid-2013. The$1.1-billion Phase 1A development involves adding five new productionwells and three water injectors, and expanding the subsea facilities net-work. The Sedco Energy semisubmersible is performing additional acidstimulation work on two Jubilee Phase 1 wells to further enhance output.

Located on two licenses, Deepwater Tano and West Cape ThreePoints, Jubilee is situated in water depths of 3,609 ft (1,100 m) and is oper-ated by Tullow (49.95%), with partners Kosmos Energy (18%), AnadarkoPetroleum (18%), Sabre Oil & Gas Holdings Ltd. (4.05%), and the GhanaNational Petroleum Corp. (10%).

Hess Corp. has discovered oil at the Pecan-1 exploration well in the Deepwater Tano/Cape Three Points license. The well found 245 net ft (75 m) of pay in two Turonian intervals. The well was drilledto TD of 15,420 ft (4,700 m) in 8,245 ft (2,513 m) water depth. Thewell was side tracked to get bypass cores and is being suspended.

Pecan-1 is the company’s fifth discovery on the block and follows the

previously announced discoveries at Almond, Beech, Hickory North, andParadise. The company next plans to drill the Cob prospect, located ap-proximately 15 mi (24 km) northeast of the Pecan-1 discovery. Hess holds90% interest and the Ghana National Petroleum Corp. holds 10% interest.

AngolaDevelopments are ramping up off Angola. Chevron will go ahead

with the development of Lianzi field between the Republic of Congoand the Republic of Angola. Located 65 mi (105 km) offshore in approx-imately 3,000 ft (900 m) of water, Lianzi will be developed via a tiebackto the Benguela-Belize Lobito-Tomboco platform in Angola block 14.

The $2-billion development will include a subsea production sys-tem and a 27-mi (43-km) electrically heated flowline, the first of itskind at this water depth. First oil is expected in 2015. Once complet-ed, the project is expected to produce a maximum of 46,000 boe/d.

Subsea 7 has received two contracts for the Chevron OverseasCongo Ltd.-operated project. The more recent is a $150-million en-gineering, procurement, construction, and installation (EPCI) top-side contract awarded in December 2012 that includes provision of a

Jessica TippeeAssistant Editor

Production from the Jubilee field offshore Ghana is more than 90,000 b/d.

(Image courtesy Tullow Oil).

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200-metric ton (220-ton) module housing a high-voltage generatingsystem for the new subsea direct electrically heated pipeline cable;an 80-metric ton (88-ton) flow meter deck extension; and variousupgrades on the platform.

Fabrication will be performed in both Republic of Congo andAngola by Subsea 7’s Angolan joint venture. All flowlines will bespooled to the rigid reel-lay ship the Seven Oceans at the company’sLuanda base in Angola. Offshore work including installation, hook-up, and commissioning is scheduled for 2Q 2014.

The second is a reported $600-million EPCI contract for a subseaumbilical, riser, and flowline that includes a 12-in. wet insulated pro-duction flowline with direct electrical heating.

GE Oil & Gas received a $165-million contract to supply subsea pro-duction equipment to the project. The company will supply seven trees,nine subsea control modules, topside and subsea controls distributionequipment, and vertical connection systems. Completion of the firsttree is scheduled for 4Q 2013.

Chevron has a 31.25% interest in the Lianzi field along with Total(36.75%), Eni (10%), Sonangol (10%), SNPC (the Republic of CongoNational Oil Co., 7.5%), and Galp (4.5%).

Cabinda Gulf Oil Co. (CABGOC) has contracted WorleyParsons An-gola and INTECSEA for front-end engineering and design of subseafacilities for the Lucapa field in Angola’s block 14. The scheme calls forwater injection wells and production wells with artificial lift tied backto an FPSO.

Lucapa is on the north rim of the Congo River Canyon in 3,000-6,000ft (910-1,830 m) of water. The Lucapa development is a joint venture be-tween Chevron, Sonangol, ENI, Total, and Galp. Discovered in 2007, theLucapa-1 well was drilled in 1,201 m (3,940 ft) of water to a TVD of 3,340m (10,958 ft) and encountered more than 85 m (279 ft) of oil in Miocene

sands. The well tested 24° API oil from a highly permeable sand.CABGOC awarded Saipem an EPCI contract for the Congo River

Crossing Pipeline project, to be developed offshore Angola andthe Democratic Republic of Congo. The scope includes three sub-sea pipelines, 20 and 22 in. (51 and 56 cm) in diameter, with a totallength of 110 km (68 mi), in water depths up to 117 m (384 ft). Addi-tionally, the company will install subsea spools, and perform trench-ing and crossing works. The pipelay vessel Castoro 7 will undertakethe marine activities between 4Q 2012 and 4Q 2013.

Total E&P Angola has awarded Saipem an EPCI contract for theGirRI (Girassol Resources Initiatives) project offshore Angola. Thecompany will be responsible for topside modifications for multi-phase pump systems on the Girassol and Dalia FPSOs.

NigeriaConocoPhillips has agreed to sell its Nigerian business unit for

$1.79 billion plus customary adjustments. The transaction is antici-pated to close by mid-2013. The sale to Oando PLC includes two off-

Plan to attend Offshore West AfricaOffshore West Africa, the region’s premier technical forum

for the offshore oil and gas industry, will return to Accra,Ghana, March 19-21.

Under the theme “Deepwater Discoveries, Emerging Opportu-nities,” the 17th annual edition will deliver the latest technologi-cal advancements, solutions, and lessons learned from leadingindustry professionals for the West African offshore oil and gasmarket through a comprehensive two-track technical programand three‐day exhibition.

Conference presentation topics include subsea technology, wellconstruction and drilling operations, field development, floatingproduction systems, flowlines and pipelines, geosciences, assetintegrity, safety and environmental concerns, and local content.

Ghana’s Honorable Minister of Energy Dr. Joe Oteng-Adjei hasconfirmed patronage for the event and has been invited to deliverthe keynote address at the opening plenary at the InternationalConference Center.

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shore properties consisting of 95% operatedinterest in OML 131 (Chota field) and 20%non-operated interest in OPL 214 (Uge field).

Total has sold its 20% contractor interest inNigeria’s Usan field on OML 138 offshore blockto China Petrochemical Corp. for $2.5 billion.The Nigerian National Petroleum Corp. is theOML 138 concession holder. Other partnersinclude Chevron Petroleum Nigeria Ltd. (30%),Esso E&P Nigeria (Offshore East) Ltd. (30%),and Nexen Petroleum Nigeria Ltd. (20%).

First production from Usan began in Feb-ruary 2012. The development consists of 42 development wells (23 producing and 19 wa-ter and gas injectors) connected by subseaflowlines to the FPSO Usan, one of the larg-est in the world.

Afren has relocated the jackup Adriatic IX

to the Ebok field to drill of a development wellto establish early production from the recentEbok north fault block (Ebok NFB) discov-ery via existing facilities. The results are ex-pected to provide production and reservoirdata for a full-field development solution. Thepartners plan to install a new 12-slot wellheadsupport structure and mobile offshore pro-duction unit that will be tied back to the exist-ing Ebok FSO. Oil in place at Ebok NFB couldbe more than 100 MMbbl.

Processing has been completed of a 348-sqkm (134-sq mi) ocean-bottom cable 3D seismicsurvey acquired in 2011 over the entire Ebok/Okwok/OML 115 area. The new data is assist-ing an exploration and appraisal program to testupside potential and submission of a field devel-opment plan to the Nigerian authorities. Themost likely scenario for Okwok is a dedicatedproduction processing platform tied back to, andsharing, the Ebok FSO, 13 km (8 mi) to the west.

GabonHarvest Natural Resources Inc. has encoun-

tered oil in the wildcat well Dussafu TortueMarin-1 (DTM-1) drilled in the Dussafu MarinPSC offshore Gabon.

Drilled with the Saipem Scarabeo 3 semisub-mersible drilling rig in 380 ft (116 m) of water,the DTM-1 well has reached a vertical depth of11,260 ft (3,432 m) within the Dentale forma-tion. Log and pressure data indicate approxi-mately 42 ft (12 m) of pay in a 72-ft (22-m) oilcolumn within the Gamba formation and 123 ft(37 m) of pay in stacked reservoirs within theDentale formation. The company plans addi-tional evaluation including fluid sampling anda side track to appraise Dentale sands and thelateral extent of the Gamba reservoir.

Harvest operates the Dussafu PSC with a66.667% interest and Panoro Energy holdsthe remainder.

CameroonPetrofac and Bowleven plan a strategic alliance

for the proposed development of the Etinde per-

mit offshore Cameroon. Bowleven has submit-ted the formal Etinde Exploitation AuthorizationApplication (EEAA) to the Cameroon authorities.The joint venture is targeting a final investmentdecision during the second half of 2013.

Equatorial GuineaThe Alen field development in block I offshore

Equatorial Guinea is on track for first productionduring the second half of 2013, according to part-ner PA Resources.

The Noble Energy-operated Alen, formerlyknown as Belinda, is a liquid-rich gas/con-densate discovery in the Douala basin. Initialdevelopment will include three productionwells and three subsea gas injectors tied to aprocessing platform. Produced condensatewill be separated and piped to the Aseng FPSOon block I, 15 mi (24 km) to the south. Alen’sproduced gas will be re-injected into the res-ervoir to maintain pressure and maximize liq-uids recovery. �

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G E O L O G Y & G E O P H Y S I C S

4D seismic, seabed monitoring

growing in importanceBetter survey data, reservoir simulation drive application

The expense of frontier exploration in deeper waters and ar-eas with little infrastructure, and the value of residual oil inexisting fields, are among the drivers of seismic technologydevelopment. The increasing acceptance and application of4D seismic techniques in both exploration and production in-

dicates that time-lapse 3D exploration and reservoir monitoring arecoming of age as tools to de-risk drilling and to maximize the returnon investment of field development.

Application of the technology is not new; neither is it typical.A number of 4D seismic projects have been conducted and areplanned in a variety of locales. The North Sea, particularly Statoil-operated production, and offshore Africa are two active areas for 4Dseismic work.

In the North Sea, a full-scale permanent reservoir monitoringprogram is in Ekofisk field. The CGGVeritas installation covers 60sq km (23 sq mi) in 70 m (230 ft) of water using 200 km (124 mi)of seismic cables trenched to a depth of 1 m (3.2 ft) with surveysrepeated twice a year.

The North Sea has seen some longer-term 4D projects. Statoilis one North Sea operator which has taken 4D to new levels andthe company says it has moved from qualitative to quantitative time-lapse seismic to produce saturation maps of reservoirs.

Most recently, Statoil hired Reef Subsea Norway to install a seis-mic system on the Grane field on the Norwegian continental shelf.The work scope covers installation of a permanent reservoir moni-toring system. Current plans are to install and bury 200 km (124 mi)of seismic cables with a receiver to cover about 50 sq km (19 sq mi)in 130 m (426 ft) water depth. The purpose of the monitoring systemis to increase the recovery of heavy oil from the field. Installationis scheduled to take about 100 days in 2014. Engineering already isunder way at Reef Subsea’s Bergen, Norway, office.

Statoil’s quantitative work integrates data from seismic, coring,downhole in wells, production, and simulation. It proved valuable inimproving recovery from Statfjord and is being done for Gullfaks.Statoil’s next step is to link the 4D seismic results to flow simulationto improve forecasts of reservoir behavior.

In an earlier instance, injection of CO2 into a saltwater-saturatedsand was monitored for five years. The ability to model future res-ervoir characteristics and fluid contacts based on 4D experienceproved a useful reservoir management method.

Total Exploration & Production Angola signed in 2Q 2012 a five-year-long contract with CGGVeritas to process and image 4D seis-mic data offshore Angola across five deepwater fields. This follows4D acquisition, data processing, and reservoir characterization doneby CGG for Total in the same area during the past several years. Incombination, the fields to be covered, Girassol/Jasmin, Rosa, Dalia/

Camelia, Pazflor, and CLOV, cover about 2,300 sq mi (6,000 sq km).The services under the contract include acquisition and interpreta-tion of fasttrack, base, and monitoring data.

Bowleven had ocean-bottom cable 4D seismic across parts of theEtinde permit offshore Cameroon, covering the IE and IF fields andresulting in improved imaging through the IF’s gas chimney and theIE’s volcanic carapace. That data was fed back into an existing dy-namic field model to help define locations for subsequent appraisaldrilling. The operator and partners expect to make a final invest-ment decision in the first half of this year and get first productionin 2016.

RXT has done seabed seismic acquisition offshore Nigeria for avariety of operators using cables fixed on the seafloor and holding ahydrophone and set of geophones. RXT says its experience showsthat 4D acquires both compression data and converted shear wavedata volumes.

PGS has installed the first permanent seabed seismic monitor-

Gene KliewerHouston

This shows how 4D can be used to examine reservoir performance over

time and indicate changes in fluid dynamics. Courtesy CGGVeritas.

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ing system in waters deeper than 1,000 m(3,280 ft) offshore Brazil in Jubarte field forPetrobras. Using PGS’ Optoseis fi ber-opticsystem, the seabed installation consistsof 35 km (22 mi) of sensor cable and 700four-component sensors. In 3Q 2012, PGSand Petrobras celebrated completion of theproject as the largest-ever 4D acquisition.Over a period of 45 months, PGS’ Ramform

Sovereign sailed the equivalent of 3½ timesaround the equator. Fourteen cables, each8,100-m (26,568-ft) long studded with elec-tronics were towed in formation, 50 m (164ft) apart for a total of 113,400 m (3731,952ft) of streamer cables. The array was in thewater continuously for 9½ months.

PGS predicts it could have as many as2,200 km (1,367 mi) of permanent reservoirmonitoring sensor cables installed by 2015.

The Oil and Natural Gas Corp. Ltd. of Indiahas notified SeaBird Exploration PLC of anaward for a 4C-3D Seismic API Pilot Project inMumbai High field offshore India. The data isto be used by ONGC for planning placementof two development wells. The project calledfor the Hugin Explorer and Munin Explorer todeploy more than 2,300 ocean bottom nodesat intervals of 200 m (656 ft) for data acquisi-tion. Acquisition will be in two swaths by roll-

ing phases of 760 nodes each. The contractis valued at $40 million and the duration isestimated at 110 days.

Value of 4DThe value of 4D seismic when properly

applied continues to grow. New acquisi-tion techniques, processing advances, andpractices are the reasons for the technologygaining value. The growth from qualitativetool to quantitative reservoir managementtool has come over a short time span, too.

Simply stated, 4D seismic adds the ele-ment of time to the traditional 3D seismicacquisition regime. In short, while 3D is asnapshot, 4D is a movie. This ability to “see”into the reservoir over time is what has ledto monitoring reservoir structure duringproduction and has resulted in the potentialto identify depleted or untapped zones. Theideal 4D survey exactly tracks the trail ofa baseline survey in order to make the re-sults as exactly comparable as possible. Itis this comparison of results that generatesa simulation of how a reservoir is acting.This repetition can be achieved in two ways.Careful planning, multi-vessel operations,and streamer steering work with towed ap-plications. The other method is permanent

seabed installation of sensors. The mass ofdata produced is made even more valuableby modern interpretation methods.

The specific advantages depend upon thedevelopment stage of a field. The benefitsrange from more successful well siting toshortening the time to production to extend-ing the producing life of the field.

At the front end, 4D can help place a newwell in the optimal spot by indicating howthe reservoir is likely to perform. It also canstretch the production time between initialcompletion and uneconomical water satura-tion. In a field under development drilling,an eye on 4D data can help determine howthe reservoir is acting to improve the place-ment of each successive well. It also can help in tapping productive partitions withina field that otherwise would not flow.

In older fields, 4D seismic can help locateunproduced hydrocarbons. Assessment ofthe remaining hydrocarbons can determineif additional drilling is cost-effi cient. Locat-ing fluid fronts in older fields can alert theoperator to expected breakthroughs.

Another interesting benefit that can comefrom a 4D program lies in providing a way toadjust a 3D reservoir model during produc-tion. This can be used to validate the model

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algorithm itself for future applications, aswell as to fine-tune the model of the reser-voir under study. The technology is dynamicand gives a spatial indication of fluid move-ment that can be used in the generation offlow properties to de-risk many reservoirs.

Even though 4D has been used for a de-cade or more, recent advancements make itmore informative. The technology still hasto contend with many of the factors that in-fluence the usability of most other seismictechniques, such as towed-streamer noise,water current changes, metocean influences,limited access due to existing structures, andremote locations. The use of permanent in-stallations ameliorates many of these and alsoobviates the need for exact retracing of thestreamers over the previous survey patterns.

Survey pattern is now an object for re-search and development, too. One exampleis the use of improved streamer controls toduplicate a previous survey pattern. Positionaccuracy and calibration of both the receiverand source are necessary for towed-stream-er 4D. Permanent instrument installationsmake the receiver position question moot.

Integrating 4D seismic with well logging and production data has shown that it is pos-sible to monitor effectively the movement of

fluids over time.Analysis can differentiate between drained

portions of a reservoir and portions retainingfluids to identify remaining potential produc-tion and map reservoirs with fault-boundedproduction strata.

R&D advancesAs 4D becomes more popular, and more

economically feasible, research and devel-opment into tools, techniques, and technol-ogy also advance.

One major area of work involves the useof fiber optics to get better data faster. Fiberoptics has several advantages for subsea use.For one, the number of channels per fiber ishigh, making more data points possible witha smaller and lighter weight umbilical thanis otherwise possible for comparable data re-turns. No electricity is needed at the sensor ina fiber-optic system, removing one power de-mand and potential hazard. All the electronicscan be at the surface rather than underwater,enhancing dependability and instrument life.

Suppliers are bringing other new toolsto the field. ION Geophysical Corp. hasreleased a redeployable seabed seismic ac-quisition system that also can operate at agreater water depth than before, as much

as 2,000 m (6,560 ft). ION says the system,dubbed Calypso, can handle any number of longer-length cables and with better produc-tivity. In addition to the added depth capabil-ity, ION’s microelectromechanical system(MEMS) based sensors can populate thecable with as many as 480 sensors per array.Continuous recording can be done in a buoyat the surface to eliminate the requirementof a recording vessel.

Petroleum Geo-Services and SeaBird Ex-ploration are cooperating to develop deep-water ocean-bottom node technology.

CGGVeritas has more than 1,000 ocean-bottom node units and has a proprietarysystem for ROV deployment and recoverythat can be used under platforms or otherinfrastructure.

TGS-NOPEC’s Stingray Systems is work-ing on a fiber optic sensor array capable ofseismic and microseismic measurementsfrom a permanent installation in 3,000 m(9,840 ft) water depth. Stingray is working with Atlas Elektronik UK, VerdErg Connec-tors, and the Optoelectronics Research Cen-ter at the University of Southampton. Sting-ray says it has delivered signals as far as 500 km (311 mi). This FosarDeep system is due on the market shortly. �

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D R I L L I N G & C O M P L E T I O N

Production optimization:

A question with many answersShort cuts now can raise costs later

As the offshore oil and gas industry seeks to make efficientuse of its resources, engineers seek to optimize hydrocarbonproduction. The fact is, optimized production means differ-ent things to different companies. For some it is maximumrecovery factor, for others it is maximum rate of return, but

for most it is return on capital employed. Just as there is no singleproduct that can guarantee self-optimization, there is no one thingthat can deliver production optimization.

This is not to disparage the hundreds of products, treatments, andtechniques that improve one or more facets of production. It is topoint out the well-known but little understood fact that the state of optimization varies from company to company and the cures for sub-optimal performance vary as well. There is no magic elixir.

A great part of the problem is that many operators fail to defineoptimized production as an achievable goal with measureable pa-rameters. As a result, many drilling and completion plans omit criti-

cal measurements or services that impact subsequent production.Some take short cuts motivated by the desire to cut costs that resultin much higher costs later in the completion or production phaseof their wells. Others make fatal errors during well planning thatprevent the well from ever achieving its potential.

An easy-to-assimilate example is provided by the drillers of ex-tended-reach wells. When asked to describe the most critical part ofthe operation, they refer to the construction of the vertical sectionand the build section. “Make a millimeter mistake in the surfacehole trajectory and it may cost you a mile in reaching the target,”they say. The same analogy has been described by NASA engineerswho have learned through hard experience that tiny errors madeduring the launch phase translate to huge errors in space. The les-son to be learned is that the more complex the problem is, the great-er the chance that errors will be compounded in the final analysis.

Many have found that modeling complex problems helps themreach optimum solutions with the least risk because modern math-ematical models allow engineers to test theories in advance of imple-mentation to find the approach that yields the best results. Intui-tively, this makes sense because each decision considers the totalityof relevant information available at the time. More importantly, dur-ing the early stages of modeling, one can perform a gap analysis toidentify where more information is needed before proceeding. Thebest problems are not the ones solved, but the ones prevented. Agood model will show where a certain measurement will help solvea critical problem in the completion or production phase, and it willpoint out the critical piece of information that can best be providedby adding a single open-hole log measurement. Those who proceedwithout modeling risk finding out that a key piece of information isrequired that could easily have been acquired earlier before the holewas cased.

This is not to say that all possible logs should be run. It impliesthat modeling helps engineers determine what information will beneeded before the well is placed on production and then determinethe best (least costly and least risky) way to acquire it.

