1

2

3

4

5

6

Manaus

Rosario

Cordoba

Sao Paulo

Curitiba

Porto Alegre

Salvador

Belo Horizonte

Rio de Janeiro

Fortaleza

Recife

Equator

Tropic of Capricorn

Alagoas

Amapá

Amazonas

Bahia

Ceará

Distrito

Federal

Espírito

Santo

Goiás

Mato Grosso

do Sul

Minas Gerais

Mato Grosso

Maranhão

Paraíba

Paraná

Pará

Piauí

Pernambuco

Rio de Janeiro

Rio Grandedo Norte

Rio Grande

do Sul

Rondônia

Roraima

Santa Catarina

São Paulo

SergipeTocantins

FrenchGuiana

Co

lom

bia

Suriname

GuyanaVenezuela

Bolivia

Paraguay

Argentina

Uruguay

Montevideo

Brasilia

Buenos Aires

T

Brazil Offshore Oil & Gas MapBlocks

Blocks

Exploration Licences

Production Licences

Oil

Gas

Oil & Gas

Proposed Pipeline

Capital City

Major Town

Oil

Gas

Terminals

Licence blocks courtesy of the ANP, Brazil - www.anp.gov.br

Fields

Terminals

Pipelines Abbreviations

Cities

ANADARKOBRAZALTA

DEVON ENERGYDONG

GRAN TIERRA ENERGYOGX PETROLEO

PETROBRASPETROGAL

PETROSYNERGYPOTILEO

QUANQUEIROZ

SILVER MARLINSONANGOL STARFISH

STATOILSTRATUS

WASHINGTONVIPETRO

ANADBRAZDEVONDONGGTEOGXPETRAPETROGALPETSYNPOTILEOQUANQUIRSILMARSTARSTATSTRATWASHVIP

DENTAO

GUAIUBA

UBARANA

SALEMABRANC

GUAJA

AGULHA

SIRIARATUM

SERRA

PITIGUARISALINACRIST

GUAMARE

ICAPUI

FAZENDABELEM

POCINHO

MONTEALEGRE

ESTREITO

SERRARIA

CANTODO AMA

PONTA DO MEL

BIQUARA

CIOBA

MACAU

PEDRA SENTADA

ARACARI

BOA VISTA

MORRINHO

REDONDA

NORESTE DOMORRO ROSADO

CHOPIM

FAZENDACANAAN

PAJEU

JANDUI

SABIA

PINTASSILGO

BARRINHALESTE

ACAUA LESTE

BARRINHASUDOESTE

FAZENDACURRAL

RIO MOSSORO

FAZENDAMALAQUIAS

BAIXA DO ALGODAO

RIACHODA FORQUILHA

BOAESPERANCA

ASABRANCA

LESTE DE POCO XAVIER

POCO XAVIER

VARGINHA

LIVRAMENTO CACHOEIRINHA

BAIXA DO JUAZEIRO

PERIQUITO

PARDALLORENA

PERIQUITOUPANEMA

BREJINHO

VARZEA REDONDA

JACANA

TRESMARIAS

ROLINHA

TRINCA-FERRO

ANDORINHA

ALTO DORODRIGUES

PORTOCARAO

ARABAIANA

PESCADA

OESTE DE UBARANA

PORTOCARAO

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA PETRA

UTC

UTC

PETRA

PETROGAL

PETRA

KOCH

KOCH

PETRA

AURIZONIA

PETSYN

PETROGAL

PETRA

PETROGAL

PETRA

PETRA

PARTEX

PARTEX PETRAPETROGAL PETSYN

PARTEXPARTEX

PARTEX

PETRA

PETRA

AURIZONIA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETROGAL PETRA PETRASTAR

STAR

STAR

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

BM-POT-11

BM-POT-13

BM-POT-13

BT-POT-4

BT-POT-8

POT-M-853 POT-M-855

BT-POT-10

BT-POT-10

BT-POT-8

POT-T-440

POT-T-488

POT-T-612

POT-T-619

POT-T-656

POT-T-705

POT-T-302

POT-T-352

POT-T-394

POT-T-436

POT-T-478

POT-T-479

POT-T-480

POT-T-513

POT-T-514 POT-T-520

POT-T-521POT-T-528

POT-T-557

POT-T-558

POT-T-559

POT-T-661

POT-T-700

DENTAO

ARABAIANAPESCADA

GUAIUBA

POT-T-609

POT-T-610

POT-T-699

POT-T-743 POT-T-744POT-T-745POT-T-748

POT-T-749

SALEMABRANC

GUAJA

SIRI

UBARANA

SALINA CRIST

SERRA

GUAMARE

FAZ POCINHO

MONTE

ALEGREALTO DO RODR

PAJEU

ACAUA

RIACHO DA FO

SERRARIA

PONTA DO MEL

NO MORRO ROS

CANTO DO AMA

MOSSORO

BT-POT-9

Ceará

Rio Grande do Norte

1

TIGRE

ALAGAMAR

ROBALO

POZ DOVAZA BARRIS

DOURADO

GUARICEMA

CAMORIM

TARTARUGA

ARUARI

ANGELIM

CARMOPOLISSUDOESTE

CASTANHAL

SIRIRIZINHOOESTE

RIACHUELO

AGUILHADA

CIDADEDE ARACUJA

CAIOBA

ILHA PEQUENA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETROGAL

PETROGAL

PETRA

PETRA

SEVERO

UP

PETRA

PETRA

PETRA

PETRA

PETRA

PETRONAS

RAL

PETRA

PETRA

PETRASTAR

ALVOPETRO

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

BM-SEAL-4

BM-SEAL-9

GUARICEMA

CAMORIM

SEAL-T-391

SEAL-T-412

SEAL-T-429

SEAL-T-410

TARTARUGA

CARMOPOLIS

SIRIRIZINHO

RIACHUELO

CAMORIMSEAL-T-462

SIRIRIZINHO

SEAL-T-391SEAL-T-391

SEAL-T-410

SEAL-T-390

SEAL-T-390

Sergipe

2

FAZENDAALVORADA

FAZENDABALSAMORIO SUBAUMA

RIO SAUIPE

JURITI

FAZENDAIMBE

BOM LUGAR

ARACAS

LAGOA DO PAULO

FAZENDAONCA

SUSSUARANA

FAZENDASANTO ESTEVAO

BURACICA

JAD

SAOPEDRO

TICO-TICO

FAZENDAPANELAS

CASSARONGONGOAGUA

GRANDE

TAQUIPE

NORTECARUACU

GUANAMBI

MARITACA

CEXIS MAPELE

DOMJOAO

DOM JOAOMAR

ACAJA

LAGOA VERDE

GAMELEIRAPOJUCANORTE

PEDRINHAS

FADENZASORI

RIACHO SAO PEDRO

JACUIPE

RIO JOANESMASSUI

ARATU

NORTEDE IRAI

LAGOA BRANCA

IRAI

MATINHA

ITAPARICA

GTESTAR

ALVORADAALVORADA

GTE ALVORADA

GTE ALVORADA COWAN

IMETAME STAR BRAZ

ALVORADA PETSYN

ALVORADA ALVORADA

IMETAME

GTE

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

ALVOPETRO

PETRA

PETRA

EGESA

PETRA

PETRA

PETRA

RONCONCAVO

RONCONCAVO

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

SANTANA

PETRA

PETRA PETRAPETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRASTAR

PETRA

PETRA

RONCONCAVO

REC-T-129REC-T-130

REC-T-131REC-T-132

REC-T-142 REC-T-144

REC-T-155 REC-T-157 REC-T-158

REC-T-163 REC-T-166REC-T-170

REC-T-182REC-T-183

REC-T-196 REC-T-197

REC-T-211

REC-T-224

REC-T-265

REC-T-181

BALSAMO

REC-T-139

CEXIS

REC-T-250

NORTE

DE IRAI

LAGOA BRANCA

MATINHA

REC-T-265

BT-REC-7

REC-T-195

Bahia

3 CORREGO CEDRO NORTE-SUL

RIO SAO MATEUS OESTE

JACUTINGA

RIO PRETO SUL

CORREGO DAS PEDRAS

INHAMBU

NATIVO OESTE

SAIRA

MOSQUITONORTE

MOSQIUTO

ALBATROZ

FAZENDAQUEIMADAS

CAMPOGRANDE

CORREGODOURADO

BARRA DOIPIRANGA

LAGOABONITA

RIO IBIRIBAS

CORRUIRARIO BARRA SECA

LAGOA SURUACA

CACAO

JACUPEMBA

FAZENDASAO JORGE

CANCA

FAZENDA SAO RAFAEL

FAZENDA SANTA LUZIA

RIO IPIRANGA

CACIMBAS

RIO DOCELAGOA PARDA NORTE

LAGOA PARDA SUL

LAGOA PARDA

BIGUA

SAO MATEUS LESTE

MARIRICU NORTE

VIP VIP

VIP

PETRA

PETRA

PETRA PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

CHEIMPETRA

PETRA

PETRA

PETRA

PETRA PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETROSYNERGY

CENTRAL

PETRAPETRA

ES-T-

391ES-T-

392

ES-T-466

CACAO

ES-M-411

ES-M-436 ES-M-437

BIGUA

INHAMBU

NATIVO

OESTE

ALEGRE

CEDRO

SAO JORLAGOA

SURUAC

BARRA

DO IPI

TABUIAIASAO RAF

RIO

IPIRANGA

LAC PARDA

RIO SAO MATE

ES-T-383

Espírito

Santo

4

PAPA-TERRAMAROMBA

CARATAI

PEREGRINO

POLVO

CARAPICU

PAMPO

LINGUADO TRILHA

ENCHOVA

MARIMBA

CORVINA

CHERNE

CONGRO

CARATINGA

BARARCUDA

MARLIM SUL

MARLIM LESTE

ANEQUIM

GAROUPA NORDESTE

CARAPEBA

VERMELHOALBACORA

ALBACORALESTE

FRADE

RONCADOR

CAXAREU

PIRAMBU

BALEIA AZUL NAUTILUS

JUBARTE

CACHALOTE

CATUA

BICUDO

BONITO

PIRAUNA

ESPADARTE

BIJUPIRA

SALEMA

BAGRE NAMORADO

VOADOR

PARGO

ARGONAUTA

XERELETE

GUARAJUBA

ESPADARTE SUL

PARATI

OSTRA

ABALONE

GUARAJUBA

ARUANA

BALEIABICUDA

BALEIA FRANCA

BALEIA ANA

MOREIA

PETRA

STAT

ANAD

BP

PETRA

ANAD

BP BP

YPF

PETRA

PETRA

PETRA

PETRA

STAT

PETRA

SHELL

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

SHELL

SHELL

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

BP

OGX

OGX

STAR OGX

STAT

OGX

OGX

OGX

PETRA

OGX OGX STAR

PETRA

PETRA PETRA PETRA

PETRA

SHELL

PETRA

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

CHEVRON

PETRA

SHELL

TOTAL

PETRA PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

SHELL

PETRA

PETRAC-M-530

C-M-101

C-M-61

BMC-31

C-M-202

C-M-471 C-M-473

C-M-403

C-M-401

BM-C-14

BM-C-7

LINGUADO

ESPARDARTE

MARLIM

MARLIM SUL

ALBACORA

LESTE

ALBACORA

PARATI

RONCADOR

CATUA

OSTRA

ABALONE

BM-C-25

C-M-119C-M-120

C-M-145

C-M-146

C-M-333

BADERO

POLVO

C-M-466

C-M-498 C-M-499

C-M-529C-M-535

C-M-539

C-M-560

C-M-591

C-M-592

C-M-593

C-M-620 C-M-621C-M-622

C-M-78

C-M-95 C-M-96 C-M-98

MARIMBA

FRADE

JUBARTE

NAUTILUS

VIOALA

234

ARGONAUTA

Rio deJaneiro

5

TAMBUATA

CARAMBA AZULAO SANTOS GUARANI

ABARE OESTE

GUARABEM-TE-VI

CARIOCA

LULA

LULA ALTO

IRACEMA

IARA

IGUAZU

PARATI

TAMBAU

URUGUA

PIRAPITANGA

JUPITER

MEXILHAO

CARAPIA

S-M-405

S-M-623

BM-S-24BM-S-11

BM-S-11

BM-S-9

BM-S-09

GUARA SUL

BM-S-10

BM-S-8

BM-S-21

TUPI NE

FRANCO

S-M-1127

S-M-226

S-M-239

S-M-268 S-M-270

S-M-314

S-M-322

S-M-324

S-M-415

S-M-619

TAMBUATA

BS-400

PETRA

PETRA

PETRA

PETRA

PETRAPETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

PETRA

OGX

PETRA

OGX OGX

OGX

PETRA

PETRA

PETRA

PETRA

QUEIROZ

QUEIROZ

PETRA PETRA

PETRA

PETRA

PETRA

6

©Copyright Offshore Magazine 2013

2013 Oil and Gas Concession Map

BRAZIL

Map Data Content – provided by Infeld Systems Limited, London©Infeld Systems Limited, All Rights Reserved

www.infield.com

oil | gas | marine | renewables

•Data & Project Database

•Market Forecast Reports

•Online Mapping & GIS

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Try Infield’s online oil & gas mapping site: www.offshoreenergygateway.com

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1307off_Brazilmap_1 1 6/28/13 3:59 PM

July 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:

Brazil

map a

nd jack

up

drillin

g rig p

oster

Mediterranean update

Drilling rig report

Deepwater intervention

Shipyard capabilities

Brazil/Latin America review

1307off_C1 1 6/28/13 2:01 PM

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A quick start guide to MAXIMIZING our interactive features.Welcome to the Digital Edition of

SHARE an article or page via social media.

Click PAGES to view thumbnails of each page and browse

through the entire issue.

Easily browse all BACK ISSUES.

SEARCH for specific articles or content.

View the table of CONTENTS and easily navigate directly to an article.

DOWNLOAD the issue to your desktop.

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Offshore drilling requires a strategy, especially in

today’s environment where the wrong move can be

more costly than ever. That’s why the first move should

be to look for a company with worldwide

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1307off_3 3 6/28/13 2:12 PM

International EditionVolume 73, Number 7

July 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

LATIN AMERICA REPORT

As exploration heats up, Latin American nations refne offshore regulations ..... 34While Brazil is expected to continue to lead the region’s offshore development, oil and gas exploration is expanding across Latin America. The authors present an overview of the regula-tory environments for the oil and gas industry in selected Latin American nations.

Mexico’s rig renaissance gets under way ................................... 38Mexico is one of the 10 largest oil producers in the world and the third-largest in the Western Hemisphere. While it remains a leader, Mexico faces declining domestic production. Reserve estimates in the country are high, but without increased investment, the country’s huge resources will remain in the ground.

Brazil prepares for the industry’s biggest presalt auction ...................... 42 The record $1.4 billion raised in signing bo-nuses from the Brazil Petroleum Agency’s 11th oil and gas licensing round in May marked a successful conclusion to the frst offshore con-cession issue in Brazil since 2007. However, that fgure is likely to pale against the amounts involved as the world’s biggest oil and gas companies compete for acreage in Brazil’s frst auction of presalt operating licenses scheduled for October.

OFFSHORE

MEDITERRANEAN

Mediterranean Sea plays offer new opportunities ...................... 44In April 2010, the US Geological Survey esti-mated 122 tcf of recoverable natural gas in the eastern-most part of the Mediterranean Sea (the Levant or Levantine basin), more than the world consumes in a year. If this and other esti-mates are correct, these offshore natural gas and oil deposits may play the deus ex machina to the current Greek drama.

RIG REPORT

Deepwater rig feet continues to expand ........................... 50The world’s deepwater drilling rig feet continues to grow in order to meet opera-tors’ increasing demands for rigs capable of drilling wells to deeper depths, operating in ever greater water depths, and having them equipped with the newest technologies and safety features.

Rig construction continues to focus on higher-spec units ............ 52Shipyards that build offshore drilling rigs continue to stay busy with new construction projects. Worldwide, 131 jackups, semisub-mersibles, drillships and tender-assisted units are under construction, and another 81 units are on order at shipyards awaiting construc-tion commencement.

2013 Worldwide MODU construction/new order survey ................................ 54Get the latest detailed and comprehensive list-ing of the worldwide mobile offshore drilling units under construction.

Regional demand spurs steady growth of premium jackup feet ..................... 58In the two years since Offshore’s last premium jackup rig survey, the offshore drilling indus-try has steadily added to its global feet, and all indications point to this trend continuing. However, demand for high-specifcation rigs capable of operating in depths of 350 ft (106 m) or greater and able to drill to depths of at least 25,000 ft (7,600 m) varies substantially by region.

GEOLOGY & GEOPHYSICS

Wide-tow seismic survey sets the pace for frontier exploration ........ 60When it comes to surveying large areas of frontier exploration acreage in limited windows of opportunity, seismic operators are required to think big and move fast. Dolphin Geophysical took this approach to fresh extremes in the Atlantic Ocean offshore South Africa, mobilizing the “world’s largest foating object” on behalf of client Shell.

DRILLING & COMPLETION

Tender-assist semi supports spars, TLPs in wider deepwater regions ...... 64 Singapore-based Energy Drilling has ordered three newbuild tender rigs from COSCO Shipyard in Guangdong, China. Two are barges, while the third – EDrill-3 – will be the frst tender-assist semisubmersible based on GustoMSC’s OCEAN400-TD design. The com-pany aims to be the leading provider of tender drilling solutions.

Research aims to rein in mooring installation costs ............. 66Like all aspects of ultra-deepwater exploration and production, mooring presents extraordi-nary challenges, both to engineers and to the people who hold the purse strings. In many cases, particularly in the Gulf of Mexico, the cost of deploying a mooring system has caught up to or exceeded the price of the equipment that composes the mooring system itself.

ENGINEERING,

CONSTRUCTION,

& INSTALLATION

Offshore oil and gas backlogs easing shipyard overcapacity ............ 68While global shipyard output took a big hit with the recent fnancial crisis, the industry appears to be regaining momentum, largely driven by the oil and gas business. A recent analysis by the Denmark-based shipping as-sociation BIMCO described a “soft landing” for the shipyard industry after a wave of order cancellations, delays, and postponements put the brakes on output.

38

1307off_4 4 6/28/13 2:13 PM

†Mark of M-I L.L.C

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† ultra-HT non-aqueous drilling fluid system is the industry’s first drilling fluid

proven to deliver stable rheological performance at bottomhole static temperatures (BHST)

greater than 500°F (260°C).

An operator in the Gulf of Thailand’s ‘Ring of Fire’ used the RHADIANT drilling fluid system

to efficiently drill a high-angle well with a BHST of 432°F (222°C) with zero lost circulation.

A total of seven open-hole logging runs were then performed, all with excellent results.

RHADIANTUltra-high temperature

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1307off_5 5 6/28/13 2:13 PM

6 Offshore July 2013 • www.offshore-mag.com

International EditionVolume 73, Number 7

July 2013

D E P A R T M E N T S

PRODUCTION OPERATIONS

Technology trends seek to reduce the cost of subsea well interventions ............... 70In a large sense, the world’s thirst for abundant supplies of cheap, clean-burning energy continues

to grow. The good news is that despite deepwater complexity, risks and challenges, the value of the

prize exceeds the costs to produce it. The cost of interventions has stimulated considerable innova-

tion on the part of offshore producers and service companies to forestall or eliminate them.

Island Offshore fnding new roles for subsea LWI vessels ....................................... 74Island Offshore management’s decision to commit to light well intervention in subsea wells a

decade ago is proving far-sighted. The company now has three dedicated LWI vessels in full

employment, with more feld operators looking to reap the benefts of maintaining their subsea

wells in good order.

SUBSEA

Fault tolerant, hot swappable subsea control architecture can improve reliability ....... 78Subsea control system architectural concepts can be designed to increase reliability and avail-

ability. Failure of a single subsea electronic module does not have to shut down production nor

does it have to reduce the safety integrity level of the system.

Employing a dynamic approach to fow assurance modeling .................................. 82Computational fuid dynamics can combine with traditional pipeline modeling software to

improve detail and speed of both applications for accurate fow assurance modeling. While

computational powers at present may limit the ability to use CFD across an entire system, this

technology will play an increasingly important role in fow assurance.

COVER: National and international

oil companies are stepping up their

offshore E&P activities throughout Latin

America, particularly in Brazil, where

Petrobras recently acquired 34 blocks

in the Brazil Petroleum Agency’s 11th oil

and gas licensing round. Even before that

licensing round, Sevan Drilling’s Sevan

Brasil semisubmersible drilling rig (cover)

had received a six-year contract from

Petrobras. But while Brazil is expected

to continue to lead the region’s offshore

development, oil and gas exploration is

expanding across Latin America, with

offshore activities on the rise in Mexico,

Colombia, Peru, Chile, and Argentina.

(Photo courtesy Sevan Drilling ASA)

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

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

Data ..................................................... 12

Global E&P .......................................... 14

Offshore Europe .................................. 20

Gulf of Mexico ..................................... 22

Subsea Systems ................................. 24

Vessels, Rigs, & Surface Systems ...... 26

Drilling & Production .......................... 28

Geosciences ........................................ 30

Offshore Automation Solutions .......... 32

Business Briefs ................................... 86

Advertisers’ Index ............................... 91

Beyond the Horizon ............................ 92

1307off_6 6 6/28/13 2:13 PM

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1307off_7 7 6/28/13 2:13 PM

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

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

technology, companies, personnel moves, and products.

New Videos➤ Shell Olympus

The hull for Shell’s Olympus TLP, centerpiece of the Mars B development in the Gulf of Mexico, was built by Samsung Heavy Industries in South Korea and arrived in Ingleside, Texas in January 2013.

The topsides for the Olympus TLP were installed at the Kiewit Offshore Ser-vices yard in Ingleside. The TLP was scheduled to sail out for the Mars feld in late June 2013.

http://www.offshore-mag.com/topics/video-index

New webcast➤ Deepwater Environments: New Requirements

for Premium Connection TechnologiesAs ultra-deepwater exploration and production activities become a reality,

the bar has been raised for premium connection technologies. When designing deepwater wells, a WCD scenario must be analyzed, using methodologies such as the well containment screening tool. The derived new and more extreme load cases need to be considered for connection design. Turning to risers, today fa-tigue resistance is an absolute must. Find out how Tenaris’ product engineering team is partnering with customers to take on these challenges.

http://www.offshore-mag.com/webcasts/offshore/ 2013/06/deepwater-environments.html

New maps, posters, and surveys • 2013 Worldwide MODU Construction/New Order Survey• 2013 Jackup Drilling Rig Poster• 2013 Brazil Oil and Gas Concession Map • 2013 World Survey of Stimulation Vessels• 2013 Deepwater Solutions and Records for Concept Selection

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

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

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Submit an article Offshore magazine accepts editorial contributions. To submit an article, please

review the guidelines posted on our website by following the link below.www.offshore-mag.com/index/about-us/article-submission.html

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COMMENT David Paganie • Houston

World’s largest undeveloped discovery for sale

The world’s largest undeveloped discovery, Libra, will be up for bid this October in Brazil’s unprecedented presalt bid round. Aside from the fscal parameters and full-feld appraisal, Brazil’s National Petroleum Agency (ANP) anticipates that the data available from seismic surveys of Libra and analogous discoveries will be suffcient to draw inter-national investors. An independent evaluation by Gaffney, Cline & Associates suggests the feld could hold 4-15 Bbbl of recoverable resources. The best estimate is about 8 Bbbl of oil. Full feld development of the 727-sq km (281-sq mi) area could require at least 10 FPSOs and 200 wells, according to estimates from IHS. The government, however, is moving to a production-sharing framework for the presalt blocks from a concession-based approach that was followed in May’s auction and drew $1.4 billion in signing bonuses. A total of 30 domestic and in-ternational oil and gas companies were awarded 87 onshore and 55 offshore blocks in Brazil’s 11th bid round. Under the new system, the bonus payments and local content requirements will be fxed, and it will be the percentage of proft oil that companies are prepared to sign over to the government that will determine the success of the bids. And the current law requires Petrobras to be the principal operator and 30% minimum stakeholder in the blocks up for auction. Will the increasing regulatory risk, local content require-ments, and government take deter foreign investment in the upcoming lease sale? Will geological data trump fscal terms? A recent industry note by Raymond James calls the Santos basin’s presalt reserves “best in class” among other prominent deepwater areas. That was the conclusion of an economic analysis of the infationary pressures on select deepwater projects in the US Gulf of Mexico, Brazil, and West Africa. These and other pressing issues are explored in our annual Latin America report, beginning on page 34.

The fnal scope of the presalt lease sale is expected to be available to the public this month. For more information, visit www.anp.gov.br.

Rig construction trendsThe global rig construction feet continues to grow as operators seek newer, higher-

spec equipment. According to Offshore’s annual MODU rig construction survey, pro-duced by IHS Petrodata, 131 rigs (37 drillships, 11 semis, 75 jackups, and eight tender-assisted) are under construction and an additional 81 units are on order. Since last year’s survey, 81 rigs have been ordered with the majority being premium jackups rated for 350-ft (107 m) water depth or more. Meanwhile, the older jackups in the global feet are being retired. During the past year, nine jackups left the feet with hulls built between 1975 and 1983. As of June of this year, there are 289 jackups with a year-in-service date of 1983 or earlier. In a special report for Offshore, Cinnamon Odell, IHS Petrodata, discusses these and the other changes in the annual rig construction survey. Odell also reviews the evolution and growth of the deepwater feet, citing trends in the preference of drillships versus semis, deeper water-depth rated rigs, and DP-capable units. The global supply of deepwater rigs has more than doubled during the past 10 years, from 86 in May 2003 to 204 units as of May 2013. Odell’s comprehensive analysis of the global drilling rig feet and accompanying survey begins on page 50.

Libra

1307off_10 10 6/28/13 2:13 PM

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1307off_11 11 6/28/13 2:13 PM

Worldwide offshore rig count & utilization rate

June 2011 – May 2013

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

%

June 1

1

Sept 11

Dec

11

Marc

h 12

June 1

2

Sept 12

Dec

12

Marc

h13

Contracted fleet utilization Total fleet Contracted Working

Sourc

e: IH

S

Latin America capital expenditures (%) 2008-2017 by country

100

90

80

70

60

50

40

30

20

10

0

Puerto Rico

Falkland Islands

Argentina

Brazil

Uruguay

Peru

Trinidad

Jamaica

Chile

Venezuela

Guyane (French Guiana)

Colombia

Mexcio

2008

Source: Infield Systems Ltd.

2009 2010 2011 2012 2013 2014 2015 2016 2017

US

$m

(%

)

Worldwide day rates

Year/Month Minimum Average Maximum

Drillship

2012 June $50,000 $434,143 $671,000

2012 July $50,000 $438,241 $671,000

2012 Aug $50,000 $442,866 $671,000

2012 Sept $50,000 $429,988 $671,000

2012 Oct $50,000 $429,548 $674,000

2012 Nov $50,000 $429,852 $674,000

2012 Dec $50,000 $441,340 $674,000

2013 Jan $50,000 $434,808 $674,000

2013 Feb $50,000 $449,225 $674,000

2013 Mar $50,000 $444,548 $674,000

2013 Apr $50,000 $451,860 $674,000

2013 May $50,000 $456,792 $674,000

Jackup

2012 June $36,000 $110,715 $368,000

2012 July $30,000 $111,427 $368,000

2012 Aug $40,000 $111,458 $368,000

2012 Sept $40,000 $111,845 $368,000

2012 Oct $30,000 $112,271 $368,000

2012 Nov $30,000 $114,614 $368,000

2012 Dec $30,000 $115,377 $368,000

2013 Jan $30,000 $118,351 $368,000

2013 Feb $30,000 $119,352 $368,000

2013 Mar $30,000 $120,289 $368,000

2013 Apr $30,000 $119,412 $368,000

2013 May $30,000 $121,822 $368,000

Semi

2012 June $125,000 $359,570 $648,000

2012 July $69,825 $354,158 $675,000

2012 Aug $69,825 $360,852 $675,000

2012 Sept $130,000 $358,061 $675,000

2012 Oct $130,000 $358,166 $648,000

2012 Nov $130,000 $363,193 $648,000

2012 Dec $130,000 $364,446 $648,000

2013 Jan $145,000 $363,643 $648,000

2013 Feb $145,000 $361,572 $648,000

2013 Mar $145,000 $363,044 $648,000

2013 Apr $145,000 $372,647 $648,000

2013 May $145,000 $380,095 $648,000

Source: Rigzone.com

G L O B A L D ATA

12 Offshore July 2013 • www.offshore-mag.com

Offshore development in Latin America is expected to remain dominated by Brazil until the end of the decade. Infield Systems expects 86% of the regional offshore capital expenditure to be attributed to Brazil-ian developments between 2013 and 2017. Operator Petrobras is anticipated to account for an 89% share of the market with key projects including the Lula and Franco multi-phase developments. Infield Systems expects the largest proportion of the operator’s capex to be directed toward the subsea market, with pipeline developments also forecast to demand a significant share of the operator’s investment. An additional 10 operators are expected to direct capex offshore Brazil going forward to 2017. Anadarko and OGX-EBX Group are expected to lead investment during the period on fields including Wahoo and the Waimea/Fuji develop-ment for the respective operators. In terms of water depth of developments offshore Latin America, 64% of total capital expenditure is expected to take place

in water depths of 1,500 m (4,921 ft) or greater. Brazil’s presalt prospects are expected to continue to lead the market for deep and ultra-deepwater development.

Elsewhere, capital expenditure is expected to take place across 12 additional countries. Mexico, Venezuela, and Trinidad are forecast to be the largest markets outside of Brazil for offshore develop-ment. The most significant investment is expected on the Ayatsil, Lakach, and Noxal fields offshore Mexico during the period. Offshore Venezuela, capex is likely to be directed toward 13 fields. Offshore Trinidad is also expected to have 13 fields require investment during the period, with key operators anticipated to include BG Group, BHP Billiton, and Centrica.

– Catarina Podevyn, Analyst, Infield Systems Ltd.

1307off_12 12 6/28/13 2:13 PM

© 2

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

14 Offshore July 2013 • www.offshore-mag.com

Lekoil has farmed into OPL 310 offshore Nigeria.

Eastern Canada

Husky Energy is pushing ahead with a third satellite extension at the White Rose feld in the Jeanne d’Arc basin, 350 km (217 mi) offshore Newfoundland and Labrador. The company is targeting 20 MMbbl of oil from South White Rose via a subsea tieback to the Sea Rose FPSO. Following regulatory approval, development will now include gas injection for enhanced oil recovery. Technip will install the fowlines, umbilicals, and as-sociated subsea structures with start-up scheduled for 2014. Husky also plans to fle a development application for West White Rose following completion of front-end engi-neering design (FEED).

To the south, EnCana may fnally have brought onstream its Deep Panuke gas feld, 250 km (155 mi) southeast of Halifax, Nova Scotia. SBM provided the mobile offshore production unit following a protracted con-struction delay. The gas will be processed offshore and sent via a subsea pipeline to Goldboro for onward transport through the Maritimes & Northeast Pipeline.

South America

ONGC has won an exploration block off-shore Colombia, assigned under the coun-try’s 2012 bid round. The company has a 100% interest in the Guaoff-2 concession in the Guajira basin.

•••

Peru has launched an international bid round for nine blocks in the Salaverry-Trujil-lo, Lima, Lima-Pisco, Pisco, and Mollendo ba-sins. All are 7 mi (11.2 km) from the coast and away from the protected fshing zone, and cover some of the country’s least explored geological areas. State company Perupetro said there had been enquiries from oil com-panies in North and South America, Russia, South Korea, and the UK; awards should fol-low on Oct. 17. Currently there is production on two Peruvian offshore licenses, operated by Savia Perù and BPZ Energy, respectively.

•••

Brazil’s much anticipated 11th bid round fnally closed. Petrobras, as might be ex-pected, was the biggest winner, paying a total of $454 million for interests in 34 of the 289 blocks on offer. Those with the greatest exploratory potential, the company said, are in the offshore Foz do Amazonas, Espírito Santo, and Barreirinhas basins.

Other big winners included Total, which secured shares in 10 licenses, including fve as operator in the Foz do Amazonas basin. BP picked up stakes in eight deepwater blocks, two as operator, while Statoil operates four of its six new licenses in the Espírito Santo basin, all close to two existing concessions where it is in partnership with Petrobras. Among the successful newcomers is UK in-

dependent Premier Oil, which gained stakes in three blocks off northeast Brazil.

•••

Petrobras has started production from Cidade de Paraty, the second FPSO on the Lula feld in block BM-S-11 in the presalt Santos basin. By the second half of 2014 as gas reinjection systems are commissioned, the facility should be operating at its full ca-pacity, delivering 120,000 b/d of oil and 176 MMcf/d of gas.

Elsewhere in this region, Petrobras has discovered oil with the Entorno de Iara 1 well, drilled 235 km (146 mi) offshore Rio de Janeiro state in 2,266 m (7,434 ft) of water. Wire test samples confrmed 26° API crude from good-quality carbonate reservoirs just below the salt layer at a depth of 5,045 m (16,252 ft). Petrobras plans to follow up with a formation test and another well in the area.

West Africa

Ghana’s government has approved the development plan for the country’s second deepwater production hub. The Tweneboa-Enyenra-Ntomme (TEN) felds are 30 km (18.6 mi) west of the Jubilee feld in the Deepwater Tano contract area, 60 km (37 mi) from the coast. Up to 24 wells will be drilled, connected via subsea facilities to an FPSO moored in 1,500 m (4,921 ft) of water and producing 80,000 b/d of oil at peak. Op-erator Tullow Oil says the partners will use the project to expand Ghana’s fabrication ca-pability. Start-up is scheduled for 2016.

•••

Lekoil has agreed to farm into 17.4% of li-cense OPL 310 offshore Nigeria from Afren. Optimum Petroleum Development operates the license, located in the Upper Cretaceous fairway that runs along the West African Transform Margin. The GSF Transocean Monitor was recently drilling an exploration

well targeting Ogo, a four-way dip-closed structure in Turonian to Albian sandstone reservoirs; a side track was due to follow. Total resources could be over 200 MMboe.

•••

Noble Energy has found oil with a side track of its Carla South I-7 well in block I offshore Equatorial Guinea. According to partner PA Resources, analysis suggests 9-11 m (29-36 ft) of net oil pay in good-quality sandstones.

•••

EurOil has proven more gas and conden-sate with its latest appraisal/development well (IM-5) in the Etinde concession off Cameroon. Production tests from two reser-voir intervals in the Middle and Intra Isongo formations yielded combined fow rates of up to 60 MMcf/d of gas and 7,819 b/d of condensate. EurOil’s parent company Bow-leven now estimates in-place volumes at the IM feld at 155 MMbbl and 1.05 tcf.

•••

Frontier drilling is picking up pace in the southern half of West Africa. The Ocean Rig Olympia recently spudded Diaman No. 1, Ga-bon’s frst presalt deepwater exploration well, for partners Total and Cobalt International Energy. Offshore Namibia, the semisub Trans-ocean Marianas is drilling Murombe-1, HRT’s second exploratory well on license PEL-23 in the deepwater Walvis basin. Wingat-1, the pre-ceding well drilled 15 km (9.3 mi) to the east, recovered samples of light oil and established two different source rocks. Murombe-1 is test-ing two objectives within a turbidite complex.

Mediterranean Sea

Energean Oil & Gas has secured $60 mil-lion in funds for a four-well program offshore Greece, aimed at doubling oil production from the Prinos and South Kavalos areas to 4,000 b/d by year-end. The money will also be used for development of the 32-MMbbl Epsilon

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G L O B A L E & P

structure next year via an unmanned platform connected to the main Prinos production facili-ties.

•••

Offshore Cyprus, the Noble Energy-led block 12 consortium agreed to drill an ap-praisal well on the deepwater Aphrodite gas discovery. Budget for the well, estimated to take four months to complete, is $117 mil-lion, according to partner Delek Drilling.

Additionally, Noble and its partners have confrmed a ffth deepwater gas fnd with re-serves of over 1 tcf in the Israeli Levantine ba-sin. Karish 1 was drilled in 1,740 m (5,700 ft) of water in the Alon C license, 20 mi (32 km) northeast of the Tamar feld, which came on-stream in April. The well encountered 184 ft (56 m) of gas pay in lower Miocene sands.

•••

Two ambitious independents have agreed to farm-in deals offshore Tunisia. EnQuest will take a 70% operating interest in PA Re-sources’ assets, which include the producing Didon oil feld and the planned Zarat feld development. And DNO is set to take from Atlas Petroleum and Eurgas International an 87.5% controlling interest in the shallow water Sfax and Ras El Besh concessions in the Gulf of Gabes. They contain three oil discoveries and 29 prospects with combined prospective resources of up to 700 MMbbl.

Indian Ocean Afren has completed the frst 3D seismic

surveys offshore the Seychelles in areas A and B. These covered a total of 3,375 sq km (1,302 sq mi) on the northern and southern portions of the license, including the Bonit prospect. Evaluation is under way in combi-nation with existing 2D data to assess Ter-tiary, Cretaceous, and Jurassic prospectivity. Offshore Madagascar, Chinese contractor BGP has completed a 2D multi-client survey over the west Morondova region, which will be the focus of an upcoming bid round.

IndiaReliance Industries and partners BP and

NIKO have discovered gas and condensate in the D-55 structure offshore eastern India. The KGD6-MJ1 well was drilled in 1,024 m (3,360 ft) of water, and over 2,000 m (6,562 ft) below producing reservoirs in the D1-D3 gas felds. Analysis suggests the well inter-sected a 155-m (509-ft) gas/condensate col-umn in Mesozoic reservoirs. The partners plan a follow-up appraisal program.

Asia/PacifcRosneft and INPEX will jointly explore

the Magadan-2 and Magadan-3 blocks in the Sea of Okhotsk off northern Russia. Wa-ter depths range from 120-180 m (393-590 ft), with potential recoverable resources of

1307off_16 16 6/28/13 2:13 PM

1307off_17 17 6/28/13 2:13 PM

Australia

Statoil partner

Eucla

Canyon

0 100 km

G L O B A L E & P

1.577 MM metric tons of oil equivalent (1.738 MM tons). The two companies will form a joint venture for the explora-tion program, with INPEX paying Rosneft bonuses for any commercial discoveries.

The 42,780-metric ton (47,157-ton) platform topsides for Exxon Neftegaz’ Arkutun-Dagi feld off Sakhalin Island was due to sail out of DSME’s yard in South Korea. In readiness for the trans-portation, ALE used its Mega Jack sys-tem to jack the topsides in four sets of towers to a height of 24 m (79 ft). The operation was completed in 11 hours and in wind speeds of up to 50 m/s (164 ft/s).

•••

Thang Long Joint Operating Co. (TL-JOC) has started oil production from the Hai Su Trang and Hai Su Den (HST/HSD) felds off southern Vietnam. Both are in 45 m (147 ft) of water in block 15-2/01 in the Cuu Long basin, 75 km (46.6 mi) offshore.

PetroVietnam subsidiary PTSC Mechanical and Construction built the two wellhead platforms; six wells have been drilled, with produc-tion sent by pipeline to the Te Giac Trang FPSO.

•••

Shell has contracted Royal Boskalis Westminster to install a deple-tion compression platform off Palawan Island in the Philippines. The facility will be bridge-linked to the existing gas production platform on the Malampaya feld. Boskalis’ scope extends to seabed prepa-

ration, tow out of the platform to the offshore location, and placement of iron ore gravel ballast on the four platform footings following installation to ensure stability. All work should be completed by late 2014.

Australasia

Statoil has agreed to farm into 30% of four licenses operated by BP offshore South Australia. EPP 37, 38, 39, and 40 cover 24,000 sq km (9,266 sq mi) in the Ceduna sub-basin within the Great Aus-tralian Bight. BP is currently processing a new 12,000-sq km (4,633-sq mi) 3D seismic survey over the license area, and has signed a three-year contract with Diamond Offshore for a new Moss CS60E design harsh environment semi for the drilling program. Hyundai Heavy Industries will build the 10,000-ft (3,048-

m) water depth DP rig at a projected cost of $755 million. It should become available after November 2015.

•••

Total has discovered gas in the Browse basin off northwest Aus-tralia. The Bassett-1 well was drilled in 368 m (1,207 ft) of water in license WA-274P, 475 km (295 mi) northeast of Broome. Logs con-frmed 7.5 m (24.6 ft) of gas pay in Jurassic sandstones on the struc-ture’s western fank. After the well is P&A’d, the partners planned to drill Dufresne-1 in the same license. •

BP’s exploration licenses

offshore South Australia.

1307off_18 18 6/28/13 2:13 PM

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

20 Offshore July 2013 • www.offshore-mag.com

Barents Sea dominates latest Norway license round

Statoil’s oil discoveries in the Barents Sea ensured a strong re-sponse to Norway’s frontier 22nd licensing round. The Petroleum and Energy Ministry has issued 20 new licenses in the Barents Sea and four in the Norwegian Sea to a total of 29 companies.

All Statoil’s awards were in the Barents Sea. Its three operated licenses were PL713 in the Bjørnøya basin; PL6158 in the Hoop area, close to an existing license where the company plans to drill two exploration wells in 2014; and PL714, adjacent to the Johan Castberg license, which includes the Skrugard and Havis oilfelds.

New operators in the Barents Sea include Centrica, ConocoPhil-lips, Edison, GDF Suez, RWE Dea and Shell, while Det norske Olje-selskap, Eni, Lundin, Repsol, and Total expanded their interests in the region. Lundin’s award was in the southeast of the sector, which has been opened up following resolution of Norway’s long-running median line demarcation dispute with neighbors Russia. And two of Russia’s leading oil companies, Lukoil and Rosneft, made their debuts as licensees offshore Norway with stakes in Barents Sea blocks.

However, Statoil wants to put on hold an investment decision on the Johan Castberg development, following the government’s planned pe-troleum tax review. The company and partners Eni and Petoro had selected a concept earlier this year for the project, 240 km (149 mi) northwest of Hammerfest in northern Norway. This included build-ing a new oil terminal at Veidnes in Finnmark County. There is uncer-tainty now over whether the construction would qualify for state aid, as was the case with the LNG terminal nearby in Melkoya, which was built to process gas from the offshore Snøhvit felds.

Irish frontier survey under wayIreland’s government has approved the country’s largest regional

offshore seismic survey to date, over the Atlantic Margin off the west coast. The BGP Explorer vessel is performing the 18,000-km (11,184-mi) full-fold 2D program, managed by Eni Ireland in co-operation with the Department of Communications, Energy and Natural Resources. The 145-day campaign is designed to infll data gaps, particularly over the southern Porcupine, Rockall, and Hatton basins, drawing in more bidders for future licensing rounds.

Minister Pat Rabbitte, speaking earlier in a parliamentary debate about a new Joint Committee report on Ireland’s offshore oil and gas exploration, said the country had to deal with realities. The country remains under-explored, he pointed out, with only 156 wells drilled offshore compared with over 1,200 offshore Norway and 4,000 in the UK. Norway is the world’s second largest gas exporter and sev-enth largest oil explorer, while Ireland imports over 95% of its gas and 100% of its oil. And the country has only three felds in produc-tion compared with over 300 in the UK. So more needs to be done, he said, to increase Irish exploration investment and drilling.

However, the report recommends a doubling of Ireland’s existing tax rate on petroleum production, based partly on sustained high oil prices and the impact of advances in technology on exploration success rates worldwide. Neither of these factors gives Ireland a competitive advantage over other areas, Rabbitte said, and without exploratory drilling, the country will have no discoveries. Technol-ogy helps, but only wells produce results, he added.

Statoil contracts purpose-designed jackupsStatoil has commissioned three new “Category J” harsh-environ-

ment jackups for development drilling in the North Sea. Samsung Heavy Industries will build two of the rigs in South Korea, to be operated by KCA Deutag on the Gullfaks and Oseberg Area felds in the Norwegian sector. They will be designed to provide more ef-fcient drilling and completion of subsea wells compared with exist-ing jackups, Statoil says, and to drill wells up to 10,000 m (32,808 ft)

deep. Offshore operations should start in 2016-17.Noble Corp. will manage the drilling contract for the third new

jackup for the heavy oil Mariner feld development in the UK north-ern North Sea. This rig, to be built by Jurong Shipyard in Singapore, will be an enhanced version of Statoil’s Cat J specifcations, devised originally for operations over a very large platform or for subsea drilling in the Norwegian sector. It will be equipped to deploy either a surface or subsea BOP during drilling.