Financial considerations are important. To try to achieve a pro-duction goal at all costs is a fool’s game. Models help engineers cal-culate a well’s production potential, thus providing a measureabletarget objective. Then as different tools, techniques, or services areproposed, the net present value of incremental added productioncan be calculated and compared with the cost of the proposed solu-tion. Previously an onerous task, today these calculations are facili-tated by interactive reservoir models. Since the models themselvesare updated with each new piece of information, their value and ac-curacy increases each day of the project. Many software modelingprograms contain complementary financial programs that performcost/value predictions quickly and consistently, to allow differentproposed solutions to be compared objectively.

Dick GhiselinContributing Editor

HiWAY flow-channel hydraulic fracturing provides high conductivity paths from the forma-

tion to the well with lower proppant and fluid requirements. (Image courtesy Schlumberger).

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Risk has recently loomed as a major fac-tor in all decisions – some more than others.With the cost of a single well intervention inthe Lower Tertiary play in the Gulf of Mex-ico ranging between $30 million and $50million, time spent trying to optimize wellconstruction, completion, and production istime well-spent.

Solutions that have paid offStarting with the well itself, one of the

first things is well placement. Here, one ofthe most reliable techniques is pre-drillingstructure mapping using surface seismic.Over the past few years the quality and ef-ficiency of offshore seismic acquisition hasincreased exponentially. Such techniquesas coil-shooting allow operators to acquirehigh-density, high-quality data in less timeusing fewer boats. Massively parallel seis-mic processing has given operators answersin a fraction of the time previously required.The 3D seismic map is the cornerstone of an accurate reservoir model. Permanentseabed sensor arrays remove many barri-ers to the acquisition of high-quality time-lapse (4D) seismic, which is so valuableduring the production phase. Despite theirperceived high up-front cost, seabed arrays

have proven to quickly pay for themselves insubsequent surveys. One operator was ableto relocate 20 previously-planned wells in anultra-deepwater play that would have been unproductive without the added seismicanalysis. Return on investment in that casealone was more than 30-fold. Breakthroughdevelopments in cross-well tomography areemerging that allow operators to evaluate not only what is in their wells, but what is between them. This can dramatically reducedevelopment risk.

Companies that invest in geosteering have a better chance to place their wells information sweet spots than those who tryto extrapolate log data from a vertical pilothole or an offset well. Early in the devel-opment of geosteering, it became obviousthat huge benefits could be obtained usinglogging-while-drilling boundary mappingtechnology to drill right below the cap rockto access millions of barrels of attic oil thatwould have been left behind. Not only didthe technique keep the wellbore trajectoryin the reservoir, it avoided drilling up intopotentially unstable shales. In drilling thin beds, economic forecasts showed that res-ervoir coverage had to exceed 90% in manycases for the well to be profitable. As has

been documented many times, geosteering provided that capability.

An invaluable help in critical decisionmaking are the Real-Time Operations Cen-ters (RTOC) offered by several servicecompanies. At the RTOC, experienced en-gineers and directional drillers collaboratewith operators’ engineers and geoscientists to assimilate new information streaming infrom the well site and to correlate it withthe current version of the earth model. Thistime and money-saving service enhancesthe quality of, and confidence in, decisionswhere time is a critical factor.

Completion design has taken a giant leapwith the ability to model both the reservoirquality and the completion quality. Then, theinformation can be used to precisely placeperforation clusters for maximum stimula-tion efficiency and subsequently improvedwell performance. And a new channel frac-turing technique involving scientifi c combi-nation of proppant selection, fracture fluiddesign, and pumping schedules has result-ed in completions with production improve-ments ranging from 10% to 40% dependingupon the formation stimulated. In one play,an average of 65% production improvementwas obtained. Additionally, the new tech-

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nique has reduced proppant and water useby 28% and 53%, respectively. As one mightexpect, the key to achieving these resultswas pre-job modeling that enabled a supe-rior treatment design.

Offshore, particularly in deepwater, flowassurance technology plays a key role in sus-tained production. To ensure that the rightkind and amount of flow assurance technol-ogy is deployed, engineers acquire fluid sam-ples and test them to analyze performanceunder reservoir conditions. They measureformation pressure, fluid mobility, and char-acterize formation fluid looking for indica-tions that wax, scale, hydrates, or asphaltenesmight come out of solution to impair produc-tion. Among the solutions are treatments thatcan inhibit the formation of these materials,or alteration of the production environmentto keep produced fluid above the threshold ofthe materials’ precipitation. Similar modelingtechniques provide solutions for sand man-agement, conformance, and corrosion. Thebetter the problem is understood, the easierit is to design and implement a preventiontechnique.

Prevention is a key word. The cost tosolve a problem can be extreme, but thecosts of preventing the problem from occur-

ring in the first place can be reasonable incomparison.

How to tell a true optimiza-tion tool from snake oil

Without a model or without modeling ca-pability, it is difficult to separate true produc-tion optimization solutions from hyped-upgadgetry. Models help take the subjectivityout of the choices. Models help engineersrelate the benefits of the proposed solutionto the actual problem. Since models can becustomized to fit each operator’s physicaland financial constraints, they can give anappropriate answer to each user. The samesolution may differ from operator to opera-tor, from play to play, even from well to wellin its ability to affect ultimate productivity.Depending upon the operator’s business strategy, “optimal” may mean long life, or itmay mean high initial rate, or it may meanlow operating cost. In any case, the choicesshould never be the result of a wild guess.Without a viable model to put everythingin perspective, the result of key decisionscould be as random as the guesses.

Some may think that service and tech-nology suppliers are just trying to sell theirproducts, and they are, but among those

products are ones that can turn a well intoa significant success. Over the years, themost consistent success stories are told bythose who have made informed decisionsto take advantage of appropriate technologyto improve their return on invested capital.They are the ones that have taken the timeto study objectively the situation at hand, thepotential barriers to a successful comple-tion, the probability that a certain solutionwill improve productivity, and its cost. Onlywhen positive benefits are indicated shouldthe proposed solution be implemented.

Walk down the aisle of your local phar-macy. You will see dozens of remedies fordozens of ailments. Most likely only one or two are appropriate for your specific ailmentgiven your personal condition, allergies, andbudget. Your physician has built a “model”of your health status and is best equipped to help you find the best, most effective cure.Fortunately, the type of cough medicineyou choose is rarely a life or death decision.However, when you encounter a decisionthat could mean the life or death of yourcompany’s multi-million dollar investment,you may want to take a hard look at eachproposed cure before you decide to apply itto optimize your production. �

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ENGINEER ING, CONSTRUCT ION, & INSTALLAT ION

Finland yard maintains

leadership in GoM spar hulls

Of the 17 spar platforms in service to-day, 12 incorporate hulls built at Tech-nip’s specialized construction yard inPori, western Finland. Another hull isabout to be delivered to Anadarko, the

leading advocate of deepwater spars, for theLucius project in the Gulf of Mexico.

Anadarko currently operates fi ve sparson fields in the GoM, all assembled inPori. Work has started at the Pori facilityon Anadarko’s eighth spar, which will befor the Heidelberg field. And over the nextfew years capacity could be tight, with BPcontracting more spars under a frameworkagreement for its next wave of deepwaterGoM projects.

The yard, now known as Technip OffshoreFinland, was established in 1972 as Rauma-Repola, initially to assemble nuclear powerplant modules. During the following decadeit branched out into construction and con-version of drilling jackups, starting with theSahalinskaja, delivered in 1985. “Many of theoriginal team from that era are still in place,”said General Manager Roland Bianciotto.

Rauma-Repola’s offshore division had areputation for innovation, and in the early1990s management decided to reposition theyard for the new types of structures requiredfor deepwater production. It won the contractto build the hull for the world’s first spar forthe Neptune field in the Gulf of Mexico, op-erated at the time by Oryx Energy, and hasdominated the market since. Technip has alsocollaborated on two other spars, one built onthe US Gulf Coast and the other in Malaysiafor Murphy’s Kikeh project.

The Pori yard became part of the Technipgroup with the acquisition of Coflexip in 2001.Technip has since upgraded the site and as-sembly areas to handle simultaneous con-struction of two or even three spars. Facilitiesnow include a 51,050-sq m (549,497-sq ft) cov-ered shop on a 110-ha (272-acre) yard; threemain fabrication workshops; a spar sectionworkshop; two assembly and launch lines; anoutfitting quay with gantry crane; a quay withwater depth of 8 m (26 ft) under an assemblycrane, and 11.5 m (38 ft) at assembly/load-outrails; and two heavy load assembly/load-outrails for heavy offshore structures.

Equipment includes machines that can rollsteel plates of up to 180-mm (7-in.) thickness– in Lucius’ case the thickest plates are 100

mm (3.9-in.). In addition, there is an ongoinginvestment to improve the quality of automat-ed welding by developing new techniques,in association with subcontractor Holmings,various Finnish universities, and welding ex-pertise providers such as Kemppi.

Aside from spars, the yard has been usedin recent years to convert Technip’s deepwa-ter construction vessel Apache II. It has alsoproduced subsea structures for projects inthe GoM and offshore West Africa, rangingfrom buoyancy cans for free-standing hybridrisers to suction piles for manifolds. Latterlyit has manufactured components for the GoM Marine Well Containment System.

According to Bianciotto, the location onthe Gulf of Bothnia favors fasttrack assemblyof spar hulls for various reasons. “Sea condi-tions are good. There is no tide in the area,so heavy lifts and load-outs can be done with no concern about stability. And in this partof northern Europe, steel can be procuredwithin three weeks of starting a project,provided by Finnish, German, Dutch, andUK suppliers. This helps the constructionschedule.”

Tom Ayers, VP Offshore Projects, NorthAmerica, added: “At Pori we have never beenlate in delivery of spar contracts. Even withchange orders arising during constructionwe have always been within one month of ourtarget.”

At peak periods the yard typically employs

1,500 personnel, as was the case for the Lu-cius spar, although it can accommodate over2,000, including subcontractors. “We can at-tract a tremendous labor force because ofthe yard’s reputation for safe practice,” Ayerssaid. “Welders working in a hot, tight situationknow that Technip will take care of them.” Be-cause so many of the yard’s contracts are forthe GoM, Technip Offshore Finland reportsdirectly to the business unit managementteam in Houston at Technip North America.However, the 120-strong engineering group inPori also liaises with Technip staff in Paris andKuala Lumpur on projects in other regions,such as Statoil’s Aasta Hansteen spar in theNorwegian Sea, which will be built in SouthKorea under a consortium agreement venturewith Hyundai Heavy Industries.

Spar advantagesAlthough the US GoM is now open to FP-

SOs, spars, and semisubmersible platformsremain the favored choice for most new deep-water projects in the region. According toPhilippe Barril, Technip’s Executive VP andCOO Onshore/Offshore, “the selection ofspar platform depends on the operator’s fielddevelopment requirements. TLPs are restrict-ed beyond certain water depths by the increas-ing weight of their tendons; semisubmersiblescan have large topsides, and are not restrictedby water depths, but in general cannot accom-modate dry trees. Spars have no limitations in

Jeremy BeckmanEditor, Europe

Outdoor assembly of Lucius spar.

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ENGINEER ING, CONSTRUCT ION, & INSTALLAT ION

terms of water depth, and they can supportwet or dry trees and provide product storage,although there are some restrictions in top-sides weight.” For repeat customers such asAnadarko, added Bianciotto, there can be thebenefit of favorable steel prices.

Ayers listed various other advantages interms of safety and operability. “Spars aredesigned to withstand hydrostatic pres-sure, and to support topsides and risers withbuoyancy. The construction incorporatesheave plates that minimize both heave andvertical movement. Truss spars incorporatestrakes and hard tanks that reduce vortex-induced vibration…the low motion levels make spars better suited for steel catenaryrisers in deepwater than other systems.”

Ayers continued: “This is the simplesttype of platform you can operate not on theseabed, taking less than 12 weeks to install,including six days to upend the hull usingthe variable-ballast system that pumps waterin and out of the tanks at the bottom of thestructure. Once installed, spars are uncondi-tionally safe: their center of gravity is belowthe center of buoyancy, so they are alwaysstable, even if a mooring line breaks free.That applies even in typhoons or hurricanes.”

Ayers also noted that spars can supporthigh-pressure risers, which are pulled insidethe tanks. “During production, if there areproblems with high levels of carbon dioxide(CO2) or corrosion affecting the risers, withfatigue likely, spars are the system of choice,due to reduced motions both at the floaterconnection and the seabed touchdown point.”

Assembly processConstruction of spar hulls starts with

assembly of stiffened flat panels, a typicalmethod used in shipbuilding for lightweight structures. The first step involves buildingup sections by laying plates in bending jigsfollowed by in-situ welding of ring girders.The plates are then transferred to a weldingjig where all remaining welds are completed.

Steps 2 and 3 involve assembly of the sec-tions into lower half and upper half ring sec-tions separately, which are then transferredoutdoors for assembly on rails. “RMS towerson either side hydraulically lift the upper sec-tions in the air, and the lower sections ontorollers, which are then skidded underneaththe upper sections for welding together,”Ayers explained. “This process is repeatedseven to eight times. Then we assemble thetruss, heave plates and soft tank: the key isto get the base of the hard tank into positionfor this to happen. After that, we install thepull tubes for the risers and umbilicals.”

When the transportation vessel arrivesin Pori for the transatlantic tow (Dockwise’sMighty Servant will deliver the Lucius spar),the vessel is ballasted down to be levelled

on the quayside with the completed sparstructure. Skidding onto the vessel is a 24-hour operation that involves hydraulic jack-ing over rollers. Dry-tow of the Lucius sparto the Kiewit yard on the GoM coast shouldtake 22 days. “On arrival, the spar will betaken to the quayside, the ship will be de-ballasted, with seafastenings removed andcut from the spar’s outer shell, followed bygrinding and smoothing,” Ayers said. “Wecan measure if the spar has undergone anytwisting during transport.” The spar willthen be floated off and towed to its offshorelocation.

“On arrival, the bottom of the spar isflooded to start the upending process,’ Ayersadded. “Water is poured into the ballast tanksuntil the hull becomes upright. Once vertical,the mooring chains are installed, at whichpoint the structure is storm-safe. Then a flu-idized mixture of iron ore is pumped into thespar’s soft tank, deposited in the place thatgives it correct center of gravity.”

Heerema’s Thialf heavy-lift vessel will in-stall the topsides and the nine-point chain/polyester/chain mooring system. Normallyspar topsides can be set down in a single lift,Ayers said, unless the payload is unusuallylarge, as was the case with BP’s Holsteinspar. A catamaran barge configuration wasused to install Murphy’s Kikeh spar topsidesoffshore Malaysia.

Sixth in lineAnadarko’s existing GoM spars are on the

Boomvang, Constitution, Gunnison, Nansen,and Neptune fields. “Every spar is tailored to itsenvironment and payload,” Ayers pointed out.

The Lucius field, in Keathley Canyon blocks874, 875, 918, and 919, will produce oil and gasthrough a conventional truss spar – the mostcommon choice to date – 650 ft (198 m) longand 110 ft (33.5 m) in diameter, and installed in7,100 ft (2,164 m) of water. The hull, weighingaround 20,000 tons, will support 16,500-ton top-sides, under construction by Kiewit in the US.“This spar has been optimized for performanceof wet-tree risers, with 10 risers connected tothe topsides.” Technip was awarded the con-tract in December 2011, and the hull is due tosail out of Pori in mid-April.

Production capacity will be 80,000 b/d of oiland 450 MMcf/d of associated gas from sixsubsea wells, with start-up slated for 2014. Oilwill be exported via a 145-km (90-mi), 18-in.pipeline to the South Marsh Island area block205 platform, in water depths ranging from7,025 ft (2,141 m) at the outset to 445 ft (135 m)at the reception area. In 2011, Anadarko andits partners Plains E&P, ExxonMobil, ApacheDeepwater, Petrobras, and Eni signed anagreement for the Lucius spar to additionallyprocess gas at some point from the HadrianSouth development, which could involve somemodifications to the topsides.

The Heidelberg facility will also be a trussspar with a similar weight, but for a shallow-er water depth of 1,620 m (5,310 ft). HereTechnip has a letter of intent to start fabri-cation and purchase long-lead items for the hull in advance of project sanction, expectedmid-year. Pori is performing detailed designof the hull and fabrication, with Technip’soperating center in Houston responsible foroverall project management and engineer-ing. The Heidelberg spar will have capacityto produce over 80,000 b/d of oil and 2.3MMcm/d of gas.

In January Statoil submitted a plan for devel-opment and operation of the Aasta Hansteengas/condensate field in the Norwegian Sea.Assuming regulatory approvals, the projectshould move forward this year. This will bethe biggest spar built to date, weighing 40,000tons, and with a length of 645 ft (196 m) and adiameter of 164 ft (50 m). It will also be the firstto incorporate tanks for condensate storage (inthis case 30,000 tons), with electrically operatedelevators for accessing and inspecting differentlevels.

Construction should take 16-18 months.On arrival at the designated Norwegian fjord,the spar will be upended, the topsides floatedon top, and the completed structure towedto the field location. Hyundai will build thisstructure: “There is only so much capacityavailable at Pori,” Ayers said, “and we arecontent to focus this location on deliveringspars to BP over the next 10 years,” Sayerssaid. The first project covered by this Masterservice agreement – currently in the detaileddesign phase – is Big Dog. �

Welding indoors at Pori, Finland.

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P R O D U C T I O N O P E R AT I O N S

Retrofit corrosion protection

offers life extensionCost-effective systems are available,

and modeling improves performance

The task faced by the oil and gas industry to renew some de-cades-old platforms seems formidable. However, the retrofitof a manageable and cost-effective cathodic protection sys-tem is readily achieved when done properly.

With the original cathodic protection systems of manyfixed and floating oil and gas platforms in the North Sea reachingthe end of their designed lives, retrofit corrosion protection systemswill need to be installed over the next few years to allow operators tosafely extend the platforms’ lives. The importance of designing forreliability, integrity and maintenance is clear, and corrosion protec-tion is an essential part of the solution.

Originally, sacrificial anodes were widely used on oil and gasstructures. Some of these are coming to the end of their opera-tional lives and now is the time to consider a replacement system.Engineering analysis has evolved over recent years and now offersopportunities to reduce the cost of protecting vessels and offshorestructures from corrosion, which in turn helps profitability.

Cathodic protection systems provide protection against corrosionof offshore structures. Depending on the application, either activeor passive systems can be used. Active impressed current cathodicprotection (ICCP) systems require anodes to be placed strategicallyon the structure and to be connected to a power supply and controlsystem, which outputs current to suppress the local corrosive gal-vanic cells.

The major advantage of ICCP systems over passive sacrificial anodesis that the higher-driving voltage allows for use of fewer anodes that aremore widely spaced, reducing installation costs. This does have draw-backs, however. The system is more sensitive to local environmentalconditions and more susceptible to over- and under-protection. Its ef-fectiveness also depends on what needs to be protected, whether it isthe jacket structures, vessels, subsea manifolds, or pipelines. Each partprovides its own challenges and requires specific CP design.

Advantages of ICCPSeawater, with its high conductivity, is a perfect medium for

galvanic corrosion – but it is also an ever-changing environment.Consider a vessel which also moves through different environmentsfrom dock to deepwater, and it becomes apparent that careful plan-ning and engineering must be done at the beginning to ensure anICCP system works efficiently and provides complete protection.

The primary function of ICCP is to prevent corrosion of structuressuch as jackets, subsea manifolds, and pipelines that spend their lifein harsh offshore conditions. This leads to savings, as structures re-main protected and reach their designed life span. Safely extending

the lives of offshore structures to allow continued production is acurrent focus in the North Sea. Many existing sacrificial anode sys-tems are nearly consumed, and replacement systems are needed.

The costs incurred to install and maintain offshore structuresare significant. These costs can run into millions of dollars to hirespecialist vessels and trained crews, and can far exceed the develop-ment and upfront costs of an effective corrosion protection system.

ICCP systems, while more expensive than the sacrificial alterna-tive, have fewer components. When installation costs are included,ICCP can become a cheaper alternative to replacing like for like.The lower mass in an ICCP system also places less stress on agingand corroded structures.

Forward planning is essentialA detailed understanding of the area of ocean where a structure

will sit is essential. To prepare for the changes that will take place inthat environment over the lifetime of a structure, careful modelingand verification must take place. Understanding the complexities ofa subsea environment and the intricacies of corrosion mechanisms

James HortonFrazer-Nash

Modeling of cathodic protection designs helps insure the system is effec-

tive now and into the future.

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In the case of the North Sea, industry must embrace modeling

and verifi cation of cathodic protection systems if it is to ensure

that its structures, pipelines, and vessels successfully and

safely reach and even exceed their designed lives.

P R O D U C T I O N O P E R AT I O N S

enables facilities to be better protected because informed decisionscan be made and forward planning can ensure the systems work ef-fectively to protect the structures enough, but not too much.

The corrosion protection system must be flexible and able to providechanging outputs to match changing environmental conditions. Whileit is important that the structure is fully protected, there is the danger

with ICCP systems that the structure around anodes can be overpro-tected, leading to hydrogen embrittlement and coating disbondment.

The main factors affecting seawater conductivity are tempera-ture and salinity, and these change on a seasonal basis. The per-formance of corrosion protection systems is highly non-linear, soit is not simple to predict accurately performance changes over theseasons. The conditions must be modeled to correctly gauge thechanges due to environmental factors and to determine how the sys-tem should be configured to generate the required protection levels.

ICCP systems include a feedback loop to measure the protec-tion levels at certain points across the structure. This indicates anychanges to output that need to be made to accommodate any season-al variations. However, just because an ICCP system indicates thestructure is protected at a few points, that is not sufficient to assumethe structure is completely protected. So, even with feedback, it is

probable that as the environmental conditions change the distribu-tion of protection across the structure will change, too.

Detailed modeling is used to develop CP system designs to verifythat they provide complete protection in all conditions through thechanging seasons and to predict how the required current outputchanges over the year. This has shown that some layouts are very

sensitive to environmental conditions and are not suitable for provid-ing compete protection year round.

If the changes in condition go undetected, the structure can be ex-posed to both over- and under-protection. This leads to corrosion thatreduces structural integrity and damages coatings, exposing moremetal to sea water and exacerbating corrosion. The result is increasedmaintenance, reduced structure life, and potentially large financial loss-es. It is therefore extremely important to understand the environmentaround your structure and plan to protect it accordingly.

Over and underIn addition to the environmental changes, there are also physical

differences that must be considered. For example, it is not enoughto say that a certain amount of ICCP current will be sufficient forall pipelines. Some pipelines may be laid under the seabed, others

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Solutionson top of the seabed with debris holding them in place, while othersmay be fixed in place with steel structures. Therefore, not only mustthe environmental factors be considered; it is imperative to under-stand the implications of how the pipeline is laid.

Oil and gas structures are complex, with different metals comingin contact at various points, such as where valves are positioned andinteractions with mooring chains. There is also the exposure to air inthe splash zone. Modeling and verification can consider each of thesepoints to ensure the correct level of protection is available at all times.

An overall protectorICCP works with other corrosion protection systems to ensure good

levels of protection. Anti-corrosion coatings, for example, have improvedin recent years; some very good options are available that are imperme-able and isolate the steel structure from the seawater. Anti-corrosioncoatings, however, are susceptible to damage from a number of sources,including bio-fouling, impact damage, sand-scouring, and overprotectionfrom ICCP systems. ICCP systems can help protect an exposed area ofthe structure where the coating is damaged, and can increase the protec-tion as more coating is damaged over the life of the structure.

ICCP modeling includes predicting the effects of damage to anti-corrosion coatings on structure-wide protection. This may meanthat at the beginning of the life of a jacket with a new anti-corrosioncoating only a small ICCP current is required, whereas 20 years lat-er, when more damage has been sustained to the coating, the ICCPcurrents will need to be increased to ensure optimum protection.

In the case of the North Sea, industry must embrace modelingand verification of cathodic protection systems if it is to ensure thatits structures, pipelines, and vessels successfully and safely reachand even exceed their designed lives. �

Modeling can be done on most types of offshore structures, including this

monopole installation.

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S U B S E A

Industry advances subsea

capping technologyEquipment being staged in active drilling regions

Gene KliewerHouston

Industry and government responses tothe Deepwater Horizon blowout and subse-quent oil spill continue to evolve aroundthe world even as the legal issues con-tinue to be addressed in the courts.

On the regulatory front, for example,Standards Norway this past month issuedrevisions to the NORSOK Standard D-010Well Integrity in Drilling and Well Opera-tions that incorporate 450 changes, mostof them coming via the Norwegian Oil andGas Association report on Macondo. In par-ticular, the standards for well barriers are re-drawn. The revision final release is targetedfor June 2013.

In the Gulf of Mexico outside US waters,Pemex and BP have agreed to share tech-nical information on deepwater well cap-ping equipment. By the agreement, BP will provide technical information on building aglobal deepwater capping device for Pemexto use in addition to Pemex’s own scheme.BP also will hold workshops for Pemex todiscuss the equipment and to introduce to Pemex the equipment and service suppliersinvolved.

BP’s global deepwater well capping sys-tem is a 100-ton stack rated to 15,000 psithat can operate in 10,000 ft (3,048 m) waterdepth.

Offshore Alaska, Shell and the US Bureauof Safety and Environmental Enforcement(BSEE) are at work on a system designedfor arctic metocean use. Shell successfullydeployed and tested its emergency stack toBSEE’s satisfaction in 200 ft (61 m) of waterin Puget Sound. However, the containmentdome was damaged in handling, which de-layed Shell’s 2012-2013 exploratory drillingplans. While awaiting repair and testing,Shell is drilling topholes in anticipation of returning to those wells at a later date.

Meanwhile, the US Department of the In-terior has started an assessment of the 2012offshore drilling in the Beaufort and Chukchiseas. The assessment will include a look atShell’s safety management system, oversightof contractors, and ability to meet the standardsin place for Arctic operations. The review willexamine practices and lessons learned, plusidentify challenges going forward.

Part of the study will include investiga-tion into Shell Offshore Co.’s problemswith certifying the Arctic Challenger contain-ment vessel, deployment of the containmentdome, and issues with two drilling rigs, the Noble Discoverer and the Kulluk. The Noble

Discoverer had a fire that caused no damageor injury while in port in Alaska. The Kulluk

broke free of its tow and ran aground at Sit-kalidak Island, Alaska. It has since resumedits trip to Seattle, Washington.

In drilling to date offshore Alaska, BSEEhas had oversight of the drilling involvedwith the tophole sections of one well each inthe Chukchi and Beaufort seas.

BSEE also has released a draft Safety Cul-ture Policy Statement regarding offshoreoperators and contractors. The statementgives BSEE’s approach to development ofa safety culture and indicates the bureau’ssafety expectations, but does not contain any

regulatory requirements. The bureau says asafety culture will have the following char-acteristics:

• Leadership safety values and actions• Problem identification and resolution• Personal accountability• Work processes that maintain safety• Continuous learning• A safety-conscious environment where

workers are free to raise concerns• Respectful work environment• Inquiring attitude.In late 2012, BSEE convened its fi rst An-

nual Conference on Domestic and Interna-tional Standards with a stated goal of start-ing productive communications with the APIstandards developers and other standardsorganizations, standards coordinators, andsubject matter experts. Organizations in-vited included not only the API, but also ASME, IADC, the International Organiza-tion for Standardization, the InternationalOil and Gas Producers Association, theInternational Regulators’ Forum, the Cen-ter for Offshore Safety, and various classifi-cation societies. The conference is to be aregular event.

BSEE also has $1.2 million to consider spending on research during 2013 into fivecategories:

• Consolidating existing research andidentifying gaps relating to how differentcrude oils react to response options suchas dispersant, skimming, and burning

• Research into dispersant effectiveness• Temporary storage of recovered oil in

arctic conditions• Recovery operations and remediation in

low light conditions• Assessment of bioremediation versus

dispersants.

Well containment technologyTechnology and equipment directed at

subsea well containment is available from anumber of organizations founded since theDeepwater Horizon event with the purpose ofmeeting regulatory and practical require-ments regarding spill reaction.

The Marine Well Containment Co. isa non-profit organization with Anadarko,

The Shell capping stack system prepares for

test deployment.

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2013 International Conference“The Changing Engineering & Construction Market”

March 18 & 19 * Paris, France

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��Nabal Al-DabalManaging Director, Aramco Overseas Company

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��Mark PetersVice President, Pennwell Publishing

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S U B S E A

Apache, BHP Billiton, BP, Chevron, Cono-coPhillips, ExxonMobil, Hess, Shell, andStatoil as members. It is open to all USGulf of Mexico operators. MWCC capabili-ties include provision of subsea equipmentincluding risers, dispersant and hydraulicmanifolds, and the capping stack itself. Theorganization also meets the BSEE permit-ting requirement that operators have a con-tainment system available by continuouslymaintaining the equipment, generic proce-dures, dispersant stockpile, and supportcontracts necessary for incident response,as well as for capturing lessons learned dur-ing an event. More than 80 drilling permitshave been issued with MWCC support.

This past July, at the request of the USDepartment of Interior and BSEE, MWCCmobilized its containment system and de-ployed the capping stack on a simulated wellin the GoM. The stack was lowered 6,900 ft (2,103 m) subsea, latched onto a simulatedwellhead, and pressure tested to confirm itsability to control a well.

MWCC’s containment capabilities includeplans to cap a well beneath a floating struc-ture, whether TLP or spar.

This year the organization plans to have anexpanded containment system in service tomeet response requirements for a range ofwell designs and equipment, flow rates, andweather conditions. Also, the new systemexpects to accommodate new technologiesas they become available. Further, the ex-panded response system includes a vessel

with 700,000 bbl. Storage capacity and theability to process, store, and offload liquidsto shuttle tankers. A newly fabricated subseacontainment system will be equipped with asuite of adapters and connectors for use onvarious interface points, well designs, andequipment.

The Helix Well Containment Group is an-other entity organized to meet the deepwatersubsea blowout response requirements. TheHelix group was founded following Helix En-ergy Solutions Group’s involvement in theMacondo blowout control operations withits Q4000 intervention vessel. At presentHWCG can work in water depths to 10,000 ftand capture and process as much as 55,000b/d of oil and 95 MMcf/d of gas. It has twocapping stacks in stock, one rated at 10,000psi and the other at 15,000 psi. Members ofthe HWCG include Anadarko, Apache, ATP,BHP Billiton, Century Exploration, CobaltInternational Energy, Deep Gulf Energy, Eni,Energy Resource Technology GOM, Hess,LLOG, Marathon, Marubeni, Murphy Oil,Newfield Exploration, Nexen Petroleum,Noble Energy, Plains Exploration & Produc-tion, Repsol, Statoil, Stone Energy, Walter Oil& Gas, Woodside, and WT Offshore.

Similar devices and services are availableoutside the Gulf of Mexico.

Wild Well Control, already in the emer-gency response field, established its Well-CONTAINED Subsea Containment Solu-tion consisting of contingency planning and response from Source Control Emergency

A graphic representation of the expanded containment system, which will be available from MWCC

in 2013.The expanded system design includes use of modular capture vessels, modified tankers,

existing drillships, and/or extended well test vessels.

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GVA 7500Response Planning to field deployment ofits capping stack. The stack, staged in Ab-erdeen, UK, is designed for 10,000 ft waterdepth. Beyond the capping stack, the sys-tem’s major components include subseadebris clearing, dispersant, hydraulic power unit, and related controls.

Late in 2012, new safety and environmen-tal protection rules were unveiled in theUnited Kingdom. At its core, the new direc-tions are to develop and publish guidanceregarding critical equipment and well man-agement and design. The Department of Energy and Climate Change published guid-ance on how UK continental shelf petroleumlicense holders can demonstrate the fi nan-cial and technical response capability priorto getting a drilling permit. An oversightgroup is charged to supervise the imple-mentation of recommendations that still arebeing handed down and to make sure the re-gime stays appropriate over the long term.Committee members are DECC, the Healthand Safety Executive, and the Maritime andCoastguard Agency.

Oil Spill Prevention and Response Adviso-ry Group has designed a version of the wellcapping hardware that is stored in northeastScotland at Oil Spill Response Ltd.’s base. Itis designed to connect to typical wells in theNorth Sea and west of Shetland using com-mon BOPs and lower marine riser packages.The stack is designed to merge with variouspoints on a subsea stack in water depths be-tween 100 m and 3,048 m (328 ft and 10,000ft). It is capable of handling wells up to 1,034bar (15,000 psi) and temperatures to 121ºC(250ºF), even in the presence of high H2Scontent. The 40-ton device is 7.14 m (23 ft)tall and 3.97 m (13 ft) wide for ease of trans-port. It can flow as much as 75,000 b/d of oil.

Oil Spill Response Ltd. plans to own,store, and maintain four capping stack tool-boxes and two subsea dispersant toolboxeswith storage sites in Norway, Singapore, andSouth Africa. If plans hold, it will add Brazil early this year. The capping stack toolboxeswill contain two full-bore 15,000 psi stacksand two reduced bore 10,000 psi stacks foruse in 3,000 m water depth. OSRL also willhold 5,000 metric tons (5,512 tons) of disper-sant in various spots around the world.

Also this year, OSRL plans to developan Applied Incident Management System course for its members as part of an IncidentCommand System.

OSRL members include about 45 interna-tional oil and gas operators ranging from Ad-dax Petroleum to ONGX to Tullow, and morethan 85 companies as associate members.

Offshore Angola, BP successfully tested adeepwater emergency capping stack devel-oped in conjunction with Subsea 7, Ocean-eering, FMC, and Cameron. �

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P I P E L I N E S & F L O W L I N E S

Subsea wet insulation system

applies solid silicone scienceNew technology can help optimize flow assurance

Subsea oil and gas operations are mov-ing into deeper water and tapping res-ervoirs well below the seafloor. Han-dling production with much higherpressures and hotter temperatures

in cold waters demands balancing risks be-tween capex and opex. Extended equipmentlife and optimized flow are critical. More re-liable, cost-efficient, and lower-risk thermalinsulation is needed to maintain flow in thepipes above the hydrate formation and wax appearance temperatures to prevent block-ages and to provide sufficient no-touch timefor troubleshooting during shutdowns.

Advanced subsea wet insulation systemsbased on solid silicone science may be a via-ble option to syntactic foams or syntactic sili-cones, as well as to wet insulation systemsbased on polyurethane, epoxy, polyether,phenolic, or specialized polymers.

A new engineered thermal insulation solu-tion is being introduced to help meet the flowassurance needs of subsea oil and gas opera-tions. Formulated with silicone expertise, ap-

plication experience, and industry collabora-tion, the proposed advanced technology fromDow Corning Corp. for subsea wet insulationsystems uses a solid silicone, unlike syntac-tic foams or silicone resins that contain glassmicrospheres.

Developed to insulate high-pressure/high-temperature (HP/HT) equipment used in deep-water production infrastructure and tiebacks,the new XTI-1003 RTV Silicone Rubber Insu-lation potentially offers several advantages.Ongoing tests of performance compared toproducer specifications and applicator require-

ments indicate improvements such as: simplic-ity of use; ease of application; increased jointstrength; excellent flexibility; thermal stability;and anticipated gains in field performance, reli-ability, and service life.

Solid silicone scienceThe company’s new product, the XTI-1003

RTV Silicone Rubber Insulation system, is atwo-part, high-strength silicone rubber forsubsea wet insulation. It is designed to assist inproviding more reliability, added cost-efficien-cy, and reduced performance risks in harshsubsea environments. The non-syntactic tech-nology does not use glass microspheres whileemphasizing joint strength and resistance toextreme pressures.

Based on room-temperature-curing (RTV),liquid silicone rubber (LSR) elastomer is easyto mix and apply. It cures to a durable, flexible,translucent rubber without potentially harm-ful by-products. Projected insulation perfor-mance advantages, as well as coating-applica-tion benefits, are:

• Thermal stability across a wide tem-perature range

• Good insulating properties for longerno-touch times

• Excellent flexibility and resistance tocracking

• Reduced degradation with less poten-tial for water ingress

• Easier processing for curved, straight-line, and flexible sections

• Durable joint integrity with silicone-to-silicone bonding

Brian SwantonDow Corning Corp.

Example of solid silicone insulation application. (Photo courtesy Trelleborg Offshore UK Ltd.)

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• Fast addition-reaction cure in unlimited thickness that can be accelerated with heat.

In providing a simple, yet robust, subsea wet insulation system, XTI-1003 RTV can help opti-mize fl ow assurance and manage risks on HP/HT subsea production architecture from well-heads to tieback components. Potential appli-cations for the new silicone insulation systems could include:

• Wellheads• Subsea trees• Pipeline end manifolds (PLEMs)• Pipeline end terminations (PLETs)• Jumpers and spoolpieces• Sleds• Flowline ends and riser ends• Flange connections.

Performance profi leCompared to the Silastic E RTV silicone rub-

ber used in earlier syntactic thermal insulation systems, XTI-1003 RTV exhibits a number of improvements as a solid silicone wet insulation system. These include advancements in fl exibility, joint bonding, tear strength, and elongation, which show improved high-tempera-ture performance. This non-syntactic silicone rubber also has better resistance to degradation by reducing potential for water ingress at elevated temperatures. This is an advantage compared with syntac-tic insulation, which may have voids from microsphere collapse as a result of subsea pressure.

For deepwater subsea applications, typical wet insulation is mold-ed directly around the equipment with no need for an outer protec-tive jacket. The insulation is exposed directly to the cold seawater on the outer surface, with the inner surface exposed to the high-temperature fl uids fl ow. Critical design parameters are thermal con-ductivity, insulation thickness, and specifi c heat capacity. Primary concerns are resistance to degradation, high-temperature stability, and physical durability in both equipment deployment and saltwater production operations. The silicone rubber insulation exhibits the following physical properties when cured:

• Specifi c gravity: 1.08• Durometer hardness: 40• Tensile strength: 5.5 MPa• Elongation: 400%• Thermal conductivity (dry): 0.196 W/mK• Thermal conductivity (aged, wet): 0.201 W/mK• Specifi c heat capacity at 135°C: 1.79 J/g/°C. In a 45° bonding study during which material was cast over a two-

day period to simulate actual insulation application on subsea equip-ment, excellent silicone-to-silicone bond strength was achieved. This underscores the capability of the new technology to establish strong joint integrity that can withstand deepwater pressures and equipment movement. With the high tensile strength and elonga-tion demonstrated during testing, excellent joint strength in both rigid and fl exible sections is possible.

In testing by an insulation coating specialist in conjunction with an independent lab, the low thermal conductivity of XTI-1003 RTV was verifi ed. Qualifi cation requirements have been met for process temperatures up to 115°C (239ºF), and ongoing testing is expected to certify the technology for applications to 135°C (275ºF) and pos-sibly to 150°C (302ºF) or higher.

Further independent testing under specifi c application conditions has helped verify claims for durability, thermal stability, and excel-lent silicone-to-silicone adhesion. Cured samples of the new solid

silicone insulation were tested for extended intervals, both sub-merged and exposed to elevated temperatures. Performance was documented at 120°C, 135°C and 150°C, and results at the higher temperatures indicated improved performance over silicones used in syntactic systems.

The silicone rubber insulation performed well in simulated ser-vice tests, extended service tests, and arctic conditions testing. Ex-tensive 150°C heat-aging testing also was conducted and is being validated independently with further extended testing.

Simplicity reduces risksEven with its performance during testing, this new silicone rub-

ber insulation still must be applied properly and professionally. Experienced coating specialists are responsible for prescribed ap-plication techniques and procedures. Here, the technology adds a measure of application ease to reduce risks of inadequate adhesion or inconsistent joint integrity.

Typically, the most practical application methods for insulating complex-shaped components with this solid silicone thermal insu-lation system will be cast in place, pre-cast, or bonded to itself on metal components. Since subsea metal components can have vari-ous corrosion coatings, a primer usually is recommended to ensure maximum insulation adhesion.

Supplied as a two-part system, the low-viscosity silicone rubber base and curing agent are mixed in a 10:1 ratio and then pumped into the mold using conventional equipment. Care must be taken to avoid excessive air entrapment, so applicators should fi ll molds from the bottom up and provide suffi cient air vents toward the top of molds.

Once mixed, XTI-1003 RTV has a working time of approximately 90 minutes at a moderate temperature (23°C, or 73ºF). The addition-reaction cure (polymerization) typically requires up to 12 hours at room temperature before demolding, or the material may need to be heated. Curing will accelerate in warmer temperatures. If the in-sulation is being cast in lower temperatures, up to 24 hours may be needed before molds are removed.

Dow Corning is working with insulation coating specialists to establish application processes and quality-control procedures for this technology. Equipment-specifying producers would contract these specialists to meet their equipment thermal insulation require-ments. �

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2013

March 4-8, 2013 | Houston, Texas | www.ceraweek.com

Daniel Akerson Chairman & CEO, General

Motors

Khalid Al-Falih President & CEO, Saudi

Aramco

Motassim Al-Ma’ashouq VP, New Business

Development, Saudi Aramco

Farouk Hussain Al-Zanki Deputy Chairman of the

board of Directors & CEO,

Kuwait Petroleum

Diezani Alison-Madueke Honorable Minister of

Petroleum Resources,

Nigeria

James Baulderstone Vice President Eastern

Australia, Santos

Esperança Bias Minister of Minerals and

Mining, Mozambique

José Maria Botelho de

VasconcelosMinister of Petroleum,

Angola

Clarence Cazalot Chairman, President & CEO,

Marathon Oil

Robert Dudley Group Chief Executive

BP

Anthony Earley Chairman, CEO & President,

PG&E

Bill Gates Chairman, Microsoft, Co-

Chair, Bill & Melinda Gates

Foundation

Harold Hamm Chairman & CEO,

Continental Resources

General Michael Hayden Former Director of the CIA,

Former Director of the NCA

Walter Isaacson President and CEO, The

Aspen Institute, Best-selling

author

Ryan Lance Chairman & CEO,

ConocoPhillips

Fanrong Li CEO & President, CNOOC

Arsenio Mabote Chairman, Instituto Nacional

de Petroleo

Mark Papa Chairman of the Board &

CEO, EOG Resources

James Rogers Chairman, President & CEO,

Duke Energy

Matt Rose Chairman & CEO, BNSF

John Russell President & CEO, CMS

Energy & Consumers Energy

Philippe Sauquet President, Gas & Power,

Total

Frederick Smith Chairman, President & CEO,

FedEx

Michael Spence Nobel Laureate & Professor,

New York University

Dan Wicklum Chief Executive, Canadian

Oil Sands Innovation

Alliance

Steve Williams President & CEO, Suncor

Energy

Mark Williams Downstream Director, Royal

Dutch Shell

Mike Yeager Group Executive and Chief

Executive Petroleum

BHP Billiton

Daniel Yergin Vice Chairman, IHS

Drew Zieglgansberger SVP, Operations Shared

Services, Cenovus Energy

Featured Speakers*:

* As of January 7, 2013 please visit ceraweek.com for a complete list.