CNR invites views on platform removalCNR International has started the public consultation on its plans

for decommissioning the Murchison platform and pipelines in the UK northern North Sea. The Murchison feld, which also extends into Norwegian waters, is due to cease production early next year. Facilities that may have to be removed include the 24,500-metric ton (27,006-ton) topsides of the platform, installed in 1979 150 km (93 mi) northeast of the Shetland Islands; however, CNR may seek the UK government’s help in applying to leave the steel footings in place on the seafoor because of the structure’s large size, via derogation status under the OSPAR convention.

More positive news concerns Ninian, another elderly platform complex in the UK far north. Here CNR plans to invest $470 mil-lion in life extension measures for the Ninian feld, after success-fully applying for the UK’s Brownfeld Allowance. The government introduced this scheme last year following pressure from numerous operators – it provides tax relief on certain felds already in produc-tion, allowing incremental projects to go forward that might other-wise be uneconomic. CNR plans to drill four new producer wells and four injectors on Ninian, along with various platform/well upgrades. These measures could allow a further 27 MMboe to be produced.

Elsewhere in this sector, Maersk Oil has restarted production through the Gryphon Alpha FPSO, which had to be removed from its offshore location following storm damage in February 2011. Four anchor chains broke, causing the vessel to move off station. The FPSO was transferred to the Damen shipyard in Rotterdam for over-haul/upgrade work on its tanks, process control, power manage-ment, and mooring systems.

In the intervening period, Maersk acquired a 4D seismic survey over the wider Gryphon area, and assumed operatorship from BP of Maclure, one of four felds produced via the foater. Once all the felds are fully operational, combined production should exceed 20,000 boe/d, and Maersk plans a high level of drilling activity over the next few years based on results from the new seismic. Within seven years it aims to double its overall UK production to 80-100,000 boe/d. •

Cat J rig example.

1307off_20 20 6/28/13 2:13 PM

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1307off_21 21 6/28/13 2:13 PM

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

22 Offshore July 2013 • www.offshore-mag.com

Shell preps Olympus TLP for Mars B installation

The major topsides modules were in-stalled on the Olympus tension leg platform (TLP) as Shell prepared to tow the 120,000-ton structure from Kiewit Offshore Services yard to the deepwater Mars feld.

During a June 5 tour of the TLP – said to be the largest ever deployed in the Gulf of Mexico – Shell offcials said the project will be the frst in the region to employ an ad-ditional foating production system in a pro-ducing deepwater feld.

“This is the frst time in the Gulf of Mex-ico that a company has built another host structure to go in an existing feld,” rather than using subsea tiebacks to expand a feld, said John Hollowell, Shell’s executive vice president for deepwater.

The Olympus platform will be moored in 3,000-ft (914-m) water depths in the Missis-sippi Canyon area, about one mi (1.6 km) from the existing Mars platform, which started production in 1996. The new TLP hosts a 24-slot drilling unit supplied by Na-bors Industries and includes capacity for six subsea wells to gather production from the nearby West Boreas and South Diemos felds. Olympus has a production capacity of about 100,000 boe/d.

Noble Corp.’s Noble Bully I has drilled the top sections of the 24 wells at what Shell has dubbed Mars B, and is on location to drill the satellite wells at West Boreas and South Diemos.

The project is expected to extend the feld life of Mars to at least 2050, Hollowell said. Shell has said the feld could contain recover-able reserves of 1.1 Bboe. Shell operates the feld with 71.5% interest; partner BP holds the remaining 28.5% interest.

When Olympus begins production, likely in the frst half of 2014, the focus of the ex-isting Mars production platform will shift to the feld’s shallower reservoirs and to water injection. Olympus, outftted with 15,000 psi-rated trees furnished by FMC Technologies, will concentrate on high-pressure reservoirs that range in depth from 20,000-22,000 ft.

Shell will install a third platform at its West Delta 143 gathering hub to link production from Mars B with existing pipeline infrastructure.

Heerema’s Balder deepwater construction vessel will be used to install the TLP.

EIA sees greater disruptions in upcoming storm season

The US Energy Information Administra-tion says it expects greater losses in GoM oil and natural gas production from tropical storms this year than was seen in 2012.

As reported by Reuters, the EIA said that in a study, the median loss in Gulf of Mexico crude oil production from tropical storms in 2013 was expected be 19.3 MMbbl, up from 14.3 MMbbl in 2012.

The EIA expects a median loss of 46.4 bcf in natural gas output due to the 13 to 20 named storms forecast by the US National Oceanic and Atmospheric Administration for the six-month 2013 Atlantic hurricane season, which began June 1.

The 19 named storms in the 2012 hurri-cane season accounted for 32.1 bcf in lost natural gas production, the EIA said.

Last year’s season was one of the milder ones to hit US energy production. The total number of named storms was seven above av-erage, but only three tropical storms and two moderate hurricanes came through the Gulf.

The EIA also said the percentage of na-

tional crude oil and natural gas production provided by the US-regulated areas in the northern GoM has shrunk in recent years as onshore production has increased.

In 2012, the Gulf provided 19% of crude oil production, down from 26% in the 2007-2011 period. In 2012, the Gulf accounted for 6% of natural gas output, compared to 26% in 1997, according to the EIA.

The Gulf produces 1.3 MMbbl/d of crude oil, according to the EIA. In 2011, 1.7 tcf/d in natural gas came from the Gulf.

The amount of shut-in production depends on the intensity of a storm and the path it takes across production areas, according to the EIA.

For example, 2012’s Hurricane Sandy, which struck the US East Coast, had no impact on Gulf production. But 2008’s major Hurricane Gustav, which came ashore in Louisiana after passing through the heart of the Gulf’s offshore oil patch, shut 98% of Gulf oil production and 96% of natural gas output.

Exxon awards Julia feld contracts

Exxon Mobil Corp. has awarded feld de-velopment contracts for its Julia feld in the deepwater Gulf of Mexico, with 2H Offshore winning a production riser design contract and Technip winning a deepwater pipelay contract.

The Julia development will be a subsea tieback to a moored semisubmersible in ap-proximately 7,000 ft (2,134 m) of water.

2H Offshore will perform detailed design of two 10-in. production steel catenary risers to use in Phase 1.

Technip will provide project management, engineering, fabrication, installation, and pre-commissioning of more than 48 km (30 mi) of 10.75-in. (27.3-cm) outer diameter insulated fowlines, steel catenary risers, and fowline end terminations.

Technip’s Houston center will provide proj-ect management, with detailed fowline design by Genesis, fowline and riser fabrication in Mobile, Alabama, and installation in 2015 us-ing the Deep Blue pipelay vessel.

Hess taps Wood Group for platform services

Hess Corp. has awarded a fve-year contract to Wood Group PSM (WGPSN) for operations and maintenance services to the Baldpate produc-tion platform in the deepwater Gulf of Mexico.

The company will also provide these servic-es to Hess for the Tubular Bells and Stampede deepwater facilities when they go onstream in the Mississippi Canyon and Green Canyon ar-eas of the GoM.

WGPSN will develop a computerized main-tenance management system to track the main-tenance and repair of rotating equipment and maintenance parts. They will also manage the inventory of engineering parts. •

Shell’s Olympus tension leg platform for the Mars B project will be moored in 3,000-ft (914-m) water

depths in the Mississippi Canyon area, about one mile from the existing Mars platform. (Photo

courtesy Shell)

1307off_22 22 6/28/13 2:13 PM

1307off_23 23 6/28/13 2:13 PM

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

24 Offshore July 2013 • www.offshore-mag.com

GoM gets rush of subsea equipment orders

Anadarko Petroleum Corp. has ordered subsea hardware for its Heidelberg feld in the Gulf of Mexico from FMC Technologies Inc. FMC will supply fve enhanced hori-zontal subsea trees, tree mounted controls, two manifolds, and other associated tooling and equipment. The Heidelberg feld covers fve Green Canyon blocks in water depths of 5,310 ft (1,618 m). Anadarko also has award-ed Subsea 7 the Heidelberg pipelay contract covering fabrication and installation of ris-ers, pipelines, and fowlines.

Also in the GoM, ExxonMobil has award-ed a $100-million contract to Prysmian Group for the supply and installation of sub-

marine cables in a section of ExxonMobil’s existing offshore operations. Prysmian will replace 50 km (31 mi) of existing submarine power cables with increased capacity 40 kV EPR cables designed for water depths of up to 450 m (1,476 ft). The cables will supply electric power from an existing shore-based generating plant to offshore platforms. The Cable Enterprise vessel will undergo modif-cations in 2014 to become a fully dynamical-ly positioned vessel in order to do the work.

Further south in the Gulf, PEMEX Ex-ploration and Production has signed an $84-million agreement with GE Oil & Gas to supply and install subsea wellheads in deep and ultra-deepwater drilling projects. GE will supply SMS800 and DWHC 700 high-capacity

wellheads; similar GE technology is installed at several other Mexican oil felds, including Perdido, Lakach, and Kunah. Perdido is in water depths of 500 m (1,640 ft) or more. Ku-nah is 125 km (78 mi) northeast of Veracruz in 2,157 m (7,077 ft) water depth. Lakach is in about 988 m (3,241 ft) of water.

Shell has contracted FMC Technologies to supply subsea equipment for the Stones ultra-deepwater project in the Gulf of Mex-ico. The Stones feld is in the Walker Ridge area, about 200 mi (322 km) off the Louisi-ana coast in about 9,600 ft (2,926 m) of water. FMC Technologies’ scope of supply includes eight subsea trees, a subsea manifold, top-side and subsea controls, and associated equipment. Shell plans to develop Stones us-ing an FPSO and subsea infrastructure with eight production wells ultimately tied back to the vessel. Tankers will take the oil to shore and the gas will go via pipeline.

Technip inaugurates subsea Innovation and Technology Center

Technip has inaugurated its Innovation and Technology Center in Rueil-Malmaison, France. The facility opens with more than 50 subsea specialists on staff and is charged to manage Technip’s technology development and to coordinate relevant research and de-velopment centers.

“This new site builds upon our strategic efforts in terms of technology: it is a real showcase of our technological achieve-ments – starting with subsea – targeted at our clients and partners,” said Alain Mar-ion, senior vice president, Innovation and Technology and director of the center. “Its actions will draw on important and regular investments, as well as on Technip’s R&D breakthroughs over the past few years.” •

Deepwater subsea spending to continue growingInfield Systems latest edition of its “Global Perspectives Subsea Market Report To

2017” says high oil prices, technological developments, and declining production in

mature shallow-water basins are driving offshore oil and gas operations into deep

and ultra-deep waters. Operators increasingly target reservoirs over a wider area

than before, using subsea tiebacks to both fixed platforms in shallow waters or to

floating infrastructure in deeper waters.

The report predicts that these operating circumstances will result in capital-intensive

ultra-deepwater developments that will capture 48% of capex and 23% of tree installa-

tions in 2013-2017, in contrast to 37% of capex and 15% of installations in 2008-2012.

Latin America and West Africa account for more than half of the subsea capex ex-

pected between 2013 and 2017. This is driven by large deepwater and ultra-deepwater

discoveries offshore Brazil, particularly in the presalt basins, and offshore Angola

and the Gulf of Guinea.

The US shift from shallow water toward large discoveries further offshore is well

under way. The deepwater Gulf of Mexico is expected to host many new floating

platform developments, combined with the tieback of subsea satellite fields later on

in the forecast period.

Europe remains an area of opportunity, with drilling activity in producing fields and

subsea tiebacks for small, remote reserves.

New large gas discoveries in the last five years in the eastern Mediterranean are

driving subsea investments in the Middle East. Asia, Australasia, and the Middle East

present emerging opportunities for the subsea market. These three regions will to-

gether increase their market share from 8% in 2008-2012 to 15% in the next five years.

The Marine Well Containment Co. (MWCC) now has available a 10k psi capping stack for use in the deepwater U.S. Gulf of Mexico. It joins the 15k psi stack already available. The capping stack stands 25 ft (7.6 m) tall, including the necessary lifting gear, and weighs 50 tons. In support of MWCC, Shell agreed to lead the design and construction efforts for the 10k psi capping stack. With a footprint of 9 ft x 9 ft (2.7 m x 2.7 m), the 10k psi capping stack is easier to maneuver in areas where wellheads and riser systems are closely spaced, such as TLPs, where wells are beneath a floating production facility. The new dual ram capping stack can cap a well in depths up to 10,000 ft.

1307off_24 24 6/28/13 2:13 PM

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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

26 Offshore July 2013 • www.offshore-mag.com

Tidewater acquires Troms Offshore

Louisiana-based offshore supply vessel provider Tidewater has entered a $395-mil-lion agreement with HitecVision to acquire Troms Offshore Supply AS.

The purchase of the Norwegian company will add fve large platform supply vessels and an additional PSV under construction at the VARD Aukra yard in Møre og Romsdal, Nor-way, to Tidewater’s feet. Troms Offshore also has an option available to build a seventh vessel.

Tidewater said the acquisition would ex-pand its footprint in the Norwegian sector of the North Sea “and supplement Tidewater’s experience and vessel feet operating in harsh environments, including cold climates.”

The purchase price includes $150 million in cash and the assumption of about $245 mil-lion in debt and the balance of payments for vessels under construction.

Fleets grow with new KFELS jackup deliveries

Keppel FELS has delivered the frst of its KFELS Super A Class harsh environment jack-ups to Hercules Offshore-managed Discovery Offshore. Dubbed Discovery Triumph, the jack-up was delivered 46 days ahead of schedule, Keppel said. The rig is one of two Super A Class jackups that Discovery Offshore is scheduled to receive this year. The Discovery Resilience is slated for delivery in 4Q 2013.

The high-specifcation jackup, designed for use in the UK sector of the North Sea, was cus-tomized to operate in 400-ft (122-m) water depths and to drill to a depth of 35,000 ft (10,668 m).

Hercules manages and holds a 32.1% stake in Luxembourg-based Discovery Offshore, which was established in early 2011.

Keppel FELS has also delivered the Laurus high-specifcation jackup to Mexican oilfeld services company Integradora de Servicios Petroleros Oro Negro.

The KFELS B Class jackup will go to work for state oil company Pemex offshore Mexico. The rig is the second high-spec jackup that Keppel FELS has built for Oro Negro. The frst was the Primus, delivered in December 2012.

The KFELS B design can operate in water depths up to 400 ft (122 m) and drill to depths of 30,000 ft (9,144 m). Two such rigs – the Tonala, operated by Peforadora Central, and the Ocean

Scepter, operated by Diamond Offshore – are currently working offshore Mexico.

Keppel FELS is currently building two KFELS B Class jackup rigs for Pemex as well as another four for Grupo R and two for CP La-tina, the company said. The Keppel AmFELS yard in Texas recently delivered a jackup rig to Perforadora Central, with another due for delivery in 1Q 2014.

Sembcorp jackup backlog builds

Sembcorp Marine’s Jurong Shipyard sub-sidiary landed a $596-million contract with Noble Corp. for a newbuild ultra-high specif-cation jackup to be deployed in the UK North Sea. The contract includes an option for an additional rig. Rated for harsh environment water depths of up to 150 m (492 ft), the rig will be based on the Gusto MSC CJ70 design and include an enhanced version of Statoil’s Cat J specifcations, Sembcorp said. The new jackup is scheduled for delivery in 1Q 2015. Noble currently has six F&G JU3000N class jackups under construction at Jurong at a cost of some $1.3 billion.

Sembcorp’s PPL Shipyard received a $220.5- million jackup construction contract from BOT

Lease Co., a leasing company of The Bank of Tokyo-Mitsubishi UFJ. Scheduled for delivery at end January 2015, the new rig will be built based on PPL Shipyard’s Pacifc Class 400 de-sign. The high-specifcation jackup is capable of operating in depths of up to 400 ft (122 m) and can drill to depths of 30,000 ft (9,144 m). PPL has received orders for 12 Pacifc Class 400 jackups and has delivered six since the series was launched, the company said.

Ensco orders eighth UDW drillship

Ensco has ordered an eighth ultra-deepwa-ter drillship based on the Samsung GF12000 hull design, to be delivered by Samsung Heavy Industries in 3Q 2015. The $625-mil-lion deal includes an option for an additional GF12000 drillship.

The vessel will be dubbed ENSCO DS-10 in keeping with the company’s standardiza-tion strategy. ENSCO DS-8 and ENSCO DS-9 are scheduled for delivery next year; EN-

SCO DS-7, to be delivered later this year, will be under contract to Total into 2016. Ensco’s four active DP-3 drillships are working in the Gulf of Mexico, Brazil, and West Africa.

Atwood Achiever bound for Morocco

Kosmos Energy has inked a long-term rig agreement with Atwood Oceanics for the At-

wood Achiever drillship, under construction at Daewoo Shipbuilding and Marine Engi-neering in South Korea. Kosmos plans to put the rig to work offshore Morocco soon after a scheduled June 2014 delivery. The initial three-year agreement includes a base day rate of $595,000 and an option to extend for an additional three years. Kosmos COO Darrell McKenna said the company was also “closing in on a rig of opportunity” in order to launch an exploration drilling campaign offshore Morocco in 1Q 2014. •

Shipping and energy services firm Craig Group christened the Grampian Sceptre platform supply vessel at the Balenciaga Shipyard in Spain. The 83-m (272-ft) long PSV is a sister ship to the Grampian Sovereign, delivered this year. Both vessels are under contract to Talisman Sinopec Energy UK. (Photo courtesy Craig Group)

The Discovery Triumph Super A Class harsh

environment jackup. (Photo courtesy Keppel

Offshore & Marine)

1307off_26 26 6/28/13 2:13 PM

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

28 Offshore July 2013 • www.offshore-mag.com

Reviewing new technologies from OTC 2013The 2013 Offshore Technology Conference presented a trove of

technology innovations. Besides technology treats sprinkled across the acreage of one of the largest OTC events, there were several off-site attractions that commanded attention.

Halliburton could not transport its new Technology Center to Reliant Park, so it opted to host onsite visits. The center, located at its recently expanded site near Houston’s Bush Intercontinental Airport, is the hub of a new approach to research. As explained by Dr. Greg Powers, vice president of technology for the company, “Fundamental research is not specifc to a particular product or service line. The work we do here ben-efts all our divisions worldwide, and we have taken great pains to create a spirit of collaboration that transcends conventional operational groups.”

Powers explained that with the new center, Halliburton is able to focus on reducing time-to-production solutions for its clients, not specifc hard-ware or systems. “It has also enabled us to set global standards for all our research labs, regardless of where they are located,” Powers added.

The concept has advantages. For example, it allows the concentra-tion of sophisticated testing equipment to maximize the company’s re-turn on its R&D investment, which amounted to $460 million in 2012.

Presently, the company is focusing on deepwater, mature felds, and un-conventional resource development. An example of the high productivity enabled by the centralized research organization is a materials testing unit that can run thousands of samples per day. “Our workers set up the tests during the day,” Powers said. “Then the machines work all night, and when the workers return in the morning, all the tests have been completed. It’s a great way to get maximum beneft from our plant and personnel.”

A dramatic exhibit demonstrated the evolution of high-performance and high environmental specifcation integrated microcircuitry that enables tools equipped with these components to operate reliably under sustained environments as high as 230°C (450°F) and more than 30,000 psi.

Powers explained that his lifelong dedication to chemistry is ener-gized by dozens of projects ongoing in the center. He demonstrated this by showing Well Lock, a new organic resin. Well Lock is an ep-oxy that does not react with water, H2S, CO2, or oil at temperatures as high as 250°F (121°C). It is designed to withstand the extreme stresses and strains of wellbore operations, as the failure limits can be designed in excess of 10k psi and 20% deformation.

Much of the company’s focus is on well stimulation services. To address the industry’s very real concerns regarding the global shortage of guar, a major component of hydraulic fracturing fuid, the lab has developed PermStim, which substitutes for guar, often at one-third the cost. And a newly introduced Frac Pump, the dual-fuel Q-10, can replace two standard pumps in terms of throughput, delivering 18 bbl/min at 20,000 psi.

Back at OTC Schlumberger exhibited its Seismic Guided Drilling (SGD) sys-

tem that can produce a real-time depth migration to continuously up-date the 3D reservoir model while drilling ahead. With look-ahead capability of as much as 1,500 ft (457 m), the system can do iterative surface seismic depth imaging and anisotropic velocity modeling workfows constrained by real-time drilling and logging-while-drill-ing (LWD) measurements. The system aims for precise steering to geologic targets while avoiding geohazards.

Enabled by advances in real-time LWD acquisition and large in-creases in cost-effective computer power, a 3 mi x 3 mi (4.8 km x 4.8 km) block (with the well in the center) can be imaged within the drilling schedule.

The company also revealed its unique NeoScope nuclear LWD system, the industry’s frst neutron/density logging device that does not require a chemical radioactive source. Answering an in-dustry concern that has lasted decades, the new tool measures a full spectrum of nuclear logging measurements including neutron gamma density, neutron porosity, nuclear elemental spectroscopy, and Sigma. Heretofore, the requirement of chemical radioactive logging sources was a persistent risk that plagued operators. The concern was magnifed by the fact that the risk was amplifed as wells were drilled to deeper depths in deeper waters, but these were the wells that benefted from the measurements most. The new tool eliminates this risk.

Previous radioactive tools were safe enough when handled by trained logging crews using approved handling tools. The concern came when a tool became stuck in the borehole. Regulations re-quired that attempts be made to fsh the tool, which was time-con-suming and potentially costly. Special measures were required if the fshing job was unsuccessful. Not only is the new tool sourceless, but it saves rig time previously taken to load and unload the sources from the tool and replace them in their safety shields.

The NeoScope tool is combinable with all of the company’s other LWD tools to create a composite logging string capable of perform-ing all petrophysical measurements on a single trip. It is powered by a mud turbine that eliminates the requirement for batteries.

Riserless drilling? Winner of the OTC Spotlight on Technology Award for the second

time, the ReelWell riserless drilling technique has moved closer to its commercial introduction after successful testing in Norway. The tech-nique features a pipe-in-pipe circulation capability completely encased inside the drill pipe. Drilling fuid is pumped down the annulus between the drill pipe and an inner mud conduit. After exiting through conven-tional bit nozzles, the mud sweeps cuttings from the toolface and sucks them up through ports located just above the bit for transport to the surface through the center conduit. Cuttings transport, often the bane of extended-reach drilling operations, is not a problem because no cut-tings are left outside the drillstring to form potential pack-offs.

The system encourages managed pressure drilling operations because well fuid is controlled at all times. If desired, heavy kill mud can be spotted in the borehole annulus for insurance without affecting drilling effciency. According to the company, when drill-ing laterals, the system offers a constant pressure from heel to toe, unlike conventional drilling techniques. This adds to the potential lateral length that can be delivered.

A unique feature of the system is a “pushing” force that can be ap-plied by pumping an external piston-like element down the outer an-nulus. Whereas conventional drillstrings are completely energized by gravity, the ReelWell system can get a boost from the piston to extend its lateral reach. The system claims compatibility with LWD tool strings which provide real-time petrophysical measurements as well as geosteering capability. •

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1307off_28 28 6/28/13 2:14 PM

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

30 Offshore July 2013 • www.offshore-mag.com

Survey action Dolphin Geophysical has secured a 3D award from an undis-

closed client for work in the North Sea. The survey will be acquired by the high-capacity 3D vessel M/V Polar Duke starting in August and expected to last for fve weeks.

Electromagnetic Geoservices ASA (EMGS) has entered into an agreement with North Sea Shipping to extend the charter the ves-sel Atlantic Guardian from September 2013 to March 2014. EMGS has agreed to charter the vessel for an additional period of at least two years, with three optional one-year extensions. Under the agree-ment, the vessel owner will upgrade the vessel to improve fuel eff-ciency and station-keeping capabilities. It is expected that this work will be done during a fve-week yard stay in the frst or second quar-ter of 2014.

Processing advancesParadigm has released Paradigm 2011.3 upgrade. Paradigm

2011.3 includes an upgrade to the SeisEarth multi-survey regional-to-prospect interpretation solution, says Paradigm. By extending the structural and stratigraphic workfows with new voxel volume rendering, this GPU-based rendering enables real-time subsurface scene creations with accelerated refresh speeds and negligible alias-ing. The release also incorporates multi-horizon fattening (GPU-based), horizon slicing, and proportional slicing with property ex-tractions. For development felds, SeisEarth can carry out quality

control and validation of time-lapsed 4D seismic data volumes with new analysis tools embedded in the system. A new, interactive disk roaming approach has been introduced where data is roamed at lower resolution and higher resolutions invoked when the desired scene setting is reached. The upgrade has Paradigm’s SKUA sub-surface modeling with a new interpretation modeling workfow that incorporates automatic intra-formation seismic interpretation with true 3D modeling in geologic time and space. The release also has a new 5D regularization module in the Echos processing application, as well as quality and performance enhancements to the Echos re-verse time migration application.

Blueback Reservoir has released its Blueback Toolbox Version 14. Split into four domain modules, the Blueback Toolbox is a col-lection of more than 100 plug-ins complementing Petrel workfows. Version 14 contains several new and improved tools, such as the “Freeze Window” tool that prevents common user mistakes when creating presentation material, and the “Interactive Facies Genera-tor.” The four modules of Blueback Toolbox seamlessly integrate with Petrel using the familiar interface and can be downloaded from Schlumberger’s Ocean Store.

Schlumberger has released the 2013 Petrel E&P software plat-form. This version brings advances in integration, multi-user col-laboration, and applied science, including improved petroleum sys-tem modeling, structural interpretation, and production analytics, according to Schlumberger. •

The bidding process for permits offshore Lebanon in the Mediterranean is under way through the Ministry of Energy & Water and the Lebanese Petroleum Administration. It runs until this November. The schedule calls for bid evaluations starting in Novem-ber and lasting through January 2014, with the awards coming in February 2014.

In preparation for the bidding, Spectrum and Petroleum Geo-Services both ran multi-client 3D seismic data acquisition programs on separate parts of the available acreage followed by migration processing.

PGS’ surveys offshore Lebanon include extensions of previous surveys in the Latakia Ridge and other large Syrian- and Cyprus-Arc deformation folds covering structural closures extending south into the Levantine basin, as well as surveys in the northeast, central, and southern parts of the Levantine basin and Levant margin, close to the Tamar, Dalit, Leviathan, and Aphrodite gas discoveries.

Spectrum’s surveying covers both the northern part of the Levantine basin and the basin margins north of a survey done last year. Those results indicate the areas have a high likeli-hood for generation and trapping of thermogenic hydrocar-bons. The results also indicate large, simple structures with a compelling reservoir case, says Spectrum.

(Above) PGS coverage off-

shore Lebanon.

(Right) Spectrum coverage offshore Lebanon.

Lebanon draws offshore exploration interest to eastern Mediterranean

1307off_30 30 6/28/13 2:14 PM

Equatorial Margins BrazilMulti-Client Seismic - Data Available for Brazil Round 11

+1 281 647 0602

mc-us@spectrumasa.com

www.spectrumasa.com

Spectrum is active in five basins along the Equatorial Margins of Brazil, all

of which are available to license in Round 11. We offer new PSTM and

PSDM data for each of the Foz do Amazonas, Barreirinhas, Ceara and

Potiguar Basins. All of these surveys were acquired with 10,000 m offsets and

10-13 second record lengths.

Reprocessing efforts are complete along the Equatorial Margins. The

first is a 9,600 km program in the Para-Maranhao Basin that links the

Foz do Amazonas Basin to the Barreirinhas Basin. The second project

covered 2,027 km in the deep waters of French Guiana, which will link

the Zaedyus discovery with data recently acquired offshore Brazil.

Seismic section from the Potiguar Basin data

1307off_31 31 6/28/13 2:14 PM

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

32 Offshore July 2013 • www.offshore-mag.com

Peter ReynoldsSenior Consultant,

ARC Advisory Group

Many industrial organizations face pres-sure to increase workplace and process safety, improve asset performance, and gain visibility into operational risks before inci-dents occur. Asset-intensive industries con-tinue to suffer from unplanned downtime, failure to meet planned production rates, and too many safety and environmental in-cidents. Until they can manage and mitigate operational risks proactively, companies will continue to struggle to improve proftability and build shareholder value due to continu-ing production interruptions, lost productiv-ity, and collateral brand damage.

Statoil provides an interesting case study. While the company’s origins approximately 40 years ago were as an upstream exploration and production company focused on the Norwe-gian continental shelf (NCS), it has expanded its operations over the years to become an inte-grated international energy company with oper-ations in 35 countries. These include more than 40 production assets plus refneries, terminals, and gas processing plants. Statoil is the third largest crude oil seller and the second largest gas exporter to Europe.

Statoil’s stated goal is to be the industry lead-er in health, safety, and environment (HSE). According to president and CEO Helge Lund, “HSE must be the frst priority in everything we do. Should a confict arise, safety must al-ways take precedence over production.” To this end, Statoil has worked to further improve its safety culture and better understand and man-age risks through various campaigns and train-ing efforts. The company has also developed management systems at all levels to be able to effectively identify, evaluate, manage, and miti-gate many business risks. These efforts have yielded signifcant results and the company continues to make progress managing process safety and risk at the operational asset level.

Like most global upstream companies, Statoil operates in various challenging environments with different regulatory regimes and operating conditions. Exposure to harsh weather condi-tions, shipping and logistical challenges, and the need to ensure safe execution of work both offshore and onshore, only increase these chal-lenges. Arctic-specifc risks such as remoteness, darkness, ice, and low temperatures require that the company to take a stepwise approach in which continuous learning and improvements are derived from experience.

The company has run several programs to help ensure compliance with its management system, improve risk management, simplify and harmonize business processes, govern

documentation, and increase focus on techni-cal integrity and its barriers.

Statoil personnel regularly plan and prepare activities to be able to identify operational risks at the lowest level. They use various method-ologies, including HAZOP/HAZID-based quan-titative measures supported by Excel spread-sheets or other simple solutions. The company has also developed its own Work Permit and Safe Job Analysis systems to provide a standard way to help ensure that the risk-mitigating mea-sures are implemented effectively and commu-nicated to all involved workers. The Work Per-mit system also helps coordinate simultaneous activities, partly through visualization of physi-cal assets in a 3D model.

Risk analysis for assets largely focuses on process safety to avoid major accidents. On the asset level, the risk management efforts center around: identifying technical, organizational, and operational (human) barriers to process safety; tracking activities executed on the asset, includ-ing high-risk activities, activity conficts, and total activity level; and managing external impacts.

SAP technology has been employed within several areas to both improve safety and in-crease operations effciency and performance. Most of the company’s operations involve large production assets in remote locations that are often exposed to rough weather conditions and have limited bed and storage capacities. This challenges both safety and performance, and requires precision and risk awareness when planning and executing activities. The compa-ny has established several initiatives to address these challenges. They are described below.

The Technical Integrity Management Pro-gram developed a common work process and a Technical Integrity Management Portal to help assess, follow up on, and report the tech-nical condition of barriers, systems, and equip-ment on the company’s production assets. The solution consolidates information from a vari-ety of different source systems, and the portal helps users visualize the status of technical barriers and assess and document the overall technical integrity of the plant.

The Work Permit Management System in-corporates Safe Job Analysis based on speci-fcations from a joint NCS effort. In addition to using the solution internally, Statoil has li-censed it to several other energy companies. The Work Permit Management System is now a standard, SAP-certifed oil and gas solution.

Statoil developed a simple visualization solution using Microsoft .NET technology. This displays the appropriate location of all planned and active work permits in a simple 3D model of the plant. The company plans to further develop this capability.

Statoil used SAP technology to develop its Operational Performance Dashboard portal.

Using KPIs and proactive process indicators, it measures operational performance on the company’s production assets on a daily basis and provides drill-down options to other data.

The company has also initiated a successful pi-lot project for its Mobile Asset Management so-lution, based on the SAP Mobile Asset Manage-ment platform, at one of its refneries to support operator rounds, data logging, and notifcations. It is now running a project to establish mobile solutions for all production assets, with the frst priority to support its US onshore operations.

For Enterprise Resource Management (ERP) applications, Statoil uses SAP to procure materi-als and services through a vendor portal. It also uses SAP technology to manage its spare part in-ventories. However, the company developed its own Remote Logistics Management application to support its offshore operations.

The Operational Performance Dashboard has helped the company shift from a reactive mindset, focusing on coordination and con-trol, to a more proactive approach that focuses on quality and precision when planning and executing activities. Constant benchmarking across production assets includes a daily over-view of the 10 best performers. By making the underlying results easily available through drill-down, the company has generated a spirit of competiveness, resulting in signifcant im-provements on many assets.

Statoil will continue to focus on improve-ments within process safety and asset risk man-agement by systematic and proactive follow-up of barriers. The goal is to optimize its portfolio of activities within an acceptable risk level.

Engineering and other support organiza-tions require additional knowledge and aware-ness about risks when executing concurrent activities. This applies to both external con-tractors and the company’s own organization. While the company has recently addressed the need for improvements in this area, and initiated training efforts, more work is needed to standardize risk analysis methods and tools across process areas like operations and main-tenance, drilling, and the well area.

The company manages change using various procedures and solutions. In operations, differ-ent work order types are used to manage asset modifcation activities and update documenta-tion. In the future, the company plans to establish a corporate management-of-change framework.

At the moment, there is not a single Statoil risk management program, but several ini-tiatives focusing on different aspects of risk management. Within operations, the company is working to align focus and priorities across process areas around operational risk man-agement and process safety on the asset level. This includes areas like barrier management, planning, and activity management. •

Technology key to operational integrity management

1307off_32 32 6/28/13 2:14 PM

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34 Offshore July 2013 • www.offshore-mag.com

L AT I N A M E R I C A R E P O R T

As exploration heats up, Latin American

nations refine offshore regulations

National oil companies dominate Lat-in America’s oil and gas industry: Petrobras in Brazil, Pemex in Mex-ico, PDVSA in Venezuela, Ecopetrol in Colombia, Petroperu in Peru,

Enap in Chile, and Enarsa in Argentina. While Brazil is expected to continue to lead the region’s offshore development, oil and gas exploration is expanding across Latin America. The following is an overview of the regulatory environments for the oil and gas industry in selected Latin American nations.

BrazilThe Brazilian oil and gas industry is

booming. In May, the national oil agency (ANP) held the 11th bid round in which 289 blocks were offered. Blocks located in the presalt area were not included in this bid round. A total of 30 domestic and interna-tional oil and gas companies were awarded 87 onshore and 55 offshore blocks. A histor-ic record signature bonus of approximately $1.38 billion will be collected by the ANP by July 30 as a result of the bid round.

And there is much more to come. After more than fve years of study, the frst bid round for presalt blocks is scheduled for Octo-ber 2013. The new regulatory model approved by the Brazilian congress for the presalt (and strategic areas) is the production-sharing con-tract. Until now, the concession contract was the only method used by the government to grant exploration and production rights in Bra-zil. It is estimated that 100 Bbbl of oil lie below the surface in the presalt area, which extends 800 km (497 mi) from the state of Espírito Santo to the state of Santa Catarina.

The ANP has also announced an unconven-

tional bid round slated for November 2013. Ac-cording to the International Energy Agency, Brazil contains the third-largest amount of unconventional gas reserves in Latin America after Argentina and Venezuela. Preliminary studies indicate that Brazil has a potential 14.6 tcm (516 tcf) of unconventional natural gas.

Technical and regulatory challenges await those participating in the country’s oil and gas industry. For example, soon after the 11th bid round, Brazilian oil and gas players were hit by an increase in the VAT (ICMS) tax charged by the state of Rio de Janeiro, where a signifcant portion of the Brazilian oil and gas industry is located. The state of Rio de Janeiro transformed the ICMS tax exemption – previously applicable to the importation of goods and equipment for use in exploration activities, or for use in both exploration and production activities but for a period of less than 24 months – into a “tax basis reduction.” As a result of this change, importers of such equipment in the state of Rio de Janeiro will now be required to pay a 1.5% ICMS tax on the customs value of all such equipment with-out the right to a credit. Some view this action as inconsistent with principles guaranteed to

the taxpayer by the constitution of Brazil. It remains to be seen, however, if any action will be taken to repeal the exemption.

VenezuelaIn Venezuela, mineral rights are held by

the state. The 2006 Organic Law on Hydro-carbons (OLH) governs exploration and pro-duction of oil and associated natural gas and the 1999 Organic Law on Gaseous Hydrocar-bons (Gas Law) governs exploration and pro-duction of non-associated natural gas. Those laws cover both onshore and offshore areas.

Under the OLH, private operators are not allowed to acquire rights for exploration and production of oil in Venezuela. Those rights must be held by a state-owned entity or a mixed company (empresa mixta). Usu-ally, the empresa mixta will be a Venezuelan corporation (compañía anónima), domiciled in Venezuela and subject to national law. The Venezuelan state must hold more than 50% – commonly 60% – of the capital stock of the empresa mixta and must control operations and corporate decisions. Under the Gas Law, the exploration and production of non-associated natural gas may be undertaken

Danielle ValoisMaria Fernanda Furtado

Eugenio Hernández-BretónIgnacio Duque

Adolfo DurañonaRoberto GranéAlejandro Mesa

Mary Elena LaresEduardo GuevaraDiana Lizarraga

Benjamín Torres-BarrónAntonio Ortuzar Jr.

Ben H. Welmaker Jr. Baker & McKenzie

With a presalt prospects bid round scheduled this October, the map of holdings offshore Brazil will

be expanding. (See more on the topic on page 42.)

1307off_34 34 6/28/13 2:14 PM

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by the state directly or indirectly through state-owned companies alone or with nation-al or foreign private investor participation or by national or foreign private investors.

The primary offshore non-associated natu-ral gas projects with private participation are Mariscal Sucre (Northeast), Rafael Urdaneta (Gulf of Venezuela), and Delta Caribe Oriental (Northeast). In the Delta Caribe Oriental proj-ect, a unitization agreement was executed be-tween companies operating in Venezuela and Trinidad & Tobago. Production is expected to begin between 2017 and 2020. Production from the Mariscal Sucre project is expected soon and important discoveries of non-asso-ciated natural gas have been reported in the Rafael Urdaneta area.

ArgentinaJurisdiction over onshore areas and off-

shore areas up to 12 nautical miles out are governed by the provinces. Offshore areas from 12 to 200 nautical miles out are gov-erned by the federal government.

Exploration permits in the federal offshore area are granted for up to 12 years plus an exten-sion of seven years (with the acreage diminish-ing at intervals). A production concession may then be granted that lasts up to 25 years, plus a possible 10-year extension. Provincial offshore

areas follow the same terms and conditions.As of November 2004, all new offshore

exploration permits and concessions in fed-eral waters must be issued to the state-owned company, Enarsa. That company may develop those areas alone or in association with private companies. The selection of the private parties to participate with Enarsa is to be done through public bid. In 2010, Enarsa announced that it would license 31 offshore blocks in hopes of making discoveries similar to those in Brazil. The bids, however, were canceled. Although no information on the potential of the areas has been released, it is expected that calls for bids will again take place during 2013 or 2014.

Finally, no company (or its shareholders) authorized to operate in the Argentine offshore area may enter into any commercial relation-ship with any other company operating in that area without authorization from the Argentine government. In practice, that means that com-panies authorized to do business in Argentina cannot do business with companies operating in the Malvinas or Falkland Island area.

ColombiaIn Colombia, the subsurface is owned by

the state. Exploration and exploitation of hy-drocarbons, onshore and offshore, require a concession from the government. The National

Hydrocarbon Agency (ANH) is in charge of administering hydrocarbon resources. ANH has structured several competitive processes where prequalifed operators can participate to be awarded exploration areas. Currently, Petro-bras, Ecopetrol, Equion (an Ecopetrol/Talis-man joint venture), ONGC Videsh, Reliance, Shell, Repsol (in a joint venture with Ecopet-rol), Chevron, and Anadarko (in a joint venture with Ecopetrol) hold offshore blocks in Colom-bia. Most blocks are in the exploration phase except for Chevron’s Guajira block, which has been in production for more than 25 years.

The most current version of a concession contract for offshore areas contemplates a six-year exploration phase, normally divided into two subphases of 36 months each. Gen-eral minimum exploratory obligations include 3D seismic (15 sq km per 200 sq km of area), piston core tests (one per 200 sq km of area), and the drilling of one exploratory well. The exploitation phase is for 24 years.

During the exploration phase the contrac-tor must pay a subsurface use fee of $0.82 per hectare. During exploitation, the con-tractor must pay:

• Royalties at a percentage consisting of 60% of the usual base rate of 8% to 25% (depending on production levels)

• A share of extra revenue in a scenario

1307off_36 36 6/28/13 2:14 PM

AR12-14 © The Lincoln Electric Co. All Rights Reserved.

www.lincolnelectric.com/offshore

Out here isn’t the place to find out ifyou chose the right welding products.

L AT I N A M E R I C A R E P O R T

of high prices• An additional participation in produc-

tion, which the contractor bids in order to be awarded the block.

Peru

On May 31, the Peruvian hydrocarbons agen-cy, Perupetro, offcially launched the 2013 bid round for license agreements over nine offshore blocks. Bids will be awarded based on additional royalties offered.

In the event of a commercial discovery, the Peruvian national oil company, Petroleos del Peru (Petroperu), will have the right to be awarded a participating interest of up to 25% in the license agreement. Its share of the explora-tion and development costs will be paid from its share of production.

Currently, offshore activities in Peru focus mainly on the north coast, where SAVIA, a joint venture between KNOC and Ecopetrol, is producing oil and is looking to produce gas, once environmental permits are completed. In addition, BPZ has a discovery in that area. SK Innovation and Karoon Energy are perform-ing offshore exploration activities.

The conditions applicable for offshore li-cense agreements are the same as for onshore. Under license agreements, ownership of the extracted hydrocarbons belongs to the licensee subject to the payment of royalty.

The licensee under each license agree-ment will have the beneft of the following provisions:

• The license contract will be governed by private law and, therefore, cannot be modifed or terminated unilaterally by the state

• Stability of the tax regime• Access to free currency exchange and

stability of the currency exchange re-gime, including the right to repatriate its investments and profts

• Export of hydrocarbons is exempt from all taxes

• Import of assets required for explora-tion activities are exempt from all taxes.

Mexico

In Mexico, direct ownership of oil and hy-drocarbons is held at all times exclusively by the Mexican state. Furthermore, the activities related to exploration, exploitation, and pro-duction of petroleum and other hydrocarbons are reserved exclusively to the Mexican state and no concessions or similar agreements can be granted under any circumstance in favor of any individuals or private entities. Such ac-tivities are carried out by the Mexican state through its state-owned company, Petroleos Mexicanos (Pemex) and its subsidiaries, which is the only entity allowed to perform ex-ploration and exploitation activities in Mexico.

The current regulatory framework of Pe-

mex enables it to contract exploration and production activities with third parties with certain limitations such as that the Mexican state shall always maintain direct ownership over hydrocarbons and the consideration to contractors must be paid only on a cash basis.

As a general rule, Pemex is required to pro-cure its exploration and production activities through a public tender process and only as an exception may it use restricted invitations to bid (invitation to at least three persons) or

direct award. Contracts may be granted by-reas of activity such as exploration; oil feld development (production); and integrated exploration and production contracts.

The government of President Peña Nieto has announced that in August or September 2013, it will present to the Congress an en-ergy reform initiative to improve the opera-tion of Pemex, provide a more fexible fscal regime for Pemex, and increase private in-vestment in the oil and gas industry. •

1307off_37 37 6/28/13 2:14 PM

38 Offshore July 2013 • www.offshore-mag.com

L AT I N A M E R I C A R E P O R T

Mexico’s rig renaissance gets under wayDeclining production leads to increased investment

in feet expansion, ambitious E&P plans

Mexico is one of the 10 largest oil producers in the world and the third-largest in the Western Hemisphere. While it remains a leader, Mexico faces declining

domestic production. Nearly a decade ago, production began to decrease from the Bay of Campeche in the Gulf of Mexico. Reserve estimates in the country are high, but with-out increased investment, the country’s huge resources will remain in the ground.