Drivers of Change:

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To register please visit

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Expansion of Angoflex showcases

Technip’s umbilical capability in AfricaFactory serves most major projects offshore Angola

Umbilicals are custom designed to meetthe needs of each specific field devel-opment. Traditional designs, includ-ing thermoplastic hoses for hydrauliccontrol and chemical injection, have

mainly been supplied to the UK North Sea.However, as production moved into deeperwaters and extreme environments in the1990s, the market expanded to include steeltube umbilicals. Development of steel tubeservice lines for deeper waters enabled theindustry to operate fields previously inacces-sible to control from the surface.

The umbilicals supplied by Technip forShell’s Perdido development in the Gulf ofMexico are the deepest installed anywhere,at almost 3,000 m (9,842 ft) water depth.More recently, Technip has developed me-dium voltage power technologies for subsea power applications. Another growth area forsteel tube umbilicals has been West Africa,

in particular deepwater Angola. Many of the world’s largest and most complex umbilical systems have been delivered to projects inthis sector.

Track recordIn 2002, in response to increasing de-

mand in the region, Technip and Angolanstate oil company Sonangol EP agreed to build Africa’s first umbilical manufacturingplant, known as Angoflex Ltda. The selectedlocation was Lobito, a port town in Angola’sBenguela province, now a growing hub foroffshore oil and gas activity. The new facilitywas opened in 2004, and has since suppliedsteel tube umbilicals to projects includingDalia, Greater Plutonio, Block 31, TombuaLandana, Lobito Tomboco, Gimboa, Mondo,Batuque, Kissanje East, AB 15, Kizomba,and GIRRI.

The initial investment provided a fully inde-pendent manufacturing facility, with new fac-tory building and offices, steel tube sheathing,helical assembly machine, extruder, processreels, and a Jumbo reel transporter. For manyof its projects, Angoflex works in partnership

with sister companies DUCO in the UK andDUCO Inc. in the US, which can supply umbil-icals in carousels, spooled directly onto instal-lation vessels. One recent example is Total’sPazflor development in block 17.

Technip Umbilical Systems performedumbilical design, manufacture, and projectmanagement for Pazflor. The scope of the

Sarah CridlandTechnip Umbilical Systems

Pazlfor umbilical cross-section.

(Left) Offshore umbilical installation. (Above) Angoflex umbilical manufacturing facility.

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2 Ways to Register for the Webcast:1. Register at http://bit.ly/BPWebcastSeries

2. Register by scanning the QR code below

BP Upstream – Insider InsightsWebcast Series

What You Will Learn:

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• Wednesday 20th March: An introduction to a revitalized

BP Upstream and our Global Projects Organization

• Wednesday 3rd April: An insight into Engineering &

Quality at BP

• Wednesday 17th April: An insight into my career

at BP and the delivery of major projects

Who Should Attend:

• Asset & Project Engineers & Managers

• Deepwater/Subsea Engineers & Managers

• Construction/Commissioning Engineers & Managers

• Projects and Discipline Engineers & Managers

• Quality and HSSE Engineers & Managers

Guest Speakers:

March 20, 2013 | 9:00 am CDT | 2:00 pm GMT

April 3, 2013 | 9:00 am CDT | 2:00 pm GMT

April 17, 2013 | 9:00 am CDT | 2:00 pm GMT

Ryan Malone

Delivery Mgr,Hull & Mooring

Systems, GPO —Mad Dog

Phase 2 Project

March 20th April 3rd April 17th

Ian Cummins

VP Engineering &Quality, GPO

Rob Kelly

VP TechnicalFunctions, GPO

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subsea contract, awarded in 2008, was one of the largest and most complex the company had taken on to date, requiring 33 umbilicals of various types and some of the industry’s most exacting require-ments to date.

Following initial R&D and engineering, performed in Newcastle, UK, Technip Umbilical Systems (TUS) built and tested three proto-types to demonstrate that the proposed design would perform un-der demanding deepwater and dynamic conditions. The umbilicals – dynamics, main statics, production statics, water injection and gas injection – were manufactured by TUS in Angola and in Houston. Delivery and installation followed in 2011, helping Total achieve fi rst oil ahead of schedule.

Gearing up for CLOVIn the same year as the Pazfl or award, Technip and Sonangol ap-

proved a business plan to expand Angofl ex by increasing the capac-ity of its helical assembly machine and adding two large capacity carousels. These would allow umbilicals to be spooled directly to the installation vessel. It would also provide the benefi t of having 100% of umbilicals for local projects manufactured in Angola.

The expanded facility was commissioned in 2012, and is currently working on its fi rst project sourced by 100% local content, for Total’s multi-fi eld CLOV development, again in block 17.

The Cravo, Lirio, Orquidea, and Violeta fi elds are around 150 km (93 mi) from the Angolan coast, in water depths ranging from 1,050-1,400 m (3,445-4,593 ft), and require a total of 34 wells. Angofl ex’s is supplying 75 km (47 mi) of umbilicals, in 28 lengths. The package includes four dynamic production umbilicals (total length 29 km, or 18 mi); six static production umbilicals (total length 16 km/9.9 mi); and 18 water injection umbilicals (total length 30 km/18.6 mi).

Additionally, Angofl ex will provide the pull-in hang-off arrange-ments, bend stiffeners, bend stiffener latching mechanisms, mid-wa-ter arch clamps, subsea termination interfaces, and bend limiters for the dynamic production umbilicals, as well as similar hardware and mud mats for the static production and water injection umbilicals.

The Angofl ex team has grown to include Angolan project manage-ment and engineering support in addition to manufacturing person-nel. It now employs more than 200 staff, and the company achieved two million man-hours without a single lost time incident.

Its strategic position in Angola means that developing markets in

other West African countries and off East Africa are easily accessi-ble. Currently it is working on numerous bids for projects in Angola, both directly to major operators and in partnership with Technip.

Technip in Angola itself has three main activities:• Engineering services through Technip Angola Engenharia Lim-

itada, the country’s fi rst oil and gas engineering company, formed in May 2000 via a partnership between Sonangol (40%) and Tech-nip (60%). It provides engineering and construction services to offshore and downstream oil and gas activities in West Africa, and promotes the group’s subsea capabilities for deepwater develop-ments.

• Umbilical manufacturing with Angofl ex Limitada, created in March 2002, owned 30% by Sonangol EP and 70% by Technip Group.

• A reeled steel pipe spoolbase in Dande, north of Luanda, inaugu-rated in March 2006. This facility manufactures rigid pipelines for reel-lay installation of deepwater oil and gas productions systems. It has a 600-m (1,968-ft) long jetty, with up to 12 m (39 ft) water depth at the bulkheads, allowing large installation vessels to moor and load pipe for offshore developments.Angofl ex is involved in Technip group’s ongoing umbilicals R&D

program, with various technologies under development for increas-ingly challenging environments, deeper waters, and longer tiebacks to offshore facilities and to shore.

The focus is on new types of materials and processes – for exam-ple, high strength or non-metallic strength members that provide stiffness and tensile strength without the additional weight that a conventional helically armored umbilical may have. Also, a move toward high tensile aluminum, away from copper electrical con-ductors, provides a fatigue-resistant load-bearing core for medium voltage cables used in subsea pumping and processing. Addition-ally, umbilical R&D involves enhancing existing components.

For subsea power supply, Technip has developed aluminum con-ductors which provide higher strength and fatigue resistance, reduc-ing operational risk. Other mechanical benefi ts include high corro-sion resistance and lighter weight – the density of aluminum is three times less than copper. The new cable design offers comparable elec-trical performance to copper, while also providing superior mechani-cal capabilities and enhanced long term service reliability. �

Lobito Bay.

Typical deepwater field layout.

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INVESTING IN ASIA’S

ENERGY FUTURE

6–8 MARCH 2013

Kuala Lumpur Convention Centre (KLCC)

Kuala Lumpur, Malaysia

WWW.OFFSHOREASIAEVENT.COM

The annual Offshore Asia Conference & Exhibition remains the leading source

of information on new technology and operating expertise for the Asia-Pacific

region.The three-day conference will explore emerging trends and current

solutions facing the industry in the Asia-Pacific region.

Offshore Asia provides a unique annual forum for the industry – a world-class

technical conference exclusively for the Asia-Pacific offshore market combined

with an exhibition showcasing the latest technologies, products and services.

Ensure your presence at Offshore Asia from 6 to 8 March 2013

in Kuala Lumpur, Malaysia and enhance your business opportunities in

the region.

If you have a SmartPhone, you can also register on

your mobile smartphone by scanning this QR code to

go straight to registration.

Pre-register for the Offshore Asia exhibition online at

www.offshoreasiaevent.com for FastTrack entry

Owned and Produced by: Presented by: Supported by: Supporting Organisations:

REGISTER TODAY!

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http://www.offshoreasiaevent.com






B U S I N E S S B R I E F S


PeopleBaker Hughes has named David Gallagher

vice president, production enhancement. He

will lead the global stimulation strategy for

the Pressure Pumping business. Archana

Deskus has joined the company as chief

information officer.

Secretary of the Interior Ken Salazar has

announced that he intends to leave the depart-

ment by the end of March.

Andrew L. Cochran has joined Coastal En-

ergy as an executive

director and will be

based in London.

Samsung Engineer-

ing has appointed Mi-

chel Lainé as COO of

its newly established

offshore division.

Randall K. Eres-

man has retired as

president and CEO of

Encana Corp. Clayton

H. Woitas has been

appointed interim

president and CEO.

Chevron Corp.

has appointed Maria

Lindenberg as chief

procurement officer.

She succeeds Leo

Lonergan, who has

retired from the com-

pany after 36 years of

service.

Greene’s Energy

Group has appointed

Brad Farnsworth

as CFO, and Maury

Dumba as senior vice

president of business

development.

Noreco has ap-

pointed John Bogen

as COO and vice

president HSE. He

succeeds Ellen San-

dra Bratland.

Jim Martin has

joined RSI as COO. He has more than 30

years in the upstream geology and geophysics

sector, with commercial experience in seismic

data acquisition, pro-

cessing, software and

multi-client business

models.

EPC Offshore has

appointed Jonathan

White as head of busi-

ness development.

MacArtney Inc.

has appointed Scott

Allen as items sales

manager. He will head

the SubConn support team.

Songa Offshore SE has appointed Arnaud

Bobillier and Steven James McTiernan as

independent directors.

ENGTEQ has named Innes Walker as

commercial director, Grant Wallace as busi-

ness development director, Adam Byrne

as operations director, and Simon Hurst as

engineering director.

Chris Edens has joined Offshore Design

Engineering Ltd. as senior projects manager.

SIGMA3 Integrated

Reservoir Solutions

has appointed John

Ughetta as executive

vice president of sales

and business develop-

ment. He will be re-

sponsible for directing

the company’s global

sales initiatives, opera-

tions, and resources.

Ambrey Risk has

named Mick Clifford

as full-time training director.

Nessco Group has appointed Phil Good-

all as business development manager for

MetOcean, the company’s offshore weather

monitoring business.

Timothy J. Nedwed, Ph.D., has received

the Edith and Peter O’Donnell Award for

Technology Innovation for his work in the

development of offshore oil spill response

technologies. Nedwed leads the oil spill

response research program for ExxonMo-

bil Upstream Research Co. in Houston. He

conducts research to develop new oil spill

response technologies and to study oil spill

fate and effects. His primary areas of focus

are in situ burning,

dispersants, and

remote detection.

ITF has named

Patrick O’Brien

as CEO and will

officially begin April

1. He is a recognized

expert in subsea

riser mechanics, riser

design, and flexible

pipe technology.

Majed Abu-Lawi

has joined Camco

Libya as general

manager.

Mentor IMC Group

has appointed Simon

Bonini as group man-

aging director.

UniversalPegasus

International has

named Terry Mienie

as business develop-

ment director UK and

international. He will

be responsible for the

development of the

company’s subsea

market in the UK with

a focus on the North

Sea.

Morningstar has

named Merrill A.

Miller Jr., CEO of

National Oilwell Varco,

as its 2012 CEO of the

Year.

John Fletcher has

been elected vice pres-

ident of the Institute

of Corrosion. He will

serve for two years

and then become

president elect.

Matt Yacavone

has joined Crowley

Maritime Corp. as

vice president of sales

and chartering for the

petroleum services team.

Bill Hart Jr. has joined Mayer Brown as a

partner in the banking and finance practice.

RWE Dea AG has named Dirk Warzecha

as COO.

PIDX International has appointed Christo-

pher H. Carter as CEO.

Helge Eide has stepped down as managing

director of DNO International ASA. Bjørn

Dale has been appointed acting managing

director.

Chris Charman has joined International

Marine Contractors Association as CEO.

Dryad Maritime Intelligence has appointed

David Hunkin as

commercial director.

Robin Clarkson

has been named a

partner at Burness

Paull & Williamsons

LLP.

Anindya Ray has

joined FairfieldNodal

systems sales division

as the regional sales

manager for South and

Lainé

Abu-Lawi

Mienie

Fletcher

Clarkson

Ughetta

O’Brien

Hurst, Walker, Byrne, Wallace

Dumba

Farnsworth

White

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17th Edition Conference & Exhibition

19-21 March 2013International Conference Centre, Accra, Ghana

www.offshorewestafrica.com

Presented by:Owned & Produced by: Supporting Publication: Under Patronage From Republic of

Ghana, Ministry of Energy

DEEPWATER DISCOVERIES

EMERGINGOPPORTUNITIES

INVITATION TO ATTENDThe 17th annual Offshore West Africa Conference & Exhibition will

be held in Accra, Ghana at the International Conference Centre on

19-21 March 2013.

Offshore West Africa is the premier technical forum focused

exclusively on West African offshore exploration and production.

The annual Offshore West Africa Conference and Exhibition

remains the leading source of information on new technology

and operating expertise for this booming deepwater and subsea

��

technology event in the world.

What Offshore West Africa offers:

�� !��

engineers from major and independent E&P companies focusing

��

�� "�� "��

��

improvements in African E&P operations

�� #��

with the expanding African exploration & production activity

REGISTER ONLINE NOW AT WWW.OFFSHOREWESTAFRICA.COM

Follow Offshore Events on:

PRE SHOW GUIDE AVAILABLEREGISTER TODAY AND SAVE WITH OUR EARLY BIRD OFFERRegister before 19 February 2013 and save over 10% on the Individual Conference Fee.

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http://www.offshorewestafrica.com






B U S I N E S S B R I E F S


West Asia, and the southern countries of the

former Soviet Union.

Company NewsRPS has acquired Petroleum Institute

for Continuing Education, a Canadian-

based business that provides geoscience

and engineering training to the oil and gas

industry.

GEDA USA’s Helideck Transport Platform

is the fi rst helideck transport system to be

certifi ed by the DNV.

Italian classifi cation society RINA Group

will support development of Tasneef. The aim

of the new partnership is to develop Tasneef

as an international classifi cation society capa-

ble of meeting the technical and classifi cation

needs of the United Arab Emirates’ maritime

industry, the UAE fl ag, and international com-

mercial shipping.

Aker Offshore Partner has won a fi ve-

year frame agreement to work on Talisman

Sinopec Energy UK’s brownfi eld projects in

the North Sea.

Raytheon Anschütz has launched a

containerized version of its SMARTBLUE

surveillance system. The container solution is

a customizable and ready-to-deploy surveil-

lance system complete with radar, AIS, and a

long-range surveillance camera on a buy or

rental basis for offshore asset protection.

Trelleborg Marine Systems has acquired

Sea Systems Technology Ltd.

Nexen Petroleum UK has awarded Dron

& Dickson a fi ve-year contract to perform

electrical maintenance on the Buzzard and

Scott platforms in the UK central North Sea.

A 16-strong team will handle the program,

including CompEx qualifi ed electrical techni-

cians, and a rope access team.

Bredero Shaw has introduced a packaged

combination of products, expertise, infra-

structure, and services to cover each stage

of an offshore pipeline coating project, from

concept to commissioning.

Maersk Oil UK has contracted Intertek

to provide offshore chemists in the North

Sea and related onshore laboratory analysis.

Services will range from sample gathering

and testing to monitoring process systems

and chemical injection.

Chemical Flooding Technologies has ac-

quired Tracer Technologies International.

The acquisition transfers TTI’s oilfi eld tracer

testing services for waterfl ood optimization

and enhanced oil recovery developments to

CFT’s laboratories in Tulsa, Oklahoma.

Drilling Technological Innovations

has received ISO 9001:2008 certifi cation for

the design, development, manufacture, and

assembly of motion compensation systems,

to include riser tensioner systems for the

offshore oil and gas industry.

Vallourec’s Brazilian subsidiary V & M do

BRASIL and Petrobras have signed a fi ve-

year contract to supply Petrobras’ operations

with premium OCTG products, including

seamless pipes, steel grades, and connections

using state-of-the art technology.

Unique System FZE has launched a new

division – On Site Machine Rental in the UAE.

Shell has relaunched its Technology

Center Houston following an upgrade and

expansion. The center, the largest of the

company’s three technology hubs, has more

than 1 million sq ft (92,903 sq m) of space and

some 2,000 personnel.

Private equity investment fi rm ArcLight

Capital Partners has formed North Sea

Midstream Partners. The new company

targets ownership and commercial develop-

ment of large-scale midstream oil and gas

infrastructure assets in and around the North

Sea.

EXP Engineering International has

been established to offer offshore engineer-

ing, project, and construction management

services.

Newpark Resources has acquired Alli-

ance Drilling Fluids, a provider of drilling

fl uids, proppants, and related services head-

quartered in Midland, Texas.

Momentum Engineering has achieved

ISO 14001:2004 and OHSAS 18001:2007 cer-

tifi cation in relation to environmental, health,

and safety management systems.

Aquaterra Energy has acquired the busi-

ness and assets of Hyco Ltd., a hydraulic

control system supplier.

CSA International Inc. has changed its

name to CSA Ocean Sciences Inc.

Under a three-year global framework

agreement, Allseas has contracted Exova to

provide coatings testing and consultancy ser-

vices, immersion ultrasonic testing, mechani-

cal and failure testing, plus other services to

be added as required.

Noreco Norway AS has become owner

of all the group’s licenses on the Norwegian

continental shelf, and the Norwegian Energy

Co. ASA has discontinued its direct petro-

leum activities.

NCS Survey, an Acteon company, has

opened a second offi ce block at its headquar-

ters in Aberdeen, UK, and new offi ces in Rio

de Janeiro, and Stavanger, Norway.

McDermott International and TH Heavy

Engineering Berhad have entered into a

joint venture – McDermott Sdn Bhd and

TH Fabricators Sdn Bhd – to provide ma-

rine construction services such as engineer-

ing, procurement, construction, installation,

and commissioning solutions to the Malaysian

and Asia/Pacifi c offshore oil and gas industry.

Fendercare Marine has launched a new

division, Fendercare Marine Equipment

and Lifting Services, which is located at its

Great Yarmouth base.

T.D. Williamson has opened its fi rst

Seoul, Korea, offi ce.

Proserv has acquired Total Instru-

mentation & Controls, which specializes

in advanced process and control systems

equipment.

Churchill Drilling Tools has invested

£2.5 million ($4 million) in units adjacent

to its existing Crombie Road premises in

Aberdeen to create a 1.65-acre site, which will

be upgraded over the next three to four years.

The refurbishments will include research and

development facilities, increased capacity for

new product assembly and service lines, and

offi ces.

Damen Shipyards Group has acquired

French ship repair yard Arno Dunkerque.

Aker Solutions has acquired Separa-

tion Specialists Inc., a California-based

provider of produced water de-oiling products

and fi eld services. The company’s product

range includes mechanically induced gas

fl otation, nutshell fi lters/walnut shell fi lters,

ASME tank fabrication and repair, and gravity

separation equipment. Aker Solutions has

also acquired St. John’s, Newfoundland and

Labrador-based AKCS Offshore Partner.

Fincantieri has agreed to acquire 50.75%

in the STX OSV shipyard group from STX

Europe. Assuming the deal closes in 2013,

Finacantieri will have interest in 21 shipyards

across three continents, nearly 20,000 employ-

ees, and revenues of €4 billion ($5.3 billion),

which will double its present size.

ConocoPhillips has agreed to sell its

Nigerian business unit for $1.79 billion plus

customary adjustments. The transaction is

anticipated to close by mid-2013. The sale to

Oando PLC includes two offshore proper-

ties consisting of 95% operated interest in

OML 131 (Chota fi eld) and 20% non-operated

interest in OPL 214 (Uge fi eld). Onshore, the

sale involved a power plant and Brass LNG

project.

T.D. Williamson has opened its new

144,000-sq ft Global Pipeline Integrity Center

in Salt Lake City, Utah.

Reef Subsea has secured a new regional

headquarters in Aberdeen, Scotland. The

company has moved its three main activ-

ity bases into the new premises called Reef

Subsea House.

Eni and PetroVietnam have signed a

memorandum of understanding for the devel-

opment of business opportunities in Vietnam

and abroad.

CSnet International has reached a

service level agreement with Radius Oce-

anic Communications Inc. to connect its

offshore communications backbone to the

POSEIDON system. As an anchor tenant on

POSEIDON, CSnet will be able to provide se-

cure, low-latency broadband oceanographic,

seismic, and metocean data.

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OCTOBER 22-24, 2013 | THE WOODLANDS WATERWAY MARRIOTT HOTEL & CONVENTION CENTER | HOUSTON, TX USA

www.deepoffshoretechnology.com

OWNED & OPERATED BY: PRESENTED BY: HOSTED BY:SUPPORTED BY:

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2 0 1 3 S U B S E A T I E B A C K F O R U M & E X H I B I T I O N

MARCH 5 – 7, 2013Henry B. Gonzalez Convention Center • San Antonio, Texas USA

www.SubseaTiebackForum.com

Imagecourtesyo

f FMC

Technologies

Exhibit space

and sponsorships

still available

Owned & Produced by Supported by Hosted byPresented by

ThursdayLunch Sponsor

BronzeSponsor

SilverSponsor

GoldSponsor

PlatinumSponsor

Wednesday NetworkingReception Sponsor

Hog Heaven Title Sponsor & Show Guide Bellyband Sponsor

Hotel Key CardSponsor

Online RegistrationSponsor

Opening Night NetworkingReception Sponsor

Bottled WaterSponsor

Coffee BreakSponsor

Exhibitor BrandingSponsors

MediaSponsor

SupportingOrganization

Registration Fast Track Sponsor

Wednesday NetworkingBreakfast Sponsor

In recent years, the subsea industry has seen many technological challenges, engineering demands, resource availability issues, Quality

Assurance requirements, manufacturing constraints, and most recently, changes in the governmental regulatory agencies affecting existing

standards and/or processes. The Subsea Tieback Forum & Exhibition will provide information and the opportunity for you to exchange ideas

to address many of these concerns and challenges.

The Subsea Tieback Forum & Exhibition has become the premier event for one of the fastest growing sectors of the oil and gas industry.

Next year’s Subsea Tieback Forum & Exhibition is scheduled for March 5-7, 2013 in San Antonio, TX at the Henry B. Gonzalez Convention

Center. Visit www.subseatiebackforum.com for up-to-date information about the event. You can’t afford to miss it!

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PENNWELL PETROLEUM GROUP1455 West Loop South, Suite 400, Houston, TX 77027

PHONE +1 713 621 9720 • FAX +1 713 963 6228David Davis (Worldwide Sales Manager)

[email protected] Duffy (Regional Sales Manager)

[email protected] Jordan (Classified Sales) [email protected]

GREATER HOUSTON AREA, TXDavid Davis [email protected]

USA • CANADAMitch Duffy [email protected]

WASHINGTON • OREGON • CALIFORNIAMary Sumner [email protected]

UNITED KINGDOM • SCANDINAVIA •THE NETHERLANDS

9 Tarragon Rd.Maidstone, Kent, United Kingdom ME16 OUR

PHONE +44 1622 721222 • FAX +44 1622 721333 Roger Kingswell [email protected]

FRANCE • BELGIUM • PORTUGAL • SPAIN • SOUTH SWITZERLAND • MONACO

• NORTH AFRICAProminter

8 allée des Hérons, 78400 Chatou, France PHONE +33 (0) 1 3071 1119 • FAX +33 (0) 1 3071 1119

Daniel Bernard [email protected]

GERMANY • NORTH SWITZERLAND •AUSTRIA • EASTERN EUROPE •

RUSSIA • FORMER SOVIET UNION • BALTIC• EURASIA

Sicking Industrial Marketing, Kurt-Schumacher-Str. 16 59872 Freienohl, Germany

PHONE +49 (0) 2903 3385 70 • FAX +49 (0) 2903 3385 82 Andreas Sicking [email protected]

ITALYSILVERA MEDIAREP

Viale Monza, 24 - 20127 Milano, ItalyPHONE +39 (02) 28 46716 • FAX +39 (02) 28 93849

Ferruccio Silvera [email protected]

BRAZIL / SOUTH AMERICASmartpublishing Ltd/ OGJLA Pennwell Brazil

HEADQUARTERS: Rua Raimundo Chaves 2182, L5Natal RN 59064-390, BRAZIL

RIO OFFICE: Ave. Erasmo Braga 227, 11th fl oorRio de Janeiro RJ 20024-900, BRAZIL

PHONE +55 (21) 2533 5703 or +55 (21) 3084 5384FAX +55 (21) 2533 4593

Jean-Paul Prates [email protected]

JAPANICS Convention Design, Inc.

6F Chiyoda Bldg., 1-5-18 Sarugakucho Chiyoda-Ku, Tokyo 101-8449, Japan

PHONE +81 3 3219 3641 • FAX +81 3 3219 3628Manami Konishi [email protected]

SINGAPORE19 Tanglin Road #05-20 Tanglin Shopping Center

Singapore 247909 PHONE +65 9616 8080 • FAX +65 6734 0655

Michael Yee [email protected]

INDIAInterads Ltd., A-113, Shivalik, New Delhi 110 017 PHONE +91 11 628 3018 • FAX +91 11 622 8928

Rajan Sharma [email protected]

NIGERIA/WEST AFRICAFlat 8, 3rd fl oor (Oluwatobi House) 71 Allen Ave, Ikeja, Lagos, Nigeria

PHONE +234 805 687 2630 or +234 802 223 2864 Dele Olaoye [email protected]

SALES OFFICES

A

Acteon Group .............................................41www.acteon.com/conductor

Aegion Corporation ...................................10www.aegion.com

Aker Solutions ........................................... 11www.akersolutions.com/subsea

Arnco Technology ......................................42www.hardbanding.com

ASME / UH OTC Crawfish Boil ..................52

Audubon Engineering ...............................40www.audubon-engineering.com

AVEVA Solutions, Ltd. ...............................83www.aveva.com

B

Baker Hughes Incorporated ......................59www.bakerhughes.com

Balmoral Comtec, Ltd. ...............................81www.balmoraloffshore.com

Bluebeam Software, Inc. ...........................35www.bluebeam.com/PDFSolution

Bluefin Robotics Corporation ...................69www.bluefinrobotics.com

Bredero Shaw ........................................12-13brederoshaw.com

C

CERAWeek 2013 .........................................85www.ceraweek.com/2013/

Cameron .....................................................27www.cameronrigsolutions.com

CANSCO .....................................................57www.cansco.com

Chevron ......................................................25chevron.com

CJWinter .....................................................53http://cjwinter.com

Clover Tool Company ................................63www.clovertool.com

CORTEC .....................................................67www.uscortec.com

D

Delmar Systems, Inc. .................................65www.delmarus.com

Delta Rigging & Tools ................................47www.deltarigging.com

Dril-Quip .......................................................9www.dril-quip.com

E

EMAS AMC .................................................19www.emas.com

F

FMC Technologies .................................... C2www.fmctechnologies.com

Forum Energy Technologies .....................55www.f-e-t.com/subsea

G

Greene’s Energy Group .............................37www.GreenesEnergy.com

GVA Consultants AB .................................81www.gvac.se

H

Hardbanding Solutions .............................61www.hardbandingsolutions.com

Harris CapRock ............................................5www.harriscaprock.com

Hornbeck Offshore Services, Inc. ............73www.hornbeckoffshore.com

Human Resources Mexico ........................75www.successmexico.com

HYTORC......................................................43www.hytorc.com

I

INTECSEA ..................................................20www.intecsea.com

K

KOBELCO / Kobe Steel Ltd. ......................45www.kobelcocompressors.com

L

LAGCOE 2013 .............................................77www.lagcoe.com

M

Magnetrol International .............................71www.magnetrol.com

McDermott, Inc. ..........................................15www.mcdermott.com

M-I SWACO ................................................ C4www.miswaco.com/rhadiant

N

National Oilwell Varco. ...............................29www.nov.com

National Oilwell Varco. ...............................49www.nov.com/qualitytubing

Newpark Drilling Fluids. ............................31www.newparkdf.com

Nylacast. .....................................................80www.nylacast.com

O

Oceanic Marine Contractors .....................51www.oceanicmc.com

Offshore TechnologyConference Asia.........................................68

www.otcasia.org/2014

P

PennWellDeep Offshore Technology

Conference & Exhibition ......................93www.deepoffshoretechnology.com

Offshore Asia Conference & Exhibition ...........................................89

www.offshoreasiaevent.comOffshore Group - Webcasts..................87

www.offshore-mag.comOffshore West Africa Conference

& Exhibition ...........................................91www.offshorewestafrica.com

Subsea Tieback Forum & Exhibition ..............................................94

www.subseatiebackforum.com

R

Radoil, Inc.. .................................................39www.radoil.com

Rice University - Rice GlobalEngineering & Construction Forum .........79

www.forum.rice.eduR.M. Young Company. ................................64

www.youngusa.com

S

Sembcorp Marine ......................................17www.sembcorpmarine.com.sg

Siemens AG ................................................23seimens.com/oilandgas

Society of Petroleum Engineers ...............56www.spe.org/go/Offshore

Spir Star, Inc. ..............................................64www.spirstar.com

Superior Energy Services, Inc. .................21www.superiorenergy.com

T

T.D. Williamson .......................................... C3www.tdwilliamson.com

Tendeka ......................................................33www.tendeka.com

TETRA Technologies .................................38www.tetratec.com

The Bayou Companies, LLC .....................10www.bayoucompanies.com

Tiger Offshore Rentals .............................2-3tigeroffshorerentals.com

Transocean ...................................................1www.deepwater.com

W

W&O Supply ...............................................60wosupply.com

Weatherford ..............................................6, 7weatherford.com

Wood Group Mustang ...............................18www.mustangeng.com

The index of page numbers is provided as a ser-vice. The publisher does not assume any liabilityfor error or omission.

ADVERTISERS INDEX

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This page reflects viewpoints on the political, economic, cultural, technological, and environmental issues that shape the future of the petroleum industry. Offshore

Magazine invites you to share your thoughts. Email your Beyond the Horizon manuscript to David Paganie at [email protected].


B E Y O N D T H E H O R I Z O N

As we move into 2013, the future for offshore operations appearsto be very bright. This is especially true for operations in the Gulfof Mexico, where some industry reports anticipate booming capitalexpenditures over the coming years. Thus, from the perspective ofthe multi-national owner, operator or driller, or from that of the in-dependent supplier and service provider, the potential for renewedoffshore operational success is abundantly clear. Yet, as the tumultu-ous events of the last decade have shown, the risks associated withoffshore operations have seemingly never been higher. The recentexplosion on Black Elk Energy’s West Delta 32 platform serves as astark reminder of these risks.

Undoubtedly, the past decade’s losses have had a profound impacton the offshore insurance markets. The fallout from the April 2010 Ma-condo well blowout and loss of the Deepwater Horizon is yet to be fullyrealized. Some estimates have projected losses in excess of $3 billionfrom this one event alone. Naturally, with losses of that magnitude, theoffshore energy industry experienced significant and almost immedi-ate increases in premiums across the board. This is especially true withrespect to liability, pollution, and control of well coverage, where somepremiums were anticipated to double.

But to say that all offshore energy-related premiums have in-creased solely as a result of the Macondo well blowout may be paint-ing the picture with too broad a brush. In 2005, Hurricanes Katrinaand Rita battered the Gulf of Mexico and resulted in tremendousproperty damage losses for the offshore energy industry, only to befollowed by another significant windstorm event in 2008 in the formof Hurricane Ike. In 2011, both the Gryphon and the Banff FPSOs sus-tained considerable damage due to heavy weather while operating inthe North Sea. Business interruption losses from these two eventsalone are anticipated to surpass $1 billion. Less than one year later,the marine insurance market suffered a significant event in early 2012with the sinking of the Costa Concordia off the Italian coast.

Armed with the knowledge that premiums will, more than likely,continue to increase as the risks associated with high-pressure, ultra-deepwater operations currently under development also build, manyparticipants may find themselves asking the question: What can bedone to manage the costs associated with insurance programs atrenewal? Although options for negotiation policies and associatedpremiums are as diverse as the industry itself, certain strategies mayprove beneficial in managing premium costs over the long term.

Know Thine Policies. First, careful attention should be paid tomatching the types and nature of policies sought and the coveragegranted with the operations at hand. Of course, the necessary cov-erage will vary for all participants in the offshore energy industry,often from job-to-job, and the premiums associated with each type ofcoverage will reflect the associated risks.

For the operator, typical insurance needs include the operator’s extraexpense policy, generally providing coverage control of well, redrilling,

seepage and pollution, and third-party and contractual liability coverage.Other policies commonly obtained by operators include loss of produc-tion income or business interruption, making wells safe, evacuation,property damage, and construction all risks. For the drilling contractorand offshore service provider, typical policy needs may include protec-tion and indemnity, hull and cargo, maritime employers’ liability, compre-hensive general liability, umbrella or bumbershoot coverage, and excesscoverage. Additional policy needs may again include removal of wreckor debris, loss of occupancy, property damage, and construction all-risk.

Importantly, operating and other agreements may dictate that certainof these policies be obtained by only one participant, but coverage can beextended to others by additional insured requirements. Careful negotia-tion of the insurance requirements of these agreements can easily resultin significant premium savings at all levels by eliminating redundant cov-erages and allocating risks amongst the parties. Also, recent court deci-sions defining the types of offshore structures considered “vessels” maynecessitate significant changes in coverage going forward.

Demonstrate Preparedness. Second, the ability to demonstratepreparedness to potential underwriters can make or break the renewalprocess. In August 2012, the Bureau of Safety and Environmental En-forcement released its Final Drilling Safety Rule, which imposes manyspecific requirements at all levels of offshore participation. Not the leastof the requirements is the Spill Response Plan. A complete and well-or-ganized plan, including all statutorily required elements plus additionalprovisions for training, is persuasive evidence of a coordinated, internalrisk management plan when negotiating premiums.

The “Ouch Factor.” Third, an understanding of the company’spractical ability to meet the deductibles for the policies obtained isof critical importance in managing premiums. Although lower de-ductibles can reduce the possibility of liquidity issues in the event ofa covered occurrence, sharply increased premiums may often out-weigh any benefits. For participants with the financial means, self-insuring various defined risks such as property damage may be aviable alternative to manage increased premiums.

Do Not Underestimate the Importance of a Risk Manager. Fi-nally, an experienced risk manager can be a valuable ally at renewal.Not surprisingly, the doors to coverage may be more easily openedto those who can draw on long-term relationships with various un-derwriters. Additionally, an experienced risk manager can create abeneficial, proactive relationship with underwriters, including facili-tating underwriter involvement in the contract negotiations refer-enced above to ensure proper coverages are obtained.

Daniel D. Pipitone, Chairman,Energy and Maritime Section

Kenneth W. Bullock II, Senior CounselChamberlain, Hrdlicka, White, Williams & Aughtry

Houston, Texas

Premiums and risk managementin the post-Macondo era

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You Are Invited To The 2013Subsea Tieback Forum & Exhibition


On behalf of the Subsea Tieback Advisory Board, PennWell, sponsors and exhibitors, it is my pleasure to invite you

to the 2013 Subsea Tieback Forum & Exhibition in San Antonio, Texas. The Subsea Tieback Forum & Exhibition has

become one of the subsea industry’s preeminent events. The Advisory Board has worked diligently to assemble a

fi rst-class program, which brings you the latest experiences, best practices, and technological innovations in the

subsea industry. The theme for this year’s forum is “Take it to the Limit.”

This year’s technical sessions are:

• Subsea Systems - Inspection, Maintenance, and Repair • Well Containment

• Subsea Boosting and Processing • Flowlines, Risers, and Umbilicals

• Project Learning • Innovations

Your participation is what makes the Subsea Tieback Forum a world-class event. I encourage you to attend and

actively participate – ask questions, network, and visit the exhibit hall. This is your opportunity to interface with

the best of the best in the subsea industry! The forum is organized to promote open and free information exchange

and for this reason the press is excluded from this event. Information sharing is accomplished through session

presentations, questions and answers, networking, and interaction with exhibitors.

The Subsea Underwater Technology (SUT) Workshop kicks off the forum with a one-day workshop on March 5th. This

workshop is a great means to successfully introduce new members to the subsea industry. If you would like to learn

more about the subsea industry, or just want a refresher course, I encourage you to attend this workshop.

Please join me in recognizing and thanking the sponsors, exhibitors and PennWell for making the Subsea Tieback

Forum & Exhibition such a huge success. I would especially like to recognize and thank the session presenters for

their time and effort in sharing their knowledge and experiences with us. Lastly, I would like to recognize and thank

the Advisory Board members who are the heart of the forum. The Board members work together throughout the year,

volunteering their time, to put together this program for you. Reach out to them and give them your feedback as we

are always striving to improve the forum for you.

I’m looking forward to seeing you in San Antonio!

Bob Writt

Advisory Board Chairman,

Subsea Tieback Forum & Exhibition

Senior Development Manager,

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WE OFFER 4 EASY WAYS TO REGISTER:

1. ONLINE: 2. FAX: 3. MAIL: 4. E-MAIL:

www.subseatiebackforum.com Direct: +1-918-831-9161 PennWell C&E Registration (SSTB) [email protected]

Toll-Free: +1-888-299-8057 P.O. Box 973059

Dallas, TX 75397-3059 USA

For registration questions call: Phone: +1-918-831-9160 or Toll-free (US only): +1-888-299-8016

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TABLE OF CONTENTS

SSCCHEDULE OF EVENTS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2

220013 SPONSORS & SUPPPOORRTTING ORGANIZATIONS . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3

HHAARLEY DAVIDSON GIVEAAWWAAYY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y 4

22001133 ADVISORY BOARD. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5

SSUUTT WWORKSHOP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .P 6

AASSMME WORKSHOPS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7

OOPPEENING PLENARY SESSIOONN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8

PPRREELIMINARY CONFERENCCEE PPROGRAM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100

2200122 ATTENDEE PROFILE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 188

EEXXHIBITION OPPORTUNITTIIEESS . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2200

SSUUBSEA TIEBACK FOUNDDAATTIION ANNUAL FUNDRAISERS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21

DDIRECTEVENTCONNECT AATTTTENDEE INFORMATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22

EEXHIBITOR LIST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2244

FFLOOR PLAN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2266

AATTENDEE REGISTRATTIIOONN FORM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2288

HOTEL REGISTRATIOONN FFOORM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3300

2013 PETROLEUM CCAALLENDAR OF EVENTS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3322

EVENT CONTACTSS. . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3333

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2 0 1 3 S U B S E A T I E B A C K F O R U M & E X H I B I T I O N P R E L I M I N A R Y E V E N T G U I D E2

SCHEDULE OF EVENTS

Monday, March 4

3:00 PM - 5:00 PM Registration Open Convention Center West Foyer

8:00 AM - 8:00 PM Exhibitor Move-In Exhibit Halls

Tuesday, March 5

7:00 AM - 11:00 AM Exhibitor Move-In Exhibit Halls

7:30 AM - 5:00 PM ASME Workshops (Additional Registration) Street Level 101 for ASME Workshops

8:00 AM - 7:00 PM Registration Open Convention Center West Foyer

9:00 AM - 5:00 PM SUT Workshop (Additional Registration) River Level 001

5:00 PM – 7:00 PM Exhibit Hall Opening and Networking Reception Exhibit Halls

Wednesday, March 6

7:00 AM - 8:00 AM Networking Breakfast Ballroom A Foyer

7:15 AM – 6:30 PM Registration Open Convention Center West Foyer

8:00 AM - 9:30 AM OPENING PLENARY SESSION Ballroom A

9:00 AM – 7:00 PM Exhibit Hall Open Exhibit Halls

9:30 AM - 10:30 AM Coffee Break Exhibit Halls

10:30 AM - 12:00 PM SESSION 1 Ballroom A

12:00 AM - 1:00 PM Delegate Lunch Exhibit Halls

1:00 PM - 1:30 PM Networking Dessert Exhibit Halls

1:30 PM - 3:00 PM SESSION 2 Ballroom A

3:00 PM - 4:00 PM Coffee Break Exhibit Halls

4:00 PM - 5:30 PM SESSION 3 Ballroom A

5:30 PM - 7:00 PM Networking Reception Exhibit Halls

Thursday, March 7

7:00 AM - 8:00 AM Networking Breakfast Ballroom A Foyer

7:30 AM - 1:00 PM Registration Open Convention Center West Foyer

8:00 AM - 9:30 AM SESSION 4 Ballroom A

9:00 AM - 1:30 PM Exhibit Hall Open Exhibit Halls

9:30 AM - 10:30 AM Coffee Break Exhibit Halls

10:30 AM - 12:00 PM SESSION 5 Ballroom A

12:00 PM - 12:45 PM Delegate Lunch Exhibit Halls

12:45 PM- 1:15 PM Networking Dessert Exhibit Halls

1:15 PM Harley Davidson Motorcycle Giveaway Exhibit Hall

1:30 PM – 5:30 PM Exhibitor Move-Out Exhibit Halls

1:30 PM – 3:00 PM SESSION 6 Ballroom A

3:00 PM – 3:15 PM Recognition Awards & Closing Remarks Ballroom A

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PLATINUM SPONSOR

THURSDAY LUNCH SPONSOR

COFFEE BREAK SPONSOR

HOG HEAVEN TITLE SPONSOR

GOLD SPONSOR

WEDNESDAY NETWORKINGRECEPTION SPONSOR

SILVER SPONSOR

HOTEL KEY CARD SPONSOR

OPENING NIGHT NETWORKINGRECEPTION SPONSOR

BRONZE & WEDNESDAYLUNCH SPONSOR

ONLINE REGISTRATIONPAGE SPONSOR

EXHIBITOR BRANDING SPONSORS MEDIA SPONSOR

BOTTLED WATER SPONSOR

FAST TRACKREGISTRATION SPONSOR

SHOW GUIDE BELLYBAND SPONSOR

SUPPORTINGORGANIZATION

WEDNESDAY NETWORKINGBREAKFAST SPONSOR

OFFICIALAIRLINE

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2013 SPONSORS & SUPPORTING ORGANIZATIONS

SPONSORSHIP OPPORTUNITIES

Optimize your visibility and leave an impression on over 3,000 industry professionals. Subsea Tieback Forum &

Exhibition offers a wide range of sponsorship options to maximize your exposure. You can reach conference and exhibit

attendees with any of the following sponsorship packages. Or contact your sales representative to customize a package

to fit your needs. Book early to showcase your company branding immediately on print and digital marketing materials.