According to the US Energy Information Administration (EIA), approximately 1.9 MMb/d of oil is produced from the Bay of Campeche. More than half of Mexico’s pro-duction comes from two offshore felds in the northeast portion of the bay. The Cantarell feld, once the largest feld in the world, was discovered in 1976 and came online in 1981. It comprises Akal, Nohoch, Chac, Kutz, and the newly discovered Sihil feld. Ku-Maloob-Zaap (KMZ), now the Bay of Campeche’s most prolifc feld, began with the Ku feld discovery in 1980, the Maloob feld discovery in 1984, and the Zaap feld discov-ery in 1991. Production from Ku began in 1981. Today, the development covers 121 sq km (47 sq mi) and includes the Ku, Maloob, Zaap, Bacab, Lum, and Zazil-Ha felds. Additional GoM production comes from the Ab-katun-Pol-Chuc and Litoral de Tabasco projects in the south-west sector of the bay offshore Tabasco state.

The Cantarell feld, which hit peak production at 2.1 MMb/d in 2003, declined to 400,000 b/d in 2011, according to Mexico’s Ministry of Energy. While pro-duction numbers have risen and leveled off in the last two years, there is no question that the feld is in serious decline.

While Mexico expected offshore produc-tion to decrease over time, the rapid decline at Cantarell has produced a serious situation because no additional large development projects have started.

Average production was 2.96 MMboe/d in 2011, according to the EIA. Crude oil accounted for 2.55 MMb/d, or 86% of total production. The fact that oil production has been relatively stagnant since 2009 has cre-ated a dilemma because of how heavily the country relies on oil revenue. According to the EIA, the oil industry (including taxes and direct payments from Petróleos Mexicanos

(PEMEX, the state oil company) accounted for 34% of the total government revenue in 2011. With consumption rising and produc-tion decreasing, Mexico is unable to sustain export levels. This could have a substantive impact on the country’s growth. The need for oil has prompted increased investment in exploration activity with the goal to fnd, develop, and monetize additional reserves as fast as possible.

Even though the situation is critical, it is far from irreparable because Mexico has the potential resources to support a long-term recovery. The US Central Intelligence Agen-cy estimates Mexico’s proved oil reserves at 10.4 Bbbl. However, there is a technology gap that poses a serious obstacle, particular-ly for deepwater and shale gas development. While there is a frm understanding of the potential value of deepwater development and onshore shale gas production, the lack of domestic technical ability currently pre-

vents Mexico from realizing its full potential. The upshot is that in the next few years produc-tion increases will come from mature felds, shallow-water, and onshore felds, which are easier to drill and produce.

Government plansThe Mexican government

has assessed the declining production and has developed plans to turn the numbers around. One component of the solution comes from the Minis-try of Energy, which has imple-mented an energy strategy that targets three specifc focus ar-eas: energy security, economic effciency, and environmental sustainability. The key objec-tives of the Ministry’s national strategy are: restore reserves, reverse the decline of oil pro-duction, and maintain natural gas production.

Accomplishing these objec-tives will be a challenge, but it is one that PEMEX is deter-mined to overcome. Created in 1938 as the sole oil operator in the country, PEMEX is the

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4,500

4,000

3,500

3,000

2,500

2,000

1,500

1,000

500

02000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011

Production

Mexico’s oil production has steadily declined in the last decade. (Source EIA)

Mexico’s oil production 2000-2011 (thousand barrels per day)

40 Offshore July 2013 • www.offshore-mag.com

L AT I N A M E R I C A R E P O R T

largest company in Mexico and one of the largest oil companies in the world. As the only operator in the country, PEMEX bears the burden of restoring oil reserves and increasing production.

The PEMEX Business Plan 2010-2024 calls for annual capital ex-penditures of $30 billion from 2010 through 2019. About $22.2 billion will go toward E&P, which is managed via PEMEX Exploration and Production (PEMEX E&P).

PEMEX E&P kicked off its program by identifying prospects. The program’s exploratory strategy includes assessing the country’s pe-troleum potential. A key component has been to accelerate explora-tion activity by investing in 15,000 to 20,000 sq km (5,792 to 7,722 sq mi) of seismic data annually to evaluate oil potential in the GoM. Seismic surveys have included wide azimuth, gravimetric, and mag-netometric technology.

These surveys have identifed new oil provinces such as the extra heavy oil Salina del Istmo Province (a continuation of the producing KMZ complex) in addition to onshore and shallow-water reserves. PEMEX E&P also has invested in drilling. The company recently drilled and completed 15 wells, of which nine were declared pro-ducers, yielding a success rate of 66% and adding more than 540 MMboe in probable reserves.

Rig construction takes offWith domestic drilling picking up, additional assets are needed.

Mexico anticipates a signifcant increase in drilling and production activity over the next 10 years, and recent rig orders refect the growing need for more domestic units.

In 2013, nine new rigs will enter Mexico for Perforadora Central SA de CV, Oro Negro, Aban Offshore, Perforadora Mexico, and China Oilfeld Services Ltd. Mexico, with another 12 scheduled to arrive in 2014.

Oro Negro has a business plan that includes adding 10 rigs, most of which are jackups, although there are plans for three or four semisubmersibles as well. The Grupo R conglomerate, which cur-rently operates three semisubmersibles, has ordered four jackups from Keppel FELS in Singapore. Perforadora Mexico has taken two jackups originally ordered by Prospector Offshore Drilling in the US. The rigs are being built in Dalian, China. Perforadora Central

has another jackup scheduled for delivery in February 2014, which is under construction at AmFELS in Brownsville, Texas. EVYA has plans to add fve jackups to its feet. The company recently located two rigs in Dalian, China, and is in the process of securing another three to meet its acquisition goal. PEMEX plans to build a feet of 12 jackup rigs in the near term and has indicated that by 2030, the anticipated rig count needs to range from a high of 40 jackup rigs to a low of 25 rigs.

The newbuild program is indicative of the amount of work shap-ing up in Mexico, but it could result in overbuilding. With the Mexi-can government’s move toward allowing outside investors to work in Mexican waters, it is possible that the need for local rigs could drop as international oil companies move in. It is likely that these new players would employ drilling contractors with a known track record and those with which the operators have a work history. Re-gardless of how this scenario plays out, Mexico will be walking a tightrope balancing a growing domestic feet against rig demand and rig utilization.

Offshore support vesselsIn addition to the jackups on order, PEMEX has issued a tender

for tugs and barges. The Servicios Navales e Industriales shipyard in Mazatlan is expected to build four of the 12 tugs on order, Tall-

eres Navales del Golfo yard in Veracruz will build four, and Astilleros Bender shipyard in Tampico will build the remaining four. Mean-while, the Seaport shipyard in Ensenada has been contracted to build two 10,000-bbl barges and one 5,000-bbl barge.

Activity in Mexico is on the rise and expand-ing E&P plans will continue to be a catalyst for newbuild and feet expansion.

The frst big steps toward identifying re-serves and building a feet capable of managing increased exploration activity are in progress, as is construction of the support vessels that will serve offshore operations. The next hurdle is the same one the rest of the oil and gas in-dustry faces – fnding skilled and experienced people to carry out the work. •

The bulk of Mexico’s GoM production

comes from the Cantarell and KMZ fields.

Ku-Maloob-Zaap

Integral Business Unit

Gulf of Mexico

Dos Bocas

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42 Offshore July 2013 • www.offshore-mag.com

L AT I N A M E R I C A R E P O R T

Brazil prepares for the industry’s

biggest presalt auction

The record $1.4 billion raised in sign-ing bonuses from the Brazil Petro-leum Agency’s (ANP) 11th oil and gas licensing round in May marked a successful conclusion to the frst off-

shore concession issue in Brazil since 2007. However, that fgure is likely to pale against the amounts involved as the world’s biggest oil and gas companies compete for acreage in Brazil’s frst auction of presalt operating licenses scheduled for October. Following a meeting between President Dilma Rousseff, her Minister for Mines and Energy Edison Lobão, and Finance Minister Guido Man-tega, it had become clear that global dis-coveries since 2007’s confrmation of huge reserves deep under the country’s Atlantic coast have heightened the need to re-con-centrate the industry’s interests in Brazil.

The available blocks are in the Libra prospect within the Santos basin about 170 km (106 mi) off the coast of Rio de Janeiro. CGG estimates potential re-coverable reserves between 8-12 Bbbl across an area of 727 sq km (281 sq mi), making it the biggest auction of its kind anywhere in the world. With that in mind, director-general of ANP Magda Chambriard announced that the auction will be moved to Brasília, to ensure the presence of the presi-dent.

“The volumes in Libra are com-pletely unique and unimaginable,” said Chambriard. “I believe that only large-scale companies will take part in the auction, including Asia’s.” The same Chinese, Japanese, and Indian compa-nies were conspicuous in their absence from the 11th round, possibly to allow themselves greater concentration on the presalt auction.

The move to a production-sharing frame-work for the presalt blocks does away with the former concession-based approach that was followed in May’s auction and in which, after paying a signing bonus, companies owned 100% of the oil in that block. Under the new system, the government will main-tain ownership of the minerals and divide up the profts based on the cost of extraction. In contrast to the concession system, the bonus payments and local content requirements will be fxed, and it will be the percentage of proft oil that companies are prepared to

sign over to the government that will deter-mine the success of the bids. The ongoing fall in production costs, coupled with the high success rate in exploratory drilling in the presalt prospects – up to four times that of the global average – should mean that the new deal remains an attractive investment.

Tom Coleman, senior vice president at inves-tor analysts Moody’s, does not foresee any hesi-tation within the industry. “The 11th round was quite successful and although the ANP didn’t get rid of all the blocks, most of the important offshore acreage was taken up,” said Coleman. “For the new auction, as long as companies can

get the proftable oil out, the new system will work fne. The uncertainty is how much bonus they are willing to offer and how much proft oil they are prepared to give to the government. Besides the economics of it, though, the ques-tion is, after this long hiatus, ‘is Brazil willing to fully open itself up to foreign investment?’ and I think the answer is ‘yes’.”

The new framework also leaves Petrobras looking at a huge and potentially costly ex-pansion program to keep pace with the new acreage. The current law mandates that the company be the principal operator and at least 30% owner of every block auctioned. In spite of the almost unprecedented $11 billion raised in bonds by the company earlier this year, the demands of that 30% could both hinder its op-

erations and put off international companies already wary of the restrictive local content re-quirements. Even across the one prospect, the company’s productivity targets remain high enough to create a fne line between maximiz-ing resources and spreading them too thinly between international oil companies, each with their own strategies.

Petrobras acquired 34 blocks at May’s auction, with OGX the next biggest Brazil-ian investor with a working interest in 13 blocks, seven in deepwater, two in shallow water offshore, and the rest onshore. OGX CEO Luiz Carneiro said, “The partnership with ExxonMobil and Total, two major inter-national oil and gas players with signifcant expertise and resources, with a strong track record of success in West Africa and the At-lantic Margin, underscore the high potential

of the blocks, as well as our ability to identify and develop future growth op-portunities.” Total, partner with OGX in the CE-M-663 block in the Ceará ba-sin, was among the international com-panies to announce their intentions in Brazil with the acquisition of 10 new blocks. Expansion in the region is a key part of the company’s strategy in 2013, which is expected to lead to fur-ther investment come October.

BG Brasil secured 10 blocks in the Barreirinhas basin on the Brazilian equatorial margin and, with 100% own-ership of six of those, has resumed in earnest its operating position in the country. The company announced that it is set to invest around $3 billion per

year in Brazil between 2013-2018, but it re-mains to be seen how much of that will be di-rectly poured into future operations in Libra.

As ever, doubt remains over the realiza-tion of October’s auction should the fnal royalties bill remain unconfrmed. Whether or not any new distribution of profts will apply to old contracts remains a question awaiting the Supreme Court’s answer. The planned creation of state company Pré-Sal Petróleo SA to handle the running of the auction and manage the capital has also yet to come into effect. It is dependent on a presidential decree, which could leave the ANP to handle the mandatory details while the potentially laborious election of the com-pany’s members takes place. •

Doug GrayContributing Editor

The available presalt blocks are located in the Libra prospect

within the Santos basin.

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44 Offshore July 2013 • www.offshore-mag.com

O F F S H O R E M E D I T E R R A N E A N

Mediterranean Sea plays

offer new opportunities Offshore reserves may help Greece and Cyprus

rejuvenate their economies

As Greece searches for a solution to its unending debt debacle and Cyprus seeks €5.8 billion ($7.6 billion) for its European bailout, both countries’ best hope may lie under their very shores. In the past four years, fortunes in fossil fuels have been unearthed in the eastern Mediterranean. In April 2010,

the US Geological Survey estimated 122 tcf of recoverable natural gas in the eastern-most part of the Mediterranean Sea (the Levant or Levantine basin), more than the world consumes in a year. If this and other estimates are correct, these offshore natural gas and oil deposits may play the deus ex machina to the current Greek drama.

Although parts of the Mediterranean Sea have been explored for many years, new technologies that allow highly sensitive underwa-ter surveying and deeper offshore drilling have exhumed previously inaccessible reserves underneath the sea. Cyprus, for example, may hold 7 tcf of natural gas, which according to Cyprus’ own commerce minister may be worth €100 billion ($131 billion). These fgures have led some to speculate that Cyprus may lease or sell the rights to its newly discovered natural gas and oil to pay off its debts. A recent visit by Cyprus’ fnance and energy ministers to Russia to dis-cuss debt solutions certainly helps fuel those whispers. Yet Cyprus was not the frst place in the Mediterranean to unearth oil and gas.

Israel’s initiationIt all started offshore Israel. Noble Energy, a Houston-based oil

and gas company with Israeli ties, led the exploration of oil and gas in Israel’s waters in the Levant basin. There Noble frst discovered the Mari-B feld, the frst offshore natural gas production facility in Israel, which began production in 2004. Then Noble moved farther offshore discovering the felds Tamar in 2009 (9 tcf); Dalit in 2009

(0.5 tcf); Leviathan in December 2010 (17 tcf – enough to supply Israel’s gas needs for 100 years); and Dolphin/Tanin in February 2012 (1.2 tcf). To put these amounts into perspective, in 2011 the three largest natural-gas consuming countries consumed 24.3 tcf (the United States), 17.9 tcf (Russia), and 5.4 tcf (Iran).

The Leviathan gas feld is Noble Energy’s largest fnd, and Noble retains a 39.66% working interest, sharing with Avner Oil and Gas (22.67%), Delek Drilling (22.67%), and Ratio Oil Exploration (15%). Leviathan is predicted to start production in 2016, while Tamar, the second-largest fnd in the Levant basin, began production this past March. Along with natural gas, Noble Energy also estimates that Le-viathan could hold up to 4.3 Bbbl of oil. Israel has long depended on foreign sources for its energy needs, making these fnds very wel-come news. Gideon Tadmor, chairman of Delek Drilling and chief of Avner Oil, both subsidiaries of Delek Energy Systems, said in a New York Times article that these offshore natural gas discoveries have “enabled Israel to enter a new era in which we will become an exporter of energy.”

Cypriot second windWhile developing its Israeli fnds, Noble Energy also eyed the wa-

ters of Cyprus. In October 2008, Noble Energy received the explora-tion rights off the southern coast of Cyprus to block 12 of Cyprus’ maritime Exclusive Economic Zone (EEZ). After beginning explor-atory drilling in September 2011, Noble discovered the Aphrodite gas feld. This fnd is 21 mi (13 km) west of the Leviathan gas feld. It is believed to hold 7 tcf of natural gas, more than Cyprus could con-sume in a century. Noble shares ownership of the well (70%) with

John PappasChadbourne & Parke LLP

Major plays in the Mediterranean Sea.

Cyprus’ Exclusive Economic Zone (EEZ) is emerging as a significant

offshore play.

1307off_44 44 6/28/13 2:15 PM

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3,000

2,500

2,000

1,500

1,000

500

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Source: Data obtained from U.S. Energy Information Administration, International Energy Statistics www.eia.gov

2011 European natural gas production vs. consumption (bcf)

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Production Consumption

46 Offshore July 2013 • www.offshore-mag.com

O F F S H O R E M E D I T E R R A N E A N

Delek Drilling (15%) and Avner Oil Explora-tion (15%), the same partners in the Levia-than feld. The country’s Commerce Minis-ter, Praxoulla Antoniadou, estimated that 7 tcf of gas in block 12 is worth around €100 billion. In fact, Solon Kassinis and Charles Ellinas, heads of the Cyprus Natural Hydro-carbons Co. (CNHC), have both said that Cyprus envisages having more than 60 tcf of total gas reserves in its EEZ. This too comes as welcome news to a debt-ridden and cash-strapped Cyprus.

In February 2012, Cyprus announced a second licensing round for the remaining 12 out of 13 blocks of Cyprus’ EEZ. On Jan. 24, 2013, Cyprus licensed a consortium includ-ing Italy’s Eni and South Korea’s KoreaGas Corp. (Kogas) to explore blocks 2, 3, and 9 of Cyprus’ EEZ. Additionally, on Feb. 6, 2013, France’s Total paid Cyprus €24 million ($31.6 billion) for the license to explore blocks 10 and 11. Total announced it would conduct a series of 10 exploratory drillings for gas and oil over the next three years. It is thought that it will focus mainly on oil. It will likely take these companies until 2018 to produce oil and gas for domestic consumption and 2019 for export.

Pipelines versus LNGThe greatest debate surrounding the Le-

viathan and Aphrodite discoveries is how to transport the oil and gas to market. There seem to be four possibilities on the table: a pipeline to Turkey; a pipeline to Greece; a liquefaction plant in Cyprus; and a foating liquefed natural gas (FLNG) vessel.

The frst option is politically complicated. Building a pipeline to Turkey that would feed into existing pipeline infrastructure to Europe could be the most cost-effcient choice. However, Turkey has already de-cried Cyprus’ offshore exploration, claiming the waters as its own, threatening to cut par-ticipating energy companies from access to Turkey’s market, and sending a warship into the area after test drilling started in 2012. Even if Cypriots and Turks could agree on the rights to the Aphrodite oil and gas, Cy-priots worry that Turkey will, like Russia, use the gas valves for political ploys.

As for the Israelis, Turkish relations have been similarly strained; at least they were before March 22, 2013. On that day, Israeli Prime Minister Benjamin Netanyahu publicly apologized to Turkish Prime Minister Tayyip Erdogan for Israel’s 2010 raid on the Turkish ship Mavi Marmara that resulted in the death of nine Turkish activists seeking to bring aid to Gaza. Israel may have extended this olive branch to facilitate warmer relations between Israel and Turkey on the Syrian issue, and to smooth the possibility of a potential pipe-line to bring natural gas from Leviathan to

Europe through Turkey. However, while this public statement may ease tensions between the two countries, the threat of Turkey turn-ing off the pipeline in the future remains; and there is also the unending Palestinian impasse (Turkey supports Palestine). Thus although possible, a pipeline through Turkey remains problematic.

The second option would entail con-structing a pipeline from Cyprus to Crete and from Crete to Greece, connecting then to existing pipelines throughout Europe. However, this option appears to not be com-mercially viable. At least that seemed to be the conclusion at the 2nd Cyprus Energy Forum in December 2012. Solon Kassinis, vice president of the CNHC, hinted that this idea has been all but abandoned. The main concerns appear to be the high construction cost, long construction time, falling electric-ity demand and prices in Europe, and the necessary long-term supply contracts that would be linked to the price of oil.

The third option consists of construct-ing a liquefaction plant in Cyprus, where the natural gas from both the Leviathan and Aphrodite felds could be liquefed and shipped. The major beneft of this option is that the LNG can then be shipped to a va-riety of markets (Europe as well as Asia), garnering higher prices on the spot market. The largest drawback however is the price tag – LNG terminals typically cost about $10 billion (as compared to $1 billion for a Cy-prus-Turkey pipeline). Kassinis explained at the 2nd Cyprus Energy Forum that Cyprus was contemplating an LNG facility with up to three trains for a total capacity of up to

15 MM tons/yr. An LNG train is a liquefac-tion and purifcation facility, which typically has capacity for 5 MM tons of natural gas a year. For those wondering about construct-ing an LNG plant in Israel instead of Cyprus, this option appears impractical because of limited space, environmental concerns, and security problems in Israel.

The fourth option is mooring a foating LNG vessel at Leviathan and Aphrodite. On one hand, this option has great advantages – exportable LNG and lower cost relative to a pipeline to Greece – but on the other hand the technology is new and untested. There are also fears that the vessel would be vul-nerable to terrorism.

While no option has defnitively been cho-sen, recent developments suggest that an LNG plant in Cyprus will win the day. Cyprus has announced plans to build the Vasilikos LNG Terminal at the Vasilikos Energy Cen-tre, which already serves as an energy hub on the island. It seems that the CNHC and Noble Energy are waiting for fnal confrma-tion of block 12 reserves before potentially entering into a joint venture to build Train 1 of the LNG terminal. They should have this confrmation by the end of 2013. Subsequent trains will depend on the extent of more nat-ural gas fnds. It is not clear whether Israel will choose to connect its Leviathan feld to the Vasilikos LNG terminal. While it has achieved some sort of rapprochement with Turkey, suggesting that it is contemplating building a pipeline to Turkey, such a pipe-line would also pass through Lebanese and Syrian waters and require those countries’ approval. Considering this and the other

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Reefer Units

1307off_47 47 6/28/13 2:15 PM

Source: Data obtained from U.S. Energy Information Administration, International Energy Statistics www.eia.gov.Russia’s reserves are 1,680 Tcf, dwarfing even Norway’s.

European natural gas reserves of 2011 (Tcf)

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48 Offshore July 2013 • www.offshore-mag.com

O F F S H O R E M E D I T E R R A N E A N

shortcomings of a Turkish pipeline listed before, it is likely that Israel will connect to the Vasilikos terminal any natural gas that exceeds its domestic needs.

Greek hopesThese oil and gas discoveries in Israel

and Cyprus are also providing inspiration to those Greeks who hope to drill themselves out of debt, and lessen Russia’s natural gas grip over Europe. “It is important that Greece returns to the energy map again,” said Energy Minister Evangelos Livieratos. “Our country can attract new investment, create new jobs, and boost its geo-strategic position and competitiveness to exit the crisis.” In 2012, one study by Athens-based Flow Energy estimated €600 billion ($787.9 billion) worth of offshore natural gas in Greece over 25 years. This study discovered geological similarities between the Levan-tine basin and offshore Crete. In the waters south of Crete, the study estimates 3.5 tcm (123.6 tcf) of natural gas, enough to cover over six years of EU gas demand, and 1.5 Bbbl of oil.

Still others estimate that total offshore oil in Greek waters exceeds 22 Bbbl of oil in the Ionian Sea and some 4 Bbbl in the northern Aegean Sea. Evangelos Kouloumbis, former Greek Industry minister, recently stated that Greece could cover 50% of its needs with the oil to be found in offshore felds in the Aegean Sea. Highlighting how unex-plored Greece is regarding hydrocarbon potential, one Greek analyst, Aristotle Vas-silakis, cited surveys that estimate $9 trillion worth of natural gas. Tulane University oil

expert David Hynes told an audience in Ath-ens recently that Greece could potentially solve its entire public debt crisis through de-velopment of its new-found gas and oil, con-servatively estimating that reserves already discovered could bring Greece more than €302 billion ($396.5 billion) over 25 years.

Despite the touted potential of oil and gas in Greece, it is important to remember that al-most 200 fruitless test wells have been bored in various parts of Greece in the past century. The most recent one was approximately 12 years ago. However, those who are optimis-tic about Greece’s energy potential respond that most of the tests were badly managed or carried out at the wrong locations. Right now, Greece spends €10-12 billion ($13-15.7 billion) a year on oil imports, about 5% of its GDP. This dependence on foreign oil, coupled with its need for fnancial solutions, might make oil and gas Greece’s silver bullet.

On Nov. 11, 2012, the Norwegian Petro-leum Geo-Services ASA (PGS) began a three-month long seismic survey of the Ionian Sea and water south of Crete, an area that covers a total 220,000 sq km (84, 942 sq mi), an area 40% larger than mainland Greece. By mid-2013, the survey analysis should be complete, and in the frst half of 2014 Greece plans to hold a licensing round for exploration blocks. However, before holding a licensing round, Greece would also need to establish an EEZ, a move it has yet to undertake.

Other Mediterranean hopesIn addition to Israel, Cyprus, and Greece,

other Mediterranean countries are inter-ested in exploring for natural gas and oil. In-

cited by the fnds of their eastern neighbors, Spain and Italy are looking into offshore exploration. “There is a lot of potential, we believe, in the Mediterranean region,” said Simon Thomson, chief executive of Cairn Energy of Britain, which is exploring off the coast of Spain and bidding for licenses in Cyprus. “A lot of hydrocarbons have already been discovered, but we believe there’s a lot more to be discovered.”

Expressing the same sentiment, petroleum geologist David Peace told Reuters that “[i]f you look at the offshore license map of Italy, about two-thirds of it is open…Italy is one area that has been overlooked, especially the south.” To facilitate these efforts, Italy is relax-ing its ban on offshore drilling, placed after the 2010 Deepwater Horizon spill.

More specifcally, there appears to be in-terest in the waters around Malta, with ge-ologists believing that the oil-rich geology of nearby Libya extends northward underneath the sea. The prospects are strong enough that Genel Energy (headed by former chief executive of BP Tony Hayward) has part-nered with Bill Higgs (chief executive of Lon-don-based Mediterranean Oil and Gas). The company hopes to fnish drilling its frst well in the area by the end of 2013.

Natural gas in EuropeTo compare the fgures in Israel, Cyprus,

and Greece to Europe, one needs to review the natural gas production and consumption among European countries and the reserves of natural gas these countries hold. For this analysis, all fgures were taken from the Energy Information Administration’s website. Norway clearly leads the continent in natural gas pro-duction while also having a very low degree of consumption. The Netherlands and United Kingdom are the only other two signifcant pro-ducers, although production in the UK has de-clined signifcantly over the past four years. As a comparison, one could note that in 2011, Rus-sia produced 23,686 bcf, more than six times what Norway produced. The major consum-ers of natural gas are the UK, Germany, Italy, France, Turkey, the Netherlands, and Spain. In general, consumption seems to have declined in the past four years, especially in Germany, except in Turkey, which shows an upswing in consumption in 2011. Lastly, Norway and the Netherlands lay claim to the largest reserves in Europe by far, although Russia’s 1,680 tcf in reserves dwarfs that amount. •

The author John Pappas is a Project Finance Associate in the

Washington, D.C., offce of the law frm Chadbourne &

Parke LLP. He is a member of the New York Bar and

the Energy Bar Association, and can be contacted at

jpappas@chadbourne.com.

1307off_48 48 6/28/13 2:15 PM

1307off_49 49 6/28/13 2:15 PM

50 Offshore July 2013 • www.offshore-mag.com

R I G R E P O R T

Deepwater rig fleet continues to expand

The world’s deepwater (>3,000 ft, or 914 m) drilling rig feet continues to grow in order to meet operators’ increasing demands for rigs capable of drilling wells to deeper depths, operating in

ever greater water depths, and having them equipped with the newest technologies and safety features. However, the demand for deepwater rigs in general is currently strong enough to keep the older units working for the time being, even though some operators are showing a preference for newer units. As a matter of fact, the only deepwater rig to be removed from the drilling feet in the past 20 years is the Deepwater Horizon, which sank in the April 2010 Macondo accident in the US Gulf of Mexico.

The global supply of deepwater rigs has more than doubled over the last 10 years, growing from 86 in May 2003 to 107 in May 2008, and reaching 204 units as of May 2013. Of the 204 current deepwater units, 112 are labeled as ultra-deepwater (>7,500 ft, or 2,286 m). This is up from 28 ultra-deepwater units just fve years ago. In addition, more deepwa-ter units are presently under construction or on order with shipyards, which will further increase the global supply once they are deliv-ered over the next several years.

Despite the infux of new units, deepwater drilling rig utilization remains at high levels. For the full year 2003, total contracted utili-zation was 87.3%. This fgure rose each year thereafter through 2008, when it reached 99.1%. Since then, total contracted utilization has not dropped below 94%. 2013 is on target to maintain this trend, coming in at 94.1% through the end of May.

Narrowing the discussion to the ultra-deep-water rig feet, this trend of absorbing addi-tional units while maintaining high contracted utilization is even more apparent. Full-year 2003 contracted utilization was 97.7%, and it has remained above 97% ever since. Notably, in both 2007 and 2008, total contracted utiliza-tion averaged 100% for the entire year. Last year came in at 99.3%, and the average so far this year is 99.1%, clearly demonstrating opera-tors’ desire for ultra-deepwater units.

Looking at the makeup of the entire deep-water rig feet, a substantial change has tak-en effect in several key specifcations, such as rated water depth and dynamic position-

ing (DP) capability. In 2008, approximately 73.8% of the feet was rated for between 3,001 and 7,500 ft of water, with the remain-ing 26.2% comprising the ultra-deepwater segment.

Fast-forward to 2013, and the proportions have shifted to 45.1% for rigs rated for 3,001-7,500 ft of water and 54.9% ultra-deepwater. This trend is also expected to continue, even though it does not actually follow that char-tering deeper-rated rigs means operators are drilling in deeper water depths. While some deepwater drilling is taking place in over 7,500 ft of water, the majority of wells are still being drilled in less than ultra-deep-water depths.

Additionally, the gap between rigs with DP capability versus those that are conventional-ly moored continues to widen. Five years ago, 57.8% of the deepwater feet had DP capabil-ity, while 75.3% of today’s feet is identifed as DP. In some regions, such as those in the potential path of hurricanes or typhoons, hav-ing DP units is preferable to moored units, as the time needed to move the rig out of harm’s way is much shorter. However, in certain other regions, such as harsh environment lo-cations like the North Sea, moored units are preferred due to the shallower water depths, and because sea conditions place extra stress on the DP system’s station-keeping ability.

Organized by rig manager, Transocean is by far the largest for deepwater rigs, with 48 units. Next come Ensco and Noble Corp. with 21 each, followed by Diamond Offshore with 19 and Seadrill with 13. Ensco, Noble and Diamond each added one net deepwa-ter unit to their feets over the past year. In all, 30 managers are currently active in the worldwide deepwater rig market. While the longer-term trend has been for the number

of deepwater players to increase, the fgure actually went down by one earlier this year when Songa Offshore sold its only deep-water unit, semi Songa Eclipse, to Seadrill. Songa is now purely a mid-water player, with nine rigs, four of which are under construc-tion or on order.

In terms of regions, the so-called “Golden Triangle” of deepwater activity, which com-prises the US Gulf of Mexico, West Africa, and South America (namely Brazil), is fac-ing some competition for the drilling rig supply from emerging deepwater markets in other parts of the world. While just over 70% of the current deepwater rig supply is in one of those three regions, other areas are also being targeted as potential candidates for some of the new units still under construc-tion or on order at shipyards.

Northwest Europe has 13 deepwater units at present, and Southeast Asia is not far be-hind with 11. An up-and-coming deepwater market is Australia, which currently has eight units. BP recently awarded a three-year program to Diamond Offshore for a newbuild semi to work off Australia, with a projected delivery date in late 2015.

Another signifcant market is the Indian Ocean, where a number of east African countries have seen some discoveries over the past few years. This has led to a recent push to bring additional rigs to the area to appraise these fnds, as well as to conduct additional exploration work. Multiple opera-tors are believed to be considering future drilling programs off Kenya, Madagascar, Mozambique, and Tanzania. As the resource potential begins to become clearer, more east African countries may end up being added to the deepwater hot spot list in the years to come. •

Cinnamon Odell

IHS PetrodataDynamically positioned vs. moored units

1307off_50 50 6/28/13 2:16 PM

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52 Offshore July 2013 • www.offshore-mag.com

R I G R E P O R T

Rig construction continues

to focus on higher-spec units

Shipyards that build offshore drilling rigs continue to stay busy with new construction projects. Worldwide, 131 jack-ups, semisubmersibles, drillships and tender-assisted units are under construction, and another 81 units are on order at shipyards awaiting construction commencement. This is

down from this time last year, when 143 units were under construc-tion, but up from two years ago, when the total was 127. This year’s under-construction fgure breaks down as: 37 drillships, 11 semis, 75 jackups, and eight tender-assisted rigs. Delivery dates range from this month to late 2015 for the rigs currently under construction, and from early 2014 through mid-2019 for the units still on order.

Since June of last year, 81 rigs have been ordered, with 43 of those orders coming in since January 2013. The majority of the past year’s orders have been for jackups. Rig owners have secured 45 slots at ship-yards for new jackups. A closer look at the jackup orders reveals only two commodity units rated for less than 300 ft (91 m) of water. One is for China’s Shengli Offshore, a subsidiary of Sinopec, and the other is for Teniz Burgylau, a subsidiary of KazMunaiGas, which is the national oil company of Kazakhstan. Three orders are for 300-ft independent-leg cantilever units. One is for China Petroleum Liaohe Equipment Co., or CPLEC; one is for China’s Shanghai Zhenhua Heavy Industries, or ZPMC; and the third is for Singapore’s KS Drilling.

The remaining 42 jackup orders are for premium rigs rated for 350 ft (107 m) or more. This refects a growing preference by operators worldwide for newer, higher-specifcation equipment.

Interestingly, not all of the companies that ordered these jackups are rig contractors. Financial companies, shipyards, and one operator have also placed orders. The fnancial companies will often sell the rig before delivery or hire a rig contractor to manage the contracting and day-to-day rig activities.

Shipyards sometimes plan ahead based on market intelligence and start building a rig on spec with the intention of selling it to another party. This allows them to keep their skilled labor working and also provides the future owner with a unit that will be delivered much sooner than if construction was starting from scratch. In December, PEMEX, Mexico’s state oil company, hired Keppel FELS to build two units for it directly. In addition, several Mexican rig contractors are also building jackups aimed at the Mexican market in an effort to help PEMEX achieve its operational expansion goals.

As these units are delivered, some of the older jackups in the world-wide feet are being retired from active duty or cold-stacked. Over the past year, nine jackups have left the feet, only one of which was due to an accident. The others were converted into non-drilling production units, scrapped, or simply retired. The hulls of these nine units were built between 1975 and 1983, placing them all at 30-plus years old. As of early June, there are 289 jackups with a year-in-service date of 1983 or earlier. Attrition is expected to increase over the next several years as rig contractors modernize their feets with newer rigs.

While many of these older rigs are cold-stacked or out-of-service, this

is not to say that operators are unwilling to charter older units. As a matter of fact, the oldest currently-working jackup has a year-in-service date of 1958. Hercules 120, a 120-ft (36.5-m) mat cantilever unit, is work-ing in the US GoM and is frmly committed until the end of this year. The next oldest working jackup is Al Borz, which was in service in 1968 and is working offshore Iran.

Meanwhile, all but one of the 32 semis and drillships ordered are for ultra-deepwater depths of >7,500 ft (2,286 m). The one exception is a semi ordered by Caspian Drilling for operations in the Caspian Sea. It has a maximum designed water depth of 3,280 ft (1,000 m), but will initially be outftted for 2,624 ft of water (800 m).

Besides deeper water depths, another trend regarding newbuild foating rigs is a preference for drillships over semis. While there are still more than twice as many semis in the world as drillships, most of the foating rig orders over the past fve years have been for drillships. Between 2008 and 2012, rig owners ordered 90 drillships, versus just 29 semis. It will take some time, however, for the current supply of 87 drillships to overtake the global semi count of 217.

A signifcant number of the foating rig orders are from Brazilian com-panies targeting the Brazilian market and looking to meet the high local content requirements. Etesco, Odebrecht, Queiroz Galvao, and Sete Brasil have placed new rig orders over the past year, resulting in about 15 total foating rigs, all of which are set to work for national oil company Petrobras. Altogether, only 13 of the 32 foater orders were placed on a speculative basis, without a frm contract already in place; one of those units has since been chartered. This leaves little negotiating room for operators still look-ing for new deepwater units over the next few years.

Turning to the tender-assisted rig market, only four orders have been placed over the past year. BassDrill ordered two, bringing its total feet to four units. Energy Drilling Pte. of Singapore and Norwegian newcomer Pentacle each ordered one unit.

Focusing on the places that will be building these rigs, China, Sin-gapore, and South Korea will be constructing over 70% of the rigs or-dered over the past year. Chinese yards were the biggest winner, with 29 confrmed orders, followed by 16 for Singapore yards and 14 for South Korea. Other countries set to build rigs are Azerbaijan, Brazil, Indonesia, Kazakhstan, and the United Arab Emirates. •

Cinnamon Odell

IHS Petrodata

Rig orders 2008-2013 (year-to-date)

1307off_52 52 6/28/13 2:16 PM

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1307off_53 53 6/28/13 2:16 PM

2013 Worldwide MODU construction/new order survey as of May 31, 2013.

R I G R E P O R T

54 Offshore July 2013 • www.offshore-mag.com

Rated Delivery Owner or manager/ water date Shipyard Rig name Rig type depth (ft) Status from yard Shipyard location

Apexindo

Tasha Jackup 400 Under Construction 2Q 2014 Dalian Shipbuilding Industry Co. China

Arabian Drilling

Arabdrill 50 Jackup 400 Under Construction 2Q 2013 Keppel FELS Singapore

Arabdrill 60 Jackup 400 Under Construction 4Q 2013 Keppel FELS Singapore

Atwood

Atwood Achiever Drillship 10000 Under Construction 2Q 2014 Daewoo South Korea

Atwood Advantage Drillship 10000 Under Construction 3Q 2013 Daewoo South Korea

Coastal Contracts

CIMC Raffles JU Tbn3 Jackup 400 Under Construction 4Q 2014 Yantai CIMC Raffles China

COSL

COSLProspector Semisubmersible 5000 Under Construction 3Q 2014 Yantai CIMC Raffles China

CP Latina

Covadonga Jackup 400 Under Construction 4Q 2013 Keppel FELS Singapore

Standard Integrity Jackup 400 Under Construction 3Q 2013 Keppel FELS Singapore

CPLEC

CP300-3 Jackup 300 Under Construction 4Q 2013 CPLEC China

DSJ-300 L1 Jackup 300 Under Construction 4Q 2013 CPLEC China

CPOE

CPOE-16 Jackup 400 Under Construction 1Q 2014 Shanghai Waigaoqiao Shipbuilding China

CPTDC

CP300-2 Jackup 300 Under Construction 2Q 2013 CPLEC China

DSJ-300 JU Tbn3 Jackup 300 Under Construction 2Q 2013 Dalian Shipbuilding Industry Co. China

DSJ-300 JU Tbn4 Jackup 300 Under Construction 4Q 2013 Dalian Shipbuilding Industry Co. China

Diamond Offshore

Ocean Apex Semisubmersible 5000 Rebuild 2Q 2014 Jurong Shipyard Pte Ltd Singapore

Ocean BlackHawk Drillship 12000 Under Construction 2Q 2013 Hyundai Heavy Industries South Korea

Ocean BlackHornet Drillship 12000 Under Construction 4Q 2013 Hyundai Heavy Industries South Korea

Ocean BlackRhino Drillship 12000 Under Construction 2Q 2014 Hyundai Heavy Industries South Korea

Ocean Onyx Semisubmersible 6000 Rebuild 3Q 2013 Keppel AmFELS USA

Dolphin

Bolette Dolphin Drillship 10000 Under Construction 3Q 2013 Hyundai Heavy Industries South Korea

Drydocks World

DDW-PaxOcean JU Tbn1 Jackup 375 Under Construction 4Q 2014 Drydocks World – Graha Indonesia

Ensco

ENSCO 110 Jackup 400 Under Construction 1Q 2015 Keppel FELS Singapore

ENSCO 120 Jackup 400 Under Construction 3Q 2013 Keppel FELS Singapore

ENSCO 121 Jackup 400 Under Construction 4Q 2013 Keppel FELS Singapore

ENSCO 122 Jackup 400 Under Construction 3Q 2014 Keppel FELS Singapore

ENSCO DS-7 Drillship 10000 Under Construction 3Q 2013 Samsung Heavy Industries South Korea

ENSCO DS-8 Drillship 10000 Under Construction 3Q 2014 Samsung Heavy Industries South Korea

ENSCO DS-9 Drillship 10000 Under Construction 4Q 2014 Samsung Heavy Industries South Korea

Eurasia Drilling

Mercury Jackup 350 Under Construction 4Q 2014 Lamprell UAE

Neptune Jackup 250 Under Construction 3Q 2013 Lamprell UAE

GOL Offshore

GOL Offshore JU V351 Jackup 350 Under Construction 4Q 2013 Bharati Shipyard India

Gulf Drilling International

Dukhan Jackup 300 Under Construction 3Q 2014 Keppel FELS Singapore

Gulf Drilling International

Qatar 2022 Jackup 300 Under Construction 3Q 2013 Keppel FELS Singapore

Hercules Offshore

Discovery Resilience Jackup 400 Under Construction 4Q 2013 Keppel FELS Singapore

Discovery Triumph Jackup 400 Under Construction 2Q 2013 Keppel FELS Singapore

Japan Drilling

Hakuryu-11 Jackup 425 Under Construction 2Q 2013 Keppel FELS Singapore

Jindal Drilling

Jindal Star Jackup 350 Under Construction 4Q 2013 Lamprell UAE

Star Drilling JU Tbn1 Jackup 350 Under Construction 4Q 2014 Keppel FELS Singapore

1307off_54 54 6/28/13 2:16 PM

2013 Worldwide MODU construction/new order survey

R I G R E P O R T

www.offshore-mag.com • July 2013 Offshore 55

Rated Delivery Owner or manager/ water date Shipyard Rig name Rig type depth (ft) Status from yard Shipyard location

KS Drilling

KS Orient Star 1 Jackup 400 Under Construction 4Q 2013 COSCO Nantong China

KS Orient Star 2 Jackup 400 Under Construction 1Q 2014 COSCO Nantong China

Maersk Drilling

Maersk Drsh Tbn1 Drillship 12000 Under Construction 3Q 2013 Samsung Heavy Industries South Korea

Maersk Drsh Tbn2 Drillship 10000 Under Construction 4Q 2013 Samsung Heavy Industries South Korea

Maersk Drsh Tbn3 Drillship 10000 Under Construction 2Q 2014 Samsung Heavy Industries South Korea

Maersk Drsh Tbn4 Drillship 10000 Under Construction 3Q 2014 Samsung Heavy Industries South Korea

Maersk XL Enhanced 1 Jackup 492 Under Construction 2Q 2014 Keppel FELS Singapore

Maersk XL Enhanced 2 Jackup 492 Under Construction 3Q 2014 Keppel FELS Singapore

Maersk XL Enhanced 3 Jackup 492 Under Construction 1Q 2015 Keppel FELS Singapore

National Drilling

Marawah Jackup 200 Under Construction 2Q 2014 Lamprell UAE

NDC JU Tbn5 Jackup 200 Under Construction 4Q 2014 Lamprell UAE

NDC JU Tbn6 Jackup 200 Under Construction 1Q 2015 Lamprell UAE

Quarnin Jackup 200 Under Construction 1Q 2014 Lamprell UAE

Noble

Noble Bob Douglas Drillship 10000 Under Construction 4Q 2013 Hyundai Heavy Industries South Korea

Noble Globetrotter II Drillship 10000 Under Construction 2Q 2013 STX Offshore & Shipbuilding China

Noble Houston Colbert Jackup 400 Under Construction 4Q 2013 Jurong Shipyard Pte Ltd Singapore

Noble Mick O Brien Jackup 400 Under Construction 2Q 2013 Jurong Shipyard Pte Ltd Singapore

Noble Regina Allen Jackup 400 Under Construction 3Q 2013 Jurong Shipyard Pte Ltd Singapore