The following packages are still available for Subsea Tieback 2013:

• Thursday Networking Breakfast Sponsor

• Room Drop Sponsor

• Product Locator Sponsor

• Exhibit Floor Map Sponsor

• Hog Heaven Harley Giveaway Sponsor

(multiple available!)

• Registration Confi rmation Page Sponsor

• Online Registration Page Sponsor

• Cyber Café Sponsor

• Conference Notepads and Pens Sponsor

• Exhibitor Branding Sponsor (only 2 left!)

• You Are Here Signage Sponsor

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_______________________







While at Subsea Tieback Forum & Exhibition, Conference Delegates can register

for their chance to win a 2013 Harley-Davidson® motorcycle. Exhibitors have

the opportunity to become a Hog Heaven Sponsor, where all Conference

Delegates must go to each Hog Heaven Sponsor’s booth to obtain a

‘stamp’ to complete their entry form. A drawing will be held on the

Exhibit Floor the last day of the event where the lucky winner will

be announced. Must be present to win!

SUBSEA TIEBACK FORUM & EXHIBITION WANTS TO PUT YOU IN

HOG HEAVEN TITLE SPONSOR HARLEY-DAVIDSON HOG HEAVEN SPONSORS

Peter Cantu

United States

Phone: +1 713 963 6213

Fax: +1 713 963 6212

Mobile: +1 713 503 2451


Sara Lowery Ng

United States

Phone: +1 713 963 6277

Cell: +1 713 725 8536

Fax: +1 713 963 6212


Jane Bailey

Northern Europe & Middle East

Phone: +44 1992 656 651

Mobile: 07983 388 367


Tony B. Moyo

Europe, Middle East & Africa

Phone: +44 1992 656 658

Mobile: +44 798 522 9324


HARLEY DAVIDSON EXHIBIT FLOOR GIVEAWAY!

For more information about sponsoring at Subsea Tieback, please contact your sales representative.

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Don Beesley

Eni Petroleum

Barry Brasher

Anadarko Petroleum Corporation

Bob Carter

Vaela Resources

Mark Carter

Cameron

Richard Case

Newfield Exploration Company

Bruce Crager

Endeavor Management

Antonio Critsinelis

Chevron Energy Technology Co.

Christopher Curran

BP E&P

John Fitzgerald

Granherne

Steve Frantz

ERT GOM

Clyde Hewlett

Oceaneering International, Inc.

Chuck Horn

Genesis

Jay Hursh

Aker Solutions

David LaCaze

Shell International E&P, Inc.

Jim Macklin

InterMoor

Sergio Porciuncula

Petrobras

Gene Raborn

Technip

Tony Ray

ConocoPhillips

Randy Seehausen

INTECSEA

Jon Sonka

ExxonMobil Development Company

Pete Stracke

Statoil

Bobby Voss

GE Oil & Gas

Steve Whitaker

HESS Corporation

Michael Williams

FMC Technologies

Mason Wu

McDermott Subsea Engineering

Bruce Beaubouef

Offshore

Chairman

Bob Writt

BHP Billiton

Board Members

2013 ADVISORY BOARD

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K E Y E L E M E N T S O F S U B S E A T I E B A C K S

A one-day seminar designed to educate people on the key elements of subsea tiebacks – subsea, umbilicals,

risers, fl owlines (SURF) to be conducted under the auspices of the Society for Underwater Technology (SUT).

Registration fee: $500.00 if registered by February 1, 2013; $600 thereafter

Go to www.subseatiebackforum and click on the Registration tab to register.

For Registered Professional Engineers, this course counts for 6 Professional Development Hours.

TUESDAY, MARCH 5, 2013

9:00 a.m. – 9:05 a.m. Introduction

Don Schlater – SUT Training Committee Chairman

9:05 a.m. – 10:30 a.m. SESSION 1: SETTING THE SCENE

Bill Donlon – BHP Billiton

· Deepwater Forecast

· Tieback Facts and Figures

· Tieback Drivers and Issues

· Key Components

· Example Layouts

10:30 a.m. – 11:00 a.m. Break

11:00 a.m. – 12:30 p.m. SESSION 2: SUBSEA ELEMENTS

Tom Kelly - FMC Technologies

· System Considerations

· Subsea Completions

· Control Systems

· Manifolds and Tie-in Systems

12:30 p.m. – 1:30 p.m. Lunch

1:30 p.m. – 3:00 p.m. SESSION 3: UMBILICALS, RISERS AND FLOWLINES

Chuck Horn – Genesis

· Flowline Tie-ins

· Offshore Flowlines/Pipelines

· Subsea Production Control Umbilicals

3:00 p.m. – 3:30 p.m. Break

3:30 p.m. – 4:30 p.m. SESSION 4: PRODUCTION HANDLING AGREEMENTS

Cory Loegering – Apache Corporation

4:30 p.m. – 4:45 p.m. WRAP-UP

Don Schlater – SUT

4:45 p.m. – 5:00 p.m. Q&A

5:00 p.m. – 7:00 p.m. OPENING NIGHT Sponsored by:

EXHIBIT HALL RECEPTION

SUT WORKSHOP

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ASME WORKSHOPS

TUESDAY MARCH 5, 2013

FUNDAMENTALS OF DEEPWATER RISER ENGINEERING 8:00 a.m. – 5:00 p.m.

Course Fees

Early Bird: $500 if registered by February 1, 2013 Regular: $600 if registered after February 1, 2013

Course Overview:

The “Fundamentals of Deepwater Riser Engineering” will provide attendees with the basic principles and technologies of riser

engineering design, fabrication and installation, and provide an understanding of the primary drivers behind riser system selection

for deepwater fl oating production. Each student will receive 6.5 PDH’s.

Course Attendees:

This course is designed for subsea, pipeline or riser engineers with 1-5 years of experience and industry professionals who interface

with riser engineering.

Course Topics:

• Deepwater riser technology

• Riser codes of practice

• Riser selection

• Steel based risers

• Flexible, hybrid, and unbilical risers

• Material, fabrication and installation

• Deepwater projects and lessons learned

FUNDAMENTALS OF DEEPWATER PROJECT DEVELOPMENT 8:00 a.m. – 5:00 p.m.

Course Fees


Course Name:

Fundamentals of Deepwater Project Development

Course Overview:

Deepwater projects will account for an increasing portion of offshore oil and gas supply. Developing deepwater fi elds entail signifi cant

technical and commercial challenges. This course, taught by leaders in the industry, will provide a fundamental understanding of

deepwater development planning and familiarize attendees with essential fl oating platform, subsea and riser technologies that enable

safe and profi table extraction of hydrocarbons in deepwater. The course material is designed to serve as a handy reference and guide

to deepwater project development.

Course Attendees:

Anyone with the desire to better understand the fundamentals of deepwater development planning and the key surface facility

components that constitute a deepwater project development.

Course Topics

• Importance of deepwater oil and gas

production

• Introduction to deepwater fi eld

development planning

• Introduction to fl oating production

platforms

• Overview of Subsea hardware

• State of the art Riser Technology

SUBSEA PIPELINE DESIGN OVERVIEW 8:15 a.m. – 5:00 p.m.

Course Fees


Course Overview:

The “Subsea Pipeline Design Overview” course will provide you with an appreciation of pipeline engineering as a design discipline

and process and an understanding of how system solutions are implemented via procurement, fabrication, and installation – resulting

in project delivery.

Course Attendees:

This course is intended for pipeline engineers with 1-5 years experience and senior engineers and managers outside the offshore

pipeline industry.

Course Topics:

• Design basis

• Flow assurance

• Pipeline route selection

• Pipeline mechanical design issues

• Materials technology overview

• Offshore pipeline installation and

tie-in methods

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2013 OPENING PLENARY SESSION

Wednesday March 6, 2013

8:00 a.m. – 9:30 a.m.

Open To All Registered Attendees!

CONFERENCE MANAGEMENT WELCOME & INTRODUCTION

MARK PETERS – PENNWELL

Mark F. Peters is a Vice President of PennWell Publishing and Group Publisher of Offshore and

Oil & Gas Financial Journal. He has over 30 years of industry-related experience having been a

publisher of a refi ning, petrochemical, gas processing publication and a pipeline and gas industry

publication. He is a frequent speaker addressing oil, gas, refi ning and offshore issues and trends

at seminars, conferences and users groups. His extensive travel schedule includes attendance at

major upstream and downstream meetings around the world. He holds a BA degree in psychology

from Brown University.

CHAIRMAN’S OPENING REMARKS

BOB WRITT – BHP BILLITON

Bob Writt is Senior Development Manager for BHP Billiton Petroleum. BHP Billiton Petroleum

is headquartered in Houston, Texas where Mr. Writt is responsible for the Company’s worldwide

development of brownfi eld oil and gas projects.

Mr. Writt joined BHP Billiton in 2009. Prior to joining the Company, Mr. Writt worked for Shell

International as a Subsea Project Manager leading a number projects, including Bonga and BC-10,

to fi rst oil. Mr. Writt also worked for FMC Technologies as a subsea engineer and was responsible

for developing the fi rst standard deepwater subsea tree. Mr. Writt is a mechanical engineering

graduate of Texas A&M University and earned his MBA degree from the University of Houston.

BHP Billiton is one of the world’s largest diversifi ed resources corporations. BHP Billiton

Petroleum has development, production and marketing activities in more than a dozen countries

around the globe, including a signifi cant deepwater position in the Gulf of Mexico, as well as

operations in Australia, United Kingdom, Africa, the Middle East and Asia. The Company also

has signifi cant shale operations in Louisiana, Texas and Arkansas. These world-class resources

are making material contributions to the growth and diversifi cation of the Company’s oil and gas

portfolio.

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KEYNOTE PRESENTATION

NIGEL SMITH – BHP BILLITON

Nigel Smith is President, Development for BHP Billiton Petroleum. BHP Billiton Petroleum is

headquartered in Houston, Texas where Mr. Smith is responsible for the Company’s worldwide oil

and gas development activities.

Mr. Smith was previously President of Operations and Development for Australia and Asia. He

joined BHP Billiton in 2000 as Vice President of the Liverpool Bay Asset. Prior to joining the

Company, Mr. Smith worked for Atlantic Richfi eld Corporation (ARCO) and Shell International

where he held positions of increasing responsibility in Asia, United Kingdom and The Netherlands.

Mr. Smith serves on BHP Billiton Petroleum’s business executive leadership team. He is a

graduate of Nottingham University in the United Kingdom.

BHP Billiton is one of the world’s largest diversifi ed resources corporations. BHP Billiton Petroleum

has development, production and marketing activities in more than a dozen countries around the

globe, including a signifi cant deepwater position in the Gulf of Mexico, as well as operations in

Australia, United Kingdom, Africa, the Middle East and Asia. The Company also has signifi cant

shale operations in Louisiana, Texas and Arkansas. These world-class resources are making material

contributions to the growth and diversifi cation of the Company’s oil and gas portfolio.

SCENE SETTING PRESENTATION

TYLER SCHILLING – SCHILLING ROBOTICS

Tyler Schilling co-founded Schilling Robotics, along with Wes Gerriets, in 1985, with the vision of

providing productive tools to remotely perform work in the deep ocean. As the president he sets

Schilling Robotics’ vision to guide product innovation and development.

Under his consistent leadership for over 27 years, and a never-ending passion for the pursuit

of excellence, Schilling Robotics has established a worldwide market supplying intervention

systems to virtually every operator of subsea remotely operated vehicles (ROVs). Mr. Schilling’s

entrepreneurial growth of the Company has been built on fostering an environment of ensuring

customer success.

Mr. Schilling has been an innovator, advocate, and sought-after speaker for the expansion of

remote technology on the sea fl oor. The introduction of Schilling manipulators to the industry has

changed the capabilities of ROVs and they are currently used in 95% of subsea work. He holds

three patents on subsea devices and has accumulated a wealth of experience and expertise in

offshore operations.

As a reserve power forward on the 1968 US Men’s Olympic Basketball team, Tyler has always

operated Schilling Robotics with the focus and enthusiasm of a World-class sportsman.

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2013 PRELIMINARY CONFERENCE PROGRAM

TUESDAY, MARCH 5, 2013

5:00 -7:00 p.m. EXHIBIT HALL OPENING RECEPTION Sponsored by:

WEDNESDAY, MARCH 6, 2013

7:00 a.m. – 8:00 a.m. NETWORKING BREAKFAST Sponsored by:

8:00 a.m. – 9:30 a.m. OPENING PLENARY SESSION

CONFERENCE MANAGEMENT WELCOME & INTRODUCTION

Mark Peters – PennWell

CHAIRMAN’S OPENING REMARKS

Bob Whitaker – BHP Billiton

KEYNOTE PRESENTATION

Nigel Smith – BHP Billiton

SCENE SETTING PRESENTATION

Tyler Schilling – Schilling Robotics

9:30 a.m. – 10:30 a.m. COFFEE BREAK Sponsored by:

10:30 a.m. – 12:00 p.m. SESSION 1: SUBSEA SYSTEMS: INSPECTION, MAINTENANCE AND REPAIR

Chair: David LaCaze – Shell

Co-Chair: Clyde Hewlett – Oceaneering

Co-Chair: John Fitzgerald – Granherne

Chinook Riser Incident - Resuming Production

Sergio Porciuncula – Petrobras America Inc.

In 2011, one of the Free Standing Hybrid Riser (FSHR) of the Cascade and Chinook Project

experienced a problem in its tether chain system. An emergency response plan was implemented

and successfully executed to secure the safety of personnel, the environment and the production

system. The following solutions were developed and executed post stabilization to resume

production on both fi elds: a) Enabling production in Cascade by replacing the existing chain

tethers and installing additional synthetic rope tethers to the other FSHRs; b) Enabling production

in Chinook by interconnecting a new fl owline to the Cascade production system and installing a

subsea pig launcher to regain full functionality.

Sergio Porciuncula is the Subsea Manager for Petrobras America Inc. in Houston, a wholly owned

subsidiary of Petrobras S.A. He is responsible for the implementation of the subsea production

system in the Cascade and Chinook project, located in the ultra-deep waters of the Gulf of Mexico’s

lower tertiary. He is member of the Subsea Tie Back Forum Steering Committee and University

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of Houston-Subsea Engineering Department Advisory Board. He has been with Petrobras

since 1980, providing subsea technical and managerial expertise to the company in the

areas of subsea engineering, operations, and market intelligence for more than 30 years.

Mr. Porciuncula has a degree in Materials and Metallurgical Engineering from the Federal

University of Rio de Janeiro, a graduate degree in Equipment Engineering from Petrobras

University, and an MBA degree from Getulio Vargas Foundation in Brazil.

Replacement of Caisson-ESP’s in the BC-10 Field

Michiel Bekker – Shell

An overview with lessons learnt and challenges of replacing failed Caisson-ESP’s in the

deepwater BC10 field offshore Brazil using a Semi Submersible Drilling Rig.

Michiel A Bekker, MSc CE , works as a Subsea Systems Engineer for Shell Oil since 2012.

Bekker joined the industry in 2004 in Shell UK. In 2008 he became Subsea Intervention

Coordinator for Shell Brazil’s deepwater fields, where he led all subsea interventions, including

Caisson-ESP replacements on BC10.

Pyrenees MPFM and Manifold Corrosion and Rectification

Karl Schnakenburg – BHP Billiton - INVITED

Session 1 Alternate: Light Vessel Open Water Interventions Supporting Shell Brazil

Adam Urban – Shell Brazil

The installation of an ROV and a 22 ton heave-compensated subsea crane on the 65 meter

Austral Abrolhos vessel has added exciting subsea surveillance and light intervention

capabilities to Shell Brazil’s operating assets. The complete value of this full-time-hire

vessel is realized considering the vessel has not lost its original scope of supporting tanker

offloading, cargo transfers and oil-spill response. The presentation explores the learnings and

challenges of the vessel since the commissioning of the crane in December 2011.

Adam Urban is accountable for the delivery of open water interventions, as the Subsea

Interventions and Aftermarket Team Lead in Shell Brazil. This is Adam’s eighth year in

industry and with Shell, having also worked subsea deepwater completions and onshore

unconventional subsurface development.

9:30 a.m. – 10:30 a.m. LUNCH Sponsored by:

1:30 p.m. – 3:00 p.m. SESSION 2: SUBSEA BOOSTING AND PROCESSING

Chair: Christopher Curran – BP

Co-Chair: Mike Williams – FMC Technologies

Co-Chair: Chuck Horn – Genesis

Wet Gas Compressor Development and Testing

Nils Arne Soelvik – Framo Engineering

This paper will present the multiphase compressor technology, it’s impact on the system

solution, the technical qualification program to commericalize it and the results of the testing.

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Nils Arne Soelvik, is Sales Manager, Pumps & Subsea Processing Systems, in the Western

Hemisphere with Framo Engineering since 2003. He also had the responsibility to

commercialize the Framo multiphase compressor technology.

Jack & St. Malo Subsea Pumping System - New Challenges, Strategies & Accomplishments

Ashish Karamchandani – Chevron

The Jack St Malo project in the deepwater GOM will require subsea single phase pressure

boosting. Subsea pumping is an area of new technology for Chevron therefore an extensive

technology development program was carried out, followed by a contract to deliver 3 subsea

boosting systems. The successful deployment for this new technology system on which the

success of a multi-billion dollar MCP relies requires diligence, risk management and innovative

strategies. This presentation will give an overview of the challenges and accomplishments.

Ashish Karamchandani is an electrical engineer at Chevron. He is responsible for the delivery

of Jack & St. Malo Subsea Pump’s Power System and coordinator for the Subsea Pump System

Integration Test program.

BC-10 Phase I Caisson ESP Operating Experience

Francisca Ogundele – Shell Brasil Petróleo

This presentation will focus on the challenges facing the Shell BC-10 subsea field operations

and surveillance team in operating caisson ESPs. The goal is to maintain high ESP availability

while at the same time debottle-necking the ESPs to maximize production from the wells. This

is no small task given the changing fluid properties, access to too much or too little information,

and rapid system transients.

Francisca Ogundele is the Subsea Surveillance Lead for the BC-10 and Bijupira-Salema Subsea

developments in Shell Brasil Petróleo. She has been working for 11 years in New Orleans, USA;

Miri, Malaysia, and Rio de Janeiro, Brasil. She has operations and project experience on both

deep and shallow water subsea developments.

Session 2 Alternate: Cascade and Chinook Horizontal ESPs Learnings/Performance

Christina Waggoner – Petrobras America Inc.

The Cascade and Chinook Seabed Boosting System presents an innovative and unique design

to overcome the challenges of the severe project conditions. The presentation describes the

performance of the boosting system during tests and system integration test (SIT), the process

of development and qualification of pioneer components as well as lessons learned and key

improvements to be applied to future projects.

Cristina Waggoner is a Subsea Engineer with Petrobras America Inc., based in Houston,

working in the implementation of the subsea production system in the Cascade and Chinook

project, located in the ultra-deep waters of the Gulf of Mexico’s lower tertiary. She has been

with Petrobras since 2003, providing subsea technical expertise to the company in the areas of

subsea engineering.

3:00 p.m. – 4:00 p.m. COFFEE BREAK Sponsored by:


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4:00 p.m. – 5:30 p.m. SESSION 3: PROJECT LEARNINGS

Chair: Sergio Porciuncula - Petrobras

Co-Chair: Bruce Crager – Endeavor Management

Co-Chair: Mark Carter – Cameron

Shell Perdido Subsea Lessons Learned

Larry Obst – Shell Exploration & Production Company

Larry will present learnings from startup and early operations on the Perdido subsea system.

Larry Obst is a Flow Assurance Engineer supporting operating Shell assets in the GOM.

He spent three years supporting the startup and operations of the Perdido subsea system,

including twelve wells and five subsea caissons and ESPs on the sea floor. Prior to joining

Shell, Larry was an engineer officer in the Army for seven years.

Project Learnings: Husky White Rose Sub-Arctic Development Experience

Jason Kemshall – Husky

A review of the system challenges presented by ice related threats, comparison with seven

years of Husky White Rose Field operational history and discussion of applicability for

progression into Arctic regions.

Jason Kemshall, Subsea Developments Project Engineering Lead with Husky Energy was a

member of the original White Rose Project FEED phase, and served as senior subsea engineer

leading subsea intervention and well tie in operations from first oil in Q4 2005 until late 2011.

Ceiba Field Lessons, the Cost of Planning for Expansion vs. the Cost of

Expanding Beyond the Plan

David Murphy – Hess Corporation

A review of the Ceiba original field development and the various stages of field expansion.

The review both the capital costs of the expansions, and expandability build into the system

as well as the operational limitations these provided.

David has been working in subsea field developments for almost 10 years. His experience

includes fields in Australia, Asia, the Gulf of Mexico, Ghana, and Equatorial Guinea. As the

Subsea Team Lead for Hess’s Ceiba Field Redevelopment he is responsible for ensuring the

delivery and tie-in of all subsea equipment for the redevelopment. This requires interfacing

and understanding the limitations of the existing field architecture, taking advantage of inbuilt

expandability, and creating additional expansion capability both for this redevelopment and

possible future developments.

Session 3 Alternate: New Technologies Applied to Riser Tower Installation

Edward Nakajima – Chevron Energy Technology Company

Enhanced innovative method to install single riser tower based on lessons learned from the

few already installed so far in the industry.

Edward Nakajima works for Chevron Energy Technology Company, Pipeline, Flexible

and umbilical group. Strong and consolidated Subsea experience in multi-disciplinary

environment, main areas of expertise include management, engineering and planning of

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pipeline projects including rigid, flexible, umbilical from the design to fabrication, onshore

testing, installation and commissioning phases.

5:15 p.m. – 6:45 p.m. EXHIBIT HALL NETWORKING RECEPTION Sponsored by:

THURSDAY, MARCH 7, 2013

7:00 a.m. – 8:00 a.m. NETWORKING BREAKFAST

8:00 a.m. – 9:30 a.m. SESSION 4: WELL CONTAINMENT

Chair: Jon Sonka – ExxonMobil

Co-Chair: Randy Seehausen – Intecsea

Co-Chair: Don Beesley – Eni Petroleum

Marine Well Containment Company Capping Stack Demonstration in the U.S. Gulf of Mexico

Marty Massey – Marine Well Containment Company

Marine Well Containment Company (MWCC), Shell Oil Company and the Bureau of Safety and

Environmental Enforcement (BSEE) completed a successful demonstration of the industry’s

ability to respond to a deepwater well control incident in the U.S. Gulf of Mexico in July, 2012.

At the direction of the Department of the Interior and BSEE, MWCC initiated mobilization of its

containment system, including the physical deployment of the capping stack, the centerpiece of

the system. The single ram capping stack stands roughly 30 feet tall, 14 feet wide and weighs

about 100 tons. This presentation will discuss the planning process and key learnings from the

event; photos and video captured during the demonstration will be shared as well.

Martin W. Massey serves as chief executive officer of Marine Well Containment Company. In

this role, he leads MWCC in the execution of its mission and strategic plan and serves as the

company’s Incident Commander in the event of a deepwater well control incident.

The Evolution of Helix Well Containment System

Roger Scheuermann – Helix Well Containment Group

HWCG is a solution to meet regulations concerning BOMRE NTL No. 2010-N10.

Roger is Commercial Director for Helix Well Containment Group - For the past 2 years, Roger has

worked as Commercial Director for Helix Well Containment Group (HWCG) which is a consortium

of 24 deepwater operators in the Gulf of Mexico who have come together with the common goal

of quickly and comprehensively responding to a well control incident to protect people, property

and the environment. Roger has assisted in obtaining additional members and development

of HWCG to become the premier well containment solution in the Gulf of Mexico. Roger has

over 20 years’ experience in coordinating and conducted well containment and oil spill drills,

equipment deployments and other emergency notifications processes.

Utilizing Existing Sub Sea Infrastructure in a Containment Response

Jonathan Shipley and Fernando Gama – Petrobras America Inc.


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Many fields in the GoM have existing sub sea infrastructures that could potentially be used as

a containment option in the event of a catastrophic blowout. The Cascade and Chinook fields

in Walker Ridge are sub sea wells which flow to an FPSO. In the event of a blowout and a cap

and flow scenario, the Operator developed a strategy to connect the capping stack to the well

manifold, and flow back to the pipeline/FSHR, and to the FPSO ~ 3 miles away. These options

were presented to the Regulators, and although the Regulators categorize wells as either 1.)

100% shut-in or 2.) Cap and flow, Regulators and the industry should develop alternatives to

flow the wells on a field specific basis for a faster response time and reduce the equipment

needed and the personnel put in harms way. This presentation outlines the options specific to

the Cascade and Chinook Fields and a strategy that may be useful for other operators.

Jonathan Shipley is a Sr. Well Engineering Advisor for Petrobras America Inc., officing in

Houston Texas with his main focus being the Cascade & Chinook projects in the GOM/Walker

Ridge area. Mr. Shipley was previously the Cascade Drilling Manager for Devon Energy Inc.

and prior to that he was the Brazil Drilling Manager for Devon do Brasil in Rio de Janeiro,

Brazil. Mr. Shipley has 30 years of experience in Drilling, Completions and Well Engineering

and has held Senior Engineering and Management positions in North America/GOM, Africa

and South America with Chevron, ConocoPhillips and Devon.

Session 4 Alternate: Flow Assurance When Blockages Occur

James McAllister – Oceaneering International

This presentation will address several different methods and tools that are available when

flowline blockages occur.

James McAllister joined Oceaneering International in 2001. He has held offshore and

onshore positions concentrating on deep water pipeline remediation, riserless wireline well

interventions, and chemical well stimulations. James holds a Bachelor of Science and

attended Tulane University and Northwest Christian University. His current position is IMR

Program Manager with Oceaneering’s Oilfield Projects Group.

9:30 a.m. – 10:30 a.m. COFFEE BREAK Sponsored by:

10:30 a.m. – 12:00 p.m. SESSION 5: FLOWLINES, RISERS AND UMBILICALS

Chair: Antonio Critsinelis – Chevron

Co-Chair: Mason Wu – McDermott Subsea Engineering

Co-Chair: Bob Carter – Vaela Resources

Gulf of Mexico FSHR Non-Clashing Design: Lessons Learned from Cascade & Chinook

Craig Masson – RiserTec

This presentation examines field layout considerations for Free-Standing Hybrid Risers (FSHRs)

in the Gulf of Mexico. The material is based on experience from the Petrobras Cascade &

Chinook project, both from design and from monitoring of the FSHR system in place.

Craig Masson was Petrobras’s EPCI Contract Manager, responsible for delivery of the Cascade

& Chinook FSHRs, from the EPCI bid process through engineering, procurement, fabrication,

installation, and pre-commissioning. Craig is now a Senior Consultant at RiserTec Inc., and

continues to provides support to the Petrobras Cascade & Chinook project.

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Subsea Wet Insulation System Research

John Lawson – Chevron ETC

This paper will present a brief background to the JIP which has been progressing into the testing

of wet insulation and field joint material. About half of the tests have been completed with

some interesting results. There will also be an opportunity to look ahead to emerging insulation

materials for subsea use.

Texaco’s Operations Pipeline Engineer in Aberdeen from 1998, progressing, post merger, to

Chevron’s Head of Subsea Engineering, leading a team of engineers working on design and

installation, operations, integrity management of subsea systems whilst concurrently pursuing a

strong interest in research & development.

Remediation of a Paraffin / Hydrate Plug in the Appaloosa MC-460 Flowline

Don Beesley – Eni Petroleum

The Appaloosa MC-460 project is a subsea development of a single oil well that is tied back

20 miles to Eni’s Corral MC-365 platform. The flowline is unheated and uninsulated, and

only chemicals are used to achieve flow assurance. This presentation will compare actual flow

assurance performance to the original design basis, and review how a paraffin / hydrate plug was

successfully remediated with chemicals.

Don Beesley, DPM Gulf of Mexico Manager for Eni Petroleum, has 37 years of experience in

the petroleum industry, including 18 years at Eni, where he has worked in both the Production

Operations and Development departments and during that time he has managed both flow

assurance designs and the remediation of paraffin and hydrate plugs in pipelines.

Session 5 Alternate: Galapagos In-Line Sleds Cooldown Time

Maria Nass – BP

This presentation will cover the improvement of galapagos In-Line Sleds cooldown time by

means of CFD simulation.

Maria Nass is a Petroleum Engineer working for BP’ GoM Base Management group in Houston.

She has 10 years experience in Flow Assurance and Petroleum Engineering. She was the Lead

Flow Assurance engineer for Galapagos. She has a MSc in Petroleum Eng from Texas A&M, she

is a registered PE in the State of Texas.

12:00 p.m. – 1:30 p.m. LUNCH Sponsored by:

10:30 a.m. – 12:00 p.m. SESSION 6: INNOVATIONS

Chair: Steve Whitaker – Hess Corporation

Co-Chair: Gene Raborn – Technip

Co-Chair: Richard Case – Newfield Exploration Company

Moving Compression from Topside to Subsea, an Operator’s Perspective

Peter Batho – Chevron Energy Technology Corporation

This paper intends to explore the current state of technology and highlight interesting technology

trends that are emerging. The bigger picture is that there is significant potential to rationalize

/ optimize subsea compression system to minimize footprint, weight and complexity. This

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technology development work is potentially important and timely for Chevron and the industry

as a whole to allow increased economic recovery for subsea gas assets globally.

Peter Batho is a Subsea Pump Systems Specialist in Chevron Energy Technology

Corporation based in Houston. Peter has 17 years experience in the oil and gas industry

in a variety of technical roles that have primarily focused on topside and subsea pumps

and supporting hardware.

Bawal Smart Well Completion Design & Implications on Subsea Architecture

John Leitch – ConocoPhillips

This presentation will cover the 40 Km subsea tieback with a 6 zone Intelligent Well

System completion.

John Leitch is a Completions Engineer for ConocoPhillips based in the Global Wells group in

Houston Texas. He started in the Oilfield in Aberdeen Scotland in the early 1980s, worked

on the development of the first intelligent completion equipment developed by PES, and

installed the first IWS system in the Snorre field in Norway in 1997. John was the completion

engineer offshore for the installation of the Bawal 01 well.

Caesar-Tonga Steel Lazy Wave Risers

Mike Beattie – Anadarko Petroleum Corporation

Steel lazy wave risers were used for the Caesar-Tonga field development. This represents

the first application of this technology in the Gulf of Mexico and the first tie-back to a spar

floating platform. The presentation will cover the design, fabrication and installation details of

this technically challenging project.

Mike Beattie is the General Manager of the Deepwater Facilities Group at Anadarko Petroleum

Corporation. Mike was the project manager for the Caesar Tonga project and has worked on a

number of deepwater developments such as Constitution, Nansen, Boomvang, and tie backs

to the Neptune platform.

Session 6 Alternate: Atlantis Flow-Limited De-Oiling and Flushing Concept Development

Richard Lau – BP

The Atlantis Subsea Team developed an effective, low-flowrate flushing technique to de-oil

deadlegs in valveless manifolds to support well tie-in’s. This presentation discusses the

significant effort to develop this flushing technique.

Richard Lau, Subsea Installation Engineer at BP, has supported installation and de-oiling/

dewatering activities for Atlantis and ThunderHorse since 2006. He currently works in

the Subsea, Survey, Installations, & Interventions (SSII) team within BP’s Global Projects

Organization.

3:00 p.m. – 3:15 p.m. RECOGNITION AWARDS, iPAD GIVEAWAY & CHAIRMAN’S CLOSING REMARKS

Bob Writt – BHP Billiton

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Major Oil & Gas Operating Company, Independent Oil & Gas Company, National/State Oil Company 24.2%

Equipment Manufacturing Company 23.5%

Consulting Company Engaged in Projects or Providing Services to Oil and/or Gas Companies 18.5%

EPC (Engineering/Procurement/Construction) Main Contractor 13.5%

Other 7.7%

Service Company 4.3%

Supply Company 3.5%

Drilling/Drilling Contractor 1.8%

Educational Institution/Government Agency/Research Laboratory 1.1%

Subcontractor 0.7%

Insurance or Financial Services 0.7%

Marine Support Services 0.3%

Subsea Systems Installation 49.1%

Subsea Operations 48.4%

Risers & Umbilicals 47.3%

Flowlines & Pipelines 44.1%

Subsea Production Equipment & Services 43.1%

Subsea Field Development Case Histories, Challenges & Lessons Learned 39.9%

Subsea Systems Inspection, Maintenance & Repair 39.9%

Subsea Production Facilities/Concept Selection 35.2%

Subsea Processing 34.2%

Subsea Technology Innovation, Verification and Validation 33.8%

Flow Assurance 28.1%

Automation Systems/Instruments & Control/Valves & Accessories 27.8%

Enhanced Production 23.5%

Artificial lift 21.0%

Marine Transportation/Construction Equipment & Services 19.2%

Motors/Engines/Pumps/Compressors/Turbines/Generators 16.7%

Mooring and Station Keeping Equipment & Services 13.9%

Engineering 37.9%

Management (Production Manager, Engineering Manager, Exploration Manager) 18.4%

Executive Management (CEO, President, Owner, VP, Managing Director, etc.) 17.4%

Other 11.7%

Consulting 8.2%

Purchasing (Purchasing Agent, Purchasing Manager) 3.9%

Field Professional (Superintendent, Foreman, Assistant Foreman, Toolpusher) 2.1%

Geology or Geophysics 0.4%

JOB FUNCTION

ORGANIZATIONAL TYPE

AREAS OF INTEREST


2012 ATTENDEE PROFILE

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Recommend 54.8%

Final Decision 17.8%

No role 16.0%

Specify 11.4%

Networking 52.7%

Encounter new technology 52.0%

Attend the conference sessions 44.8%

Encounter new products/services 43.8%

Do business with existing supplier 27.4%

Do business with new supplier 26.0%

Evaluate products for purchase 18.9%

PURCHASING AUTHORITY

PRIMARY REASON FOR ATTENDING


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2013 EXHIBITION OPPORTUNITIES

If your company has involvement in the following areas, the Subsea Tieback Forum & Exhibition is an essential platform

to exhibit your product and services:

As a company interested in the latest challenges of the subsea tieback industry, you

can’t afford to miss this event. Exhibiting will provide opportunities to make instrumental

connections that hold the key to your success in this growing market.

• Buildings

• Chemicals

• Compressor Equipment and Services

• Contracting Services

• Corrosion/Abrasion Control

• Diving Services and Underwater

Maintenance

• Drilling

• Dynamic Positioning Propulsion

• Engines

• Enhanced Recovery

• Environmental Monitoring and

Protection

• Exploration and Production

• Fasteners

• Financial Services

• Governmental Services

• Information Technology

• Instruments and Control

• Logging and Formation Evaluation

• Logistics

• Lubricants

• Marine Equipment and Services

• Offshore Platforms

• Pipeline Coating Applicators

• Pollution and Spill Control

• Power Supply

• Process Equipment and Services

• Production

• Pump Equipment and Services

• Recruitment and Consultancy

• Safety Equipment and Systems

• Safety, Environmental Protection

& Regulatory Services

• Ships, Boats, Vessels and

Equipment

• Sponsor Societies

• Subsea

• Technical, Laboratory and

Computer Services

• Telecommunication Systems

• Thrusters

• Tools

• Trade Associations

• Transportation

• Tubulars and Piping

• Valves and Actuators

• Well Completion

• Waste Disposal

Exhibiting will provide opportunities to:

• Meet strategic decision makers face-to-face

• Increase brand awareness and build brand value

• Source new suppliers

• Build upon existing relationships and start new ones

Cost to Exhibit:

US $44.00 per sq. ft.

Corner or island booths: US $46.00 per sq. ft.

Book your space now! The 2012 exhibit hall fl oor was SOLD OUT and the event showed record attendance!

Subsea Tieback Exhibitors Receive:

• Exhibit space starts at 10’ x 10’ units

• Complimentary fl oor passes to distribute to your customers

and prospective clients

• One full conference registration for a member of your staff

per each 100 sq. ft. of booth space

• Two booth staff personnel passes per each 100 sq. ft.

of booth space

• Company and booth listing on the Subsea Tieback Forum

& Exhibition website

• 35 word/200 character listing in the Subsea Tieback Forum

& Exhibition show guide

• 50 word/300 character listing on the Subsea Tieback Forum

& Exhibition website

• Extensive event advertising in industry-leading magazines

including Oil and Gas Journal and Offshore

• Booth backdrop, side dividers and company identifi cation sign

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SUBSEA TIEBACK FOUNDATION & ANNUAL FUND RAISERS

Because of your help raising funds over the past 6 years and the work of a number of dedicated volunteers, the Subsea Tieback Foundation continues to grow and

deliver on its promise to inform, educate and introduce careers in the oil and gas industry, specifi c to offshore and subsea disciplines.

This growth is happening on numerous fronts including scholarships, educational and industry speakers programs, college senior design projects, and fundraising.

ABOUT THE FOUNDATION

The Subsea Tieback Foundation provides funds that are used for programs that raise awareness and promote careers in the subsea industry to students at

all levels. With the funds raised at these events, we provide scholarships for qualifi ed students as well as develop programs that bring together students

and subsea professionals in an environment that introduces the value and challenges of our industry, and a potential career in it. We are a non-compensated

group of volunteers and are registered as a 501(c), non-profi t entity. Further information can be found at: http://subseatiebackfoundation.org/

SUBSEA TIEBACK FOUNDATION GOLF TOURNAMENT

Date: Tuesday, March 5th, 2013

Location: The Quarry Golf Club

4444 East Basse Road, San Antonio, Texas 78209

Registration: http://www.subseatiebackgolf.com

Website: http://www.cccshooters.com

E-Mail: [email protected]

Times: 7:30 Registration / Breakfast

9:00 Shotgun Start

2:30 Lunch and Awards

SUBSEA TIEBACK FOUNDATION SPORTING CLAYS TOURNAMENT

Date: Tuesday, March 5th, 2013

Location: National Shooting Complex

5931 Roft Road San Antonio, Texas

Registration: http://www.stfsportingclays.com

Website: http://www.nssa-nsca.org/



9:00 On Station and Shooting


SUBSEA TIEBACK FOUNDATION THREE GUN SHOOT

Date: Saturday, February 23rd, 2013

Location: Cawthon Cartridge Club

Millican, Texas

LAT 30.42404 LON -96.24019

Registration: http://www.stf3gunshoot.com

Website: http://www.cccshooters.com



9:00 Shotgun Start


EXHIBIT

The Subsea Tieback Foundation will exhibit in San Antonio, sharing the results

of our efforts and our plans for the future. Please visit us at our booth and view

our completed SEATIGER exhibit; which has made numerous visits to schools

and events delivering our message.

FUND RAISER ACTIVITIES

This year there are three options to support our fundraising efforts:

The Subsea Tieback Foundation Golf Tournament, Three Gun Shoot and

Sporting Clays Tournament. Space is limited so be sure to visit the sites below

to register your participation.

Gather your customers and co-workers and join us for a fun day of golf, sporting clays, and/or three-gun competition.

For sponsorship information on these events, please contact Rosemary Abramson at [email protected].