Noble Sam Croft Drillship 10000 Under Construction 2Q 2014 Hyundai Heavy Industries South Korea

Noble Sam Hartley Jackup 400 Under Construction 4Q 2014 Jurong Shipyard Pte Ltd Singapore

Noble Sam Turner Jackup 400 Under Construction 1Q 2014 Jurong Shipyard Pte Ltd Singapore

Noble Tom Madden Drillship 10000 Under Construction 4Q 2014 Hyundai Heavy Industries South Korea

Noble Tom Prosser Jackup 400 Under Construction 4Q 2014 Jurong Shipyard Pte Ltd Singapore

North Atlantic Drilling

West Linus Jackup 492 Under Construction 4Q 2013 Jurong Shipyard Pte Ltd Singapore

West Rigel Semisubmersible 10000 Under Construction 1Q 2015 Jurong Shipyard Pte Ltd Singapore

North Sea Rigs

North Dragon Semisubmersible 3937 Under Construction 4Q 2015 Yantai CIMC Raffles China

Ocean Rig

Ocean Rig Athena Drillship 10000 Under Construction 4Q 2013 Samsung Heavy Industries South Korea

Ocean Rig Mylos Drillship 12000 Under Construction 3Q 2013 Samsung Heavy Industries South Korea

Ocean Rig Skyros Drillship 10000 Under Construction 4Q 2013 Samsung Heavy Industries South Korea

Odfjell Drilling

Dalian Developer Drillship 10000 Under Construction 3Q 2013 COSCO Dalian China

Deepsea Aberdeen Semisubmersible 7500 Under Construction 2Q 2014 Daewoo South Korea

Opus Offshore

Opus Tiger 1 Drillship 5000 Under Construction 2Q 2014 Shanghai Shipyard China

Opus Tiger 2 Drillship 3000 Under Construction 4Q 2014 Shanghai Shipyard China

Pacific Drilling

Pacific Khamsin Drillship 10000 Under Construction 2Q 2013 Samsung Heavy Industries South Korea

Pacific Meltem Drillship 10000 Under Construction 2Q 2014 Samsung Heavy Industries South Korea

Pacific Sharav Drillship 10000 Under Construction 4Q 2013 Samsung Heavy Industries South Korea

PEMEX

Yunuen Jackup 400 Under Construction 1Q 2015 Keppel FELS Singapore

Perforadora Central

Coatzacoalcos Jackup 375 Under Construction 1Q 2014 Keppel AmFELS USA

Perforadora Mexico

PROSPECTOR 2 Jackup 400 Under Construction 3Q 2013 Dalian Shipbuilding Industry Co. China

PROSPECTOR 4 Jackup 400 Under Construction 4Q 2013 Dalian Shipbuilding Industry Co. China

Perisai

Perisai Pacific 101 Jackup 400 Under Construction 3Q 2014 PPL Shipyard Singapore

Petrobras

P-60 Jackup 350 Under Construction 2Q 2013 Sao Roque do Paraguacu Brazil

Prospector Offshore Drilling

PROSPECTOR 1 Jackup 400 Under Construction 3Q 2013 Dalian Shipbuilding Industry Co. China

PROSPECTOR 3 Jackup 400 Under Construction 4Q 2013 Dalian Shipbuilding Industry Co. China

PROSPECTOR 5 Jackup 400 Under Construction 1Q 2014 Shanghai Waigaoqiao Shipbuilding China

PROSPECTOR 6 Jackup 400 Under Construction 3Q 2014 Shanghai Waigaoqiao Shipbuilding China

1307off_55 55 6/28/13 2:16 PM

2013 Worldwide MODU construction/new order survey

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Rated Delivery Owner or manager/ water date Shipyard Rig name Rig type depth (ft) Status from yard Shipyard location

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Brava Star Drillship 12000 Under Construction 4Q 2014 Samsung Heavy Industries South Korea

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AOD III Jackup 400 Under Construction 3Q 2013 Keppel FELS Singapore

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West Jupiter Drillship 12000 Under Construction 3Q 2014 Samsung Heavy Industries South Korea

West Neptune Drillship 10000 Under Construction 2Q 2014 Samsung Heavy Industries South Korea

West Oberon Jackup 400 Under Construction 4Q 2013 Dalian Shipbuilding Industry Co. China

West Saturn Drillship 12000 Under Construction 2Q 2014 Samsung Heavy Industries South Korea

West Telesto Jackup 400 Under Construction 3Q 2013 Dalian Shipbuilding Industry Co. China

West Tellus Drillship 10000 Under Construction 3Q 2013 Samsung Heavy Industries South Korea

West Tucana Jackup 400 Under Construction 3Q 2013 Jurong Shipyard Pte Ltd Singapore

West Vela Drillship 10000 Under Construction 2Q 2013 Samsung Heavy Industries South Korea

Sevan Drilling

Sevan Louisiana Semisubmersible 10000 Under Construction 4Q 2013 COSCO Qidong China

Sevan UDW4 Semisubmersible 10000 Under Construction 2Q 2014 COSCO Qidong China

Shengli Offshore

Shengli XI Jackup 164 Under Construction 3Q 2014 Yantai CIMC Raffles China

Songa Offshore

Songa Encourage Semisubmersible 1640 Under Construction 1Q 2015 Daewoo South Korea

Songa Endurance Semisubmersible 1640 Under Construction 4Q 2014 Daewoo South Korea

Songa Equinox Semisubmersible 1640 Under Construction 2Q 2014 Daewoo South Korea

Standard Drilling

Standard Virtue Jackup 400 Under Construction 2Q 2014 Keppel FELS Singapore

Teniz Burgylau

Teniz Burgylau JU Tbn1 Jackup 262 Under Construction 1Q 2015 Keppel Kazakhstan Kazakhstan

1307off_56 56 6/28/13 2:16 PM

2013 Worldwide MODU construction/new order survey

VARIABLE BORE RAMS, INC.www.vbri.com+1.337.256.5334

Rated Delivery Owner or manager/ water date Shipyard Rig name Rig type depth (ft) Status from yard Shipyard location

Tianjin Haiheng

HAI HENG 2 Jackup 375 Under Construction 3Q 2014 China Merchants Heavy Industry China

HAI HENG 3 Jackup 375 Under Construction 1Q 2015 China Merchants Heavy Industry China

Transocean

Deepwater Asgard Drillship 10000 Under Construction 1Q 2014 Daewoo South Korea

Deepwater Invictus Drillship 10000 Under Construction 2Q 2014 Daewoo South Korea

Transocean Ao Thai Jackup 350 Under Construction 4Q 2013 Keppel FELS Singapore

TS Drilling

TS Amber Jackup 375 Under Construction 4Q 2013 China Merchants Heavy Industry China

TS Pearl Jackup 375 Under Construction 4Q 2013 China Merchants Heavy Industry China

Vantage Drilling

Decus Jackup 400 Under Construction 1Q 2014 PPL Shipyard Singapore

Fortius Jackup 400 Under Construction 4Q 2013 PPL Shipyard Singapore

Impetus Jackup 400 Under Construction 4Q 2014 PPL Shipyard Singapore

Tungsten Explorer Drillship 10000 Under Construction 2Q 2013 Daewoo South Korea

Varada Petroleum

Varada 1 Jackup 350 Under Construction 1Q 2014 ABG Shipyard India

Varada 2 Jackup 350 Under Construction 2Q 2014 ABG Shipyard India

Varada 3 Jackup 375 Under Construction 1Q 2015 ABG Shipyard India

Varada 4 Jackup 375 Under Construction 2Q 2015 ABG Shipyard India

Yantai Raffles

CIMC Raffles JU Tbn1 Jackup 300 Under Construction 4Q 2013 Yantai CIMC Raffles China

CIMC Raffles JU Tbn2 Jackup 300 Under Construction 4Q 2013 Yantai CIMC Raffles China

ZPMC

Zhenhai 1 Jackup 300 Under Construction 4Q 2013 ZPMC Nantong China

Source: IHS Petrodata (info as of May 31, 2013)

1307off_57 57 6/28/13 2:16 PM

58 Offshore July 2013 • www.offshore-mag.com

R I G R E P O R T

Regional demand spurs steady growth

of premium jackup fleet

Effciency and extended reach among criteria for new rigs

In the two years since Offshore’s last pre-mium jackup rig survey, the offshore drilling industry has steadily added to its global feet, and all indications point to this trend continuing. However, de-

mand for premium rigs, which are rated for water depths of 350 ft (106 m) or greater and drilling depths of at least 25,000 ft (7,600 m), varies dramatically by region.

The greatest demands are from the great-er Asia/Pacifc region, the North Sea, and Middle East. Roughly 31 of the 142 rigs high-lighted in this year’s survey are deployed in Asia Pacifc (22% of the total), followed by 28 in the North Sea (20%) and 15 in the Middle East (11%).

“Operators in these regions share com-mon drilling demands that typically cannot be met by older, lower-specifcation rigs,” says Jan van Bohemen, senior director of marketing, Eastern Hemisphere, for Ensco plc. These include the ability to drill extend-ed-reach wells to greater lateral distances and more high-pressure/high-temperature (HP/HT) wells, while achieving effciency gains to lower drilling costs.

Many of the newer rigs coming out of the shipyards include design upgrades to meet these demands. For example, the Ensco 120, a Keppel FELS Super “A” class rig, boasts effciency improvements such as a derrick system that automatically moves and racks pipe, which reduces operator error and im-proves safety by keeping rig workers off the foor while the derrick is in operation.

“Our engineers have further improved der-rick effciency by developing a new cantilever that uses nearly the full hoisting capacity of the derrick—up to 2.5 MMlb—when skidded out, even in the corners,” says Bohemen.

The Super “A” rig design also incorpo-rates improvements in pipe handling, al-lowing an operator to make up doubles and triples offine. The rig’s racking system can store up to 7,000 ft (2,134 m) of 13 3/8-in. casing, 10,000 ft (3,048 m) of 9 5/8-in. casing or 13,000 ft (3,962 m) of 7-in. casing. Ensco has expanded the rig’s capacity further to handle quad pipes.

“Once they are needed downhole, the der-rick and cantilever can pick up, move and run

these multi-joint casing strings, which is a huge effciency gain,” says Bohemen. “This reduces fat times by making fewer connec-tions, which also makes for a safer operation. It lets the operator optimize the time they ac-tually spend on bottom.”

Another requirement, particularly for op-erators in the North Sea, is for improved rig accommodations, which includes both an increase in the number of sleeping quarters and upgrades such as private rooms with fast wireless Internet connections. This year’s survey shows that many of the newer rigs are capable of accommodating 100 or more rig personnel, and new rigs are com-ing by 2015 that will house up to 140 people.

Going deeperMany of the newer rigs currently under

contract, and those still under construction in shipyards around the world, are designed for deeper waters and wells. Nearly 50 of the pre-mium jackups in the global feet are rated to wa-ter depths of 400 ft or greater, including Atwood Oceanics’ Mako, Manta and Orca rigs, all BMC Pacifc 400 class rigs rated for 400 ft (122 m) of water and 30,000 ft (9,144 m) of drilling depth. Similarly rated rigs include three Seadrill F&G JU-2000E rigs, the West Castor, West Oberon, and West Telesto. Over the next two years, Seadrill will add fve F&G JU-2000E rigs to its feet, while Ensco will add at least one Super “A” class rig and Noble Drilling will add at least three JU-2000 rigs, the Tom Prosser, the Sam Turner, and Sam Hartley. Freide & Goldman, the engineer-ing frm behind the JU-2000E design, states that there are currently more than 30 F&G jackup rigs under construction at various ship-yards around the world.

These rigs will likely be secured for con-tracts before they leave the shipyard, if cur-rent utilization rates hold. In May 2013, the global supply of premium jackups was 166, while the total under contract was 158, for a utilization rate of 95%. This is a marked in-crease from May 2011, when 122 premium

jackups out of a total of 142 were under con-tract (an 86% utilization rate).

This level of activity is not shared by so-called commodity rigs, those designed for water depths of 250 ft (76 m) or less.

“Our research has not uncovered any commodity rigs being built,” says Cinnamon Odell, analyst, Rigs, for IHS Petrodata. “In fact, operators are cold-stacking more of these traditional rigs due to their age. Many of these rigs have been in operation for more than 30 years, and rather than try to upgrade or refurbish them, operators are instead opt-ing for new, higher-specifcation rigs.”

Declining numbers The utilization rate in the US Gulf of

Mexico (GoM), while higher than it was in 2011, is still only at 63%—much lower than the global average.

“Deeper water foaters are seeing a steep-er incline in utilization and demand than jackups in US waters,” Odell says.

The past two years have seen a signifcant drop in the US jackup feet, as operators have sold off or simply decommissioned their older, smaller rigs. In late 2012, for example, Trans-ocean completed its sale of 38 jackups to Shelf Drilling Holdings. Many of these rigs went into service in the mid-1980s and are rated to a maximum water depth of 300 ft (91 m).

“Sell-offs like this help confrm that there is not as much frontier acreage out there for jackups, particularly those rated for shallow-er depths,” Odell says. “There will likely be a continued slight incline in premium jackup demand, but largely outside of the US Gulf.”

At the same time, jackup builders are gearing up for a move into the Arctic. Keppel Offshore & Marine and ConocoPhillips are jointly designing a frst-of-its-kind jackup rig to operate in the harsh and icy waters of the Barents and Beaufort seas. The joint design project, scheduled for completion by the end of 2013, may usher in a new class of rig that will soon fnd a place on future premium jackup rig surveys.

Additional information on the current state of the premium jackup feet can be found in the poster contained within this issue of Off-shore. •

Ted MoonSpecial Correspondent

1307off_58 58 6/28/13 2:16 PM

1307off_59 59 6/28/13 2:16 PM

2013 WORLDWIDE SURVEY OF

DEEPWATER JACK-UP RIGS

For additional paper copies or general comments E-mail: posters@pennwell.com. PDF Downloads available at www.offshore-mag.com

JULY 2013

M A G A Z I N E

Offshore Magazine – 1455 West Loop South, Suite 400; Houston, TX 77027 Tel: 713-963-6200; Fax: 713-963-6296; www.offshore-mag.com

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RIG INFORMATION RIG RATINGS CONTRACT INFORMATION VESSEL PARTICULARS MOORING SYSTEM LIFTING EQUIPMENT MUD & SOLIDS CONTROL SYSTEMS BOP EQUIPMENT & CONTROL SYSTEMSNORMAL COMPLEMENT OF TUBULARS

Ft. Ft. Ft. Ft. Ft. Ft. Expiration As of July 2011 H.P. Ft. Ft. Ft. Y/N Y/N S.T. S.T. W x L Ft. x Ft. No. S.T. in. Ft. No. & H.P. S.T. S.T. S.T. S.T. S.T. S.T. Y/N Name Ft. x Ft. H.P. in. in. Model ModelManufacturer & Model Manufacturer & Model Psi Bbls Bbls Bbls Cu.Ft. No. No. No. No. No. No. Ksi I.D. in. No.Manufacturer Manuf. Manuf.Ft. Ft. Ft. Ft. Ft. Ft. No.ManufacturerModelKnots PAXY/N Ft. Kips No. Kips Type Type Manuf.in. I.D Y/NGrade

RO

TATI

NG

MO

US

EHO

LE (

Y/N

)

Y/N

CO

ND

UC

TER

TEN

SIO

NIN

G C

APA

CIT

Y

DRILLING EQUIPMENT

S.T.

BOP & BOP CONTROL DATA

ABAN OFFSHORE CONTACT: P. Venkateswaran, Dy, Managing Director; Aban; Tel: +91-44-28195555; Fax: +91-44-28195527; Email: venkatp@aban.com; Web site: www.aban.com

16 ABAN VIII BMC Pacific 375 2008 Singapore ABS 375' 10' 30' 506' N 56' 30,000' Jun-13 Middle East 120 245' 224' 16' S61 N Y Y 2,495 70' x 30' 4 1.5" IWRC 6x36 3,500' 6 50 50 22.6 Y 1,600 Loadmaster 35' x 35' 3,000 National 1.625" 49.5" 227 N Rogers OilTools National TDS 85A NOV Varco NOV 3 LEWCO 2215 7,500 1,000 3,000 10,560 3 2 1 1 1 15 3" 2 Hydril 2 Hydril 132 13-5/8" Flange 49.5" 14" PLC CAD Y

16 Deep Driller 1 Baker Marine Pacific 2006 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' West Coast of India 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 N 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 250 N Hydralift-MPT National HPS-E-DC-2S-SG NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 2 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 2 KFELS Super ‘B’ class 2006 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' Middle East 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-220 7,500 1,950 2,950 15,700 4 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

13 Deep Driller 3 KFELS Super ‘B’ class 2006 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-221 7,501 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

16 Deep Driller 4 Baker Marine Pacific 2007 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 Y 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 227 N Hydralift-MPT National HPS-E-DC-2S-SG NOV 6T Bridge Racker NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 4 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 5 KFELS Super ‘B’ class 2007 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 2 National 14-P-222 7,502 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

13 Deep Driller 6 KFELS Super ‘B’ class 2008 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' May-14 Middle East 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-223 7,503 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

16 Deep Driller 7 Baker Marine Pacific 2008 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 Y 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 227 N Hydralift-MPT National HPS-E-DC-2S-SG NOV 6T Bridge Racker NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 2 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 8 KFELS Super ‘B’ class 2008 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' Sep-14 Brunei 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR-6 Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-224 7,504 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

PT APEXINDO PRATAMA DUTA Tbk CONTACT: Irman Rumadja PT. Apexindo Pratama Duta, Tbk. Medco Building 2nd – 3rd Floor, Jl. Ampera Raya No. 20, Cilandak Jakarta 12560 Tel : (62-21) 7800840, 7804766 Fax : (62-21) 7804666, 7800815; Email: irman.rumadja@apexindo.com, Website: www.apexindo.com

15 Raniworo BMC 350 Singapore ABS 350' 15' 30' Y 55' 25,000' Jan-16 Indonesia 100 45' X 24' 1,250 2,000 Oil Well Varco TDS-4S Varco 3 Oil Well - Triplex 1,700 9,140 4 1 2 10 4 1 13-5/8" Flange 30" Hydraulic

16 Soehanah BMC Pacific 375 2007 Singapore ABS 375' 15' 30' 505' Y 55' 25,000' Aug-15 Indonesia 14,450 4-5 115 326' 224' n/a S61 N N Y 2,500 3,975 75' 60' x 30' 4 40 1.5" n/a 3,000' 6 75 @ 35' 45 @ 25' 25 @ 20' Y 1,400 Pyramid 35' x 35' 2,800 Wirth 1.63" 49.5" 220 N Maritime Hydraulic Maritime Hydraulics 650 Ton Hitec 2,000' 13,000' 7,000' 3 Wirth - 2200 7,500 1,900 3,500 1,800 11,600 5 1 1 3 10 3.0625" 4 Shaffer 1 Shaffer 155 Flange 49.5" 14" Hydraulic Sara N

ATWOOD OCEANICS, INC. CONTACT: Tony Dyne, Alpha Offshore Drilling Services Co., 332-A-11C, 11th floor, Plaza Ampany City Jalan Ampang 50450 Kuala Lumpur, Malaysia, Tel: 603-4256-9590, Fax: 603-4257-9208, Email: marketing@atwd.com, Website: www.atwd.com

12 Atwood Beacon KFELS enhanced ‘B’ class 2003 Singapore ABS 400' 25' 18' 517' Y 47' 36,000' Jul-13 Israel 9,275 est. 3-4 112 234' 208' 15' S61 N & S92 N Y 2,800 4 50 1.5" EIPS 2,500' 5 36.5 @ 45' 27.7 @ 40' 27.7 @ 40' Y 1,500 WCI 36' x 36' 3,300 NOI Ensco 1.63" 49.5" 250 Y Varco ST-80 Varco TDS-8SA NOI Cyber Base 15,000' 5,000' 3 Lewco 2200 7,500 24,112 647 838 11,100 5 linear 5 1 1 1 2K & 15K 3" 2 & 4 Cameron 1 & 1 Shaffer 60 & 147 Flanged 49.5" 14" Electro-pneumatic S & S

17 Atwood Mako BMC Pacific 400 2012 Singapore ABS 400' 532' Y 55' 30,000' Sep-14 Thailand est. 3-4 150 237' 224' 15' N Y 2,500 3,750 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" Y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Flanged Electro-pneumatic CAD

17 Atwood Manta BMC Pacific 400 2012 Singapore ABS 400' 532' Y 55' 30,000' Dec-13 Thailand est. 3-4 150 237' 224' 15' N Y 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" Y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Electro-pneumatic CAD

17 Atwood Orca BMC Pacific 400 2013 Singapore ABS 400' 532' Y 55' 30,000' May-15 Thailand est. 3-4 150 237' 224' 15' N Y 2,500 3,750 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Flanged Electro-pneumatic CAD

6 Atwood Aurora LeTourneau Super 116E 2008 USA ABS 350' 33' 18' 477' Y 46' 30,000' Feb-14 Cameroon 10,750 est. 3-4 110 243' 206' 16.5' S61 N & S92 N Y 2,425 4 1.5" EIPS 2,500' 5 50 @ 25' 41 @ 25' 41 @ 25' Y 1,500 Loadmaster 35' x 35' 4,500 Lewco 1.75" 49.5" 200 Y ST-80 Varco TDS-8SA Atwood System Omron 5,000' 3 Lewco 2215 7,500 5,056 1,068 682 12,200 5 linear 5 1 1 1 15K 3-1/16" 2 Cameron 1 Shaffer 212 Flanged 49.5" 14" Electro-pneumatic CAD

CHINA OILFIELD SERVICES Ltd. CONTACT: None provided by company

12 COSL Craft KFELS ‘B’ class 2007 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Lewco W-2215 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Power BMC Pacific 375 2006 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 25 45 55 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

16 COSL Superior BMC Pacific 375 2007 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

12 COSL Boss KFELS ‘B’ class 2007 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Mission Magnum or equivalent 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Force BMC Pacific 375 2008 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 25 45 55 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

12 COSL Strike KFELS ‘B’ class 2009 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Lewco W-2215 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Seeker BMC Pacific 375 2008 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

16 COSL Confidence BMC Pacific 375 2009 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

23 COSL 941 F & G JU2000 2006 China ABS 400' 30' 548' 30,000' 120 231' 249' N 4,150 5,000 75' 75' x 30' 2,000 National 40' x 40' NOV 49.5" Hydralift HPS 750-E

23 COSL 942 F & G JU2000 2008 China CCS 400' 30' 548' 30,000' 120 231' 249' N 4,150 5,000 75' 75' x 30' 2,000 National 40' x 40' NOV 49.5" Hydralift HPS 750-E

DIAMOND OFFSHORE DRILLING, INC. CONTACT: Contracts & Marketing, 15415 Katy Fwy Suite 100, Houston, Texas 77094; Phone: (281) 492-5300; Fax: (281) 492-5310; Website: diamondoffshore.com

2 Ocean Titan LeTourneau 64 1974 USA 2003 ABS 350' 25' 26' 467' N 46' 25,000' 1Q/14 US GoM 5,850 4 76 237.1' 200.5' 17' S61 N Y 2,530 3,375 65' 30' x 55' 0 46 30 N 1,700 Brown 30' x 30' 3,000 National 1.75" 37.5" N Varco AR3200 Varco TDS-4H Petron 15,000' 3 National 12-P-160 5,000 980 445 5,500 3 2 1 1 1 10 3-1/16" 4 Cameron 1 Shaffer 75 Flanged 10M 27.5" 12" Electro-pneumatic Shaffer N

13 Ocean Scepter KFELS Super ‘B’ class 2008 USA –– ABS 350' 36' 20' 486' Y 47' 35,000' Aug-13 Mexico 12,069 4 120 246' 218' 16' S61 N & S92 Y Y 2,431 3,992 70' 60' x 30' 0 62 53 53 Y 2,000 National 36' x 36' 4,600 National 2" 49.5" 250 N Nat’l Hydratong MPT National Oilwell HPS National BR6-SD National 7,000' 15,000' 13,000' 3 NOV 14-P-220 7,500 3,330 1,879 1,000 15,000 4 1 1 1 1 15 3-1/16" 4 Shaffer 1 Shaffer NXT 18-3/4" x 15M 49.5" 16" Electro-Hydraulic CAD Y

EGYPTIAN DRILLING COMPANY CONTACT: Km 17.5, Cairo Suez Desert Road P.O.Box 8071 Nasr City Housing, Cairo 11371; Phone: (+202) 24062222; Fax: (+202) 24062310; Email: contactus@egyptian-drilling.com

16 Setty BMC 375 2010 Singapore ABS 375' 506' Y 30,000' Aug-14 9,275 120 236' 224' 2,268 3,401 75' x 30' 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Cameron 18-3/4" 49.5" CAD

16 Sneferu BMC 375 2009 Singapore ABS 375' 506' 30,000' Sep-15 9,275 120 236' 224' 2,268 3,401 75' x 30' 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

EGYPTIAN OFFSHORE DRILLING COMPANY Contact: 85 Nasr Road, 1st District, Nasr City, Cairo, Egypt, P. O. Box 8064, Nasr City 11371; Phone: 202 24055845, 6, 7, 8; Fax: 202 24055876; Email: egas@egas.com.eg

16 El Qaher I BMC 375 2010 Singapore ABS 375' 506' 30,000' Aug-13 9,275 120 237' 224' 2,268 3,401 70' x 30' 38 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

16 El Qaher II BMC 375 2011 Singapore ABS 375' 506 30,000' Q2 2013 9,275 120 237' 224' 2,268 3,401 70' x 30' 38 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

ENSCO PLC CONTACT: Mike Roth 5847 San Felipe Suite 3300 Houston, Texas 77057; Phone: (713) 789-1400; (713) 789 -1430; Email: mroth@enscoplc.com; Website: www.enscoplc.com

3 ENSCO 67 MLT 84-CE (enhanced) 1976 Scotland 2005 ABS 350' 25' 24' 511' Y 46' 30,000' 2Q16 SE Asia 6,600 5 108 238' 227' 16' MI-172 N Y 1,987 3,792 60' 60' x 30' 4 25 1-3/8" IWRC 2,500' N 5 45 45 50 N/A N/A Y 1,500 NOI / Dreco 30' x 30' 3,000 National 1.75" 37.5" 175 Y Varco ST 80 Varco TDS-4H N/A MDT 20,000' 3 National 12-P-160 5,000 2,644 Incl. 2,472 6,240 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 48/58 Cameron 37.5" 12" TD-280-3S Shaffer Y

4 ENSCO 68 MLT 116-CE (enhanced) 1976 USA 2003 ABS 400' 12' 22' 512' Y 46' 30,000' 1Q14 GoM 6,600 4 80 261' 227' 15.5' S61 N Y 2,753 3,783 60' 45' x 30' N/A N/A N/A N/A N/A N N/A 45 45 45 N/A N/A Y 1,500 NOI / Dreco 30' x 30' 3,000 National 1.75" 37.5" 175 Y Varco ST 80 NOI PS2-650 N/A MDT 15,000' 3 National 12-P-160 5,000 1,685 Incl. 6,240 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 48/58 Cameron 21.25" 12" TD-280-3S Shaffer Y

5 ENSCO 75 MLT Super 116C 1999 USA N/A ABS 380' 42' 32' 544' N 57' 30,000' 1Q14 GoM 7,420 3 83 243' 206' 16' S61 N Y 1,750 3,250 70' 55' x 30' N/A N/A N/A N/A N/A N N/A 50 50 50 N/A N/A Y 1,500 Loadmaster 32' x 35' 3,000 National 1.75" 49.5" 175 Y MH-1899 Varco TDS 8SA N/A Hi-Tech 26,000' 26,000' 3 National 14-P-220 7,500 2,229 Incl. 1,100 11,100 5 0 1 1 1 0 10 3.06" 3 Cameron 1 Shaffer 86 Cameron 29.5" 12" TX392-15BT3X Koomey Y

5 ENSCO 76 MLT Super 116C 1999 USA N/A ABS 350' 25' 16' 411' Y 46' 30,000' 2Q14 Saudi Arabia 10,056 3.5 100 243' 206' 16' S61 N Y 1,907 4,000 65' 50' X 30' 2 25 1.5" 6 x 36 IWRC 2,000' N N/A 50 50 50 N/A N/A Y 1,500 Dreco 40' x 32' 3,000 National 1.63" 49.5" Y Varco AR-3200 Varco TDS-8SA N/A Hi-Tech 24,000' 24,000' 3 National 14-P-220 7,500 2,907 1,416 10,880 5 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer 100 Flange 39" 12" SSB2403S11 M/SS Y

4 ENSCO 81 MLT 116-C 1979 UK 2003 ABS 350' 25' 20' 477' N 46' 25,000'+ 4Q13 GoM 6,600 4 106 243' 200' 16' S61 N Y 1,975 3,920 59.5' 45' x 24' N/A N/A N/A N/A N/A N N/A 45 45 45 N/A N/A Y 1,500 Dreco 30' x 30' 3,000 National 1.75" 37.5" Y Varco TDS 4H 750 T N/A Oilfield Inst. 15,000' 3 National 12-P-160 5,000 1,401 Incl. 8,160 4 1 0 10 3.06" 3 Shaffer 1 Shaffer 80 Flange 21.25" 12" T-SB-540 CAD Y

4 ENSCO 87 MLT 116-C 1982 USA 2006 ABS 350' 25' 25' 477' N 46' 25,000'+ 3Q13 GoM 6,600 4 75 243' 200' 16' S61 N Y 1,970 4,234 60' 45' x 30' N/A N/A N/A N/A N/A N N/A 50 50 50 N/A N/A N 1,500 National 30' x 30' 3,000 National 1.75" 37.5" Y Varco ST-80 Varco TDS 8SA N/A MDT 15,000' 3 National 12-P-160 5,000 1,689 Incl. 6,880 4 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 60 Flange 21.25" 12" T-SB-540 CAD Y

10 ENSCO 101 KFELS MOD V ‘A’ class 2000 Singapore 2010 ABS 400' 25' 25' 540' Y 60' 30,000' 1Q15 North Sea 11,130 4 to 5 96 228' 222' 16' S92 N Y 3,500 6,400 70' 55' x 30' 4 51 2" 6 x 36 IWRC 2,060' N 7.5 55 55 55 N/A N/A Y 1,500 Dreco 40' x 40' 3,000 National 1.75" 49.5" 500 Y AR-3200 Varco TDS-4H PRS4i MDT 9,000' 19,500' 3 National 14-P-220 5,000 4,808 Incl. 1,370 17,600 4 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer Flange 57" 14" Hydraulic Shaffer Y

10 ENSCO 102 KFELS MOD V ‘A’ class 2002 Singapore N/A ABS 400' 25' 25' 541' Y 60' 30,000' 1Q16 North Sea 11,130 4 to 5 122 246' 222' 16' S92 N Y 4,281 6,378 70' 55' x 30' 4 51 2" 6 x 36 IWRC 2,060' N 7.5 55 55 55 N/A N/A Y 1,500 Dreco 40' x 40' 3,000 National 1.75" 49.5" 400 Y AR-3200 Varco TDS-4H PRS4i MDT 20,000' 5,000' 3 National 14-P-220 7,500 5,216 Incl. 1,370 17,640 4 0 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer 190 Flange 49.5" 14" Hydraulic Shaffer Y

12 ENSCO 104 KFELS MOD V ‘B’ class 2002 Singapore 2011 ABS 400' 25' 20' 517' Y 47' 30,000' 1Q14 Australia 9,275 4 to 5 110 225' 208' 14' S61 N Y 2,500 3,348 70' 70' X 30' 4 50 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 National 1.63" 49.5" Y Varco ST-80/ST4566 Varco TDS-8SA N/A Hi-Tech 20,000' 11,400' 3 National 14-P-220 7,500 3,598 Incl. 2,438 11,100 5 5 1 1 1 2 10 3.06" 4 Cameron 1 Shaffer Flange 30" 12" TX-392 15BT3X ABB Y

12 ENSCO 105 KFELS MOD V ‘B’ class 2002 USA 2010 ABS 400' 25' 16' 517' Y 46' 30,000' 4Q13 SE Asia 9,275 4 to 5 94 225' 208' 14.5' S61 N Y 3,600 6,649 70' 70' x 30' 2 25 1.25" IWRC 3,000' N 7.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 National 1.63" 49.5" 250 Y AR-3200 Varco TDS-4H N/A NOV SDI /200 20,000' 3 National 14-P-220 7,500 3,876 Incl. 1,083 11,100 5 1 0 10 3.06" 4 Cameron 1 Shaffer 164 Flange 30" 12" TX-392 15BT3X Koomey Y

12 ENSCO 106 KFELS MOD V enhanced ‘B’ class 2005 Singapore N/A ABS 400' 25' 20' 517' Y 53' 30,000' 4Q13 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 Varco / MIL 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA N/A Varco Amphion 20,000' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 10 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

12 ENSCO 107 KFELS MOD V enhanced ‘B’ class 2006 Singapore N/A ABS 400' 25' 20' 517' Y 53' 30,000' 3Q14 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 WCI 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA Varco Compact Racker Varco Amphion 20,000' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 10 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

12 ENSCO 108 KFELS MOD V enhanced ‘B’ class 2007 Singapore 2009 ABS 400' 25' 20' 517' Y 53' 30,000' 2Q14 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 WCI 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA N/A Varco Amphion 20,000' 10,300' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 15 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

13 ENSCO 109 KFELS MOD V Super ‘B’ class 2008 Singapore N/A ABS 400' 25' 20' 486' Y 53' 30,000' 3Q13 Australia 12,250 4 to 5 120 246' 218' 16' S92 Y Y 5,221 7,984 70' 70' x 30' 0 N/A N/A N/A N/A N N/A 50 50 55 N/A N/A Y 2,000 NOV 36' x 36' 4,600 NOV 2.0'' 49.5'' 500 N NOV Hydratong NOV HPS-1000 NOV Bridge Racker NOV SDI /Cyberbase 10,000' 15,000' 3 National 14P-220 7,500 5,364 Incl. 1,015 15,890 4 4 1 1 0 15 3.06" 4 NOV/Shaffer 1 Shaffer 207 BX 164 49.5" 16" CAD4801037OU2 CAD Y

11 ENSCO 120 KFELS MOD V Super ‘A’ class 2013 Singapore N/A ABS 400' 100' 25' 540' N 59.7' 40,000' 2Q15 North Sea 12,900 4 150 246' 250' 20.4' S92 N Y 4,048 7,148 80' 60' x 32' 4 49 2" IWRc 2,000' N 7 70 70 70 N/A N/A Y 2,500 NOV 40' x 40' 6,000 NOV 2.0" 60.5" 600 Y NOV ST-160 NOV TDX-1250 NOV PRS-6is NOV Amphion 20,000' 5,070' 3 NOV 14-P-220 7,500 7,500 Incl. 17,640 4 1 1 0 15 3.06" 4 NOV/Shaffer 1 Shaffer BX 164 49.5" 16" Koomey Y

EURASIA DRILLING CONTACT: Kim L. Kruschwitz, Vice President, Marketing; investor.relations@eurasiadrilling.com

6 Neptune LeTourneau Super 116E 2013 UAE 350' 30,000' Caspian 1,500 Woolslayer 35' x 32' 3,000 Lewco 49.5" NOV TDS-8SA 3 Lewco W-2214 7,500

12 Saturn KFELS Mod V 2000 Azerbaijan ABS 350' n/a 19' 496' n/a 2,690' 26,000' Caspian 6,436 3.5 100 228' 228' 17.7' S61N or MI-8 Y Y 2,700 5,900 45' 12' x 12' 4 103 1.5" 2,625' N 4 x 4 55 55 55 N 1,300 Loadmaster 40' x 40' 3,000 National 1.75" 37.5" MH-1899 Canrig 1275 E MH BC01 Sedco Forex 22,000' 1,000' 3 National 14-P-200 7,500 4,000 2,000 5,800 5 2 2 1 N 15 3.06" 2 Shaffer 1 Shaffer 180.7 Shaffer 27.5" 12" Hydraulic Shaffer Y

GREATSHIP GLOBAL ENERGY SERVICES CONTACT: Mr. V. Sheshashayee, 15, Hoe Chiang Road, Tower Fifteen, #06-03, Singapore 089316; Phone +65 65765600

6 GreatDrill Chaaya LeTourneau Super 116E 2013 UAE ABS 350' 30 478' 30,000' 10,750 106 243 206 29' S61 N Y 1,826 3,322 4 30 1.5" XIPS 2,500' 5 68 @ 39' 38 @ 25' 38 @ 25' 1,500 LeTourneau 32' x 35' 4,500 LEWCO 49.5" Varco ST-120 NOV TDS-8SA 3 Lewco W-2214 2,200 12,250 4 1 1 1 15K/2K 3.06" 3 Cameron 2 Cameron Cameron 49.5" Pneumatic Ingersol Rand

12 GreatDrill Chiltra KFELS 'B' class 2009 Singapore ABS 350' 15' 30' 491' Y 53' 30,000' 9,275 112 234' 208' 16' S61 N N Y 3,600 70' 51.5' x 30' 4 30 1.5" XIPS 2,500' n/a 5 50 @ 40' 50 @ 40' 50 @ 40' Y 1,500 WCI 35' x 32' 3,000 NOV 1.75" 49.5" 200 Y Varco ST-80 NOV TDS-8SA VCR NOV 308' stds 308' stds 10 stds 3 NOV 14-P-220 7,500 1,750 1,750 11100 4 1 1 1 1 1 10K / 2K 3.06" 4 Cameron 1 Cameron 68 29.5" Cameron Y

12 GreatDrill Chetna KFELS 'B' class 2009 Singapore ABS 350' 15' 30' 491' Y 53' 30,000' 9,275 104 234' 208' 16' S61 N N Y 1,631 3,600 70' 51.5' x 30' 4 30 1.5" XIPS 2,500' n/a 5 50 @ 40' 50 @ 40' 50 @ 40' Y 1,500 WCI 35' x 32' 3,000 NOV 1.75" 49.5" 200 Y Varco ST-80 NOV TDS-8SA VCR NOV 308' stds 10 stds 3 NOV 14-P-220 7,500 1,750 1,750 11100 4 1 1 1 1 1 10K / 2K 3.06" 4 Cameron 1 Cameron 68 Cameron 29.5" Cameron Y

HERCULES OFFSHORE CONTACT: Brad James, 9 Greenway Plaza, Suite 2200, Houston, Texas 77046; Phone: 713-350-8438; Fax: 713-350-5114; Email: bjames@herculesoffshore.com; Website: www.herculesoffshore.com

4 Hercules 350 LeTourneau 116-C 1982 Canada 8/1/2010 ABS 350' 25' 25' 477' N/A 46' 25,000' GOM 6,000 4.2 83 243' 200' 15.75' S61/S92 60' Y/N 3,704 5,204 60' N/A N/A N/A N/A N/A N/A N/A 50 50 50 N/A N/A Y 1,250 Brown 30' x 30' 3,000 National 1625 1.5" 37.5" N/A Y CanRig TM-80 Varco TDS-3 N/A MD Totco 15,000' N/A N/A N/A N/A N/A 2 National 12-P-160 3,980 851 916 1,200 4,200 3 N/A 1 1 1 N/A 3 3" 4 Cameron 1 Hydril 50 Flange 21.25" 12" Electrohydraulic CAD N

JAPAN DRILLING CO. Ltd. CONTACT: Mr. Michiharu Ureshino, Shin-horidome Bldg. 6F, 2-4-3 Nihonbashi Horidome-cho, Chuo-ku, Tokyo, 103-0012, Japan Tel : (81-3) 5847-5855 Fax : (81-3) 5644-5702 Email: michiharu.ureshino@jdc.co.jp Website: www.jdc.co.jp

16 Hakuryu 10 BMC Pacific 375 2008 Singapore ABS 375' 30' 30' 506' N 55' 30,000' 12000 4 to 5 120 236' 224' 17' S61 N & S92 N Y 2,500 3,000 70' 55' x 30' 4 32 1.7" IWRC 3,000' 6 55 @ 25' 45 @ 25' 25 @ 20' Y 1,500 NOV 35' x 35' 3,000 NOV 1.63" 49.5" N MPT200 NOV HPS-750E-AC Bridge Racker NOV BR6-SD NOV cyberbase 308' stds 10 stds 3 National 14-P-220 7,500 2,000 2,000 1,200 11,750 4 1 15 3" 4 Cameron 1 Shaffer 265 15K flanged 49.5" 12" mod. 2QD00 Shaffer Y

13 Hakuryu 11 KFELS Super ‘B’ class 2013 Singapore ABS 425' 10' 531' 47' 35,000' 150 246' 218' S61 N & S92 2,268 3,400 70' 4 57 @ 25' 57 @ 25' 70 @ 25' Y 2,000 1,150 NOV 2" 49.5" NOV ST-120 NOV TDS-1000A NOV Amphion 366' stds 3 National 14-P-220 7,500 15,050 5 1 15 4 Cameron 1 Shaffer 18-3/4" Cameron

DISCOVERY DRILLING Pte. Ltd. (Jindal's JV Company) CONTACT: V. K. Nagpaul, 63, Robinson Road, #02-10 Afro Asia Building, Singapore-068894 Tel: +65-62218522 Fax:+65-62218225 Email: vkn@discoverydrilling.sg

12 Discovery I KFELS ‘B’ class 2008 Singapore ABS 350' 15' 30' 491' Y 47' 30,000' 1Q/2017 Indian W. Offshore 9,275 4 112 234' 208' 15' S61 N Y Y 1,800 3,700 70' 70' x 30' 4 30 1.5" IWRC, EIPS 2,000' 5 50 50 50 Y 1,600 WCI 32' x 35' 3,000 Varco ADS 1.75" 49.5" 220 Y Varco ST 80 Varco TDS-8S-A Varco VCR Varco Amphion 5,000' 11,500' 4,000' 3 NOV 14-P-220 7,500 1,648 2,000 1,000 11,000 4 1 1 1 1 10 3.06" 4 Cameron 1 Cameron 143 Flanged 29.5" 14" Hydraulic Cameron N

12 Virtue I KFELS ‘B’ class 2008 Singapore ABS 350' 15' 30' 491' Y 47' 30,000' 1Q/2014 Indian W. Offshore 9,275 4 112 234' 208' 15' S61 N Y Y 1,800 3,700 70' 70' x 30' 4 30 1.5" IWRC, EIPS 2,000' 5 50 50 50 Y 1,600 WCI 32' x 35' 3,000 Varco ADS 1.75" 49.5" 220 Y Varco ST 80 Varco TDS-8S-A Varco VCR Varco Amphion 5,000' 11,500' 4,000' 3 NOV 14-P-220 7,500 1,648 2,000 1,000 11,000 4 1 1 1 1 10 3.06" 4 Cameron 1 Cameron 143 Flanged 29.5" 14" Hydraulic Cameron N

KCA DEUTAG Contact: Minto Drive, Altens Industrial Estate, Aberdeen AB12 3LW, Scotland; Phone: 44 1224 299600; Fax: 44 1224 230403; Website: www.kcadeutag.com

1 Ben Rinnes LeTourneau 53 1973 USA 2007 ABS 350' 18' 478' 46' 30,000' West Africa 8,880 100 284' 233' S61 43 50 44 1,500 Pyramid 30' x 40' 3,000 National 37.5" Varco TDS-8SA 300' stds 3 National 12-P-160 7,500 3 1 10 2 Cameron 1 Cameron 21.25" Shaffer

MAERSK DRILLING CONTACT: Maersk Drilling; 50, Esplanaden; 1098 Copenhagen K, Denmark; Phone: (45) 33-63-33-63; FAX: (45) 33-63-31-82; Email: copenhagen@maersk-drilling.com; Website: www.maersk-drilling.com

15 Maersk Endurer BMC 350 1984 Japan 1997 ABS 350' 16.4' 30' 479' N 56' 30,000' 4Q/’14 Cameroon 11,420 4 98 236' 236' 17.1' S61 N N Y 2,075 3,250 55' 45' x 32' 4 20 1.5" BS302 3,000' N 5 47.6 47.6 Y 1,500 WCI 35' x 30' 3,000 Continental Emsco 1.63" 49.5" 4 x 81 Varco AR3200 Varco TDS-4S PRS-3 mD TOTCO 14,800' 11,000' 3 Cont'l Emsco FC-2200 7,500 1,610 1,885 1,500 10,000 4 15 3.06" 4 Shaffer 1 Shaffer 156 Flange 49.5" 16" Multiplex Shaffer Y

20 Maersk Gallant MSC CJ62-120S 1993 Singapore Lloyds 394' 16.4' 30' 575' Y 64' 25,000' 2Q/’14 North Sea 8,075 4 100 257' 296' 19.4' S61 N Y Y 2,959 5,000 64' 54' x 30' 4 53 2" BS302 2,620' N 8 50 34 50 Y 2,000 Emsco 40' x 40' 3,000 Continental Emsco 1.75" 49.5" 4 x 60 Varco AR3200 Varco TDS-6S PHM-3 HiTEC 15,000' 5,000' 3 Cont'l Emsco FC-2200 7,500 3,150 1,890 1,700 14,700 4 1 2 15 3.06" 3 Shaffer 1 Shaffer 185 Flange 49.5" 14" TX 448 Koomey Y

24 Maersk Giant Hitachi Zosen 1986 Japan 2012 Lloyds 350' 16.4' 30' 525' Y 56' 25,000' 3Q/’13 North Sea 8,253 4 100 277' 295' 15.7' S61 N & S92 Y Y 3,050 5,000 55' 45' x 26' 3 55 2" BS302 2,460' N 8 27 45 65 Y 1,000 National 30' x 30' 2,000 National 1.50" 49.5" 4 x 100 Varco AR4497 Varco TDS-4S PRS 8i Varco 17,000' 3 National 12-P-160 5,000 2,900 1,450 13,500 4 15 2.5" 3 Shaffer 1 Shaffer 143 NT-2 49.5" 12" T-3000 NL Shaffer Y

24 Maersk Guardian Hitachi Zosen 1986 Japan 2011 Lloyds 350' 16.4' 30' 515' Y 56' 25,000' 2Q/’14 North Sea 8,253 4 100 277' 295' 15.7' S61 N & S92 N Y 3,050 5,000 55' 45' x 26' 4 55 2" BS302 2,620' N 8 68 27 45 Y 1,000 National 30' x 30' 2,000 National 1.50" 49.5" 4 x 75 Varco AR4498 Varco TDS-4S PRS 8i Varco 16,000' 6,200' 3 National 12-P-160 5,000 2,500 2,830 1,448 13,500 4 15 2.5" 4 Shaffer 1 Shaffer 183 Flange 49.5" 12" T-3000 NL Shaffer Y

21 Mærsk Innovator MSC CJ70-150MC 2003 Korea DnV 492' 9.8' 30' 673' Y 72' 30,000' 1Q/’17 North Sea 14,420 4 120 291' 336' 26.2' GKN Westland 101 & S61 N N Y 4,680 10,000 90' 86' x 66' 4 80 2.25" BS302 3,400' N 8 100 100 100 Y 2,000 WCI 46' x 52.5' 4,600 Varco 1.75" 49.5" 4 x 100 Varco AR4500 Varco TDS-8SA PRS 6is Varco 25,100' 4 Wirth TPK 7,500 6,400 3,030 4,760 15,883 6 2 2 15 3.06" 4 Shaffer 1 Shaffer 200 NT-2 49.5" 14" MUX 4rd Generation Shaffer Y

21 Mærsk Inspirer MSC CJ70-150MC 2004 Korea DnV 492' 9.8' 30' 673' Y 72' 30,000' 4Q/’14 North Sea 14,420 4 120 291' 336' 26.2' GKN Westland 101 or S61 N N Y 4,680 10,000 90' 86' x 66' 4 80 2.25" BS302 3,400' N 8 100 100 100 Y 2,000 WCI 46' x 52.5' 4,600 Varco 1.75" 49.5" 4 x 100 Varco AR4500 Varco TDS-8SA PRS 6is Varco 25,100' 4 Wirth TPK 7,500 6,400 3,030 4,760 15,883 6 2 2 15 3.06" 4 Shaffer 1 Shaffer 200 NT-2 49.5" 14" MUX 4rd Generation Shaffer Y

19 Maersk Resilient MSC CJ50 2008 Singapore 2011 ABS 350' 15' 30' 479' Y 69' 30,000' 3Q/14 North Sea 9,920 120 229' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 4 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 100 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Mærsk Resolute MSC CJ50 2008 Singapore N/A ABS 350' 15' 30' 479' Y 52' 30,000' 2Q/’15 North Sea 9,920 120 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 2 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Mærsk Resolve MSC CJ50 2009 Singapore N/A ABS 350' 15' 30' 479' Y 52' 30,000' 3Q/’13 North Sea 9,920 120 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 2 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Maersk Reacher MSC CJ50 2008 Singapore 2011 ABS 350' 15' 30' 479' Y 69' 30,000' 3Q/’14 North Sea 9,920 110 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 4 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

16 Maersk Completer BMC Pacific 375 2007 Singapore N/A ABS 375' 15' 30' 507' Y 55' 30,000' 4Q/’14 Brunei 11,765 120 236.5' 224.4' 18' S61 N Y 2,268 4,950 70' 70' x 30' 4 31.7 1.5" EIPS 3,000' N 7 15 40 34 Y 1,500 National 35' x 35' 3,000 National 1.63" 49.5" 4 x 115 N National LPT National HPS750 NOV NOV 20,000' 3 National 14-P-220 7,500 1,025 3,075 1,200 11,645 4 1 1 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

16 Maersk Convincer BMC Pacific 375 2008 Singapore N/A ABS 375' 15' 30' 507' Y 55' 30,000' 4Q/’13 Malaysia 11,765 120 236.5' 224.4' 18' S61 N Y 2,268 3,750 70' 70' x 30' 4 31.7 1.5" EIPS 3,000' N 7 15 40 34 Y 1,500 National 35' x 35' 3,000 National 1.63" 49.5" 4 x 115 N National LPT National HPS750 NOV NOV CyberBase 20,000' 3 National 14-P-220 7,500 1,025 3,075 1,200 11,645 4 1 1 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

NOBLE DRILLING CORPORATION CONTACTS: 13135 South Dairy Ashford, Suite 800, Sugarland, Texas 77478; Phone: (KH) (281) 276-6333 or (MN) (281) 276-6226; Fax: (281) 276-6303; Website: www.noblecorp.com

25 Noble Al White CFEM T-2005-C 1982 France 2005 DNV 360' 60' 50' 504' N 49.2' 25,000' 2Q/14 North Sea 9,790 4 96 245' 282' 15' S61 N Y Y 2,097 2,921 45' 41' x 24' 4 32 2.25"/ 1.25" IWRC 2,300'/2,900' N 9.1 45 45 Y 1,000 JA Paris 36' x 36' 4,600 National 1.50" 37.5" Y Varco Varco TDS-8SA MH114008 Martin Decker / Electro-flow as required 2 NOV HEX 240 7,500 840 845 1,623 11,020 4 1 1 15 3.06" 3 Cameron 1 Cameron 117 Flange 36.25" 12" Hydraulic Koomey N

3 Noble Bill Jennings MLT Class 84 ERC 1975 USA 1997 ABS 390' 8' 25' 500' N 46' 25,000' 1Q/15 Mexico 5,850 6 102 248' 201' 16' S76 N Y 1,784 3,000 70' 50' x 30' N 50 50 65 Y 1,300 Dreco 30' x 30' 3,000 Continental Emsco 1.50" 49.5" Y National ST-100 National PS2-750A TOTCO as required 3 Continental Emsco FB 1600 5,000 1,230 467 1,400 8,640 3 2 1 1 1 10 3.06" 4 Cameron 1 Hydril 62 Flange 29.5" 10" 80 Koomey N

3 Noble Eddie Paul MLT Class 84 ERC 1975 USA 1995 ABS 350' 8' 21' 500' N 46' 25,000' 1Q/16 Mexico 4,200 6 100 247' 200' 15' S61 N Y 1,886 3,000 70' 50' x 30' N 50 50 65 Y 1,671 Dreco 30' x 30' 2,000 National 1.50" 37.5" Y NOV AR3200 NOV PS2-750A TOTCO as required 3 National 12-P-160 5,000 1,450 490 1,400 6,240 4 2 1 1 1 10 3.06" 3 Cameron 1 Hydril 62 Flange 21.25" 10" 80 Koomey N

1 Noble Leonard Jones MLT Class 53 ERC 1972 USA 1998 ABS 350' 8' 25' 500' N 46' 25,000' 2Q/15 Mexico 4,200 6 104 247' 201' 17' S61 N Y 2,457 3,559 65' 54' x 30' N 50 50 50 Y 1,671 Dreco 30' x 14' 3,000 National 1.50" 37.5" Y NOV AR3200 Varco TDS-4S TOTCO as required 3 National 12-P-160 5,000 1,480 490 1,400 6,240 4 2 1 1 1 10 3.06" 3 Cameron 1 Hydril 62 Flange 29.5" 10" 80 Koomey N

23 Noble Roger Lewis JU-2000E 2007 China ABS 400' 10' 30' 547' N 59' 35,000' 1Q/14 Saudi Arabia 17,750 6 130 231' 249' 21' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 2,000 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Hydraracker HR-III-X-Y-SB TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 5 2 1 1 1 1 15 3.06" 4 Cameron 1 Shaffer 100 Flange 49.5" 12" UET60-VT460 Vetco Gray N

23 Noble Hans Duel JU-2000E 2009 China ABS 400' 10' 30' 549' N 59' 30,000' 3Q/14 North Sea 17,750 6 120 328' 255' 22' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 1,500 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Column Racker TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 5 2 1 1 1 15 3.06" 4 Cameron 1 Cameron 100 Flange 49.5" 12" 80 Vetco Gray N

23 Noble Scott Marks JU-2000E 2009 China ABS 400' 10' 30' 548' N 59' 30,000' 3Q/14 Saudi Arabia 17,750 6 120 231' 249' 22' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 2,000 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Hydraracker HR-III-X-Y-SB TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 6 2 1 1 1 15 3.06" 4 Cameron 1 Shaffer 100 Flange 49.5" 12" 80 Vetco Gray N

PERFORADORA CENTRAL, S.A. DE C.V. CONTACT: Ing. Ricardo Cortina C., Calle 24 No. 52 Altos, Cd de Carmen, Campeche, 24100 Mexico; Tel: (52) 938-382-05-35; Fax: (52) 938-382-05-77; Email: rccentral@prodigy.net.mx

12 Tonala KFELS ‘B’ class 2004 USA ABS 375' 15' 517' 46' 25,000' Mexico 9,275 6 100 234' 208 15 S61 N Y 6,000 8,000 70' 60' x 30' 50 50 50 Y 1,500 Dreco 35' x 35' 3,000 National 1.63" 49.5" N NOI IR30SP NOI - PS2-650 Hitec 3 National 14-P-220 7,500 2,514 incl. 1,083 11,100 5 1 1 1 10 3.06" 3 Cameron 1 & 1 Cameron 75 & 56 Flange 30" 12" C240 IE30-AG Cameron Y

4 Panuco LeTourneau 116-CE 2007 USA ABS 350' 25,000' Mexico

6 Tuxpan LeTourneau Super 116-E 2010 USA ABS 375 511' 30,000'

6 Papaloapan LeTourneau Super 116-E 2013 USA ABS 375 511' 30,000' Mexico 120 243' 50 50 50 1,500

PV DRILLING CONTACT: 4th Floor, Sailing Tower,111A Pasteur St., Ben Nghe Ward, District 1, Ho Chi Minh City, Vietnam; Phone: (84 8) 39 142 012; Fax: (84 8) 39 142 021; Email: info@pvdrilling.com.vn; Website: www.pvdrilling.com

12 PV Drilling II KFELS B 2009 Singapore ABS 400' 517' 46' 30,000' 120 234' 208 S61N, S92, MI-17 N N 70' 30' x 70' 4 1.75" EIPS 2,625' 50 @ 20' 24 @ 120' 1,500 Woolslayer 36' x 36' 3,450 NOV 49.5" NOV ARM3200M NOV TDS-8SA 3 NOV 14-P-220 7,500 5 1 1 2 15 3.0625" 2 Shaffer 1 Shaffer 18-3/4" 49.5" 14" Hydraulic NOV

12 PV Drilling III KFELS B 2009 Singapore ABS 400' 517' 53' 30,000' 111 234' 208 S61N, S92, MI-17 4 100 @ 20' 24 @ 120' 680 Woolslayer 32' x 35' 3,200 NOV 49.5" NOV ARM3200M NOV TDS-8SA 3 NOV 14-P-220 5 1 1 1 15 3.0625" 1 Shaffer 1 Shaffer 18-3/4" 49.5" 12" Hydraulic

ROWAN COMPANIES, INC. CONTACT: Mark A. Keller, 2800 Post Oak Blvd, Suite 5450, Houston, Texas 77056-6196; Phone: (713) 621-7800; Fax: (713) 960-7678; Email: marketing@rowancompanies.com; Website: www.rowancompanies.com

3 Rowan Alaska Letourneau 84 1975 USA 2010 ABS 350' 25' 26' 477' N 46' 30,000' Well to Well GoM 6,900 4.5 79 248' 201' 15' S61 N Y N 3,964 6,714 50' x 41' slot 15' x 15' 2 Pulls 25 1.5" 6 x 37 EIPS 2,500' 2 @ 800 hp 5.5 50 @ 24' 50 @ 24' 50 @ 25' 50 @ 24' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 37.5" 45.25 N Varco IR TW-61 Varco TDS-3 N/A Rowan TBD TBD TBD TBD TBD TBD 3 2 National 12-P-160 and 1 Lewco 1600 5,000 1,465 incl. incl. 10,880 4 1 1 10 3" 3 Cameron 1 Hydril 43.5 13-5/8" 5M Flange 21.25" 12" 80 Super T Koomey N

7 Rowan Gorilla II Gorilla 1984 Singapore 2000 ABS 350' 30' 30' 638' N 66' 30,000' 3Q/13 Malaysia 7,998 4 88 297' 292' 18' S-61 N Chinook 234LR N N 4,827 8,328 52' x 45' 52' 52' x 24' 2 Pulls 25 1.25" 6 x 37 3,000' 2 @ 3,200 ea 5 75 @ 59' 50 @ 25' 50 @ 25' 50 @ 25' 50 @ 25' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 49.5" 250 Y Varco IR TW-60 Varco TDS-4S N/A Rowan TBD TBD TBD TBD TBD TBD 3 National 12-P-160 5,000 2,478 incl. incl. 16,400 4 1 1 10 3" 3 Cameron 1 Hydril 145 13-5/8" 10M Flange 49.5" 12" 80 Super T Koomey Y

7 Rowan Gorilla III Gorilla 1984 USA N/A ABS 325' 30' 30' 504' Y 66' 30,000' 3Q/13 GoM 7,950 4 92 297' 292' 17' S-61 N Chinook 234LR N N 3,201 7,885 52' x 45' 52' 52' x 24' 2 Pulls 25 1.25" 6 x 37 3,000' 2 @ 3,200 ea 5 50 @ 26' 60 @ 58' 60 @ 58' 60 @ 58' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 49.5" 375 N Varco IR TW-61 NOI PS-2 650/650 N/A Rowan TBD TBD TBD TBD TBD TBD 3 Continental Emsco FB-1600 5,000 2,474 incl. incl. 15,370 4 1 1 15 3" 4 Cameron 1 Hydril 145 13-5/8" 10M Flange 30" 12" 80 Super T Koomey N

7 Rowan Gorilla IV Gorilla 1986 USA 2003 ABS 450' 30' 30' 638' Y 66' 30,000' 4Q/13 Mexico 7,950 4 86 297' 292' 17' S-61 N Chinook 234LR N N 3,830 8,470 52' x 45' 75' 75' x 24' 2 Pulls 25 1.5" 6 x 37 3,000' 2 @ 4,000 ea 5 60 @ 58' 60 @ 58' 60 @ 58' 25 @ 26' Y 2,000 L. C. Moore 30' x 30' 4,500 NOV 1.63" 49.5" 100 N Varco IR TW-60 NOI PS-2 750A N/A Rowan TBD TBD TBD TBD TBD TBD 3 Lewco W-2215 7,500 2,475 incl. incl. 15,540 4 1 1 15 3" 4 Cameron 1 Hydril 145 13-5/8" 10M Flange 30" 16" MX 36011 Koomey N

8 Rowan Gorilla V Super Gorilla 1998 USA N/A ABS / DNV 400' 45' 30' 574' Y 57' 35,000' 3Q/13 North Sea 16,975 4 120 306' 300' 22' EH101/S-61N Chinook 234LR Y Y 6,250 6,884 60' x 45' 85' 85' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 400 Y Varco A-3200 Letourneau DDTD 750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 National 14-P-220 7,500 5,294 incl. incl. 22,000 5 2 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 49.5" 16" Minuteman Cameron Y

8 Rowan Gorilla VI Super Gorilla 2000 USA 2005 ABS / DNV 450' 45' 30' 607' Y 57' 35,000' 4Q/13 North Sea 16,975 4 120 306' 300' 21' EH101/S-61N Chinook 234LR Y Y 6,230 6,230 60' x 45' 100' 100' x 40' 4 Pulls 45 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 600 Y Varco A-3200 NOI PS-2 650/750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 Continental Emsco FC-2000 7,500 5,575 incl. 2,425 22,000 4 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 49.5" 16" Minuteman Cameron Y

8 Rowan Gorilla VII Super Gorilla 2002 USA N/A ABS / DNV 450' 45' 30' 607' Y 57' 35,000' 2Q/15 North Sea 16,975 4 120 306' 300' 22' EH101/S-61N Chinook 234LR Y Y 5,952 6,000 60' x 45' 100' 100' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 678 Y Varco A-3200 NOI PS-2 650/750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 Continental Emsco FC-2000 7,500 5,294 incl. 2,425 22,000 6 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 28" 16" Minuteman Cameron Y

8 Bob Palmer Super Gorilla XL 2003 USA 2007 ABS / DNV 490' 45' 30' 647' N 67.7' 35,000' 2Q/14 Middle East 12,900 4 118 306' 300' 31' S62 N / S92 Y Y 5,772 5,800 60' x 45' 100' 100' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,600 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 4,500 LEWCO 2.00" 49.5" 678 Y NOV ST-120 NOI PS-2 750A PRS 8i MD Totco TBD TBD TBD TBD TBD TBD 3 Lewco W-3000 7,500 7,889 incl. 2,425 22,400 6 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 28" 16" AMSN - 5801 ABB Y

9 Rowan Joe Douglas Letourneau 240-C 2011 USA ABS / DNV 375' 491' N 35,000' 3Q/13 GOM 108 228' 220' S-61N / S-92 4,711 75 @ 30' 75 @ 30' 75 @ 30' Y 2,500 Loadmaster 36' x 36' 3,000 LEWCO 2.00" 49.5" Y LTI DDTD-750-V2 TBD TBD TBD TBD TBD TBD 3 Lewco W-3000 3,000 4,005 incl. incl. 13,800 5 3 2 15 3" 4 Cameron 1 Hydril 18-3/4" 15M Flange 30" Y

3 Rowan Louisiana Letourneau 84 1975 USA 2006 ABS 350' 25' 24' 466' N 46' 25,000' 3Q/13 GoM 7,950 4.5 78 248' 201' 20' S61 N Y N 3,963 7,310 50' x 41' slot 15' x 15' 2 Pulls 25 1.25" 6 x 37 3,000' 5 50 @ 24' 50 @ 24' 50 @ 24' 43 @ 28' Y 1,500 WCI 30' x 30' 4,500 NOV 1.63" 37.5" 100 N Varco IR TW-61 National PS2 750A N/A Rowan TBD TBD TBD TBD TBD TBD 3 National 12-P-160 5,000 1,467 incl. incl. 10,880 3 1 1 10 3" 3 Cameron 1 Hydril 45.3 13-5/8" 10M Flange 21.25" 12" CAD3600874BU2 CAD N

9 Ralph Coffman Letourneau 240-C 2009 USA N/A ABS 375' 15' 20' 491' Y 56' 35,000' 3Q/14 Egypt 12,900 4.5 108 228' 220' 19' S-61N or S-92 N Y 5,050 4,711 N/A 80' 80' x 30' 2 Pulls 25 1.25" 6 x 36 Galy 2,500' 6 56 @ 45' 56 @ 45' 56 @ 45' Y 2,500 Loadmaster 36' x 36' 4,500 LEWCO 2" 49.5" 250 Y NOV IR30120 LTI DDTD-750-V2 Loadmaster MRS 12 MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-3000 7,500 4,005 incl. 529 13,820 5 1 1 15 3" 4 Cameron 1 Hydril 210 18-3/4" 15M Flange 30" 12" EH/PLC Cameron Y

6 Rowan EXL I Super 116E 2010 USA N/A ABS 350' 33' 20' 477' Y 46' 35,000' 3Q/13 Indonesia 10,750 4.5 120 228' 206' 17' S-61N N Y 3,977 3,250 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 56 @ 45' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 1 Hydril 210 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL II Super 116E 2010 USA N/A ABS 380' 63' 20' 511' Y 46' 35,000' 1Q/14 Trinidad 10,750 4.5 120 228' 206' 17' S-61N N Y 3,348 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 6 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 1 Hydril 210 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL III Super 116E 2010 USA N/A ABS 350' 33' 20' 477' Y 46' 35,000' 3Q/13 GoM 10,750 4.5 120 228' 206' 17' S-61N N Y 3,825 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LeTourneau 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 5 1 1 15 3" 4 Cameron 1 Hydril 135 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL IV Super 116E 2011 USA N/A ABS 320' 444' Y 35,000' 4Q/14 Malaysia 120 228' 206' 17' S-61N N Y 3,348 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30121 LTI DDTD-750-V3 N/A MD Totco TBD TBD TBD TBD TBD TBD 4 LTI W-2216 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 2 Hydril 136 13-5/8" 15M Flange 36-1/3" 17" EH/PLC Cameron Y

9 Rowan Mississippi Letourneau 240-C 2008 USA N/A ABS 375' 15' 15' 491' Y 56' 35,000' 2Q/14 Saudi Arabia 12,900 4.5 108 228' 220' 19' S-61N or S-92 N Y 4,202 4,835 N/A 80' 80' x 30' 2 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 2.24 65 @ 45' 65 @ 45' 67 @ 45' Y 2,500 Loadmaster 36' x 36' 4,500 LEWCO 2" 49.5" 250 Y NOV IR30120 LTI DDTD-750-V2 Loadmaster MRS 12 MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-3000 7,500 4,100 incl. 529 13,820 5 1 1 15 3" 4 Cameron 1 Hydril 210 18-3/4" 15M Flange 30" 12" EH/PLC Cameron Y

14 Rowan Stavanger KFELS N-Class 2011 Singapore 2011 DNV 400' 10' 30' 568' Y 66' 35,000' 1Q/14 North Sea 13,460 4.5 120 264' 289' 24' S-61N or S-92 N Y 5,123 8373-17780 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30' 50 @ 29' Y 2,200 NOV 40' x 40' 4,600 NOV 2" 49.5" 350 N Wellquip JiM20 NOV HPS 03-1000 NOV HydraRacker III NOV TBD TBD TBD TBD TBD TBD 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 NOV 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

14 Rowan Viking KFELS N-Class 2010 Singapore N/A DNV 400' 10' 30' 568' Y 66' 35,000' 2Q/14 North Sea 13,460 4.5 120 264' 289' 21' S-61N or S-92 N Y 5,123 8373-17780 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30 50 @ 29' Y 2,200 NOV 40' x 40' 4,600 NOV 2" 49.5" 350 N Wellquip JiM20 NOV HPS 03-1000 NOV HydraRacker III NOV TBD TBD TBD TBD TBD TBD 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 Shaffer 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

14 Rowan Norway KFELS N-Class 2011 Singapore N/A DNV 400' 10' 30' 568' Y 66' 35,000' 1Q/17 North Sea 13,460 4.5 120 264' 289' 21' S-61N or S-92 N Y 5,123 8,373 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30' 50 @ 29' Y 2,200 TTS 40' x 40' 4,600 TTS 2" 49.5" 350 N Wellquip JiM20 TTS ITAG TTS SmartRacker III-P TTS 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 Shaffer 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

SEADRILL Contact: Rolf Mathiesen, Lokkeveien 107, 4007 Stavanger, Norway; Phone: +47 51 30 99 69; email: rolf.mathiesen@seadrill.com; website: www.seadrill.com

15 West Leda Baker Marine Pacific 2010 Singapore ABS 375' 15' 55' 506' Y 55' 30,000' Apr-14 Malaysia 10,750 4-4.5 120 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 25 55 55 N/A N/A Y 1,500 Loadmaster 35' x 35' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y Varco AR-3200 Varco TDS-8SA NOV Amphion System - 20,000' - - - - 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - - - - - 15 3" 2 CIW 1 CIW 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

15 West Triton Baker Marine Pacific 2008 Singapore ABS 375' 15' 55' 506' Y 55.5' 30,000' Oct 2013 Arabian Gulf 10,750 4-4.5 115 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 25 45 55 N/A N/A Y 1,500 Bailys 35' x 35' 4,050 Dreco 1.63" 49.5" 9 Y Hydralift PD-MPT Hydralift HPS-750 NOV/FB-F NOV Hitec C 30,000' 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - 1 1 - - 15 3" 2 Hydril 1 Hydril 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

15 West Cressida Baker Marine Pacific 2009 Singapore ABS 375' 15' 55' 506' Y 55' 30,000' Apr-14 Thailand 10,750 4-4.5 120 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 38 45 17 N/A N/A Y 1,500 NOV 35' x 35' 3,000 NOV D3000 AC 1.63" 49.5" 250 Y NOV Hydratong NOV HPS-750-E-AC Hydralift HPS750 EAC NOV Cyberbase - 30,000' 20,000' - 10,000' - 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - 1 1 - - 15 3" 2 CIW 1 Shaffer 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

12 West Ariel KFELS ‘B’ class 2008 Singapore ABS 400' 25' 55' 517' Y 47' 30,000' Jan-13 Vietnam 10,750 4-4.5 112 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 28.1 1.50" 6 x 36 EIPS 2,500' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 36' x 36' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y NOV AR 3200 M Varco TDS-8SA PH 100 V-ICIS 2.1 - 20,000' - - - 10,000' 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - - 1 - - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

12 West Callisto KFELS ‘B’ class 2010 Singapore ABS 400' 25' 55' 517' Y 47' 30,000' Nov-15 Saudi Arabia 10,750 4-4.5 112 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 28.1 1.50" 6 x 36 EIPS 2,500' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 36' x 36' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y Varco AR-3200CM Varco TDS-8SA PH-100 Amphion System - 20,000' - - - - 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - 1 1 1 - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

12 West Prospero KFELS ‘B’ class 2007 Singapore ABS 400' 25' 55' 514' Y 47' 30,000' july 2013 Vietnam 10,750 4-4.5 110 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 40 1.50" 6 x 36 EIPS 2,600' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 32' x 35' 3,000 Varco ADS-10T 1.75" 49.5" 250 Y Varco AR-3200CM Varco TDS-8SA VCR V-ICIS 2.1 - 20,000' - - - - 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - - 1 - - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

23 West Castor F & G JU 2000 E 2013 Singapore ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS-1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

23 West Oberon F & G JU 2000 E 2013 China ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS- 1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

23 West Telesto F & G JU 2000 E 2013 China ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS-1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

20 West Epsilon MSC CJ62 120S 1993 Singapore 2002 DNV 400' N/A N/A 575' Y 58' 30,000' Dec 2016 North Sea 8880 4-4.5 115 237' 224' 19' S-61 Y Y 1,000 3,800 N/A 60' 15' x 15' 4 50 2.125" IMRC 2,000' 8 55 @ 36' 55 @ 36' 37 @ 31' Y 1,650 CE-LTV 40' x 40' 3,000 Continental Emsco C3 1,75" 49.5" 240 N Varco PHM-3i Varco TDS-6S Varco PHM3i NOV 17,000' 3,000' 3 CE FC2200 7,500 5,346 incl. 3,522 19,040 4 TBA TBA TBA TBA 2 15 3" 4 Hydril 1 Hydril 185 Flange 36.5" 12" Hydraulic MH-Koomey Y

21 West Elara MSC CJ 70 X150A 2011 Singapore DNV 492' N/A 32' 672' N 75' 40,000' Apr-17 North Sea 19000 4-4,5 120 290' 318' 22' S-61 / S-92 N Y TBA 6,600 N/A 80' 100' x30' 4 27.5 2.2" 6 x 36 WS IWRL 3,379' N/A 5.6 80 @ 25' 80 @ 25' 80 @ 25' 5 @ 9' Y 2,200 TTS / Holandia 48' x 40' 4,600 Sense Ultra Hoist 2" 49.5" 441 N Sense Jim 20 Sense / 1000 Ton Sense Smar racker Sense On Track System NA NA NA NA 3 Wirth TPK 7,500 1302 2201 5,592 19,176 4 4 2 2 2 NA 15 3" 4 Hydril 1 Hydril 180 NT-2 Vetgo 49.5" 16" Hydraulic Hydril Y

5 Offshore Courageous LeTourneau Super 116C 2007 USA ABS 350' 25' 16' 477' Y 46' 30,000' Dec 2014 Malaysia 8,600 4-4.5 110 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 70' x 30' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 2" 50" 150 Y NOV 30120 NOV TDS-8SA None MDT - 20,000' - - - - 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 - 1 - 15 3-1/16" 2 Cameron 1 Shaffer 176 Flanged 30" 12" Hydraulic Shaffer Y

5 Offshore Resolute LeTourneau Super 116C 2008 USA ABS 350' 25' 16' 477' Y 46' 30,000' oct 2015 Arabian Gulf 8,600 4-4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 70' x 30' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 2" 50" 150 Y NOV 30120 NOV TDS-8SA None MDT - 20,000' - - - 6,600' 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 - 1 - 15 3-1/16" 2 Cameron 1 Shaffer 176 Flanged 30" 12" Hydraulic Shaffer Y

5 Offshore Defender LeTourneau Super 116C 2007 USA ABS 350' 25' 16' 477' Y 46' 30,000' june 2016 Brunei 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

5 Offshore Vigilant LeTourneau Super 116C 2008 USA ABS 350' 25' 16' 477' Y 46' 30,000' Oct 2013 Malaysia 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

5 Offshore Intrepid LeTourneau Super 116C 2009 USA ABS 350' 25' 16' 477' Y 46' 30,000' Nov-13 Arabian Gulf 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

6 Offshore Freedom LeTourneau Super 116E 2009 UAE ABS 350' 25' 16,5' 477' Y 46' 30,000' May 2013 Arabian Gulf 10,750 4-4.5 105 243' 206' 16' S61 N N Y 2,146 3,757 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 35' 3,000 Lewco 1.63" 49.5" 150 Y NOV-ST-120 Letourneau DDTD 750 LTI/DDTD-750 TBD TBD TBD 3 LEWCO W-2214 7,500 3,334 1,000 1,000 12,250 5 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

6 Offshore Mischief LeTourneau Super 116E 2009 UAE ABS 350' 25' 16,5' 477' Y 46' 30,000' Aug-11 Brazil 10,750 4-4.5 105 243' 206' 16' S61 N N Y 2,146 3,757 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 35' 3,000 Lewco 1.63" 49.5" 150 Y NOV-ST-120 Letourneau DDTD 750 LTI/DDTD-750 TBD TBD TBD 3 LEWCO W-2214 7,500 3,334 1,000 1,000 12,250 5 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

SINO THARWA DRILLING CO. Contact: Ali Salem Mubarak, Chairman & Managing Director, 16 W/6 El Nasr St., New Maadi, Cairo, Egypt; Tel: 20 2 2519 7226; Fax: 20 2 2519 5597; Email: asalem@sinotharwa.com.eg; Website: www.sinotharwa.com.eg

23 ST Bahari I F&G JU2000E 2011 China ABS 400' 10' 30,000' Egypt 120 N N 3,766 3,200 49.5" NOV TDS-8SA 3 NOV 7,500

TRANSOCEAN CONTACT: Mark Monroe, P.O. Box 2765, Houston, Texas 77252-2765; Phone: (713) 232-7500; Fax: (713) 232-7880; Email: mark.monroe@deepwater.com; Website: www.deepwater.com

23 GSF Constellation I F&G JU 2000 2003 Singapore ABS 400' Site Spec Site Spec 548' N 59' 30,000' 1Q/'16 Indonesia 9,275 - 120 231' 250' 21' S61 N N Y 4,050 5,000 75' 75' x 30' 4 44 2" 6 x 36 EPIS/ IWRC 3,000' N 8.4 55.6 55.6 55.6 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N NOV IR-170 PSA NOV PS2 Star Racker NOV Cyberbase 20,000' 3 National 14-P-220 7,500 4,766 900 17,920 5 3 1 15 3.06" 4 Hydril 1 Hydril 167.1 Flange 49.5" 16" Hydraulic Hydril Y

23 GSF Constellation II F&G JU 2000 2004 Singapore ABS 400' Site Spec Site Spec 548' N 59' 30,000' 3Q/’15 Gabon 9,275 - 120 231' 250' 21' S61 N N Y 4,050 5,000 75' 75' x 30' 4 44 2" 6 x 36 EPIS/ IWRC 3,000' N 8.4 55.6 55.6 55.6 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N NOV IR-170 PSA NOV PS2 Star Racker NOV Cyberbase 15,000' 3 National 14-P-220 7,500 4,727 900 17,920 5 3 1 15 3.06" 4 Hydril 1 Hydril 167.1 Flange 49.5" 16" Hydraulic Hydril Y

22 GSF Galaxy I F&G L-780 Mod VI 1991 Singapore 2001 ABS 400' Site Spec Site Spec 560' N 60' 30,000' 3Q/'13 North Sea 10,000 4 120 244' 250' 22' S61 N* N Y 3,260 4,350 67' 67' x 30' 4 37 2" 6 x 36 IWRC 1,969' N 8.3 39.7 39.7 39.7 N 1,600 Brown 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco PHM 3i Varco TDS-4H Varco PHM3i Rigserve 15,000' 3 National 14-P-200 6,000 4,429 1,627 18,200 3 15 3.06" 4 Hydril 1 Hydril 150 NT 2 49.5" 16" Hydraulic Hydril Y

22 GSF Galaxy II F&G L-780 Mod VI 1998 Singapore ABS 400' Site Spec Site Spec 560' N 60' 30,000' 4Q/’14 North Sea 11,400 4 120 244' 250' 22' S61 N* Y Y 3,984 7,372 55' 55' x 30' 4 37 2" 6 x 36 IWRC 3,000' N 7.5 52 52 52 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco AR-3200 Varco TDS-4S Varco PRS3i MD/V-ICIS 15,000' 3 National 14-P-220 6,000 4,430 1,627 18,200 4 1 1 15 3.06" 4 Hydril 1 Hydril 130 BX 159 flange 49.5" 16" Hydraulic Koomey Y

22 GSF Galaxy III F&G L-780 Mod VI 1999 Singapore ABS 400' Site Spec Site Spec 560' N 60' 30,000' 2Q/’14 North Sea 11,400 4 120 244' 250' 22' S61 N* Y Y 3,435 6,000 80' 60' x 30' 4 37 2" 6 x 36 IWRC 2,500' N 8.3 39.7 39.7 39.7 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco AR-3200 Varco TDS-4S PRS3i MD Totco 20,000' 3 National 14-P-200 6,000 4,430 1,627 18,200 5 3 15 3.06" 4 Shaffer 1 Shaffer BX 165 flange 49.5" 16" Hydraulic Shaffer Y

17 Transocean Honor PPL Pacific Class 400 2012 Singapore ABS 400' Site Spec Site Spec 532' N 55' 30,000' 2Q/'15 Angola 10,750 - 150 236' 224' 19' S61 & S92 N Y 2,549 3,822 75' 75' x 30' 4 36 1.5" 6 x 36 EPIS/ IWRC 3,000' N 6.6 55.9 55.9 25.3 Y 1,500 Loadmaster 35' x 35' 3,000 NOV 1.63" 49.5" 225 Y NOV ST-120 NOV-TDS-8SA Loadmaster NOV Cyberbase 30,000' 20,000' 3 National 14-P-200 7,500 4,150 1,255 11,652 5 - - - - - 15 3" 4 Shaffer 1 Shaffer 18-3/4" Flange 49.5" 16" Hydraulic Shaffer

13 Transoean Siam Driller Keppel FELS Super B 2013 Singapore ABS 350' Site Spec Site Spec 486' N 35,000' 2Q/'16 Thailand 11,250 3.5 150 246' 226' 18' MI-172 & S-92 Y Y 2,750 4,600 63' 63' x 30' 4 30 1.5" 6 x 36 IWRC 2,500' N 5 50 50 50 Y 1,500 NOV 36' x 36' 4,500 NOV SSGD 750 1.75" 49.5" 300 Y Hawkjaws Jnr. NOV-TDS-8SA NOV Dreco NOV SDIS 15,000' 3 National 14-P-200 7,500 4,000 2,000 8,000 5 - - - - - 10 3" 4 Cameron 1 Hydril 13-5/8" Flange 49.5" 14" Hydraulic NOV

13 Transoean Andaman Keppel FELS Super B 2013 Singapore ABS 350' Site Spec Site Spec 486' N 35,000' 2Q/'18 Thailand 11,250 3.5 150 246' 226' 18' MI-172 & S-92 Y Y 2,750 4,600 63' 63' x 30' 4 30 1.5" 6 x 36 IWRC 2,500' N 5 50 50 50 Y 1,500 NOV 36' x 36' 4,500 NOV SSGD 750 1.75" 49.5" 300 Y Hawkjaws Jnr. NOV-TDS-8SA NOV Dreco NOV SDIS 15,000' 3 National 14-P-200 7,500 4,000 2,000 8,000 5 - - - - - 10 3" 4 Cameron 1 Hydril 13-5/8" Flange 49.5" 14" Hydraulic NOV

22 GSF Magellan F&G L-780 Mod V 1992 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 2Q/'13 North Sea 10,000 6 115 228' 222' 17' S61* Y Y 4,831 5,200 65' 65' x 30' 4 50 2" 6 x 38 RHO 2,200' N 8.3 44.6 44.6 44.6 N 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N PHM 3i Varco TDS-4S PHM 3i DAQ 20,000' 3 National 14-P-200 7,500 3,167 2,243 17,400 4 - 15 3.06" 4 Hydril 1 Hydril 140 Flange 47.5" 16" Hydraulic Hydril Y

22 GSF Monarch F&G L-780 Mod V 1986 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 2Q/’15 North Sea 8,260 4 98 228' 222' 17' S61* N Y 3,707 3,707 52' 52' x 30' 4 44 2" 1770 IWRC 2,000' N 7.5 36 36 36 N 1,400 JA Paris 36' x 36' 3,000 Emsco 1.50" 49.5" 300 N Varco AR-3200 Varco TDS-4S Varco PRS 2 MD Totco 12,000' 3 Cont'l Emsco FB 1600 5,000 2,436 4,030 15,070 5 3 10 3.06" 4 Shaffer 1 Hydril 70 BX 159 flange 36.5" 16" Hydraulic Koomey Y

22 GSF Monitor F&G L-780 Mod V 1989 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 4Q/'13 Nigeria 9,900 5 115 228' 222' 17' S61 N N Y 3,776 5,900 55' 55' x 30' 4 25 2" 4 x 25 IWRC 3,000' N 6.8 38.6 38.6 44 N 1,550 Dreco 50' x 50' 3,000 Emsco 1.63" 49.5" 300 N Varco AR-3200 Varco TDS-4H Varco PRS 2 Rigserve / WOM /ANA 14,000' 3 Cont'l Emsco FB 1600 5,000 3,230 911 15,048 5 - - - - - 15 3.06" 4 Cameron 1 Hydril Flange 8" 16" Hydraulic Hydril

VANTAGE DRILLING COMPANY CONTACT: Mike Derbyshire, #07-01 Pacific Tech Centre, 1 Jalan Kilang Timor, Singapore 159303, Tel: (65) 6577-0270; Email: mderbyshire@vantagedrilling.com; Website: www.vantagedrilling.com

16 Emerald Driller Baker Marine Pacific 375 2008 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 2Q/’15 Thailand 9,275 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,740 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 75 @ 25' 43 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Wirth 1.625" 49.5" 220 N AKMH MH-1898 Mk I AKS DDM-650-AC-1M-1S-1150 Loadmaster AKMH 10,000' 10,000' N/A N/A N/A N/A 3 Wirth TPK 2200 CL, 2200HP 7,500 4,376 bbls total 11,652 5 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Sapphire Driller Baker Marine Pacific 375 2009 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 2Q/'13 Cote d'Ivoire 10,750 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 45 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N T-Wrex Canrig 1275 AC Loadmaster Sense EDM 10,000' 15,000' N/A N/A N/A N/A 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Aquamarine Driller Baker Marine Pacific 375 2009 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 4Q/'13 Malaysia 10,750 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 55 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N Rogers Oiltools Canrig 1275 AC Loadmaster Sense EDM 10,000' 15,000' N/A N/A N/A N/A 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Topaz Driller Baker Marine Pacific 375 2009 Singapore 2011 ABS 375' 15' 30' 506' Y 55.5' 30,000' 3Q/'11 Indonesia 9,275 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 55 @ 25' 25 @ 20' Y 1,800 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N T-Wrex Canrig 1275 AC Loadmaster Sense EDM 5,000' 20,000' N/A N/A N/A 10,000' 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

400'

400'

400'

400'

400'

400'

400'

400'

400'

400'

350'

350'

350'

350'

350'

350'

375'

425'

375'

375'

375'

375'

375'

375'

375'

375'

350'

350'

350'

350'

350'

350'

350'

400'

400'

492'

490'

350'

350'

350'

350'

350'

400'

400'

400'

400'

400'

400'

400'

375'

375'

375'

375'

375'

360'

390'

350'

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350'

350'

350'

350'

350'

350'

350'

350'

350'

350'

350'

375'

375'

492'

492'

394'

2

LeTourneau Class 64

3

LeTourneau Class 84

4

LeTourneau 116C

5

LeTourneau Super 116C

6

LeTourneau Super 116-E

7

LeTourneau Gorilla Class

8

LeTourneau Super Gorilla

9

LeTourneau 240-C

10

KFELS A Class

11

KFELS Super A Class

12

KFELS B Class

13

KFELS Super B Class

1

LeTourneau Class 53

14

KFELS N Class

16

BMC-375 Jackup

17

BMC Pacific 400

18

GustoMSC CJ46

19

GustoMSC CJ50

20

GustoMSC CJ62-120S

21

GustoMSC CJ70-150MC

22

F&G L780

23

F&G JU2000

24

Hitachi-Zosen

25

CFEM-T-2005-C

15

BMC 350

Information Accuracy: Every attempt has been made to

locate all the deepwater Jack-up Rigs and contact worldwide

contractors. No contractor was intentionally excluded from the

survey. In some cases, a deepwater Jack-up Rig was not

included because information was not provided. we make no

guarantee that this list is all inclusive. we have also been

careful to summarize the capability and experience of each

contractor as best as possible, by acting as a neutral party

and integrator of information. we have collected the data

from contractor-supplied information, personal interviews,

websites, phone interviews, and

company brochures. Offshore Magazine

neither guarantees nor assumes

any responsibility or liability for any

reliance on the information presented

in this spreadsheet poster. ©2

01

3 O

ffsh

ore

POSTER

106prepared by: Offshore Magazine

PH

OTO

NU

MB

ER/R

IG T

YP

E

50 Years Building a Reputation in Marine and Offshore Construction.

Discover Sembcorp Marine. enquiries@sembcorpmarine.com.sg

T: +65 6858 6635 F: +65 6858 2884 E: email excelmarco.com@

www.excelmarco.com

Together We Excel

TURN-KEY SOLUTIONS PROVIDER FOR PROCESS AUTOMATION & SAFETY SYSTEMS GustoMSC is a leading design and engineering company for all

types of mobile offshore units: jack-ups, semi-submersibles and offshore

vessels. Our business approach is to deliver proprietary designs under

license and associated equipment like jacking systems, skidding systems

and offshore cranes to the market.

www.GustoMSC.com

DESIGNENGINEERINGEQUIPMENT

C o n f e r e n c e & E x h i b i t i o n

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Near market, near customer Keppel FELS is the industry’s choice offshore solutions partner.