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_______________________


http://subseatiebackfoundation.org/

http://www.nssa-nsca.org/

http://www.stfsportingclays.com

http://www.cccshooters.com

http://www.subseatiebackgolf.com

http://www.cccshooters.com

http://www.stf3gunshoot.com





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HOW IT WORKS:

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BENEFITS OF DIRECTEVENTCONNECT BEFORE ATTENDING THE EVENT:

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BENEFITS OF DIRECTEVENTCONNECT WHILE AT THE EVENT:

• Use your personalized floor plan to quickly direct you through the exhibition floor• Search for more companies, products and services onsite at the DirectEventConnect product locator

kiosks throughout the event• Reprint your customized floor plan from the onsite product locators or anywhere Internet is provided,

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BENEFITS OF DIRECTEVENTCONNECT AFTER THE EVENT:

• Follow-up with those exhibitors and fellow attendees that you met at the event• Connect with exhibitors and fellow attendees that you weren’t able to meet with onsite

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3M OIL & GAS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 873

A.P.P./E.P.I. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 422

ABCO SUBSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 476

ADVANCED TECHNOLOGY VALVES SPA . . . . . . . . . . . . . . . . . . 679

AFL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 577

AGITO CORPORATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 984

AIMS INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 584

AKER SUBSEA INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 601

ALLOY METALS & TUBES . . . . . . . . . . . . . . . . . . . . . . . . . . . . 435

AMETEK SOLARTRON ISA . . . . . . . . . . . . . . . . . . . . . . . . . . . 463

ASHTEAD TECHNOLOGY . . . . . . . . . . . . . . . . . . . . . . . . . . . 1006

AUDUBON ENGINEERING . . . . . . . . . . . . . . . . . . . . . . . . . . . 847

BAKER HUGHES INCORPORATED . . . . . . . . . . . . . . . . . . . . . . 653

BALMORAL OFFSHORE ENGINEERING . . . . . . . . . . . . . . . . . . 534

BASF CORPORATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 829

BAYOU WASCO INSULATION, LLC . . . . . . . . . . . . . . . . . . . . . 1022

BEL VALVES LTD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 473

BENESTAD AS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1007

BHP BILLITON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1130

BLUEVIEW TECHNOLOGIES INC . . . . . . . . . . . . . . . . . . . . . . . 937

BOA MARINE SERVICES INC. . . . . . . . . . . . . . . . . . . . . . . . . . 667

BORNEMANN PUMPS, INC . . . . . . . . . . . . . . . . . . . . . . . . . . . 953

BP CASTROL OFFSHORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . 439

BPP CABLES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 462

BPP-TECH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 461

BREDERO SHAW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 717

C & C TECHNOLOGIES, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . 475

CAMERON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 635

CDL INC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 817

CETCO OILFIELD SERVICES CO. . . . . . . . . . . . . . . . . . . . . . . . 426

CETIX AS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 776

C-INNOVATION LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 579

CLAMPON, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 835

CRC-EVANS PIPELINE INTERNATIONAL, INC . . . . . . . . . . . . 1017

CROSS GROUP INC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 613

CUMING CORPORATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 872

DAN-LOC BOLT & GASKET . . . . . . . . . . . . . . . . . . . . . . . . . . . 677

DEEP DOWN INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 841

DEEPFLEX INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 878

DEEPSEA TECHNOLOGIES . . . . . . . . . . . . . . . . . . . . . . . . . . . 441

DEEPWATER RENTAL AND SUPPLY . . . . . . . . . . . . . . . . . . . . . 567

DEUTSCH OFFSHORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 865

DOF SUBSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 805

DOW CORNING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 957

DOW HYPERLAST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 947

DOX-STEEL LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 368

DYNAMIC SEALING TECHNOLOGIES, INC . . . . . . . . . . . . . . . . 465

EATON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 946

EDG, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 573

EMAS AMC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 513

EMERSON PROCESS MANAGEMENT . . . . . . . . . . . . . . . . . . . 405

ENERMECH SERVICES LLC . . . . . . . . . . . . . . . . . . . . . . . . . . 773

EW FUEL MANAGEMENT LTD . . . . . . . . . . . . . . . . . . . . . . . . 1014

EXPRO AMERICAS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 423

FLOATEC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 801

FMC TECHNOLOGIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 501

FORUM ENERGY TECHNOLOGIES . . . . . . . . . . . . . . . . . . . . . . 539

FUGRO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 546

GATE, LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 564

GAUS ANODES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 451

GE OIL & GAS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 701

GENESIS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 522

GEOSPACE OFFSHORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 566

GEP-AFTP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1016

GL NOBLE DENTON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 967

GREENE’S WATER TREATMENT . . . . . . . . . . . . . . . . . . . . . . . 950

GRI SIMULATIONS INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 881

HALLIBURTON ENERGY SERVICES INC. . . . . . . . . . . . . . . . . 1009

HCL FASTENERS INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 972

HELIX ENERGY SOLUTIONS . . . . . . . . . . . . . . . . . . . . . . . . . . 629

HIGH PRESSURE EQUIPMENT COMPANY . . . . . . . . . . . . . . . . 900

HIMA AMERICAS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 939

HOERBIGER CORPORATION OF AMERICA, INC. . . . . . . . . . . . . 410

HOFFER FLOW CONTROLS . . . . . . . . . . . . . . . . . . . . . . . . . . . 780

HOLLOWAY HOUSTON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 816

HORIZON MARINE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 861

HOSE & FITTINGS INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 424

HOUGHTON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 408

HUNTING ENERGY SERVICES SUBSEA TECHNOLOGIES . . . . . 739

HYDRASUN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1038

HYDRATIGHT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 417

IMCA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 875

INFIELD SYSTEMS LIMITED . . . . . . . . . . . . . . . . . . . . . . . . . . 452

INTECSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 528

INTEGRA SERVICES TECHNOLOGIES INC. . . . . . . . . . . . . . . . 453

INTERMOOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 661

ITP INTERPIPE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 440

JP KENNY, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 561

KNIGHTHAWK ENGINEERING . . . . . . . . . . . . . . . . . . . . . . . . 420

KONGSBERG OIL & GAS TECHNOLOGIES . . . . . . . . . . . . . . . . 411

LANKHORST MOULDINGS . . . . . . . . . . . . . . . . . . . . . . . . . . . 853

LONE STAR-WALKER BOLT . . . . . . . . . . . . . . . . . . . . . . . . . . . 427

LTS ENERGY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 940

MACARTNEY INC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 915

2013 EXHIBITOR LIST (AS OF NOVEMBER 8, 2012)

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MACDERMID OFFSHORE SOLUTIONS . . . . . . . . . . . . . . . . . . . 922

MANATEE, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 772

MASTER FLO VALVE (USA), INC . . . . . . . . . . . . . . . . . . . . . . . 774

MCDERMOTT SUBSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 553

MODUSPEC USA, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1117

MOOG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 479

NATIONAL OILWELL VARCO . . . . . . . . . . . . . . . . . . . . . . . . . . 485

NAUTRONIX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 917

NEXANS/NORTECH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 907

NICHE PRODUCTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 404

NYLACAST LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 472

OCCUPATIONAL SAFETY TRAINING, INC. . . . . . . . . . . . . . . . . 477

OCEANEERING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 647

OCEANOS JSC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 929

OCEANWORKS INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . 429

OIL STATES INDUSTRIES, INC. . . . . . . . . . . . . . . . . . . . . . . . . 623

OIL STATES INDUSTRIES, INC. . . . . . . . . . . . . . . . . . . . . . . . . 623

OMB OFFSHORE APPLICATIONS LTD . . . . . . . . . . . . . . . . . . . 885

OMNISENS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 926

OMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 918

PACSON VALVES LIMITED . . . . . . . . . . . . . . . . . . . . . . . . . . . 961

PARKER HANNIFIN, ENERGY PRODUCTS DIVISION . . . . . . . . 760

PCC ENERGY GROUP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1101

PCC ENERGY GROUP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1105

PENNWELL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 784

PERMA-PIPE OIL & GAS/THE BAYOU COMPANIES . . . . . . . . . . 428

PHOENIX INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . . . . 884

PPI TECHNOLOGY SERVICES . . . . . . . . . . . . . . . . . . . . . . . . 1028

PRAXAIR SURFACE TECHNOLOGIES . . . . . . . . . . . . . . . . . . . 1008

PREVCO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1137

PROSERV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1037

QATAR AIRWAYS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 586

QUALITY CONNECTOR SYSTEMS LLC . . . . . . . . . . . . . . . . . . . 867

QUEST OFFSHORE RESOURCES . . . . . . . . . . . . . . . . . . . . . . 1128

RADOIL, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 767

REMOTE OCEAN SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . 933

ROVSCO, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 901

RPSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 450

RTI ENERGY SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 550

SAAB SEAEYE LTD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 676

SAMSON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 680

SANDVIK MATERIALS TECHNOLOGY . . . . . . . . . . . . . . . . . . . . 980

SCANA INDUSTRIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 928

SCHLUMBERGER SUBSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . 531

SEABOTIX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 464

SEACON . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 444

SEAL-TITE INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . . . 839

SEANIC OCEAN SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . 400

SEATREPID INTERNATIONAL, LLC . . . . . . . . . . . . . . . . . . . . . 777

SECC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 877

SERIMAX . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 672

SIDUS SOLUTIONS LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 478

SIEMENS AG . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 761

SIEMENS SUBSEA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 811

SKOFLO INDUSTRIES, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . 952

SMD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 753

SOCOTHERM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1029

SONARDYNE INC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 673

SPIR STAR, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 438

SPITZER INDUSTRIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 964

SPT ENERGY GROUP, LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . 442

SPT GROUP, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 560

SPX BOLTING SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 578

STRESS ENGINEERING SERVICES . . . . . . . . . . . . . . . . . . . . . 934

SUBSEA 7 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 723

SUBSEA TECHNOLOGIES INC./ TRITECH INTERNATIONAL LTD . . 474

SURF SUBSEA, INC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 876

T.D. WILLIAMSON, INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1036

TECHNIP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 523

TELEDYNE OIL & GAS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 538

TENARIS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 747

TITANIUM ENGINEERS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 851

TRACERCO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 572

TRELLEBORG OFFSHORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . 552

TRENDSETTER ENGINEERING INC. . . . . . . . . . . . . . . . . . . . . 823

T-REX ENGINEERING & CONSTRUCTION . . . . . . . . . . . . . . . . 447

TUBACEX – SCHOELLER BLECKMANN EDELSTAHLROHR . . . . 778

ULTRA DEEP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 879

UMBILICALS INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . 576

UNITECH INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . . . . 938

UNIVERSALPEGASUS INTERNATIONAL, INC . . . . . . . . . . . . . . 766

UTEC SURVEY INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 526

VECTOR GROUP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 547

VEOLIA ES- MARINE DIVISION . . . . . . . . . . . . . . . . . . . . . . . 1015

VERSABAR INC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 731

VFL ENERGY TECHNOLOGIES . . . . . . . . . . . . . . . . . . . . . . . . 779

VIV SOLUTIONS LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 785

WACHS SUBSEA, LLC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 434

WALTHER PRÄEZISION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 412

WEATHERFORD INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . 713

WFI INTERNATIONAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 448

WHITEFIELD PLASTICS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 960

ZETECHTICS LTD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 905

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ATTENDEE REGISTRATION FORM




Registration confirmation will be sent via-email, if a unique email address is provided above.

First Name: _____________________________________________________ Last Name: _________________________________________________

Title/Position: _____________________________________________________________________________________________________________

Company: ________________________________________________________________________________________________________________

Address: _________________________________________________________________________________________________________________

City/State/Zip: _________________________________________________ Country: __________________________ Postal Code: _______________

Telephone: ______________________________________________________ Fax: ______________________________________________________

Email: ____________________________________________________________________________________________________________________

1. Type of Company or Organization ��02 Major Oil & Gas Operating Company ��03 Independent Oil & Gas Company��04 National/State Oil Company ��07 Drilling/Drilling Contractor��51 Consulting Company Engaged in Projects or Providing Services to Oil and/or Gas Companies��09 EPC (Engineering/Procurement/Construction) Main Contractor��08 Subcontractor ��10 Seismic Company��29 Pipeline/Installation Contractor��37 Supply Company

3. Areas Of Interest/Involvement��60 Exploration/Seismic/Formation Evaluation Equipment Sales��61 Drilling Rigs & Rig Equipment��62 Drilling Contractor Services ��63 Downhole Drilling Tools/Coiled Tubing/Muds & Chemicals/Well Maintenance Equipment & Services��64 Cementing/Well Completion/Stimulation Equipment Sales��65 Subsea Production Equipment & Services

Type of Company or Organization - cont.��41 Marine Support Services��36 Equipment Manufacturing Company��38 Service Company��11 Ship/Fabrication Yard��12 Insurance or Financial Services��13 Educational Institution/Government Agency/Research Laboratory��98 Other (specify) __________________

Areas Of Interest/Involvement - cont.��66 Surface Production Equipment & Services��67 Motors/Engines/Pumps/Compressors/Turbines/Generators��68 Automation Systems/Instruments & Control/Valves & Accessories/Safety Equipment��69 Marine Transportation/Construction Equipment & Services��70 Mooring and Station Keeping Equipment & Services

2. Job Function:��40 Executive Management (CEO, President, Owner, VP, Managing Director, etc.)��41 Management (Production Manager, Engineering Manager, Exploration Manager)��39 Engineering ��43 Field Professional (Superintendent, Foreman, Assistant Foreman, Toolpusher)��45 Purchasing (Purchasing Agent, Purchasing Manager)��48 Consulting ��46 Geology or Geophysics ��47 Other (specify) ________________________

Areas Of Interest/Involvement - cont.��71 IT/Computer Hardware/Software Equipment & Services��72 Financial/Insurance/General Business Services��73 Other (specify) ________________________ ��99 None of the above

4. Purchasing Role: ��Specify ��Recommend ��Approve ��Purchase ��None

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For information on corporate packages contact Cary Shipley

Phone +1 918 831 9160Email: [email protected]

Conference Fees:1. Individual Delegate (Full Conference Registration)*

Includes:� Access to all Conference Sessions� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast & Coffee Breaks� Delegate Lunch on Wednesday and Thursday (Ticketed)

��Paid By February 1, 2013 .................................... US$ 895��Paid After February 1, 2013 ............................... US$ 995

2. Corporate Plan (5 delegates)Includes:� Access to all Conference Sessions� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast & Coffee Breaks� Delegate Lunch on Wednesday and Thursday (Ticketed)

��Paid By February 1, 2013 .................................... US$ 3,565��Paid After February 1, 2013, ............................. US$ 4,000

Corporate Plan (6 to 10 delegates��Paid By February 1, 2013 .................................... US$ 6,685��Paid After February 1, 2013 ............................... US$ 7,500

3. Exhibitor DelegateIncludes:

� � Access to all Conference Sessions� Access to the Exhibition Hall, including move-in and move-out � Access to Opening & Networking Receptions� Continental Breakfast & Coffee Breaks� Delegate Lunch on Wednesday and Thursday (Ticketed)


4. Season Pass (Full Conference Registration)*Includes:�� !��"�� #�!��%��'��;� Two Events ...........................................................US$ 1,050

Topsides, Platforms & HullsSubsea Tieback

5. ��Student Conference Delegate ........................... US$ 95Includes:� Access to all Conference Sessions� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast & Coffee Breaks in Exhibition Hall� Delegate Lunch on Wednesday and Thursday (Ticketed)

6. Single Day Conference Delegate (Wednesday OR Thursday)Includes:� Access to Conference Sessions on the corresponding day� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast & Coffee Breaks� Luncheon on corresponding day (Ticketed)

��Wednesday, Paid By February 1, 2013 ........... US$ 615��Wednesday, Paid After February 1, 2013 ...... US$ 725��Thursday, Paid By February 1, 2013 ................ US$ 615��Thursday, Paid After February 1, 2013 ........... US$ 725

7. ��Exhibit Visitor........................................................... US$ 50Includes:� Access to Opening Session� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast & Coffee Breaks

8. ��SUT Workshop (Registrant Only)Includes:� Access to the SUT Workshop on March 5, 2013 only� Continental Breakfast, Lunch & Coffee Breaks for the Workshop��<"��!�=>!��=�?��!�G�"��


9. Combined Individual Delegate and SUT Workshop*Includes:� Access to all Conference Sessions� Access to the Exhibition Hall, including Opening & Networking Receptions� Continental Breakfast, Lunch & Coffee Breaks for the Workshop� Access to the SUT Workshop on March 5, 2013

��Paid By February 1, 2013 .................................... US$ 1,325��Paid After February 1, 2013 ............................... US$ 1,425

10. ASME Workshop (Registrant Only)Includes:� Continental Breakfast, Lunch & Coffee Breaks for the Workshop� Access to the ASME Workshop on designated day��<"��!�=>!��=�?��!�G�"��

One Day Workshops - Tuesday, March 5, 2013Fundamentals Of Deepwater Riser Engineering


Fundamentals Of Deepwater Project Development��Paid By February 1, 2013 .................................... US$ 500��Paid After February 1, 2013 ............................... US$ 600

Subsea Pipeline Design Overview��Paid By February 1, 2013 .................................... US$ 500��Paid After February 1, 2013 ............................... US$ 600

11. Additional Lunch Tickets (for non-delegates) ��Wednesday................................................... ( ) @ US$ 35/day��Thursday........................................................ ( ) @ US$ 35/day

4 ways to register:

1

Fax:Direct: +1 918 831 9161

Toll-Free (US only): +1 888 299 8057

2

Website:www.subseatiebackforum.com

3

Mail:PennWell C&E Registration (SSTB)

P.O. Box 973059Dallas, TX 75397-3059 USA

4

E-Mail:[email protected]

For questions please call:Phone: +1 918 831 9160

Toll Free (US only): +1 888 299 8016

*Your full-price registration fee includes a one-year paid subscription to Oil & Gas Journal (US$ 69.00 value).

Payment must be received prior to the conference.If payment is not received by the conference date, the registration fee must be guaranteed on charge card until proof of payment is provided. Make check payable to PennWell/Subsea Tieback 2013.

Cancellation: Cancellation of registration must be received in writing. Any individual, exhibitor, or corporate registrations cancelled before February 1, 2013 will receive a 50% refund of registration fee. After February 1, 2013, no refunds will be permitted. Substitutions may be made at any time by contacting the registration office.

Due to the deeply discounted rate of the Season Pass, refunds due to cancellations will not be issued. Substitute attendees may be sent to subsequent events if attendee is unable to attend.

Expiration Date:

Method of Payment: ��Check enclosed (in U.S. funds only) ��Wire (Wire information will be provided on invoice)

Credit Card: ��Visa ��Mastercard ��AMEX ��Discover

Full Name (as it appears on card): ________________________________________________________

Card Holder Signature: ________________________________________________ Date: _______________

(Required for credit card payment)

Credit Card Number:

TOTAL PAYMENT AMOUNT = US$ ____________


ATTENDEE REGISTRATION FORM




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HOTEL REGISTRATION FORM





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HOTEL REGISTRATION FORM





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http://www.preferred1.com/reservations





HEADERHEADER


Connect with us through Social Media to findout more about PennWell’s Offshore and OGJ Events

For further information please visit

www.offshoreoilevents.com or www.ogjevents.com

2013 GLOBAL PETROLEUM EVENTS CALENDAR

Energy burns at the root of PennWell’s history. First printing our fl agship publication

—the Oil & Gas Journal—in 1902, our petroleum division covers the topics, issues, challenges

and solutions most critical to the international petroleum industry. With a network of global

events located throughout the world, PennWell collectively reaches more than 135,000 petroleum

professionals in 75 countries, providing unparalleled reach of the international petroleum market.

Offshore Middle East

Conference & Exhibition

January 21-23, 2013

Doha, Qatar

www.offshoremiddleeast.com

Strategies in Heavy Oil Conference

January 23-24, 2013

Galveston, Texas, USA

www.heavyoilstrategies.com

S T R A T E G I E S

IN HEAVY OIL TM

Topsides, Platforms & Hulls


February 5-7, 2013

Galveston, Texas USA

www.topsidesevent.com

Subsea Tieback

Forum & Exhibition

March 5-7, 2013

San Antonio, Texas USA

www.subseatiebackforum.com

Offshore Asia


March 6-8, 2013

Kuala Lumpur, Malaysia

www.offshoreasiaevent.com

Offshore West Africa


March 19-21, 2013

Accra, Ghana

www.offshorewestafrica.com

Oil Sands and

Heavy Oil Technologies


July 23-25, 2013

Calgary, Alberta, Canada

www.oilsandstechnologies.com

PetroWorld India


August 22-24, 2013

Mumbai, India

www.petroworldindia.com

Deep Offshore

Technology International


October 22-24, 2013

The Woodlands, Texas USA

www.deepoffshoretechnology.com

Deepwater Operations


November 5-7, 1013

Galveston, Texas USA

www.deepwateroperations.com

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http://www.ogjevents.com

http://www.offshoreoilevents.com

http://www.deepwateroperations.com


http://www.deepoffshoretechnology.com


http://www.petroworldindia.com

http://www.topsidesevent.com

http://www.oilsandstechnologies.com

http://www.heavyoilstrategies.com


http://www.offshoremiddleeast.com





EVENT CONTACTS

OFFSHORE GROUP PUBLISHER AND VICE PRESIDENT:

Mark Peters

1455 W. Loop South, Suite 400

Houston, TX 77027

Phone: +1 713 963 6260


MANAGING EDITOR, OFFSHORE MAGAZINE:

Bruce Beaubouef

Phone: +1 713 963 6290

Fax: +1 713 963 6201


CONFERENCE MANAGER:

Gail Killough

Phone: +1 713 963 6251

Fax: +1 713 963 6201


SENIOR EVENT OPERATIONS MANAGER:

Jennifer Lindsey, CMP

Phone: +1 918 832 9313

Fax: +1 918 831 9729


EXHIBIT SERVICE COORDINATOR:

Michael Donnell

Phone: +1 918 831 9707

Fax: +1 918 831 9729


SENIOR EVENT MARKETING MANAGER:

Jennifer McPhail

Phone: +1 918 831 9701

Fax: +1 918 831 9729


EXHIBIT & SPONSORSHIP SALES:

Peter Cantu

United States

Phone: +1 713 963 6213

Fax: +1 713 963 6212

Mobile: +1 713 503 2451


Sara Lowery Ng

United States

Phone: +1 713 963 6277

Cell: +1 713 725 8536

Fax: +1 713 963 6212


Jane Bailey

Northern Europe & Middle East

Phone: +44 1992 656 651

Mobile: 07983 388 367


Tony B. Moyo

Europe, Middle East & Africa

Phone: +44 1992 656 658

Mobile: +44 798 522 9324


REGISTRATION DEPARTMENT:

Direct Phone: +1 918 831 9160

Direct Fax: +1 918 831 9161

Toll Free Phone: +1 888 299 8016

Toll Free Fax: +1 888 299 8057

PENNWELL CORPORATE HEADQUARTERS

1421 S. Sheridan Road

Tulsa, OK 74112

Phone: +1 918 835 3161

Fax: +1 713 963 6270

Web: www.subseatiebackforum.com

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PRSRT STDUS POSTAGE

PAIDWOODSTOCK ILPERMIT # 60

Subsea Tieback Forum & Exhibition

1421 South Sheridan Road

Tulsa, OK 74112

Please use this code when registering:


We Offer 4 WaysTo Register

Online:


Mail:

PennWell C&E Registration (SSTB)

P.O. Box 973059

Dallas, TX 75397-3059 USA

Fax:

+1 918 831 9161

Toll-free (US only): +1 888 299 8057

Email:

[email protected]

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Documents

OM Feb 2013