50 Gul Road Singapore 629351 Tel: (65) 6863 7200 www.keppelfels.com

1307off_rigposter_1 1 6/28/13 4:27 PM

2013 WORLDWIDE SURVEY OF

DEEPWATER JACK-UP RIGS

For additional paper copies or general comments E-mail: posters@pennwell.com. PDF Downloads available at www.offshore-mag.com

JULY 2013

M A G A Z I N E

Offshore Magazine – 1455 West Loop South, Suite 400; Houston, TX 77027 Tel: 713-963-6200; Fax: 713-963-6296; www.offshore-mag.com

WATER DEPTH RATINGS

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RIG INFORMATION RIG RATINGS CONTRACT INFORMATION VESSEL PARTICULARS MOORING SYSTEM LIFTING EQUIPMENT MUD & SOLIDS CONTROL SYSTEMS BOP EQUIPMENT & CONTROL SYSTEMSNORMAL COMPLEMENT OF TUBULARS

Ft. Ft. Ft. Ft. Ft. Ft. Expiration As of July 2011 H.P. Ft. Ft. Ft. Y/N Y/N S.T. S.T. W x L Ft. x Ft. No. S.T. in. Ft. No. & H.P. S.T. S.T. S.T. S.T. S.T. S.T. Y/N Name Ft. x Ft. H.P. in. in. Model ModelManufacturer & Model Manufacturer & Model Psi Bbls Bbls Bbls Cu.Ft. No. No. No. No. No. No. Ksi I.D. in. No.Manufacturer Manuf. Manuf.Ft. Ft. Ft. Ft. Ft. Ft. No.ManufacturerModelKnots PAXY/N Ft. Kips No. Kips Type Type Manuf.in. I.D Y/NGrade

RO

TATI

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LE (

Y/N

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Y/N

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ND

UC

TER

TEN

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NIN

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APA

CIT

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DRILLING EQUIPMENT

S.T.

BOP & BOP CONTROL DATA

ABAN OFFSHORE CONTACT: P. Venkateswaran, Dy, Managing Director; Aban; Tel: +91-44-28195555; Fax: +91-44-28195527; Email: venkatp@aban.com; Web site: www.aban.com

16 ABAN VIII BMC Pacific 375 2008 Singapore ABS 375' 10' 30' 506' N 56' 30,000' Jun-13 Middle East 120 245' 224' 16' S61 N Y Y 2,495 70' x 30' 4 1.5" IWRC 6x36 3,500' 6 50 50 22.6 Y 1,600 Loadmaster 35' x 35' 3,000 National 1.625" 49.5" 227 N Rogers OilTools National TDS 85A NOV Varco NOV 3 LEWCO 2215 7,500 1,000 3,000 10,560 3 2 1 1 1 15 3" 2 Hydril 2 Hydril 132 13-5/8" Flange 49.5" 14" PLC CAD Y

16 Deep Driller 1 Baker Marine Pacific 2006 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' West Coast of India 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 N 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 250 N Hydralift-MPT National HPS-E-DC-2S-SG NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 2 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 2 KFELS Super ‘B’ class 2006 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' Middle East 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-220 7,500 1,950 2,950 15,700 4 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

13 Deep Driller 3 KFELS Super ‘B’ class 2006 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-221 7,501 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

16 Deep Driller 4 Baker Marine Pacific 2007 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 Y 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 227 N Hydralift-MPT National HPS-E-DC-2S-SG NOV 6T Bridge Racker NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 4 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 5 KFELS Super ‘B’ class 2007 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 2 National 14-P-222 7,502 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

13 Deep Driller 6 KFELS Super ‘B’ class 2008 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' May-14 Middle East 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR6-SD Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-223 7,503 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

16 Deep Driller 7 Baker Marine Pacific 2008 Singapore ABS 375' 15' 30' 506' Y 55' 30,000' 12,900 120 240' 224' 20' S61 N N Y 2,500 3,750 70' 70' x 30' 4 40 1.5" EIPS 2,500' 6 21 41 50 Y 1,600 National 35' x 35' 3,450 National 1.63" 49.5" 227 N Hydralift-MPT National HPS-E-DC-2S-SG NOV 6T Bridge Racker NOV-Cyberbase 20,000' 3 Mission Magnum or equivalent centrifugal 7,500 1,970 2,082 11,650 4 4 1 1 1 15 3" 2 Hydril 1 Hydril 192 18-3/4" Flange 49.5" 14" Hydraulic Hydril Y

13 Deep Driller 8 KFELS Super ‘B’ class 2008 Singapore ABS 350' 18' 30' 486' Y 52' 35,000' Sep-14 Brunei 12,575 120 246' 218' 16' S61 N Y Y 2,500 3,800 70' 70' x 30' 4 40 1.5" EIPS 2,500' 5 50 50 50 Y 2,000 National 36' x 36' 4,600 National 2.00" 49.5" 250 N Hydralift-MPT NOV-HPS-1000-2E-AC-KT NOV BR-6 Bridge Racker NOV-Cyberbase 20,000' 3 National 14-P-224 7,504 1,950 2,950 15,700 4 5 1 1 1 15 3" 2 Cameron 1 Cameron 197 18-3/4" Flange 49.5" 16" Hydraulic Cameron Y

PT APEXINDO PRATAMA DUTA Tbk CONTACT: Irman Rumadja PT. Apexindo Pratama Duta, Tbk. Medco Building 2nd – 3rd Floor, Jl. Ampera Raya No. 20, Cilandak Jakarta 12560 Tel : (62-21) 7800840, 7804766 Fax : (62-21) 7804666, 7800815; Email: irman.rumadja@apexindo.com, Website: www.apexindo.com

15 Raniworo BMC 350 Singapore ABS 350' 15' 30' Y 55' 25,000' Jan-16 Indonesia 100 45' X 24' 1,250 2,000 Oil Well Varco TDS-4S Varco 3 Oil Well - Triplex 1,700 9,140 4 1 2 10 4 1 13-5/8" Flange 30" Hydraulic

16 Soehanah BMC Pacific 375 2007 Singapore ABS 375' 15' 30' 505' Y 55' 25,000' Aug-15 Indonesia 14,450 4-5 115 326' 224' n/a S61 N N Y 2,500 3,975 75' 60' x 30' 4 40 1.5" n/a 3,000' 6 75 @ 35' 45 @ 25' 25 @ 20' Y 1,400 Pyramid 35' x 35' 2,800 Wirth 1.63" 49.5" 220 N Maritime Hydraulic Maritime Hydraulics 650 Ton Hitec 2,000' 13,000' 7,000' 3 Wirth - 2200 7,500 1,900 3,500 1,800 11,600 5 1 1 3 10 3.0625" 4 Shaffer 1 Shaffer 155 Flange 49.5" 14" Hydraulic Sara N

ATWOOD OCEANICS, INC. CONTACT: Tony Dyne, Alpha Offshore Drilling Services Co., 332-A-11C, 11th floor, Plaza Ampany City Jalan Ampang 50450 Kuala Lumpur, Malaysia, Tel: 603-4256-9590, Fax: 603-4257-9208, Email: marketing@atwd.com, Website: www.atwd.com

12 Atwood Beacon KFELS enhanced ‘B’ class 2003 Singapore ABS 400' 25' 18' 517' Y 47' 36,000' Jul-13 Israel 9,275 est. 3-4 112 234' 208' 15' S61 N & S92 N Y 2,800 4 50 1.5" EIPS 2,500' 5 36.5 @ 45' 27.7 @ 40' 27.7 @ 40' Y 1,500 WCI 36' x 36' 3,300 NOI Ensco 1.63" 49.5" 250 Y Varco ST-80 Varco TDS-8SA NOI Cyber Base 15,000' 5,000' 3 Lewco 2200 7,500 24,112 647 838 11,100 5 linear 5 1 1 1 2K & 15K 3" 2 & 4 Cameron 1 & 1 Shaffer 60 & 147 Flanged 49.5" 14" Electro-pneumatic S & S

17 Atwood Mako BMC Pacific 400 2012 Singapore ABS 400' 532' Y 55' 30,000' Sep-14 Thailand est. 3-4 150 237' 224' 15' N Y 2,500 3,750 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" Y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Flanged Electro-pneumatic CAD

17 Atwood Manta BMC Pacific 400 2012 Singapore ABS 400' 532' Y 55' 30,000' Dec-13 Thailand est. 3-4 150 237' 224' 15' N Y 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" Y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Electro-pneumatic CAD

17 Atwood Orca BMC Pacific 400 2013 Singapore ABS 400' 532' Y 55' 30,000' May-15 Thailand est. 3-4 150 237' 224' 15' N Y 2,500 3,750 4 1.5" EIPS 3,000' 6 50 50 50 Y 1,500 Loadmaster 35' x 35' NOV 49.5" y Varco TDS-8SA NOV Cyber Base 3 National 14-P-220 7,500 11,650 4 1 1 15K 2 Hydril 1 Hydril Flanged Electro-pneumatic CAD

6 Atwood Aurora LeTourneau Super 116E 2008 USA ABS 350' 33' 18' 477' Y 46' 30,000' Feb-14 Cameroon 10,750 est. 3-4 110 243' 206' 16.5' S61 N & S92 N Y 2,425 4 1.5" EIPS 2,500' 5 50 @ 25' 41 @ 25' 41 @ 25' Y 1,500 Loadmaster 35' x 35' 4,500 Lewco 1.75" 49.5" 200 Y ST-80 Varco TDS-8SA Atwood System Omron 5,000' 3 Lewco 2215 7,500 5,056 1,068 682 12,200 5 linear 5 1 1 1 15K 3-1/16" 2 Cameron 1 Shaffer 212 Flanged 49.5" 14" Electro-pneumatic CAD

CHINA OILFIELD SERVICES Ltd. CONTACT: None provided by company

12 COSL Craft KFELS ‘B’ class 2007 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Lewco W-2215 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Power BMC Pacific 375 2006 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 25 45 55 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

16 COSL Superior BMC Pacific 375 2007 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

12 COSL Boss KFELS ‘B’ class 2007 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Mission Magnum or equivalent 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Force BMC Pacific 375 2008 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 25 45 55 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

12 COSL Strike KFELS ‘B’ class 2009 Singapore ABS 400' 15' 30' 517' Y 47' 30,000' 10,750 112 234' 208' 16' S61 N N Y 2,250 3,750 70' 70' x 30' 4 25.5 1.5" EIPS/ IWRC 5.5 50 50 50 11.9 Y 1,500 Woolslayer 36' x 36' 3,450 NOV 1.63" 49.5" 250 Y AR3200 Varco-TDS -8SA VARCO PRS-8 Racker NOV amphion 20,000' 3 Lewco W-2215 7,500 2,180 1,433 1,106 11,100 5 1 1 1 15 3" 4 Cameron 1 Cameron 197 18-3/4" Flange 30" 14" Cameron Cameron Y

16 COSL Seeker BMC Pacific 375 2008 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

16 COSL Confidence BMC Pacific 375 2009 Singapore ABS 375' 15' 30' 506' Y 56' 30,000' 10,750 115 236' 224' 20' S61 N N Y 2,245 3,745 70' 70' x 30' 4 40 1.5" EIPS/ IWRC 6 21 41 50 10 Y 1,500 National 35' x 35' 3,450 NOV 1.63" 49.5" 250 N Hydralift-MPT Hydralift HPS-750 X-Y Hydraracker Cyberbase 20,000' 3 National 14P-220 7,500 2,034 2,040 1,200 11,600 4 1 1 1 1 15 3" 4 Hydril 1 Hydril 183 18-3/4" Flange 36.5" 14" Hydril Hydril Y

23 COSL 941 F & G JU2000 2006 China ABS 400' 30' 548' 30,000' 120 231' 249' N 4,150 5,000 75' 75' x 30' 2,000 National 40' x 40' NOV 49.5" Hydralift HPS 750-E

23 COSL 942 F & G JU2000 2008 China CCS 400' 30' 548' 30,000' 120 231' 249' N 4,150 5,000 75' 75' x 30' 2,000 National 40' x 40' NOV 49.5" Hydralift HPS 750-E

DIAMOND OFFSHORE DRILLING, INC. CONTACT: Contracts & Marketing, 15415 Katy Fwy Suite 100, Houston, Texas 77094; Phone: (281) 492-5300; Fax: (281) 492-5310; Website: diamondoffshore.com

2 Ocean Titan LeTourneau 64 1974 USA 2003 ABS 350' 25' 26' 467' N 46' 25,000' 1Q/14 US GoM 5,850 4 76 237.1' 200.5' 17' S61 N Y 2,530 3,375 65' 30' x 55' 0 46 30 N 1,700 Brown 30' x 30' 3,000 National 1.75" 37.5" N Varco AR3200 Varco TDS-4H Petron 15,000' 3 National 12-P-160 5,000 980 445 5,500 3 2 1 1 1 10 3-1/16" 4 Cameron 1 Shaffer 75 Flanged 10M 27.5" 12" Electro-pneumatic Shaffer N

13 Ocean Scepter KFELS Super ‘B’ class 2008 USA –– ABS 350' 36' 20' 486' Y 47' 35,000' Aug-13 Mexico 12,069 4 120 246' 218' 16' S61 N & S92 Y Y 2,431 3,992 70' 60' x 30' 0 62 53 53 Y 2,000 National 36' x 36' 4,600 National 2" 49.5" 250 N Nat’l Hydratong MPT National Oilwell HPS National BR6-SD National 7,000' 15,000' 13,000' 3 NOV 14-P-220 7,500 3,330 1,879 1,000 15,000 4 1 1 1 1 15 3-1/16" 4 Shaffer 1 Shaffer NXT 18-3/4" x 15M 49.5" 16" Electro-Hydraulic CAD Y

EGYPTIAN DRILLING COMPANY CONTACT: Km 17.5, Cairo Suez Desert Road P.O.Box 8071 Nasr City Housing, Cairo 11371; Phone: (+202) 24062222; Fax: (+202) 24062310; Email: contactus@egyptian-drilling.com

16 Setty BMC 375 2010 Singapore ABS 375' 506' Y 30,000' Aug-14 9,275 120 236' 224' 2,268 3,401 75' x 30' 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Cameron 18-3/4" 49.5" CAD

16 Sneferu BMC 375 2009 Singapore ABS 375' 506' 30,000' Sep-15 9,275 120 236' 224' 2,268 3,401 75' x 30' 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

EGYPTIAN OFFSHORE DRILLING COMPANY Contact: 85 Nasr Road, 1st District, Nasr City, Cairo, Egypt, P. O. Box 8064, Nasr City 11371; Phone: 202 24055845, 6, 7, 8; Fax: 202 24055876; Email: egas@egas.com.eg

16 El Qaher I BMC 375 2010 Singapore ABS 375' 506' 30,000' Aug-13 9,275 120 237' 224' 2,268 3,401 70' x 30' 38 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

16 El Qaher II BMC 375 2011 Singapore ABS 375' 506 30,000' Q2 2013 9,275 120 237' 224' 2,268 3,401 70' x 30' 38 38 Loadmaster 35' x 35' 3,000 TTS Sense 1-5/8" 49.5" CanRig 1275 A/C TTS Sense Eweco E-2200 7,500 15 3-1/16" 4 Shaffer 18-3/4" 49.5" CAD

ENSCO PLC CONTACT: Mike Roth 5847 San Felipe Suite 3300 Houston, Texas 77057; Phone: (713) 789-1400; (713) 789 -1430; Email: mroth@enscoplc.com; Website: www.enscoplc.com

3 ENSCO 67 MLT 84-CE (enhanced) 1976 Scotland 2005 ABS 350' 25' 24' 511' Y 46' 30,000' 2Q16 SE Asia 6,600 5 108 238' 227' 16' MI-172 N Y 1,987 3,792 60' 60' x 30' 4 25 1-3/8" IWRC 2,500' N 5 45 45 50 N/A N/A Y 1,500 NOI / Dreco 30' x 30' 3,000 National 1.75" 37.5" 175 Y Varco ST 80 Varco TDS-4H N/A MDT 20,000' 3 National 12-P-160 5,000 2,644 Incl. 2,472 6,240 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 48/58 Cameron 37.5" 12" TD-280-3S Shaffer Y

4 ENSCO 68 MLT 116-CE (enhanced) 1976 USA 2003 ABS 400' 12' 22' 512' Y 46' 30,000' 1Q14 GoM 6,600 4 80 261' 227' 15.5' S61 N Y 2,753 3,783 60' 45' x 30' N/A N/A N/A N/A N/A N N/A 45 45 45 N/A N/A Y 1,500 NOI / Dreco 30' x 30' 3,000 National 1.75" 37.5" 175 Y Varco ST 80 NOI PS2-650 N/A MDT 15,000' 3 National 12-P-160 5,000 1,685 Incl. 6,240 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 48/58 Cameron 21.25" 12" TD-280-3S Shaffer Y

5 ENSCO 75 MLT Super 116C 1999 USA N/A ABS 380' 42' 32' 544' N 57' 30,000' 1Q14 GoM 7,420 3 83 243' 206' 16' S61 N Y 1,750 3,250 70' 55' x 30' N/A N/A N/A N/A N/A N N/A 50 50 50 N/A N/A Y 1,500 Loadmaster 32' x 35' 3,000 National 1.75" 49.5" 175 Y MH-1899 Varco TDS 8SA N/A Hi-Tech 26,000' 26,000' 3 National 14-P-220 7,500 2,229 Incl. 1,100 11,100 5 0 1 1 1 0 10 3.06" 3 Cameron 1 Shaffer 86 Cameron 29.5" 12" TX392-15BT3X Koomey Y

5 ENSCO 76 MLT Super 116C 1999 USA N/A ABS 350' 25' 16' 411' Y 46' 30,000' 2Q14 Saudi Arabia 10,056 3.5 100 243' 206' 16' S61 N Y 1,907 4,000 65' 50' X 30' 2 25 1.5" 6 x 36 IWRC 2,000' N N/A 50 50 50 N/A N/A Y 1,500 Dreco 40' x 32' 3,000 National 1.63" 49.5" Y Varco AR-3200 Varco TDS-8SA N/A Hi-Tech 24,000' 24,000' 3 National 14-P-220 7,500 2,907 1,416 10,880 5 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer 100 Flange 39" 12" SSB2403S11 M/SS Y

4 ENSCO 81 MLT 116-C 1979 UK 2003 ABS 350' 25' 20' 477' N 46' 25,000'+ 4Q13 GoM 6,600 4 106 243' 200' 16' S61 N Y 1,975 3,920 59.5' 45' x 24' N/A N/A N/A N/A N/A N N/A 45 45 45 N/A N/A Y 1,500 Dreco 30' x 30' 3,000 National 1.75" 37.5" Y Varco TDS 4H 750 T N/A Oilfield Inst. 15,000' 3 National 12-P-160 5,000 1,401 Incl. 8,160 4 1 0 10 3.06" 3 Shaffer 1 Shaffer 80 Flange 21.25" 12" T-SB-540 CAD Y

4 ENSCO 87 MLT 116-C 1982 USA 2006 ABS 350' 25' 25' 477' N 46' 25,000'+ 3Q13 GoM 6,600 4 75 243' 200' 16' S61 N Y 1,970 4,234 60' 45' x 30' N/A N/A N/A N/A N/A N N/A 50 50 50 N/A N/A N 1,500 National 30' x 30' 3,000 National 1.75" 37.5" Y Varco ST-80 Varco TDS 8SA N/A MDT 15,000' 3 National 12-P-160 5,000 1,689 Incl. 6,880 4 4 1 1 0 10 3.06" 3 Cameron 1 Shaffer 60 Flange 21.25" 12" T-SB-540 CAD Y

10 ENSCO 101 KFELS MOD V ‘A’ class 2000 Singapore 2010 ABS 400' 25' 25' 540' Y 60' 30,000' 1Q15 North Sea 11,130 4 to 5 96 228' 222' 16' S92 N Y 3,500 6,400 70' 55' x 30' 4 51 2" 6 x 36 IWRC 2,060' N 7.5 55 55 55 N/A N/A Y 1,500 Dreco 40' x 40' 3,000 National 1.75" 49.5" 500 Y AR-3200 Varco TDS-4H PRS4i MDT 9,000' 19,500' 3 National 14-P-220 5,000 4,808 Incl. 1,370 17,600 4 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer Flange 57" 14" Hydraulic Shaffer Y

10 ENSCO 102 KFELS MOD V ‘A’ class 2002 Singapore N/A ABS 400' 25' 25' 541' Y 60' 30,000' 1Q16 North Sea 11,130 4 to 5 122 246' 222' 16' S92 N Y 4,281 6,378 70' 55' x 30' 4 51 2" 6 x 36 IWRC 2,060' N 7.5 55 55 55 N/A N/A Y 1,500 Dreco 40' x 40' 3,000 National 1.75" 49.5" 400 Y AR-3200 Varco TDS-4H PRS4i MDT 20,000' 5,000' 3 National 14-P-220 7,500 5,216 Incl. 1,370 17,640 4 0 1 1 1 0 15 3.06" 4 Shaffer 1 Shaffer 190 Flange 49.5" 14" Hydraulic Shaffer Y

12 ENSCO 104 KFELS MOD V ‘B’ class 2002 Singapore 2011 ABS 400' 25' 20' 517' Y 47' 30,000' 1Q14 Australia 9,275 4 to 5 110 225' 208' 14' S61 N Y 2,500 3,348 70' 70' X 30' 4 50 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 National 1.63" 49.5" Y Varco ST-80/ST4566 Varco TDS-8SA N/A Hi-Tech 20,000' 11,400' 3 National 14-P-220 7,500 3,598 Incl. 2,438 11,100 5 5 1 1 1 2 10 3.06" 4 Cameron 1 Shaffer Flange 30" 12" TX-392 15BT3X ABB Y

12 ENSCO 105 KFELS MOD V ‘B’ class 2002 USA 2010 ABS 400' 25' 16' 517' Y 46' 30,000' 4Q13 SE Asia 9,275 4 to 5 94 225' 208' 14.5' S61 N Y 3,600 6,649 70' 70' x 30' 2 25 1.25" IWRC 3,000' N 7.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 National 1.63" 49.5" 250 Y AR-3200 Varco TDS-4H N/A NOV SDI /200 20,000' 3 National 14-P-220 7,500 3,876 Incl. 1,083 11,100 5 1 0 10 3.06" 4 Cameron 1 Shaffer 164 Flange 30" 12" TX-392 15BT3X Koomey Y

12 ENSCO 106 KFELS MOD V enhanced ‘B’ class 2005 Singapore N/A ABS 400' 25' 20' 517' Y 53' 30,000' 4Q13 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 Varco / MIL 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA N/A Varco Amphion 20,000' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 10 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

12 ENSCO 107 KFELS MOD V enhanced ‘B’ class 2006 Singapore N/A ABS 400' 25' 20' 517' Y 53' 30,000' 3Q14 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 WCI 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA Varco Compact Racker Varco Amphion 20,000' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 10 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

12 ENSCO 108 KFELS MOD V enhanced ‘B’ class 2007 Singapore 2009 ABS 400' 25' 20' 517' Y 53' 30,000' 2Q14 SE Asia 9,275 4 to 5 112 234' 208' 16' S61 N N Y 3,000 4,500 70' 70' X 30' 4 25 1.5" IWRC 2,000' N 5 50 50 50 N/A N/A Y 1,500 WCI 35' x 32' 3,000 Varco 1.75" 49.5" 400 Y AR-3200 Varco TDS-8SA N/A Varco Amphion 20,000' 10,300' 3 Lewco W-2215 7,500 3,891 Incl. 2,004 11,100 4 4 1 1 1 0 15 3.06" 3 Varco SLX 1 Shaffer Vetco NT2 49.5" 12" T60360-3S Koomey Y

13 ENSCO 109 KFELS MOD V Super ‘B’ class 2008 Singapore N/A ABS 400' 25' 20' 486' Y 53' 30,000' 3Q13 Australia 12,250 4 to 5 120 246' 218' 16' S92 Y Y 5,221 7,984 70' 70' x 30' 0 N/A N/A N/A N/A N N/A 50 50 55 N/A N/A Y 2,000 NOV 36' x 36' 4,600 NOV 2.0'' 49.5'' 500 N NOV Hydratong NOV HPS-1000 NOV Bridge Racker NOV SDI /Cyberbase 10,000' 15,000' 3 National 14P-220 7,500 5,364 Incl. 1,015 15,890 4 4 1 1 0 15 3.06" 4 NOV/Shaffer 1 Shaffer 207 BX 164 49.5" 16" CAD4801037OU2 CAD Y

11 ENSCO 120 KFELS MOD V Super ‘A’ class 2013 Singapore N/A ABS 400' 100' 25' 540' N 59.7' 40,000' 2Q15 North Sea 12,900 4 150 246' 250' 20.4' S92 N Y 4,048 7,148 80' 60' x 32' 4 49 2" IWRc 2,000' N 7 70 70 70 N/A N/A Y 2,500 NOV 40' x 40' 6,000 NOV 2.0" 60.5" 600 Y NOV ST-160 NOV TDX-1250 NOV PRS-6is NOV Amphion 20,000' 5,070' 3 NOV 14-P-220 7,500 7,500 Incl. 17,640 4 1 1 0 15 3.06" 4 NOV/Shaffer 1 Shaffer BX 164 49.5" 16" Koomey Y

EURASIA DRILLING CONTACT: Kim L. Kruschwitz, Vice President, Marketing; investor.relations@eurasiadrilling.com

6 Neptune LeTourneau Super 116E 2013 UAE 350' 30,000' Caspian 1,500 Woolslayer 35' x 32' 3,000 Lewco 49.5" NOV TDS-8SA 3 Lewco W-2214 7,500

12 Saturn KFELS Mod V 2000 Azerbaijan ABS 350' n/a 19' 496' n/a 2,690' 26,000' Caspian 6,436 3.5 100 228' 228' 17.7' S61N or MI-8 Y Y 2,700 5,900 45' 12' x 12' 4 103 1.5" 2,625' N 4 x 4 55 55 55 N 1,300 Loadmaster 40' x 40' 3,000 National 1.75" 37.5" MH-1899 Canrig 1275 E MH BC01 Sedco Forex 22,000' 1,000' 3 National 14-P-200 7,500 4,000 2,000 5,800 5 2 2 1 N 15 3.06" 2 Shaffer 1 Shaffer 180.7 Shaffer 27.5" 12" Hydraulic Shaffer Y

GREATSHIP GLOBAL ENERGY SERVICES CONTACT: Mr. V. Sheshashayee, 15, Hoe Chiang Road, Tower Fifteen, #06-03, Singapore 089316; Phone +65 65765600

6 GreatDrill Chaaya LeTourneau Super 116E 2013 UAE ABS 350' 30 478' 30,000' 10,750 106 243 206 29' S61 N Y 1,826 3,322 4 30 1.5" XIPS 2,500' 5 68 @ 39' 38 @ 25' 38 @ 25' 1,500 LeTourneau 32' x 35' 4,500 LEWCO 49.5" Varco ST-120 NOV TDS-8SA 3 Lewco W-2214 2,200 12,250 4 1 1 1 15K/2K 3.06" 3 Cameron 2 Cameron Cameron 49.5" Pneumatic Ingersol Rand

12 GreatDrill Chiltra KFELS 'B' class 2009 Singapore ABS 350' 15' 30' 491' Y 53' 30,000' 9,275 112 234' 208' 16' S61 N N Y 3,600 70' 51.5' x 30' 4 30 1.5" XIPS 2,500' n/a 5 50 @ 40' 50 @ 40' 50 @ 40' Y 1,500 WCI 35' x 32' 3,000 NOV 1.75" 49.5" 200 Y Varco ST-80 NOV TDS-8SA VCR NOV 308' stds 308' stds 10 stds 3 NOV 14-P-220 7,500 1,750 1,750 11100 4 1 1 1 1 1 10K / 2K 3.06" 4 Cameron 1 Cameron 68 29.5" Cameron Y

12 GreatDrill Chetna KFELS 'B' class 2009 Singapore ABS 350' 15' 30' 491' Y 53' 30,000' 9,275 104 234' 208' 16' S61 N N Y 1,631 3,600 70' 51.5' x 30' 4 30 1.5" XIPS 2,500' n/a 5 50 @ 40' 50 @ 40' 50 @ 40' Y 1,500 WCI 35' x 32' 3,000 NOV 1.75" 49.5" 200 Y Varco ST-80 NOV TDS-8SA VCR NOV 308' stds 10 stds 3 NOV 14-P-220 7,500 1,750 1,750 11100 4 1 1 1 1 1 10K / 2K 3.06" 4 Cameron 1 Cameron 68 Cameron 29.5" Cameron Y

HERCULES OFFSHORE CONTACT: Brad James, 9 Greenway Plaza, Suite 2200, Houston, Texas 77046; Phone: 713-350-8438; Fax: 713-350-5114; Email: bjames@herculesoffshore.com; Website: www.herculesoffshore.com

4 Hercules 350 LeTourneau 116-C 1982 Canada 8/1/2010 ABS 350' 25' 25' 477' N/A 46' 25,000' GOM 6,000 4.2 83 243' 200' 15.75' S61/S92 60' Y/N 3,704 5,204 60' N/A N/A N/A N/A N/A N/A N/A 50 50 50 N/A N/A Y 1,250 Brown 30' x 30' 3,000 National 1625 1.5" 37.5" N/A Y CanRig TM-80 Varco TDS-3 N/A MD Totco 15,000' N/A N/A N/A N/A N/A 2 National 12-P-160 3,980 851 916 1,200 4,200 3 N/A 1 1 1 N/A 3 3" 4 Cameron 1 Hydril 50 Flange 21.25" 12" Electrohydraulic CAD N

JAPAN DRILLING CO. Ltd. CONTACT: Mr. Michiharu Ureshino, Shin-horidome Bldg. 6F, 2-4-3 Nihonbashi Horidome-cho, Chuo-ku, Tokyo, 103-0012, Japan Tel : (81-3) 5847-5855 Fax : (81-3) 5644-5702 Email: michiharu.ureshino@jdc.co.jp Website: www.jdc.co.jp

16 Hakuryu 10 BMC Pacific 375 2008 Singapore ABS 375' 30' 30' 506' N 55' 30,000' 12000 4 to 5 120 236' 224' 17' S61 N & S92 N Y 2,500 3,000 70' 55' x 30' 4 32 1.7" IWRC 3,000' 6 55 @ 25' 45 @ 25' 25 @ 20' Y 1,500 NOV 35' x 35' 3,000 NOV 1.63" 49.5" N MPT200 NOV HPS-750E-AC Bridge Racker NOV BR6-SD NOV cyberbase 308' stds 10 stds 3 National 14-P-220 7,500 2,000 2,000 1,200 11,750 4 1 15 3" 4 Cameron 1 Shaffer 265 15K flanged 49.5" 12" mod. 2QD00 Shaffer Y

13 Hakuryu 11 KFELS Super ‘B’ class 2013 Singapore ABS 425' 10' 531' 47' 35,000' 150 246' 218' S61 N & S92 2,268 3,400 70' 4 57 @ 25' 57 @ 25' 70 @ 25' Y 2,000 1,150 NOV 2" 49.5" NOV ST-120 NOV TDS-1000A NOV Amphion 366' stds 3 National 14-P-220 7,500 15,050 5 1 15 4 Cameron 1 Shaffer 18-3/4" Cameron

DISCOVERY DRILLING Pte. Ltd. (Jindal's JV Company) CONTACT: V. K. Nagpaul, 63, Robinson Road, #02-10 Afro Asia Building, Singapore-068894 Tel: +65-62218522 Fax:+65-62218225 Email: vkn@discoverydrilling.sg

12 Discovery I KFELS ‘B’ class 2008 Singapore ABS 350' 15' 30' 491' Y 47' 30,000' 1Q/2017 Indian W. Offshore 9,275 4 112 234' 208' 15' S61 N Y Y 1,800 3,700 70' 70' x 30' 4 30 1.5" IWRC, EIPS 2,000' 5 50 50 50 Y 1,600 WCI 32' x 35' 3,000 Varco ADS 1.75" 49.5" 220 Y Varco ST 80 Varco TDS-8S-A Varco VCR Varco Amphion 5,000' 11,500' 4,000' 3 NOV 14-P-220 7,500 1,648 2,000 1,000 11,000 4 1 1 1 1 10 3.06" 4 Cameron 1 Cameron 143 Flanged 29.5" 14" Hydraulic Cameron N

12 Virtue I KFELS ‘B’ class 2008 Singapore ABS 350' 15' 30' 491' Y 47' 30,000' 1Q/2014 Indian W. Offshore 9,275 4 112 234' 208' 15' S61 N Y Y 1,800 3,700 70' 70' x 30' 4 30 1.5" IWRC, EIPS 2,000' 5 50 50 50 Y 1,600 WCI 32' x 35' 3,000 Varco ADS 1.75" 49.5" 220 Y Varco ST 80 Varco TDS-8S-A Varco VCR Varco Amphion 5,000' 11,500' 4,000' 3 NOV 14-P-220 7,500 1,648 2,000 1,000 11,000 4 1 1 1 1 10 3.06" 4 Cameron 1 Cameron 143 Flanged 29.5" 14" Hydraulic Cameron N

KCA DEUTAG Contact: Minto Drive, Altens Industrial Estate, Aberdeen AB12 3LW, Scotland; Phone: 44 1224 299600; Fax: 44 1224 230403; Website: www.kcadeutag.com

1 Ben Rinnes LeTourneau 53 1973 USA 2007 ABS 350' 18' 478' 46' 30,000' West Africa 8,880 100 284' 233' S61 43 50 44 1,500 Pyramid 30' x 40' 3,000 National 37.5" Varco TDS-8SA 300' stds 3 National 12-P-160 7,500 3 1 10 2 Cameron 1 Cameron 21.25" Shaffer

MAERSK DRILLING CONTACT: Maersk Drilling; 50, Esplanaden; 1098 Copenhagen K, Denmark; Phone: (45) 33-63-33-63; FAX: (45) 33-63-31-82; Email: copenhagen@maersk-drilling.com; Website: www.maersk-drilling.com

15 Maersk Endurer BMC 350 1984 Japan 1997 ABS 350' 16.4' 30' 479' N 56' 30,000' 4Q/’14 Cameroon 11,420 4 98 236' 236' 17.1' S61 N N Y 2,075 3,250 55' 45' x 32' 4 20 1.5" BS302 3,000' N 5 47.6 47.6 Y 1,500 WCI 35' x 30' 3,000 Continental Emsco 1.63" 49.5" 4 x 81 Varco AR3200 Varco TDS-4S PRS-3 mD TOTCO 14,800' 11,000' 3 Cont'l Emsco FC-2200 7,500 1,610 1,885 1,500 10,000 4 15 3.06" 4 Shaffer 1 Shaffer 156 Flange 49.5" 16" Multiplex Shaffer Y

20 Maersk Gallant MSC CJ62-120S 1993 Singapore Lloyds 394' 16.4' 30' 575' Y 64' 25,000' 2Q/’14 North Sea 8,075 4 100 257' 296' 19.4' S61 N Y Y 2,959 5,000 64' 54' x 30' 4 53 2" BS302 2,620' N 8 50 34 50 Y 2,000 Emsco 40' x 40' 3,000 Continental Emsco 1.75" 49.5" 4 x 60 Varco AR3200 Varco TDS-6S PHM-3 HiTEC 15,000' 5,000' 3 Cont'l Emsco FC-2200 7,500 3,150 1,890 1,700 14,700 4 1 2 15 3.06" 3 Shaffer 1 Shaffer 185 Flange 49.5" 14" TX 448 Koomey Y

24 Maersk Giant Hitachi Zosen 1986 Japan 2012 Lloyds 350' 16.4' 30' 525' Y 56' 25,000' 3Q/’13 North Sea 8,253 4 100 277' 295' 15.7' S61 N & S92 Y Y 3,050 5,000 55' 45' x 26' 3 55 2" BS302 2,460' N 8 27 45 65 Y 1,000 National 30' x 30' 2,000 National 1.50" 49.5" 4 x 100 Varco AR4497 Varco TDS-4S PRS 8i Varco 17,000' 3 National 12-P-160 5,000 2,900 1,450 13,500 4 15 2.5" 3 Shaffer 1 Shaffer 143 NT-2 49.5" 12" T-3000 NL Shaffer Y

24 Maersk Guardian Hitachi Zosen 1986 Japan 2011 Lloyds 350' 16.4' 30' 515' Y 56' 25,000' 2Q/’14 North Sea 8,253 4 100 277' 295' 15.7' S61 N & S92 N Y 3,050 5,000 55' 45' x 26' 4 55 2" BS302 2,620' N 8 68 27 45 Y 1,000 National 30' x 30' 2,000 National 1.50" 49.5" 4 x 75 Varco AR4498 Varco TDS-4S PRS 8i Varco 16,000' 6,200' 3 National 12-P-160 5,000 2,500 2,830 1,448 13,500 4 15 2.5" 4 Shaffer 1 Shaffer 183 Flange 49.5" 12" T-3000 NL Shaffer Y

21 Mærsk Innovator MSC CJ70-150MC 2003 Korea DnV 492' 9.8' 30' 673' Y 72' 30,000' 1Q/’17 North Sea 14,420 4 120 291' 336' 26.2' GKN Westland 101 & S61 N N Y 4,680 10,000 90' 86' x 66' 4 80 2.25" BS302 3,400' N 8 100 100 100 Y 2,000 WCI 46' x 52.5' 4,600 Varco 1.75" 49.5" 4 x 100 Varco AR4500 Varco TDS-8SA PRS 6is Varco 25,100' 4 Wirth TPK 7,500 6,400 3,030 4,760 15,883 6 2 2 15 3.06" 4 Shaffer 1 Shaffer 200 NT-2 49.5" 14" MUX 4rd Generation Shaffer Y

21 Mærsk Inspirer MSC CJ70-150MC 2004 Korea DnV 492' 9.8' 30' 673' Y 72' 30,000' 4Q/’14 North Sea 14,420 4 120 291' 336' 26.2' GKN Westland 101 or S61 N N Y 4,680 10,000 90' 86' x 66' 4 80 2.25" BS302 3,400' N 8 100 100 100 Y 2,000 WCI 46' x 52.5' 4,600 Varco 1.75" 49.5" 4 x 100 Varco AR4500 Varco TDS-8SA PRS 6is Varco 25,100' 4 Wirth TPK 7,500 6,400 3,030 4,760 15,883 6 2 2 15 3.06" 4 Shaffer 1 Shaffer 200 NT-2 49.5" 14" MUX 4rd Generation Shaffer Y

19 Maersk Resilient MSC CJ50 2008 Singapore 2011 ABS 350' 15' 30' 479' Y 69' 30,000' 3Q/14 North Sea 9,920 120 229' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 4 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 100 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Mærsk Resolute MSC CJ50 2008 Singapore N/A ABS 350' 15' 30' 479' Y 52' 30,000' 2Q/’15 North Sea 9,920 120 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 2 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Mærsk Resolve MSC CJ50 2009 Singapore N/A ABS 350' 15' 30' 479' Y 52' 30,000' 3Q/’13 North Sea 9,920 120 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 2 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

19 Maersk Reacher MSC CJ50 2008 Singapore 2011 ABS 350' 15' 30' 479' Y 69' 30,000' 3Q/’14 North Sea 9,920 110 230' 223' EH101 & S61 N N Y 3,400 4,950 70' 70' x 44' 4 50 1-5/8" EEIPS 2,624' N 80 80 12 Y 1,500 MH 46' x 46' 4,500 Wirth 1.75" 49.5" 4 x 75 N MH Torquemaster MH - DDM750 MH AKMH 6,500' 20,000' 3 Wirth TPK 7,500 2,278 2,383 3,145 10,550 4 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

16 Maersk Completer BMC Pacific 375 2007 Singapore N/A ABS 375' 15' 30' 507' Y 55' 30,000' 4Q/’14 Brunei 11,765 120 236.5' 224.4' 18' S61 N Y 2,268 4,950 70' 70' x 30' 4 31.7 1.5" EIPS 3,000' N 7 15 40 34 Y 1,500 National 35' x 35' 3,000 National 1.63" 49.5" 4 x 115 N National LPT National HPS750 NOV NOV 20,000' 3 National 14-P-220 7,500 1,025 3,075 1,200 11,645 4 1 1 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

16 Maersk Convincer BMC Pacific 375 2008 Singapore N/A ABS 375' 15' 30' 507' Y 55' 30,000' 4Q/’13 Malaysia 11,765 120 236.5' 224.4' 18' S61 N Y 2,268 3,750 70' 70' x 30' 4 31.7 1.5" EIPS 3,000' N 7 15 40 34 Y 1,500 National 35' x 35' 3,000 National 1.63" 49.5" 4 x 115 N National LPT National HPS750 NOV NOV CyberBase 20,000' 3 National 14-P-220 7,500 1,025 3,075 1,200 11,645 4 1 1 15 3.06" 4 Hydril 1 Hydril 86 18.75" studded 49.5" 14" Hydraulic Hydril Y

NOBLE DRILLING CORPORATION CONTACTS: 13135 South Dairy Ashford, Suite 800, Sugarland, Texas 77478; Phone: (KH) (281) 276-6333 or (MN) (281) 276-6226; Fax: (281) 276-6303; Website: www.noblecorp.com

25 Noble Al White CFEM T-2005-C 1982 France 2005 DNV 360' 60' 50' 504' N 49.2' 25,000' 2Q/14 North Sea 9,790 4 96 245' 282' 15' S61 N Y Y 2,097 2,921 45' 41' x 24' 4 32 2.25"/ 1.25" IWRC 2,300'/2,900' N 9.1 45 45 Y 1,000 JA Paris 36' x 36' 4,600 National 1.50" 37.5" Y Varco Varco TDS-8SA MH114008 Martin Decker / Electro-flow as required 2 NOV HEX 240 7,500 840 845 1,623 11,020 4 1 1 15 3.06" 3 Cameron 1 Cameron 117 Flange 36.25" 12" Hydraulic Koomey N

3 Noble Bill Jennings MLT Class 84 ERC 1975 USA 1997 ABS 390' 8' 25' 500' N 46' 25,000' 1Q/15 Mexico 5,850 6 102 248' 201' 16' S76 N Y 1,784 3,000 70' 50' x 30' N 50 50 65 Y 1,300 Dreco 30' x 30' 3,000 Continental Emsco 1.50" 49.5" Y National ST-100 National PS2-750A TOTCO as required 3 Continental Emsco FB 1600 5,000 1,230 467 1,400 8,640 3 2 1 1 1 10 3.06" 4 Cameron 1 Hydril 62 Flange 29.5" 10" 80 Koomey N

3 Noble Eddie Paul MLT Class 84 ERC 1975 USA 1995 ABS 350' 8' 21' 500' N 46' 25,000' 1Q/16 Mexico 4,200 6 100 247' 200' 15' S61 N Y 1,886 3,000 70' 50' x 30' N 50 50 65 Y 1,671 Dreco 30' x 30' 2,000 National 1.50" 37.5" Y NOV AR3200 NOV PS2-750A TOTCO as required 3 National 12-P-160 5,000 1,450 490 1,400 6,240 4 2 1 1 1 10 3.06" 3 Cameron 1 Hydril 62 Flange 21.25" 10" 80 Koomey N

1 Noble Leonard Jones MLT Class 53 ERC 1972 USA 1998 ABS 350' 8' 25' 500' N 46' 25,000' 2Q/15 Mexico 4,200 6 104 247' 201' 17' S61 N Y 2,457 3,559 65' 54' x 30' N 50 50 50 Y 1,671 Dreco 30' x 14' 3,000 National 1.50" 37.5" Y NOV AR3200 Varco TDS-4S TOTCO as required 3 National 12-P-160 5,000 1,480 490 1,400 6,240 4 2 1 1 1 10 3.06" 3 Cameron 1 Hydril 62 Flange 29.5" 10" 80 Koomey N

23 Noble Roger Lewis JU-2000E 2007 China ABS 400' 10' 30' 547' N 59' 35,000' 1Q/14 Saudi Arabia 17,750 6 130 231' 249' 21' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 2,000 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Hydraracker HR-III-X-Y-SB TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 5 2 1 1 1 1 15 3.06" 4 Cameron 1 Shaffer 100 Flange 49.5" 12" UET60-VT460 Vetco Gray N

23 Noble Hans Duel JU-2000E 2009 China ABS 400' 10' 30' 549' N 59' 30,000' 3Q/14 North Sea 17,750 6 120 328' 255' 22' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 1,500 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Column Racker TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 5 2 1 1 1 15 3.06" 4 Cameron 1 Cameron 100 Flange 49.5" 12" 80 Vetco Gray N

23 Noble Scott Marks JU-2000E 2009 China ABS 400' 10' 30' 548' N 59' 30,000' 3Q/14 Saudi Arabia 17,750 6 120 231' 249' 22' S76 Y Y 4,150 5,000 75' 75' x 30' 4 44 2" EIPS 3,000' N 8.3 50 50 50 Y 2,000 NOV 40' x 40' 4,600 National 1.75" 49.5" Y MPT-200 NOV HPS-750-E-AC-1S-KT NOV Hydraracker HR-III-X-Y-SB TOTCO as required 3 National 14-P-220 7,500 3,960 18,000 6 2 1 1 1 15 3.06" 4 Cameron 1 Shaffer 100 Flange 49.5" 12" 80 Vetco Gray N

PERFORADORA CENTRAL, S.A. DE C.V. CONTACT: Ing. Ricardo Cortina C., Calle 24 No. 52 Altos, Cd de Carmen, Campeche, 24100 Mexico; Tel: (52) 938-382-05-35; Fax: (52) 938-382-05-77; Email: rccentral@prodigy.net.mx

12 Tonala KFELS ‘B’ class 2004 USA ABS 375' 15' 517' 46' 25,000' Mexico 9,275 6 100 234' 208 15 S61 N Y 6,000 8,000 70' 60' x 30' 50 50 50 Y 1,500 Dreco 35' x 35' 3,000 National 1.63" 49.5" N NOI IR30SP NOI - PS2-650 Hitec 3 National 14-P-220 7,500 2,514 incl. 1,083 11,100 5 1 1 1 10 3.06" 3 Cameron 1 & 1 Cameron 75 & 56 Flange 30" 12" C240 IE30-AG Cameron Y

4 Panuco LeTourneau 116-CE 2007 USA ABS 350' 25,000' Mexico

6 Tuxpan LeTourneau Super 116-E 2010 USA ABS 375 511' 30,000'

6 Papaloapan LeTourneau Super 116-E 2013 USA ABS 375 511' 30,000' Mexico 120 243' 50 50 50 1,500

PV DRILLING CONTACT: 4th Floor, Sailing Tower,111A Pasteur St., Ben Nghe Ward, District 1, Ho Chi Minh City, Vietnam; Phone: (84 8) 39 142 012; Fax: (84 8) 39 142 021; Email: info@pvdrilling.com.vn; Website: www.pvdrilling.com

12 PV Drilling II KFELS B 2009 Singapore ABS 400' 517' 46' 30,000' 120 234' 208 S61N, S92, MI-17 N N 70' 30' x 70' 4 1.75" EIPS 2,625' 50 @ 20' 24 @ 120' 1,500 Woolslayer 36' x 36' 3,450 NOV 49.5" NOV ARM3200M NOV TDS-8SA 3 NOV 14-P-220 7,500 5 1 1 2 15 3.0625" 2 Shaffer 1 Shaffer 18-3/4" 49.5" 14" Hydraulic NOV

12 PV Drilling III KFELS B 2009 Singapore ABS 400' 517' 53' 30,000' 111 234' 208 S61N, S92, MI-17 4 100 @ 20' 24 @ 120' 680 Woolslayer 32' x 35' 3,200 NOV 49.5" NOV ARM3200M NOV TDS-8SA 3 NOV 14-P-220 5 1 1 1 15 3.0625" 1 Shaffer 1 Shaffer 18-3/4" 49.5" 12" Hydraulic

ROWAN COMPANIES, INC. CONTACT: Mark A. Keller, 2800 Post Oak Blvd, Suite 5450, Houston, Texas 77056-6196; Phone: (713) 621-7800; Fax: (713) 960-7678; Email: marketing@rowancompanies.com; Website: www.rowancompanies.com

3 Rowan Alaska Letourneau 84 1975 USA 2010 ABS 350' 25' 26' 477' N 46' 30,000' Well to Well GoM 6,900 4.5 79 248' 201' 15' S61 N Y N 3,964 6,714 50' x 41' slot 15' x 15' 2 Pulls 25 1.5" 6 x 37 EIPS 2,500' 2 @ 800 hp 5.5 50 @ 24' 50 @ 24' 50 @ 25' 50 @ 24' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 37.5" 45.25 N Varco IR TW-61 Varco TDS-3 N/A Rowan TBD TBD TBD TBD TBD TBD 3 2 National 12-P-160 and 1 Lewco 1600 5,000 1,465 incl. incl. 10,880 4 1 1 10 3" 3 Cameron 1 Hydril 43.5 13-5/8" 5M Flange 21.25" 12" 80 Super T Koomey N

7 Rowan Gorilla II Gorilla 1984 Singapore 2000 ABS 350' 30' 30' 638' N 66' 30,000' 3Q/13 Malaysia 7,998 4 88 297' 292' 18' S-61 N Chinook 234LR N N 4,827 8,328 52' x 45' 52' 52' x 24' 2 Pulls 25 1.25" 6 x 37 3,000' 2 @ 3,200 ea 5 75 @ 59' 50 @ 25' 50 @ 25' 50 @ 25' 50 @ 25' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 49.5" 250 Y Varco IR TW-60 Varco TDS-4S N/A Rowan TBD TBD TBD TBD TBD TBD 3 National 12-P-160 5,000 2,478 incl. incl. 16,400 4 1 1 10 3" 3 Cameron 1 Hydril 145 13-5/8" 10M Flange 49.5" 12" 80 Super T Koomey Y

7 Rowan Gorilla III Gorilla 1984 USA N/A ABS 325' 30' 30' 504' Y 66' 30,000' 3Q/13 GoM 7,950 4 92 297' 292' 17' S-61 N Chinook 234LR N N 3,201 7,885 52' x 45' 52' 52' x 24' 2 Pulls 25 1.25" 6 x 37 3,000' 2 @ 3,200 ea 5 50 @ 26' 60 @ 58' 60 @ 58' 60 @ 58' Y 1,250 L. C. Moore 30' x 30' 4,500 NOV 1.50" 49.5" 375 N Varco IR TW-61 NOI PS-2 650/650 N/A Rowan TBD TBD TBD TBD TBD TBD 3 Continental Emsco FB-1600 5,000 2,474 incl. incl. 15,370 4 1 1 15 3" 4 Cameron 1 Hydril 145 13-5/8" 10M Flange 30" 12" 80 Super T Koomey N

7 Rowan Gorilla IV Gorilla 1986 USA 2003 ABS 450' 30' 30' 638' Y 66' 30,000' 4Q/13 Mexico 7,950 4 86 297' 292' 17' S-61 N Chinook 234LR N N 3,830 8,470 52' x 45' 75' 75' x 24' 2 Pulls 25 1.5" 6 x 37 3,000' 2 @ 4,000 ea 5 60 @ 58' 60 @ 58' 60 @ 58' 25 @ 26' Y 2,000 L. C. Moore 30' x 30' 4,500 NOV 1.63" 49.5" 100 N Varco IR TW-60 NOI PS-2 750A N/A Rowan TBD TBD TBD TBD TBD TBD 3 Lewco W-2215 7,500 2,475 incl. incl. 15,540 4 1 1 15 3" 4 Cameron 1 Hydril 145 13-5/8" 10M Flange 30" 16" MX 36011 Koomey N

8 Rowan Gorilla V Super Gorilla 1998 USA N/A ABS / DNV 400' 45' 30' 574' Y 57' 35,000' 3Q/13 North Sea 16,975 4 120 306' 300' 22' EH101/S-61N Chinook 234LR Y Y 6,250 6,884 60' x 45' 85' 85' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 400 Y Varco A-3200 Letourneau DDTD 750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 National 14-P-220 7,500 5,294 incl. incl. 22,000 5 2 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 49.5" 16" Minuteman Cameron Y

8 Rowan Gorilla VI Super Gorilla 2000 USA 2005 ABS / DNV 450' 45' 30' 607' Y 57' 35,000' 4Q/13 North Sea 16,975 4 120 306' 300' 21' EH101/S-61N Chinook 234LR Y Y 6,230 6,230 60' x 45' 100' 100' x 40' 4 Pulls 45 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 600 Y Varco A-3200 NOI PS-2 650/750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 Continental Emsco FC-2000 7,500 5,575 incl. 2,425 22,000 4 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 49.5" 16" Minuteman Cameron Y

8 Rowan Gorilla VII Super Gorilla 2002 USA N/A ABS / DNV 450' 45' 30' 607' Y 57' 35,000' 2Q/15 North Sea 16,975 4 120 306' 300' 22' EH101/S-61N Chinook 234LR Y Y 5,952 6,000 60' x 45' 100' 100' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,800 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 5,000 NOV 1.75" 49.5" 678 Y Varco A-3200 NOI PS-2 650/750 PRS 3i Rig serve TBD TBD TBD TBD TBD TBD 4 Continental Emsco FC-2000 7,500 5,294 incl. 2,425 22,000 6 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 28" 16" Minuteman Cameron Y

8 Bob Palmer Super Gorilla XL 2003 USA 2007 ABS / DNV 490' 45' 30' 647' N 67.7' 35,000' 2Q/14 Middle East 12,900 4 118 306' 300' 31' S62 N / S92 Y Y 5,772 5,800 60' x 45' 100' 100' x 40' 4 Pulls 50 2" 6 x 36 EIPS IWRC, RRL 2 2,500' 2 @ 3,600 ea 5.5 75 @ 30' 75 @ 30' 75 @ 30' 75 @ 30' 50 @ 24' Y 2,500 WCI 40' x 40' 4,500 LEWCO 2.00" 49.5" 678 Y NOV ST-120 NOI PS-2 750A PRS 8i MD Totco TBD TBD TBD TBD TBD TBD 3 Lewco W-3000 7,500 7,889 incl. 2,425 22,400 6 1 2 15 3" 4 Cameron 1 Hydril 220 18-3/4" 15M Flange 28" 16" AMSN - 5801 ABB Y

9 Rowan Joe Douglas Letourneau 240-C 2011 USA ABS / DNV 375' 491' N 35,000' 3Q/13 GOM 108 228' 220' S-61N / S-92 4,711 75 @ 30' 75 @ 30' 75 @ 30' Y 2,500 Loadmaster 36' x 36' 3,000 LEWCO 2.00" 49.5" Y LTI DDTD-750-V2 TBD TBD TBD TBD TBD TBD 3 Lewco W-3000 3,000 4,005 incl. incl. 13,800 5 3 2 15 3" 4 Cameron 1 Hydril 18-3/4" 15M Flange 30" Y

3 Rowan Louisiana Letourneau 84 1975 USA 2006 ABS 350' 25' 24' 466' N 46' 25,000' 3Q/13 GoM 7,950 4.5 78 248' 201' 20' S61 N Y N 3,963 7,310 50' x 41' slot 15' x 15' 2 Pulls 25 1.25" 6 x 37 3,000' 5 50 @ 24' 50 @ 24' 50 @ 24' 43 @ 28' Y 1,500 WCI 30' x 30' 4,500 NOV 1.63" 37.5" 100 N Varco IR TW-61 National PS2 750A N/A Rowan TBD TBD TBD TBD TBD TBD 3 National 12-P-160 5,000 1,467 incl. incl. 10,880 3 1 1 10 3" 3 Cameron 1 Hydril 45.3 13-5/8" 10M Flange 21.25" 12" CAD3600874BU2 CAD N

9 Ralph Coffman Letourneau 240-C 2009 USA N/A ABS 375' 15' 20' 491' Y 56' 35,000' 3Q/14 Egypt 12,900 4.5 108 228' 220' 19' S-61N or S-92 N Y 5,050 4,711 N/A 80' 80' x 30' 2 Pulls 25 1.25" 6 x 36 Galy 2,500' 6 56 @ 45' 56 @ 45' 56 @ 45' Y 2,500 Loadmaster 36' x 36' 4,500 LEWCO 2" 49.5" 250 Y NOV IR30120 LTI DDTD-750-V2 Loadmaster MRS 12 MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-3000 7,500 4,005 incl. 529 13,820 5 1 1 15 3" 4 Cameron 1 Hydril 210 18-3/4" 15M Flange 30" 12" EH/PLC Cameron Y

6 Rowan EXL I Super 116E 2010 USA N/A ABS 350' 33' 20' 477' Y 46' 35,000' 3Q/13 Indonesia 10,750 4.5 120 228' 206' 17' S-61N N Y 3,977 3,250 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 56 @ 45' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 1 Hydril 210 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL II Super 116E 2010 USA N/A ABS 380' 63' 20' 511' Y 46' 35,000' 1Q/14 Trinidad 10,750 4.5 120 228' 206' 17' S-61N N Y 3,348 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 6 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 1 Hydril 210 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL III Super 116E 2010 USA N/A ABS 350' 33' 20' 477' Y 46' 35,000' 3Q/13 GoM 10,750 4.5 120 228' 206' 17' S-61N N Y 3,825 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LeTourneau 1-3/4" 49.5" 100 Y NOV IR30120 LTI DDTD-750-V2 N/A MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-2215 7,500 3,668 incl. 934 13,800 5 1 1 15 3" 4 Cameron 1 Hydril 135 13-5/8" 15M Flange 36-1/2" 16" EH/PLC Cameron Y

6 Rowan EXL IV Super 116E 2011 USA N/A ABS 320' 444' Y 35,000' 4Q/14 Malaysia 120 228' 206' 17' S-61N N Y 3,348 3,300 N/A 70' 70' x 30' 4 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 56 @ 45' 56 @ 45' 48.5 @ 25' Y 2,000 Loadmaster 32' x 35' 3,000 LEWCO 1-3/4" 49.5" 100 Y NOV IR30121 LTI DDTD-750-V3 N/A MD Totco TBD TBD TBD TBD TBD TBD 4 LTI W-2216 7,500 3,668 incl. 934 13,800 4 1 1 15 3" 4 Cameron 2 Hydril 136 13-5/8" 15M Flange 36-1/3" 17" EH/PLC Cameron Y

9 Rowan Mississippi Letourneau 240-C 2008 USA N/A ABS 375' 15' 15' 491' Y 56' 35,000' 2Q/14 Saudi Arabia 12,900 4.5 108 228' 220' 19' S-61N or S-92 N Y 4,202 4,835 N/A 80' 80' x 30' 2 Pulls 25 1.25" IWRC 6 x 36 2,500' N/A 2.24 65 @ 45' 65 @ 45' 67 @ 45' Y 2,500 Loadmaster 36' x 36' 4,500 LEWCO 2" 49.5" 250 Y NOV IR30120 LTI DDTD-750-V2 Loadmaster MRS 12 MD Totco TBD TBD TBD TBD TBD TBD 3 LTI W-3000 7,500 4,100 incl. 529 13,820 5 1 1 15 3" 4 Cameron 1 Hydril 210 18-3/4" 15M Flange 30" 12" EH/PLC Cameron Y

14 Rowan Stavanger KFELS N-Class 2011 Singapore 2011 DNV 400' 10' 30' 568' Y 66' 35,000' 1Q/14 North Sea 13,460 4.5 120 264' 289' 24' S-61N or S-92 N Y 5,123 8373-17780 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30' 50 @ 29' Y 2,200 NOV 40' x 40' 4,600 NOV 2" 49.5" 350 N Wellquip JiM20 NOV HPS 03-1000 NOV HydraRacker III NOV TBD TBD TBD TBD TBD TBD 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 NOV 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

14 Rowan Viking KFELS N-Class 2010 Singapore N/A DNV 400' 10' 30' 568' Y 66' 35,000' 2Q/14 North Sea 13,460 4.5 120 264' 289' 21' S-61N or S-92 N Y 5,123 8373-17780 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30 50 @ 29' Y 2,200 NOV 40' x 40' 4,600 NOV 2" 49.5" 350 N Wellquip JiM20 NOV HPS 03-1000 NOV HydraRacker III NOV TBD TBD TBD TBD TBD TBD 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 Shaffer 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

14 Rowan Norway KFELS N-Class 2011 Singapore N/A DNV 400' 10' 30' 568' Y 66' 35,000' 1Q/17 North Sea 13,460 4.5 120 264' 289' 21' S-61N or S-92 N Y 5,123 8,373 N/A 75' 75' x 24' 4 Pulls 16.8 2" IWRC 3,281' N/A 8.4 55 @ 29' 50 @ 30' 50 @ 29' Y 2,200 TTS 40' x 40' 4,600 TTS 2" 49.5" 350 N Wellquip JiM20 TTS ITAG TTS SmartRacker III-P TTS 3 NOV 14-P-120 7,500 7,221 incl. 4,916 15,885 5 15 3" 4 Shaffer 1 Shaffer 220 18-3/4" 15M Flange 44" 16" Koomey Shaffer Y

SEADRILL Contact: Rolf Mathiesen, Lokkeveien 107, 4007 Stavanger, Norway; Phone: +47 51 30 99 69; email: rolf.mathiesen@seadrill.com; website: www.seadrill.com

15 West Leda Baker Marine Pacific 2010 Singapore ABS 375' 15' 55' 506' Y 55' 30,000' Apr-14 Malaysia 10,750 4-4.5 120 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 25 55 55 N/A N/A Y 1,500 Loadmaster 35' x 35' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y Varco AR-3200 Varco TDS-8SA NOV Amphion System - 20,000' - - - - 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - - - - - 15 3" 2 CIW 1 CIW 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

15 West Triton Baker Marine Pacific 2008 Singapore ABS 375' 15' 55' 506' Y 55.5' 30,000' Oct 2013 Arabian Gulf 10,750 4-4.5 115 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 25 45 55 N/A N/A Y 1,500 Bailys 35' x 35' 4,050 Dreco 1.63" 49.5" 9 Y Hydralift PD-MPT Hydralift HPS-750 NOV/FB-F NOV Hitec C 30,000' 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - 1 1 - - 15 3" 2 Hydril 1 Hydril 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

15 West Cressida Baker Marine Pacific 2009 Singapore ABS 375' 15' 55' 506' Y 55' 30,000' Apr-14 Thailand 10,750 4-4.5 120 237' 224' 19' S61 N N N 3,000 3,749 N/A 70' 70' x 30' 4 34.94 1.50" 6 x 36 EIPS 2,500' N/A 7.5 38 45 17 N/A N/A Y 1,500 NOV 35' x 35' 3,000 NOV D3000 AC 1.63" 49.5" 250 Y NOV Hydratong NOV HPS-750-E-AC Hydralift HPS750 EAC NOV Cyberbase - 30,000' 20,000' - 10,000' - 3 National 14P-220 7,500 4100 2036 2,584 11,654 4 - 1 1 - - 15 3" 2 CIW 1 Shaffer 176 18-3/4" Fl./studded 49.5" 12" Hydraulic Hydril Y

12 West Ariel KFELS ‘B’ class 2008 Singapore ABS 400' 25' 55' 517' Y 47' 30,000' Jan-13 Vietnam 10,750 4-4.5 112 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 28.1 1.50" 6 x 36 EIPS 2,500' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 36' x 36' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y NOV AR 3200 M Varco TDS-8SA PH 100 V-ICIS 2.1 - 20,000' - - - 10,000' 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - - 1 - - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

12 West Callisto KFELS ‘B’ class 2010 Singapore ABS 400' 25' 55' 517' Y 47' 30,000' Nov-15 Saudi Arabia 10,750 4-4.5 112 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 28.1 1.50" 6 x 36 EIPS 2,500' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 36' x 36' 3,000 Varco ADS-10T 1.63" 49.5" 250 Y Varco AR-3200CM Varco TDS-8SA PH-100 Amphion System - 20,000' - - - - 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - 1 1 1 - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

12 West Prospero KFELS ‘B’ class 2007 Singapore ABS 400' 25' 55' 514' Y 47' 30,000' july 2013 Vietnam 10,750 4-4.5 110 234' 208' 16' S-61N / S-92 N N 2,250 3,750 N/A 70' 70' x 30' 4 40 1.50" 6 x 36 EIPS 2,600' N/A 5.5 50 50 50 N/A N/A Y 1,500 WCI 32' x 35' 3,000 Varco ADS-10T 1.75" 49.5" 250 Y Varco AR-3200CM Varco TDS-8SA VCR V-ICIS 2.1 - 20,000' - - - - 3 Lewco W-2215 7,500 3496.6 2180 1,517 11,100 5 - - 1 - - 15 3" 2 Cameron 1 Cameron 192 18-3/4" Fl./studded 49.5" 14" Hydraulic Cameron Y

23 West Castor F & G JU 2000 E 2013 Singapore ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS-1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

23 West Oberon F & G JU 2000 E 2013 China ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS- 1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

23 West Telesto F & G JU 2000 E 2013 China ABS 400' 15' TBA 547' Y 59' 30,000' Available Under Construction 10,750 4-4.5 140 231' 249' TBA S61 N N N TBA 4,151 N/A 70' 70' x 30' 4 44 1.50" 6 x 36 EIPS 2,998' N/A 8.26 75 75 75 N/A N/A Y 2,000 TBA 36' x 36' 3,000 SSGD-1000 AC TBA 49.5" 407 Y Nov MPT-200 Hydr NOV TDS-1000 PH-100 TBA - TBA - - - - 3 NOV-14-P-220 7,500 TBA TBA TBA 17,657 4 TBA TBA TBA TBA TBA 15 3-1/16" 2 Shaffer TBA TBA TBA 18-3/4" Fl./studded 49.5" 12" TBA TBA Y

20 West Epsilon MSC CJ62 120S 1993 Singapore 2002 DNV 400' N/A N/A 575' Y 58' 30,000' Dec 2016 North Sea 8880 4-4.5 115 237' 224' 19' S-61 Y Y 1,000 3,800 N/A 60' 15' x 15' 4 50 2.125" IMRC 2,000' 8 55 @ 36' 55 @ 36' 37 @ 31' Y 1,650 CE-LTV 40' x 40' 3,000 Continental Emsco C3 1,75" 49.5" 240 N Varco PHM-3i Varco TDS-6S Varco PHM3i NOV 17,000' 3,000' 3 CE FC2200 7,500 5,346 incl. 3,522 19,040 4 TBA TBA TBA TBA 2 15 3" 4 Hydril 1 Hydril 185 Flange 36.5" 12" Hydraulic MH-Koomey Y

21 West Elara MSC CJ 70 X150A 2011 Singapore DNV 492' N/A 32' 672' N 75' 40,000' Apr-17 North Sea 19000 4-4,5 120 290' 318' 22' S-61 / S-92 N Y TBA 6,600 N/A 80' 100' x30' 4 27.5 2.2" 6 x 36 WS IWRL 3,379' N/A 5.6 80 @ 25' 80 @ 25' 80 @ 25' 5 @ 9' Y 2,200 TTS / Holandia 48' x 40' 4,600 Sense Ultra Hoist 2" 49.5" 441 N Sense Jim 20 Sense / 1000 Ton Sense Smar racker Sense On Track System NA NA NA NA 3 Wirth TPK 7,500 1302 2201 5,592 19,176 4 4 2 2 2 NA 15 3" 4 Hydril 1 Hydril 180 NT-2 Vetgo 49.5" 16" Hydraulic Hydril Y

5 Offshore Courageous LeTourneau Super 116C 2007 USA ABS 350' 25' 16' 477' Y 46' 30,000' Dec 2014 Malaysia 8,600 4-4.5 110 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 70' x 30' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 2" 50" 150 Y NOV 30120 NOV TDS-8SA None MDT - 20,000' - - - - 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 - 1 - 15 3-1/16" 2 Cameron 1 Shaffer 176 Flanged 30" 12" Hydraulic Shaffer Y

5 Offshore Resolute LeTourneau Super 116C 2008 USA ABS 350' 25' 16' 477' Y 46' 30,000' oct 2015 Arabian Gulf 8,600 4-4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 70' x 30' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 2" 50" 150 Y NOV 30120 NOV TDS-8SA None MDT - 20,000' - - - 6,600' 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 - 1 - 15 3-1/16" 2 Cameron 1 Shaffer 176 Flanged 30" 12" Hydraulic Shaffer Y

5 Offshore Defender LeTourneau Super 116C 2007 USA ABS 350' 25' 16' 477' Y 46' 30,000' june 2016 Brunei 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

5 Offshore Vigilant LeTourneau Super 116C 2008 USA ABS 350' 25' 16' 477' Y 46' 30,000' Oct 2013 Malaysia 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

5 Offshore Intrepid LeTourneau Super 116C 2009 USA ABS 350' 25' 16' 477' Y 46' 30,000' Nov-13 Arabian Gulf 10,750 4.5 102 243' 206' 16' S61 N N Y 1,750 3,500 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 32' 3,000 NOV 1.63" 49.5" 150 Y NOV 30120 NOV TDS-8SA None MDT Yes 3 LEWCO W-2214 7,500 1,875 416 1,204 11,200 5 Cascade 1 1 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

6 Offshore Freedom LeTourneau Super 116E 2009 UAE ABS 350' 25' 16,5' 477' Y 46' 30,000' May 2013 Arabian Gulf 10,750 4-4.5 105 243' 206' 16' S61 N N Y 2,146 3,757 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 35' 3,000 Lewco 1.63" 49.5" 150 Y NOV-ST-120 Letourneau DDTD 750 LTI/DDTD-750 TBD TBD TBD 3 LEWCO W-2214 7,500 3,334 1,000 1,000 12,250 5 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

6 Offshore Mischief LeTourneau Super 116E 2009 UAE ABS 350' 25' 16,5' 477' Y 46' 30,000' Aug-11 Brazil 10,750 4-4.5 105 243' 206' 16' S61 N N Y 2,146 3,757 N/A 70' 15' x 15' 4 25 1.50" IWRC 2,000' N/A 2.5 50 50 50 N/A N/A Y 1,500 Dreco 35' x 35' 3,000 Lewco 1.63" 49.5" 150 Y NOV-ST-120 Letourneau DDTD 750 LTI/DDTD-750 TBD TBD TBD 3 LEWCO W-2214 7,500 3,334 1,000 1,000 12,250 5 15 3-1/16" 2 Cameron 1 Shaffer 176 Flange 30" 12" Hyd Shaffer Y

SINO THARWA DRILLING CO. Contact: Ali Salem Mubarak, Chairman & Managing Director, 16 W/6 El Nasr St., New Maadi, Cairo, Egypt; Tel: 20 2 2519 7226; Fax: 20 2 2519 5597; Email: asalem@sinotharwa.com.eg; Website: www.sinotharwa.com.eg

23 ST Bahari I F&G JU2000E 2011 China ABS 400' 10' 30,000' Egypt 120 N N 3,766 3,200 49.5" NOV TDS-8SA 3 NOV 7,500

TRANSOCEAN CONTACT: Mark Monroe, P.O. Box 2765, Houston, Texas 77252-2765; Phone: (713) 232-7500; Fax: (713) 232-7880; Email: mark.monroe@deepwater.com; Website: www.deepwater.com

23 GSF Constellation I F&G JU 2000 2003 Singapore ABS 400' Site Spec Site Spec 548' N 59' 30,000' 1Q/'16 Indonesia 9,275 - 120 231' 250' 21' S61 N N Y 4,050 5,000 75' 75' x 30' 4 44 2" 6 x 36 EPIS/ IWRC 3,000' N 8.4 55.6 55.6 55.6 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N NOV IR-170 PSA NOV PS2 Star Racker NOV Cyberbase 20,000' 3 National 14-P-220 7,500 4,766 900 17,920 5 3 1 15 3.06" 4 Hydril 1 Hydril 167.1 Flange 49.5" 16" Hydraulic Hydril Y

23 GSF Constellation II F&G JU 2000 2004 Singapore ABS 400' Site Spec Site Spec 548' N 59' 30,000' 3Q/’15 Gabon 9,275 - 120 231' 250' 21' S61 N N Y 4,050 5,000 75' 75' x 30' 4 44 2" 6 x 36 EPIS/ IWRC 3,000' N 8.4 55.6 55.6 55.6 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N NOV IR-170 PSA NOV PS2 Star Racker NOV Cyberbase 15,000' 3 National 14-P-220 7,500 4,727 900 17,920 5 3 1 15 3.06" 4 Hydril 1 Hydril 167.1 Flange 49.5" 16" Hydraulic Hydril Y

22 GSF Galaxy I F&G L-780 Mod VI 1991 Singapore 2001 ABS 400' Site Spec Site Spec 560' N 60' 30,000' 3Q/'13 North Sea 10,000 4 120 244' 250' 22' S61 N* N Y 3,260 4,350 67' 67' x 30' 4 37 2" 6 x 36 IWRC 1,969' N 8.3 39.7 39.7 39.7 N 1,600 Brown 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco PHM 3i Varco TDS-4H Varco PHM3i Rigserve 15,000' 3 National 14-P-200 6,000 4,429 1,627 18,200 3 15 3.06" 4 Hydril 1 Hydril 150 NT 2 49.5" 16" Hydraulic Hydril Y

22 GSF Galaxy II F&G L-780 Mod VI 1998 Singapore ABS 400' Site Spec Site Spec 560' N 60' 30,000' 4Q/’14 North Sea 11,400 4 120 244' 250' 22' S61 N* Y Y 3,984 7,372 55' 55' x 30' 4 37 2" 6 x 36 IWRC 3,000' N 7.5 52 52 52 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco AR-3200 Varco TDS-4S Varco PRS3i MD/V-ICIS 15,000' 3 National 14-P-220 6,000 4,430 1,627 18,200 4 1 1 15 3.06" 4 Hydril 1 Hydril 130 BX 159 flange 49.5" 16" Hydraulic Koomey Y

22 GSF Galaxy III F&G L-780 Mod VI 1999 Singapore ABS 400' Site Spec Site Spec 560' N 60' 30,000' 2Q/’14 North Sea 11,400 4 120 244' 250' 22' S61 N* Y Y 3,435 6,000 80' 60' x 30' 4 37 2" 6 x 36 IWRC 2,500' N 8.3 39.7 39.7 39.7 Y 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N Varco AR-3200 Varco TDS-4S PRS3i MD Totco 20,000' 3 National 14-P-200 6,000 4,430 1,627 18,200 5 3 15 3.06" 4 Shaffer 1 Shaffer BX 165 flange 49.5" 16" Hydraulic Shaffer Y

17 Transocean Honor PPL Pacific Class 400 2012 Singapore ABS 400' Site Spec Site Spec 532' N 55' 30,000' 2Q/'15 Angola 10,750 - 150 236' 224' 19' S61 & S92 N Y 2,549 3,822 75' 75' x 30' 4 36 1.5" 6 x 36 EPIS/ IWRC 3,000' N 6.6 55.9 55.9 25.3 Y 1,500 Loadmaster 35' x 35' 3,000 NOV 1.63" 49.5" 225 Y NOV ST-120 NOV-TDS-8SA Loadmaster NOV Cyberbase 30,000' 20,000' 3 National 14-P-200 7,500 4,150 1,255 11,652 5 - - - - - 15 3" 4 Shaffer 1 Shaffer 18-3/4" Flange 49.5" 16" Hydraulic Shaffer

13 Transoean Siam Driller Keppel FELS Super B 2013 Singapore ABS 350' Site Spec Site Spec 486' N 35,000' 2Q/'16 Thailand 11,250 3.5 150 246' 226' 18' MI-172 & S-92 Y Y 2,750 4,600 63' 63' x 30' 4 30 1.5" 6 x 36 IWRC 2,500' N 5 50 50 50 Y 1,500 NOV 36' x 36' 4,500 NOV SSGD 750 1.75" 49.5" 300 Y Hawkjaws Jnr. NOV-TDS-8SA NOV Dreco NOV SDIS 15,000' 3 National 14-P-200 7,500 4,000 2,000 8,000 5 - - - - - 10 3" 4 Cameron 1 Hydril 13-5/8" Flange 49.5" 14" Hydraulic NOV

13 Transoean Andaman Keppel FELS Super B 2013 Singapore ABS 350' Site Spec Site Spec 486' N 35,000' 2Q/'18 Thailand 11,250 3.5 150 246' 226' 18' MI-172 & S-92 Y Y 2,750 4,600 63' 63' x 30' 4 30 1.5" 6 x 36 IWRC 2,500' N 5 50 50 50 Y 1,500 NOV 36' x 36' 4,500 NOV SSGD 750 1.75" 49.5" 300 Y Hawkjaws Jnr. NOV-TDS-8SA NOV Dreco NOV SDIS 15,000' 3 National 14-P-200 7,500 4,000 2,000 8,000 5 - - - - - 10 3" 4 Cameron 1 Hydril 13-5/8" Flange 49.5" 14" Hydraulic NOV

22 GSF Magellan F&G L-780 Mod V 1992 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 2Q/'13 North Sea 10,000 6 115 228' 222' 17' S61* Y Y 4,831 5,200 65' 65' x 30' 4 50 2" 6 x 38 RHO 2,200' N 8.3 44.6 44.6 44.6 N 1,600 Dreco 40' x 40' 3,000 National 1.75" 49.5" 300 N PHM 3i Varco TDS-4S PHM 3i DAQ 20,000' 3 National 14-P-200 7,500 3,167 2,243 17,400 4 - 15 3.06" 4 Hydril 1 Hydril 140 Flange 47.5" 16" Hydraulic Hydril Y

22 GSF Monarch F&G L-780 Mod V 1986 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 2Q/’15 North Sea 8,260 4 98 228' 222' 17' S61* N Y 3,707 3,707 52' 52' x 30' 4 44 2" 1770 IWRC 2,000' N 7.5 36 36 36 N 1,400 JA Paris 36' x 36' 3,000 Emsco 1.50" 49.5" 300 N Varco AR-3200 Varco TDS-4S Varco PRS 2 MD Totco 12,000' 3 Cont'l Emsco FB 1600 5,000 2,436 4,030 15,070 5 3 10 3.06" 4 Shaffer 1 Hydril 70 BX 159 flange 36.5" 16" Hydraulic Koomey Y

22 GSF Monitor F&G L-780 Mod V 1989 Singapore ABS 350' Site Spec Site Spec 496' N 60' 30,000' 4Q/'13 Nigeria 9,900 5 115 228' 222' 17' S61 N N Y 3,776 5,900 55' 55' x 30' 4 25 2" 4 x 25 IWRC 3,000' N 6.8 38.6 38.6 44 N 1,550 Dreco 50' x 50' 3,000 Emsco 1.63" 49.5" 300 N Varco AR-3200 Varco TDS-4H Varco PRS 2 Rigserve / WOM /ANA 14,000' 3 Cont'l Emsco FB 1600 5,000 3,230 911 15,048 5 - - - - - 15 3.06" 4 Cameron 1 Hydril Flange 8" 16" Hydraulic Hydril

VANTAGE DRILLING COMPANY CONTACT: Mike Derbyshire, #07-01 Pacific Tech Centre, 1 Jalan Kilang Timor, Singapore 159303, Tel: (65) 6577-0270; Email: mderbyshire@vantagedrilling.com; Website: www.vantagedrilling.com

16 Emerald Driller Baker Marine Pacific 375 2008 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 2Q/’15 Thailand 9,275 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,740 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 75 @ 25' 43 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Wirth 1.625" 49.5" 220 N AKMH MH-1898 Mk I AKS DDM-650-AC-1M-1S-1150 Loadmaster AKMH 10,000' 10,000' N/A N/A N/A N/A 3 Wirth TPK 2200 CL, 2200HP 7,500 4,376 bbls total 11,652 5 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Sapphire Driller Baker Marine Pacific 375 2009 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 2Q/'13 Cote d'Ivoire 10,750 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 45 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N T-Wrex Canrig 1275 AC Loadmaster Sense EDM 10,000' 15,000' N/A N/A N/A N/A 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Aquamarine Driller Baker Marine Pacific 375 2009 Singapore N/A ABS 375' 15' 30' 506' Y 55.5' 30,000' 4Q/'13 Malaysia 10,750 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 55 @ 25' 25 @ 20' Y 1,500 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N Rogers Oiltools Canrig 1275 AC Loadmaster Sense EDM 10,000' 15,000' N/A N/A N/A N/A 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

16 Topaz Driller Baker Marine Pacific 375 2009 Singapore 2011 ABS 375' 15' 30' 506' Y 55.5' 30,000' 3Q/'11 Indonesia 9,275 3 to 5 120 236' 224' 19.5' S-61N / S-92 N Y 2,495 3,750 N/A 75' 75' x 30' 4 35 1.50" EIPS/ IWRC 3,000' N/A 6.5 55 @ 25' 55 @ 25' 25 @ 20' Y 1,800 Loadmaster 35' x 35' 3000 Sense EDM 1.625" 49.5" 250 N T-Wrex Canrig 1275 AC Loadmaster Sense EDM 5,000' 20,000' N/A N/A N/A 10,000' 3 Eweco E-2200-15 7,500 4,150 bbls total 11,652 4 N 1 1 1 N 15 3.06" 4 Cameron 1 Cameron 178 18-3/4" Flange 27.5" ID 12" Hydraulic CAD Systems N

400'

400'

400'

400'

400'

400'

400'

400'

400'

400'

350'

350'

350'

350'

350'

350'

375'

425'

375'

375'

375'

375'

375'

375'

375'

375'

350'

350'

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350'

350'

350'

350'

400'

400'

492'

490'

350'

350'

350'

350'

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400'

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400'

400'

400'

400'

400'

375'

375'

375'

375'

375'

360'

390'

350'

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350'

350'

350'

350'

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350'

350'

350'

350'

350'

375'

375'

492'

492'

394'

2

LeTourneau Class 64

3

LeTourneau Class 84

4

LeTourneau 116C

5

LeTourneau Super 116C

6

LeTourneau Super 116-E

7

LeTourneau Gorilla Class

8

LeTourneau Super Gorilla

9

LeTourneau 240-C

10

KFELS A Class

11

KFELS Super A Class

12

KFELS B Class

13

KFELS Super B Class

1

LeTourneau Class 53

14

KFELS N Class

16

BMC-375 Jackup

17

BMC Pacific 400

18

GustoMSC CJ46

19

GustoMSC CJ50

20

GustoMSC CJ62-120S

21

GustoMSC CJ70-150MC

22

F&G L780

23

F&G JU2000

24

Hitachi-Zosen

25

CFEM-T-2005-C

15

BMC 350

Information Accuracy: Every attempt has been made to

locate all the deepwater Jack-up Rigs and contact worldwide

contractors. No contractor was intentionally excluded from the

survey. In some cases, a deepwater Jack-up Rig was not

included because information was not provided. we make no

guarantee that this list is all inclusive. we have also been

careful to summarize the capability and experience of each

contractor as best as possible, by acting as a neutral party

and integrator of information. we have collected the data

from contractor-supplied information, personal interviews,

websites, phone interviews, and

company brochures. Offshore Magazine

neither guarantees nor assumes

any responsibility or liability for any

reliance on the information presented

in this spreadsheet poster. ©2

01

3 O

ffsh

ore

POSTER

106prepared by: Offshore Magazine

PH

OTO

NU

MB

ER/R

IG T

YP

E

50 Years Building a Reputation in Marine and Offshore Construction.

Discover Sembcorp Marine. enquiries@sembcorpmarine.com.sg

T: +65 6858 6635 F: +65 6858 2884 E: email excelmarco.com@

www.excelmarco.com

Together We Excel

TURN-KEY SOLUTIONS PROVIDER FOR PROCESS AUTOMATION & SAFETY SYSTEMS GustoMSC is a leading design and engineering company for all

types of mobile offshore units: jack-ups, semi-submersibles and offshore

vessels. Our business approach is to deliver proprietary designs under

license and associated equipment like jacking systems, skidding systems

and offshore cranes to the market.

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60 Offshore July 2013 • www.offshore-mag.com

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

Wide-tow seismic survey sets

the pace for frontier exploration

Record-setting spread gives Shell data

from diffcult metocean conditions offshore South Africa

When it comes to surveying large ar-eas of frontier exploration acreage in limited windows of opportunity, seismic operators are required to think big and move fast. Dolphin

Geophysical took this approach to fresh ex-tremes in the Atlantic Ocean offshore South Africa, mobilizing the “world’s largest foating object” on behalf of client Shell.

Dolphin was contracted to survey un-touched acreage in an area renowned for diffcult weather conditions. The window of opportunity was slim and required a radical solution to meet the survey requirements.

Going to the extremesThe acreage in question is 150 to 360 km

(93 to 224 mi) off the western coastline of South Africa, in a region known as the Or-ange basin. Shell won the licence to a 37,000- sq km (14,286-sq mi) exploration parcel from the nation’s Minister of Mineral Resources early in 2012, initially focusing in on an 8,000-sq km (3,089-sq mi) tranche. Dolphin’s task was to perform a 3D marine seismic survey on this prospect.

The potential in the basin, with evidence of source rocks suggesting possibilities of signifcant oil and gas deposits, was clear. The conditions, however, were anything but.

The southern Atlantic is notorious for its treacherous waters, with huge swells and unpredictable weather potentially combining to create a “perfect storm” for seismic sur-veyors – threatening safe vessel operations and the integrity of the acquired data with unwanted noise.

To ensure the best possible results, Dol-phin was required to stick to a limited shoot-ing season during the most dependable con-ditions. This entailed capturing data for the entire 8,000-sq km area in four months.

On Oct. 25, 2012, Dolphin mobilized one of its fagship vessels, the Polar Duchess, off the

South African coast on behalf of Shell. The 2011 built, 107 m (557 ft) long, 7,689-ton vessel was outftted with a confguration of seismic equip-ment never before witnessed.

This “wide-tow” array boasted eight seismic streamers, each measuring 8 km (5 mi) long. Each streamer was separated by a distance of 200 m (656 ft), constituting a moving width of 1.4 km (0.87 mi) of equipment through the wa-ter. This means that the total area of the seis-mic receivers towed by the Duchess was 11.2 sq km (4.3 sq mi). This is an area equivalent to the combined surface area of three Vatican Cities, two Principalities of Monaco, and two Cities of London. Dolphin had created the world’s largest foating object.

Exploring the limitsBigger was better for this particular as-

signment, as it for many of the market’s cur-rent frontier tasks. Oil companies are now contending with increasingly short explora-tion licenses for larger and larger swaths of the seafoor, and so must act quickly when

dealing with frontier acreage opportunities. Governments are eager to exploit hydro-carbon resource potential, and everyone throughout the chain is keen to maximize the net present values of reserves.

Wide-tow 3D surveys are the best solu-tion for quick regional snapshots of frontier areas. The data is not as well sampled as it is with more conventional streamer separation distances – 75 to 100 m (246 to 328 ft) – and this needs to be taken into consideration. However, the wide-tow approach allows oil companies to screen, evaluate, and zoom in on areas with prospective opportunities. Once these are identifed, one option is for the 3D vessel to return to the areas of inter-est to interleave another survey on the origi-nal one. If the vessel has on-board process-ing and can produce a fast-track product, it may not have to leave the area before the second survey.

This could be done with a boat carrying the same confguration of equipment, but surveying the prospect area 100 m either

Phil SuterGareth Williams

Dolphin Geophysical

Seismic vessel Polar Duchess conducted the survey offshore South Africa.

1307off_60 60 6/28/13 2:17 PM

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62 Offshore July 2013 • www.offshore-mag.com

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

side of the initial crosslines. This gives a fully upgraded 3D picture and provides an understanding of potential reservoir details at a fraction of the cost of undertaking a full 3D survey of the entire block.

Traditionally, this job may have fallen to a 2D vessel before a 3D survey was ordered in over specifc features. A wide-tow 3D acqui-sition provides a clearer indication of hydro-carbon evidence than a 2D survey, and also gives the option of speedy interleaving for a full-resolution 3D image. In frontier acre-age with marginal conditions, conducting an initial 2D survey would also eat up one shooting season, meaning an oil company would have to wait another year to obtain 3D results.

Putting wide tow to the test

The principal challenge to a wide tow is the weight of the array and the strain of navi-gating it through the water. A vessel needs suffcient bollard pull to safely tow such a load. In the case of the Shell task, the total drag of the towed array on the Duchess was around 90 metric tons (99 tons). Many ves-sels have the requisite bollard pull to handle this, but in frontier territories, with marginal or diffcult weather conditions, it can be dan-gerous to push too close to a vessel’s operat-ing limits.

A vessel must have the fexibility needed to tackle unforeseen circumstances, with plenty of power in reserve to handle diff-cult currents or swells, as was experienced in the northern section of the Orange basin.

The Polar Duchess was chosen based on this safety frst approach. She has total propul-sion of two 7,100 kW (shaft power) engines and a bollard pull capacity of 210 metric tons (213.5 tons). This means that despite the size and weight of the wide-tow array, she was operating at just less than 50% total en-gine capacity.

The challenge of processingA major processing task awaits the data

acquired in a wide-tow confguration. Having the streamers spaced 200 m apart

is ideal to cover large areas, but produces a different data density compared to stream-ers positioned more tightly. This can create issues.

When a survey is not as well sampled it can lead to lost resolution. Steeper depths and complex features can be aliased and hence badly imaged. There is a real need for advanced interpolation algorithms to com-bat this and get the best possible imaging results – real processing power is a must.

It is important to know the limitations of wide tow. It provides a fantastic regional snap-shot, signifcantly more so than 2D, and is very quick and cost effective, but cutting edge processing capacity is required to make the most of it, before interleaving surveys over key features to build the complete picture.

In the case of the Orange basin, Dolphin produced a fasttrack cube on the vessel that was delivered within 28 days of completion of the acquisition, and now Shell is in the driver’s seat for the fnal data processing.

Shell has entrusted the assignment to its processing experts in Houston, where the very latest interpretation technology is be-ing exploited.

Increasing demandDolphin and Shell completed the acquisi-

tion in late February 2013. Stuart McGeoch, Shell’s Regional Ventures

Exploration manager, Sub-Saharan Africa, said that despite the remote nature of the area and the challenging metocean conditions, the sur-vey was executed safely, effciently, and with low downtime, and provided quality data. The teamwork between the two parties helped fa-cilitate this accomplishment.

More and more oil companies will be in-terested in the use of wide-tow surveys now that Shell has set a precedent with wide tows in both Greenland and South Africa.

The potential of “sparse 3D” to provide rapid and cost-effective appraisals of areas previously untouched by any kind of explor-atory data acquisition are demonstrated. As more and more deepwater acreage is re-leased, demand will intensify.

The Orange basin wide tow may have been a frst of its kind, but it defnitely will not be the last. •

About the authorsPhil Suter is VP of Marketing and Sales for Dolphin

Geophysical. Gareth Williams, Ph.D., is Dolphin’s chief

geophysicist.

Shell has been awarded an explora-

tion right in the Orange basin deepwater

area, off South Africa’s western coast.

The exploration area covers just

over 37,000 sq km (14,286 sq mi) and

is approximately 150 to 350 km (93

to 218 mi) offshore in water depths

between 500 and 3,500 m (1,640 and

11,480 ft). The block’s southern edge is

approximately in line with the town of

Saldahna and the northern edge just

south of Kleinzee. It borders Namibian

waters to the north.

There has been limited exploration

activity in the area.

Shell’s exploration work program is

committed to conducting seismic work

in the block allocated within the first

three years of the license.

The large, under-explored basin

has evidence of source rocks with the

potential for significant oil and gas

discoveries. The deepwater portion,

including the block awarded to Shell, is

as yet largely unexplored and it may be

some years before the real potential is

established.

Shell on the Orange basin deepwater license

1307off_62 62 6/28/13 2:17 PM

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Tender-assist semi supports spars, TLPs

in wider deepwater regions

Singapore-based Energy Drilling has ordered three newbuild tender rigs from COSCO Shipyard in Guangdong, China. Two are barges, while the third – EDrill-3 – will be the frst tender-assist semisubmersible based on GustoMSC’s OCEAN400-TD design. Energy Drilling is actively marketing

the unit throughout Asia and West Africa and is confdent frm con-tracts will be in place before the rigs are delivered.

The company aims to be the leading provider of tender drilling solutions. Its management team, comprised of ex-employees from Seadrill and Smedvig Tender Assist Drilling Division, previously developed specifcations and managed construction for over 10 new tender rigs and has operated these for various major oil com-panies. Currently 80% of the world’s tender rig feet operates in Southeast Asia, with growing interest off West Africa. However, the OCEAN400-TD offers numerous technical and cost advantages that would also suit harsher metocean conditions and deepwater opera-tions in the Gulf of Mexico, Brazil and Western Australia.

Energy Drilling claims EDrill-3, due to be delivered in June 2015, will be the world’s most modern tender-assist production drilling semi, with the highest variable deck load and the largest air gap, 10 m (32.8 ft). COSCO, the sole specialist in tender rig construction in China, is using MagaWay Engineering to provide the derrick equip-ment set.

The package is designed to drill on wellhead platform elevations over 130 ft (40 m) above main mean sea level, and comes equipped with a bootstrap quad-mast rated for a 1-million lbs hook load and 1.2 million lbs setback load. EDrill-3 will be able to support batch drilling with offine casing, tubing and drillpipe stand building, and a rated drilling depth of 9,000 m (29,527 ft).

Improved motionsAccording to Jelmer de Weerd, project manager for Gusto MSC,

“historically, tender-assist drilling was performed on jacket struc-tures in waters too deep for a jackup rig. Now these units can work over fxed platforms or in deeper water alongside spars, TLPs and compliant towers.”

For deepwater operations, de Weerd explains, “the main driver is the weight difference – with tender-assist drilling, only the derrick and solids control unit are located on the TLP or spar, and these have a total dry and wet weight of around 1,000 metric tons (1,102 tons) maximum. For a full-size drilling package on a TLP or spar, the total dry/wet weight is close to 6,000 mt (6,614 t) – that means you have to design the platforms to be larger in order to support the ad-ditional weight. Tender-assist development drilling is cost effective in deeper waters using dry trees as opposed to subsea completions, conventional drilling semis, or drillships.”

The Ocean400-TD is a deep-draft, column-stabilized unit, but with only four columns. This provides better motions than six-column tender-assist semis, de Weerd said, and therefore improved uptime in rougher seas. “That was the main reason Energy Drilling selected this concept. It is not intended for operations in conventional severe environments, but is suited to handle severe weather presented by sub-tropical monsoons and cyclones.”

With the four-column design, the motions are the same in all di-rections, de Weerd notes. “With a six-column tender-assist semi,

due to the center column and smaller beam the roll motions are worse, resulting in lower operability fgures. The estimated gain for the OCEAN400-TD for long-term operations offshore Brazil is over 15% more workable days.”

EDrill-3 will have an overall length of 101 m (331 ft), and a 3,250-sq m (34,983-sq ft) main deck area, 10% greater than conventional semis, de Weerd said. Its operating displacement will be in the range of 26,800-31,100 mt (29,542-34,282 t), with an operating draft of 13-18 m (42.6-59 ft), and a transit draft of 7.2 m (23.6 ft) during towing moves. Variable operating load is 4,000 mt (4,409 t), well above the 2,000-3,600-mt (2,204-3,968-t) range of typical tender-assist rigs, he added. The new rig will not be equipped with thrusters or dynamic positioning capability. Its main power source will be six Caterpillar 3516C HD DITA diesel engines providing total output of 9.18 MW.

Mooring optionsOCEAN400-TD is designed to operate in water depths of 90-350

m (295-1,148 ft) using its self-contained eight-point mooring system, deployed via traction winches, or with a pre-laid mooring spread in deeper waters up to 2,000 m (6,562 ft). In shallower locations, the self-contained moorings are attached to high holding power 12-mt (13-t) Vryhof Stevpris anchors, with no piggyback retrieval lines re-quired. This reduces the time needed for an anchor handling vessel.

Connection to a TLP or spar is achieved using a 100-m (328-ft) long hawser. “The basic idea is to have a connection that is both fexible enough to allow both units to move (semi-independent), but at the same time limit the relative offset between the two units,” de Weerd explained. “Without the hawser system, there would be a risk of collision between the two free-foating bodies. This arrange-ment provides just enough fexibility to reduce motions.”

If a hurricane or typhoon approaches, he adds, “disconnection and withdrawal of the OCEAN400-TD is even more straightforward than with conventional semis, as only the fexible mud and electri-cal lines and gangway need to be disconnected. The unit will then change location to Stand-off position at a larger offset from the plat-form. The drilling equipment including BOP remains on the plat-form with the well secured and shut-in.” •

Jeremy BeckmanEditor, Europe

Artist’s impression of the OCEAN400-TD tender-assist semisubmersible.

64 Offshore July 2013 • www.offshore-mag.com

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

1307off_64 64 6/28/13 2:17 PM

OCTOBER 22-24, 2013 | THE WOODLANDS WATERWAY MARRIOTT HOTEL & CONVENTION CENTER | HOUSTON, TX USA

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1307off_65 65 6/28/13 2:17 PM

Like all aspects of ultra-deepwater explo-ration and production, mooring pres-ents extraordinary challenges, both to engineers and to the people who hold the purse strings. In many cases, par-

ticularly in the Gulf of Mexico, the cost of deploying a mooring system has caught up to or exceeded the price of the equipment that composes the mooring system itself.

The high cost of mooring system deploy-ment is behind some product development and research initiatives involving the Dutch company Lankhorst Ropes. Early this year, the company conducted feld trials for the Lanko-frst fber rope connector offshore Norway. The connector, developed in collaboration with Lankhorst Ropes Offshore Division worldwide agent Offspring International and mooring connector manufacturer First Subsea, was in-troduced in 2009; since then, it has been exten-sively tested at the Lankhorst Ropes facility and improvements have been made to the design accordingly, says David Owen, a spokesman for the company. “After that, it has been a case of waiting for a convenient opportunity to take it offshore for testing,” he says.

The Norway tests demonstrated that the Lankofrst connector could be assembled in 15 minutes, a time savings of at least one hour over traditional shackles, Lankhorst main-tains. The device can be assembled by two people, rather than the three people usually required for a shackle connection.

The company says the connector, made of forged steel, is smaller, lighter and stronger than plate links and thimbles, and can be used for all types of fber rope mooring connections. The device uses a sub-connector “donut” inte-grated into the rope termination during manu-facture, rather than a large spliced soft eye normally used with H-link and shackle con-nections. The offshore trials involved a clam design connection; snap and link connection options for the Lankofrst are in development.

As installation water depths increase, the number of connectors per mooring line go up, highlighting the importance of safely ac-celerating installation operations.

“It’s part of a mooring philosophy called ‘lean’ installation, which, like lean manufac-ture, is designed to reduce waste and improve

quality,” Owen says. “In this case, ‘waste’ is the excess time needed to make up traditional con-nectors. At the moment, lean installation as a concept includes the Lankofrst and First Sub-sea’s Ballgrab subsea mooring connector.”

First Subsea is providing 16 Ballgrab con-nectors for Chevron’s Jack/St. Malo project in

water depths of 2,133 m (7,042 ft) in the GoM. The connectors will be attached to polyester mooring lines in a 4 x 4 arrangement.

Another element of the lean installation philosophy involves a new mooring method developed by Lankhorst and Offspring In-ternational.

“Essentially, it’s aimed at reducing the need for excessive pre-tensioning of the mooring line, which is expensive and requires special-ist vessels,” Owen says. “Moreover, as lines get longer, and heavier, it will be practically impossible to pre-tension to current values.”

Ropes are currently pre-tensioned to 40% minimum breaking strength, or MBS. An alter-native could involve pre-tensioning to 30% MBS and allowing ocean conditions during a storm to provide the fnal line tensioning to 40%.

Lankhorst and Offspring International re-cently carried out tests at the Lankhorst Ropes Offshore Division facility in Portugal using a case of a turret moored FPSO. In a paper pre-sented at the Oceans ’13 conference in Bergen, Norway, last month, the companies maintain that the FPSO itself could be used to provide the pre-tensioning needed to install mooring lines by deballasting and ballasting the ves-sel. By doing so, operators could eliminate the need for expensive installation vessels, other than for deployment and hookup.

The Portugal factory last April rolled out the frst mooring lines made from an ultra-low-creep synthetic rope developed through research conducted by Lankhorst and DSM and based on Lankhorst’s Gama 98 rope con-struction. The lines incorporate DSM’s latest high modulus polyethylene (HMPE) fber for permanent moorings, named Dyneema Max Technology. •

Russell McCulleySenior Technical Editor

GE’s Inovelis thruster. (Image courtesy GE)

GE Power Conversion has introduced a podded thruster that the company says will dramatically cut fuel con-sumption while offering enhanced performance. The Inovelis thruster incorporates pump jet technology, with fixed stator vanes and a nozzle that work together to guide the water across the impeller blades, while maintaining the maneuverability and fuel economy of a podded thruster, GE says. The company calls the system “the marine equivalent of a jet engine” that could provide enough fuel efficiency to allow future offshore vessels to be designed with reduced capacity power systems, saving weight and space onboard.

GE Power Conversion also an-nounced a contract with Eastern Ship-building Group to supply integrated diesel-electric power, propulsion, and vessel control systems for two multi-purpose supply vessels. The DP-2 vessels will be operated by Hornbeck Offshore Services.

Research aims to rein

in mooring installation costs

Offspring International and First Subsea com-

pleted the first field tests of the Lankofirst fiber

rope connector for deepwater moorings offshore

Norway. (Photo courtesy Lankhorst Ropes)

66 Offshore July 2013 • www.offshore-mag.com

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

1307off_66 66 6/28/13 2:17 PM

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68 Offshore July 2013 • www.offshore-mag.com

ENGINEERING, CONSTRUCTION, & INSTALLATION

For much of this year, the Kiewit Off-shore Services fabrication yard in In-gleside, Texas, has resembled a small city in itself, with thousands of engi-neers and craftspeople onsite preparing

structures for deployment in the deepwater Gulf of Mexico.

Early this summer, four of those projects fanked the shore of Corpus Christi Bay, forming an industrial skyline visible from miles away: Shell’s Olympus TLP, bound for the Mars feld; Anadarko’s Lucius spar; and a pair of semisubmersibles headed for the Chevron-operated Jack/St. Malo and Big Foot developments. All four hulls arrived at the yard this year from shipyards overseas: Olympus and Jack/St. Malo from Samsung Heavy Industries in Korea; Bigfoot from Ko-rea’s Daewoo Shipbuilding and Marine En-gineering; and Lucius from Technip’s facility in Pori, Finland.

While global shipyard output took a big hit with the recent fnancial crisis, the industry appears to be regaining momentum, largely driven by the oil and gas business. A recent analysis by the Denmark-based shipping as-sociation BIMCO described a “soft landing” for the shipyard industry after a wave of order cancellations, delays, and postponements put the brakes on output. Comparing data from December 2011 and March 2013, BIMCO noted a “transition from recent years’ record high shipyard output to a more sustainable level of output…representing a remarkable turn for the shipyard industry.”

While work on merchant vessels like dry bulk, tanker, and container ships continues to languish, the report said, shipyards are shifting focus to offshore support vessels and other oilfeld-related orders, including FPSOs, drillships, and platform supply ves-sels.

“Moreover, there is also a clear trend in sizing up and focus on larger ship types for the new orders placed in the offshore seg-ment,” BIMCO said, noting that the amount of shipyard capacity dedicated to FPSOs and FSOs, measured in compensated gross tonnage (CGT), rose 83% during the period

under examination, and was up 75% for drill-ships. “The combined force of FPSO/FSO and drilling ships is representing 72% of the offshore orderbook today, up from 51% in December 2011,” the report said. “In addition to this the offshore orderbook also holds the longest lead into the future with a bunch of Brazilian drilling ships due for delivery in the fve years leading up to 2021.”

Overcapacity will continue to be an issue for a number of years, but orders from the offshore oil industry will provide a cushion as yards adjust to a lower but steadier level of demand, said BIMCO chief shipping ana-lyst, Peter Sand. “Looking a bit ahead, the shipyard industry will probably settle in at a solid level of demand in the 30+ million CGT region with positive growth rates going for-ward,” he commented. “As the world feet as such is projected to be almost 20% larger seven years on from now, the need for feet renewal, feet repair, demolition, or the like will be strong, keeping the shipyards busy once again.”

Despite the threat of overcapacity, ship-yards and fabrication yards continue to ex-

pand to meet offshore oil and gas industry demand. Triyards will launch a new 400,000-sq ft (37,161-sq m) shipyard in Singapore by the end of 2013, with a focus on high-spec jackups. A subsidiary of Ezra Holdings, which also controls vessel operator EMAS AMC, Triyards has two shipbuilding and fabrication facilities in Vietnam and a fabri-cation yard in Houston.

Wison Offshore & Marine, which oper-ates a 640,000 sq m (6.89 million sq ft) ship-yard in Nantong, China, is building a second yard in the Zhoushan area. The new yard, scheduled to open by the end of 2013, will be roughly twice as big as the Nantong facility.

“Momentum has picked up again, and now the oil and gas market is hot,” says Tor-Ivar Guttulsrod, vice president for LNG sales at Wison O&M.

The company last year delivered the CX-

15, the frst buoyant tower drilling and pro-duction platform, to BPZ Energy. The unit was installed at the Corvina feld offshore Peru. Wison also announced a contract with Exmar for a foating LNG liquefaction, re-gasifcation, and storage system to be used

Russell McCulleySenior Technical Editor

The Metalships yard in Vigo, Spain, recently delivered the Deep Orient OSV to Technip and is work-

ing on a newbuild pipelay vessel for McDermott, similar to the North Ocean 105, delivered to McDer-

mott last year. The North Ocean 108 is scheduled for delivery 3Q 2014. (Photo courtesy Metalships)

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“We’re looking at some FPSO projects and more buoyant tower projects, modular construction, and LNG,” Guttulsrod says. “I think there’s going to be a lot of work for us, growing these small- to medium-scale foat-ing LNG projects.”

Wison completed the BPZ Energy project in a little under a year by using subcontrac-tors to fabricate the buoyant tower’s cylin-ders while other work was under way at the Nantong yard.

“What we did on that project was pretty typical of what takes place in the industry today,” says Wison O&M construction man-ager, Beau Toll. Once the investment deci-sion has been made for high-capital projects, operators look for short development times to hasten the return on investment, he says. “By using multiple vendors to make sub-components, we found a way to speed the process up. That’s a lot of what’s happening in the industry today: where capacities are too great, they’re starting to get subcontrac-tors to produce smaller pieces that they then take in and assemble as modules.”

Coordinating various engineering and construction teams can be a challenge, Toll says, but the modular approach has acceler-

ated completion times and helped builders successfully manage several large projects at once. Automation has also played a major role in shipbuilding and fabrication effcien-cy, as well as improved crane capacity and more specialization among skilled crafts-people.

“You’re always striving to hit the Holy Grail: to produce projects on time, produce them safely, with no one getting hurt, and produce them so that good quality comes out of it, at a fair cost,” he says. “It takes a lot of time to be able to plan multiple, simulta-neous jobs in a fabrication facility, and keep them all fowing while making best use of your assets and your space. It’s a full-time challenge.” •

Wison Offshore & Marine is building a second fabrication facility in China near Zhoushan, scheduled to open in late 2013. The company’s Nantong yard

began operations in 2006. (Photo courtesy Wison O&M)

1307off_69 69 6/28/13 2:17 PM

70 Offshore July 2013 • www.offshore-mag.com

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

Technology trends seek to reduce

the cost of subsea well interventions

System overcomes lack of wellhead standardization

A great deal of engineering expertise is being applied these days to well in-tervention. Keeping wells producing is an admirable and necessary goal. However, it is quite probable that an

equal amount of engineering time is being spent on postponing interventions for as long as possible. This is particularly true in the case of deepwater wells.

Intervention decision

In deepwater areas, the cost of well inter-vention is a formidable barrier. A single in-tervention can cost many millions of dollars, and in many cases, the result is uncertain. There are no guarantees. To lower the risk, operators are equipping deepwater wells with permanent gauges and other sensors that allow them to monitor production, look-ing out for the telltale signs that may indi-cate the onset of a condition warranting an intervention. Early warning signs often trig-ger non-intervention remedial action that

can forestall or eliminate the need for an intervention altogether.

These remedies may include injection of chemicals to mitigate impending fow assur-ance issues like waxing, sanding, or the ap-pearance of hydrates, asphaltenes, or scales. Intelligent well completions allow operators to change downhole fow controls to cut off premature infux of water or gas, without having to enter the well or disrupt other pro-duction.

The common thread of all actions taken to postpone intervention is access to ac-tionable information. This can come from many sources. Time lapse seismic (or 4D) requires no downhole sensors, but can

provide reservoir-wide information on fuid migration, fow streams, compartmentaliza-tion, and other conditions. This information has dual value. It can improve understand-ing of the reservoir production unit, often called reservoir characterization, so non-intervention solutions can be developed and implemented. In addition, the good news is that if an intervention cannot be avoided, the information can prove invaluable in design-ing the most cost-effective and long-lasting solutions to the issues threatening sustained production.

Sometimes, solutions are elegant in their simplicity. Production from a deepwater feld offshore West Africa was being boosted by an electric submersible pump (ESP). At the time, in that particular area, access to a workover rig had a minimum waiting time of six months, in the worst case 12 months. Re-alizing that an ESP failure could cut off pro-duction from one of its most prolifc wells for up to a year, the operator installed two ESPs

Dick Ghiselin

Contributing Editor

Subsea intervention is facilitated by the MARS multiple application reinjection system that enables multiple services to access subsea wells through a

universal “port” module that can attach itself to any spool tree. (Photo courtesy OneSubsea)

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72 Offshore July 2013 • www.offshore-mag.com

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

in tandem with an automatic switchover de-vice. The frst ESP was energized, initiating production of 6,000 b/d. The other ESP was dormant. Both pumps were instrumented so pump condition and well performance could be monitored at the feld production offce.

If the producing pump failed, it would au-tomatically switch to the backup pump with no production loss, and an alarm would be sent to the production offce who would initi-ate a bid for a workover unit. Thus, repairs could be performed with the only interrup-tion of production being the actual time to replace the bad pump. The investment in the dual pump system was negligible compared to the cost of lost production, had there been no backup. The added beneft of instrumen-tation enabled continuous analysis of down-hole conditions and proved invaluable in predicting problems before they became serious or before they inficted collateral damage to the well or reservoir.

Modern sand management practices and solutions help operators avoid interven-tions to mitigate sanding. Even this begins with making careful measurements of geo-mechanic parameters before investing in a potentially costly solution. The best solution is prevention. Often operating parameters can be maintained within safe limits to avoid sanding altogether or at least to postpone it. Modern sand control completions that incorporate infow control devices can allow sand-free production for many years, there-by reducing intervention costs. The cost of installing effective sand control hardware with the initial completion is almost always less than the cost of a later intervention, es-pecially in deepwater.

Unavoidable interventionsOften, despite the best efforts and maxi-

mum use of technology, an intervention must be performed to restore a well to full production. This has not escaped the atten-tion of creative engineers who are working to minimize the cost and risk associated with working over a well. When the well is in deepwater, the complexities of the chal-lenges grow exponentially.

The frst hurdle is lack of standardization of subsea wellheads. This complication has been recognized and addressed by engi-neers at OneSubsea, who have developed the MARS multiple application reinjection system, often referred-to as the “subsea USB” port because it can adapt any spool tree to couple with any intervention string. No matter what the ultimate objective of the intervention is, the MARS module can en-able entry of the well safely and effciently.

An advantage of a universal connection module is that it enables light well interven-tion services, the kind that can be deployed

by a relatively small vessel. This avoids hav-ing to contract a drilling or workover rig for an overhaul that does not require one. Experience has shown that the majority of interventions can be accomplished using wireline or coiled tubing conveyances as long as they can couple with the wellhead to maintain well control.

If a riser is required, it can be deployed from a deepwater subsea landing string, as offered by service companies. These of-fer full opening access to the wellbore with double barrier BOPs. These can perform full production tests, well cleanout or stimu-lation, chemical injection, or cased hole log-ging and perforating services. One neces-sary feature of deepwater landing strings is a remotely operated emergency shutdown system and getaway capability. One com-pany touts a system that can do a complete shutdown and getaway within 15 seconds.

Deepwater challenges Conditions peculiar to deepwater wells re-

quire special considerations and challenge engineering teams to the utmost of their abilities. Since deepwater wells are beyond the depths accessible by divers, all work must be performed by ROVs. This requires advance planning because any controllable module must be designed for ROV access, or must be confgured for electro-hydraulic control from the surface. In most cases, both capabilities are required to ensure a re-dundant safety system. In the event of an un-planned disconnection, automatic well shut-in is triggered and is energized by subsea accumulators inherent to the system.

Tubular conduits to the surface must be designed to mitigate vortex-induced vibra-tion (VIV), a destructive condition caused by subsea current fowing as little as 2-3 knots per hour. Typically, the effects of VIV can be minimized by attaching helical strakes to the outer surface of the pipe to break up the harmonics induced by the passing current.

Thermal shock can affect fuid fow from subsea wells. The temperature at the sea-bed can be just a few degrees from freezing so produced fuids leaving the reservoir at temperatures of several hundred degrees cool as they reach the seabed and then rise again as they near the surface. The range of temperatures through which the produced fuid must pass can precipitate solids like wax, hydrates, scale, or asphaltene that can clog production equipment and fowlines. This can create an intervention requirement in itself. Many companies deploy insulated or even heated fowlines to maintain produc-tion temperatures above the appearance threshold of these materials.

Phase changes in produced fuids can occur over time. As reservoir pressures de-

cline past the bubble point, gas can come out of solution and impair production. Not only does this require steps to deal with the gas, but it also requires the use of multi-phase fowmeter devices to measure the produc-tion. Seabed separators may be necessary. If ESPs are used, as they are in several re-cent deepwater completions, the ESPs must be equipped with advance gas handlers or else may experience premature failure that requires an intervention.

Similarly, water cut can advance over time. Water can be separated at the seabed and re-injected into a disposal aquifer, or produced to the surface for disposal. Too much water can require an intervention to identify the source of the water infux and to seal it off. Fortunately, this can often be ac-complished through tubing without having to kill the well.

Good news and bad newsIn a large sense, the world’s thirst for

abundant supplies of cheap, clean-burning energy continues to grow. The good news is that despite deepwater complexity, risks, challenges, the value of the prize exceeds the costs to produce it. Today, completions are being executed in waters approaching 10,000 ft (3,048 m). The cost of interventions has stimulated considerable innovation on the part of offshore producers and service companies to forestall or eliminate them.

At the same time, the bad news is the inev-itability of interventions occurring at some point during a well’s life. It is unreasonable to expect a well to produce untouched for its economic life. Nevertheless, this has encouraged continued research on ways to perform them more effciently, more safely, and more effectively by extending the time between the interventions.

A third front has developed as increasing demand and improvements in technology have turned attention to the 65% of resid-ual oil left behind following initial produc-tion. With vast deepwater reservoirs being discovered today, producers and service companies are investing in enhanced oil recovery technology whose goal is not just to improve recovery factors but to double them. The key to success in these areas is data. Operators must perform timely acqui-sition of data, not just for exploration and drilling, but also for completing and produc-ing the reservoirs more effectively. The key to enhanced oil recovery is a detailed under-standing of the reservoir in all its complex-ity, along with its production history.

Once this information is gathered, pro-cessed, and stored, the vehicle by which it will be applied is called “intervention.” And deepwater resources represent the greatest prize of all. •

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74 Offshore July 2013 • www.offshore-mag.com

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

Island Offshore finding new roles

for subsea LWI vessels

Island Offshore management’s decision to commit to light well intervention (LWI) in subsea wells a decade ago is proving far-sighted. The company now has three dedicated LWI vessels in full

employment, with more feld operators look-ing to reap the benefts of maintaining their subsea wells in good order.

The business is managed from Stavanger, Norway, by Island Offshore Subsea (IOSS), created in 2005 to look after the company’s LWI activities. Its frst work was for Chevron and Nexen in the UK sector.

However, its frst major contract came from Statoil, a pioneer in subsea well inter-vention to achieve increased recovery. The contract, which started in 2006, was for a frm six years with three optional one-year extensions. Of the three dedicated vessels employed on this program, the LWI ves-sels Island Frontier and Island Wellserver have been working full-time since 2006 and 2009, respectively, while Statoil makes regular use of Island Constructor under a separate frame agreement signed in 2011.

IOSS’ LWI engagement takes place through the Riserless Light Well Intervention (RLWI) Alliance – FMC provides the subsea lubrica-tor package and Aker Well Services the down-hole wireline operations. The alliance, formed in 2004, provides services ranging from scale milling, gauging and logging, and plug-setting to reperforations.

Statoil recently signed new contracts val-ued at NOK 3.3 billion ($570 million) to ex-tend its charter of Island Frontier and Island Wellserver from 2015 to 2020, with a further four years of options.

Another existing customer, BP, has award-ed a two-year extension on its contract with Is-land Constructor through 2015: the extension is valued at $86.5 million and includes further options. IOSS has been providing LWI servic-es on BP’s Foinaven, Schiehallion, and Loyal felds west of Shetland since 2009.

Other LWI clients are ConocoPhillips (in this case services include logging operations in sub-sea wells at the Ekofsk complex in the south-ern Norwegian North Sea); and Norske Shell, for the Draugen feld in the Norwegian Sea.

With about 5,500 subsea wells in service worldwide, IOSS managing director Robert Friedberg wonders why more oil companies do not show a greater interest in what he says

is now a proven means of increasing recovery. For example, with its large stock of subsea wells, Petrobras is a potential LWI customer, but has so far limited its activities to riser-based intervention.

When all costs are included, the day rate for a monohull works out at about 30-40% of the rate for a semisub, Friedberg says. And due to its DP-3 station-keeping capability, the intervention vessel moves on and off location much faster than an anchored rig. Such advantages warrant attention at a time when the rig market is particularly tight and Statoil, for example, has a heavy exploration and development drilling workload to keep its contracted drilling rig feet occupied.

P&A savingsIsland Frontier, Island Wellserver, and Island

Constructor were all designed specifcally as LWI vessels and are classed as mobile off-shore units, equipped to enter live wells. Is-land Frontier, with deadweight of 4,200 tons, was the frst, delivered in 2004, followed by Island Wellserver and Island Constructor in 2008. The latter two units are larger, at 8,500 dwt and 8,700 dwt, respectively.

All three have an amidships moonpool measur-ing between 7 and 8 sq m (75 and 86 sq ft). And

all are equipped with National Oilwell Varco der-ricks, rated for 70-ton loads in the case of Island Frontier and 100 tons for the other two vessels, and, as mentioned, DP-3 station-keeping systems. When the Ekofsk program was initiated, a study was performed to confrm that the vessel could operate safely on dynamic positioning in the shal-low water (79 m) depth.

Each vessel can perform around 20-25 op-erations a year, spending on average 15-16 days per job.

The LWI base has enabled expansion into other subsea well-related activities, including plugging and abandonment. Last year Island Wellserver, working for Statoil, performed part of the well abandonment on the fve Troll-Ose-berg Gas Injection (TOGI) subsea wells in the North Sea, killing the wells, setting plugs, and retrieving the vertical subsea trees. To fnish the operation, a semisubmersible rig pulled the tubing. In its review, Statoil reported that the IOSS scope was completed with very good results, taking only 62.5 days rather than the 80 planned.

Following the cessation of production on Statoil’s Glitne feld earlier this year, Island Wellserver will perform the same scope as on TOGI.

IOSS has also performed P&A operations

Nick TerdreContributing Editor

The light well intervention (LWI) vessel Island Frontier has been working continuously for Statoil

since 2006. (Photo courtesy IOSS)

1307off_74 74 6/28/13 2:18 PM

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76 Offshore July 2013 • www.offshore-mag.com

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

in the UK sector. For this type of work it has developed a specialized cement adaptor tool (CAT) which may be used in conjunction with the existing lubricator package to establish a cement plug barrier in the well. If the tubing is cut at a shallow enough depth, the monohull vessel is able to pull it, thus performing the whole P&A operation, Friedberg says.

IOSS planned to move into heavier forms of subsea well interven-tion through construction of the newbuild rig Island Innovator, origi-nally designed as what Statoil calls a “Category B” rig. However, the company and its co-owner Marine Accurate Well ASA (Maracc), in-stead opted to convert the unit into a drilling rig after it had been con-tracted by Lundin for a conventional drilling campaign late last year.

Well stimulation is another form of intervention offered by Island Offshore, and which oil companies are turning to increasingly as developing tight reservoirs becomes more commonplace. Larger platform supply vessels are used to support this work.

This summer, Island Centurion and Island Captain are due to start seven-year contracts with Schlumberger as well stimulation vessels. In 2012 Halliburton chartered Island Captain for two months’ well stimulation work on the RWE Dea-operated Clipper South gas feld in the UK southern North Sea.

Island Patriot and Island Commander are also employed in well stimu-lation. Island Commander, which is outftted with a Schlumberger well stimulation spread, recently secured an extension to June 2014 to well stimulation services contracts in ConocoPhillips’ greater Ekofsk area.

From trenching to top-hole drillingIsland performs other subsea work. Island Valiant and Island Fron-

tier worked under contract to AGR Subsea on the latest development phase of Shell’s Ormen Lange gas feld in the Norwegian Sea, in wa-ter depths up to 925 m (3,035 ft). Island Valiant was the platform from which AGR deployed its ClayCutter technology for excavating the

6-km (3.7-mi) pipeline route from the northern template to the feld center in hard seabed clays, while pre-lay trenching was performed from Island Frontier.

The trenching operation allowed the company to demonstrate that 6 5/8-in. drillpipe could be deployed from the vessel in deep waters in accordance with Norwegian Petroleum Directorate requirements, Friedberg says. Similar campaigns were performed in earlier phases of Ormen Lange by Island Valiant in 2008 and Island Frontier in 2005/06.

Experience gained from handling, running, and retrieving drill pipe in trenching operations indicates a potential for top-hole drill-ing – drilling surface hole for conductor pipe, installing the subsea wellhead, and cementing the pipe in place. Again, monohull vessels working on DP-3 should be able to perform these tasks at lower cost than drilling rigs. When the rig arrives, as the wellhead system is already in place, it can straightaway run the subsea BOP system and start drilling, rather than spend time establishing the well.

An opportunity for top-hole drilling may materialize next year, Friedberg says, following an ongoing qualifcation program with Statoil. A pre-drilling phase has been performed involving use of a cylindrical can as a substitute for 30-in. casing to set conductors.

Subsea constructionIn recent years, Island Offshore has also taken advantage of grow-

ing market demand to build its feet of subsea construction vessels. In February 2014 it is due to take delivery of its latest newbuild, Island Pride, which will be equipped with a 125-ton active heave-com-pensated crane and two work ROVs. The vessel, featuring ICE-class notation, will be able to work in Arctic waters.

Another newbuild on order is Island Performer, a large X-bow ves-sel with a 250-ton crane. It will also have room to carry a carousel, and will likely be used for laying fexible pipe, a new operation for Island Offshore.

The company’s existing subsea construction feet includes Island En-

forcer, Island Pioneer, Island Spirit, Ocean Intervention III, and Island Inter-

vention. The Intervention, delivered in 2011, was designed for LWI but started by doing subsea construction on BP’s Skarv development in the Norwegian Sea, i.e. installing and testing subsea trees. Only one tree in-stallation had been intended, but the operation proved so effcient that the vessel has been kept in this role, having installed 17 trees to date.

However, it has also been used for other tasks such as changing out subsea control modules and splicing a heating cable attached to the underside of a pipeline. For this job a special chute was devel-oped to bring the required section of the cable to the surface.

With the exception of Island Intervention, the subsea construction vessels are managed by the parent company from its base in Ul-steinvik, Norway, and often work under subcontract for a subsea contractor. But IOSS provides the engineering expertise. One novel example was a feasibility study for Det norske oljeselskap’s current Ivar Aasen development in the North Sea, which envisaged the com-bined use of Island Enforcer and Island Constructor to lift and set a subsea template, rather than using a crane-vessel or drilling rig. In the event Det norske decided not to proceed with the operation, but now that it has been shown to be feasible, Friedberg hopes other opportunities will arise.

IOSS has around 140 staff, of which close to half work as superinten-dents and supervisors on the LWI and subsea vessels, with the parent company providing the marine crews. The company would like to add an international dimension to its LWI activities, and is examining sub-sea provinces offshore West Africa, Brazil, and India. It has responded to a couple of LWI tenders from Brazil and West Africa, and expects to receive another one soon. But if it were to establish a presence in one of these areas, it would do so via a dedicated vessel – it would not make sense to have a vessel transiting back and forth between, say, West Af-rica and the North Sea, Friedberg says. •

With its partners in the RLWI Alliance, Island Offshore Subsea provides

riserless intervention in subsea wells. (Image courtesy IOSS)

1307off_76 76 6/28/13 2:18 PM

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78 Offshore July 2013 • www.offshore-mag.com

S U B S E A

Fault tolerant, hot swappable subsea

control architecture can improve reliability

Subsea control system architectural concepts can be designed to increase reliability and availability. Failure of a single sub-sea electronic module (SEM) does not have to shut down production nor does it have to reduce the safety integrity level (SIL) of the system. If repair is delayed due to weather

or lack of surface-support equipment availability, subsea production can remain operational indefnitely.

Recent incidents have increased public awareness of potential hazards. This heightened awareness can only increase scrutiny from government organizations charged with overseeing offshore and subsea production. Regulation phrases such as “best practicable technology” from the Clean Water Act of 1977 place the onus on the operating company for safety and environmental protection. These requirements will become more stringent in the future.

Having the option of a TÜV-certifed SIL 3 fault-tolerant subsea system that complies with IEC61508 and IEC61511 – while also meeting ISO 13628-6 for subsea production-control systems – is a step forward in “best practicable technology.”

Fault-tolerant subsea control and safety systems are extrapolated from onshore installations where they help protect workers and the environment from hazards. Fault-tolerant safety systems are intended to be the fnal safety-protection layer. Requirements for these systems were formalized in 1998 with the publication of IEC 61508 “Functional Safety of Electrical/Electronic/Programmable Electronic Safety Sys-tems.” The committee that developed IEC 61508 realized that a large part of this standard involved classifying the hazards and risks asso-ciated with a process, as well as the likelihood that an event might occur. This resulted in the development of risk categories and the possible consequences of an event on people and the environment.

These consequences are quantifed further by estimating the probable frequency of an event.

The IEC standards are further broken down by industry. For ex-ample, the process industry is also covered by IEC 61511 “Func-tional Safety – Safety Instrumented Systems for the Process Indus-try.” IEC 61511 covers the application of electrical, electronic, and programmable electronic equipment use in Safety Instrumented Systems. IEC 61511 defnes the concept of a Safety Integrity Level (SIL) to defne risk-reduction levels. The most widely recognized certifying organization for Safety Instrumented Systems is TÜV. (TÜV is a German acronym for Technischer Überwachungs-Verein, which in English means Technical Surveillance Association). SIL is basically a design requirement for analyzing the process, as well as a performance standard for the hardware.

SIL requirements for hardware are based on an analysis of Prob-ability of Failure on Demand (PFD). Stated more simply: Will the system operate correctly when required? SIL values range from “1” to “4”, with “1” being the lowest and “4” being the most diffcult to achieve. PFD requirements are defned for each SIL rating used in an industrial continuous process.

SIL 1 can usually be achieved using standard hardware augment-ed with some combination of hardware and software diagnostics.

To achieve a SIL 2 rating or higher often requires hardware redun-dancy, along with enhanced diagnostics that provide detailed infor-mation on system health.

Topside applicationsTopside system equivalents that meet SIL 3 requirements have

been widely deployed in the petrochemical, refning, and oil and gas production industries since the publication of IEC 61508. The most successful solutions developed in the 1990s were based on triplicate hardware platforms. Triplication of CPU and I/O allowed sophisti-cated voting schemes that provide greater fault coverage and diag-nostics. This voting approach in a triplicated system is called 2oo3 (2 out of 3). A triplicate voting architecture provides a fault-tolerant ca-pability that allows continued operation of the safety function, even though faults are present in the system.

Triplicated systems support hot swapping of failed components without shutting the system down or degrading performance. This is referred to as triple modular redundant (TMR).

An input from the feld proceeds along three independent paths through the TMR system. The inputs are presented to each of the three logic solvers. The logic solvers vote on the validity of inputs and perform whatever logic is required by the application. Results of the three logic solvers then are sent to the output modules and each output module votes the results. The voted output is then sent to the

Rick McLinRockwell Automation Consequences of failures.

Risk class Defnition Interpretation

I Multiple loss of life, community impact Catastrophic

II Loss of a single life, community impact Critical

III Major injuries to one or more people Marginal

IV Minor injuries, loss of production Negligible

Likelihood of event occurrence.

Frequency Catastrophic Critical Marginal Negligible

1 per year I I I II

1 per 5 years I I II III

1 per 50 years I II III III

1 per 500 years II III III IV

1 per 5000 years III III IV IV

1 per 50,000 years IV IV IV IV

PFD requirements for SIL ratings.

SIL PFD PFD

1 0.00001 – 0.000001 10-5 – 10-6

2 0.000001 – 0.0000001 10-6 – 10-7

3 0.0000001 – 0.00000001 10-7 – 10-8

4 0.00000001 – 0.000000001 10-8 – 10-9

1307off_78 78 6/28/13 2:18 PM

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Input

Input

Input

Logicserver

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Logicserver

Output

voter

voter

voter

Outputterm

Inputterm

Output

Output

Output

voterInput

Inputterm

Logicsolver

Logicsolver

Outputterm

Input

Diagnostics

voter

Inputterm

Outputterm

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Output

Output

voter

voter

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Input

Inputterm

Logicsolver

Logicsolver

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80 Offshore July 2013 • www.offshore-mag.com

S U B S E A

fnal feld device. At any point in the chain, any disagreement is resolved by voting and any errant module’s output is not acted upon. In other words, two out of three signal paths must agree on a course of action.

TMR hardware triples the number of com-ponents, increasing system size and cost. Of-ten, that increased cost can be justifed solely by providing the ability to repair the system online, allowing a critical process to safely re-main in service. Any process that has a high cost associated with an unscheduled shut-down is a potential TMR application.

Simplex and dual systemsWhile TMR systems provide signifcant op-

erational advantages, their cost and size make them diffcult to justify for lower SIL applica-tions. With advances in hardware and diagnos-tic software, higher SIL compliance without triplication has become possible. Even a sim-plex system can achieve SIL2 coverage if it has additional diagnostics coverage coupled with a second method to insure a safe shutdown.

The simplex 1oo1D (1 out of 1 with diag-nostics) system meets the requirements for SIL2, because the diagnostics can detect a hardware fault and initiate a shutdown to in-sure fail-safe operation.

A 1oo1D system cannot continue operating in the presence of a diagnosed fault, so it must initiate a shutdown. Obviously a 1oo1D system does not support hot swap of failed modules.

Because the logic solver drives the diagnos-tics, a 1oo1D system cannot have complete diagnostic coverage. The addition of a second processor improves diagnostic coverage to the point that a simplex I/O with dual processors is capable of providing SIL3 fail-safe coverage.

Failure of any component in a SIL3 fail-safe system necessitates a shutdown. Fail-ure of one processor would degrade this system to a 1oo1D, SIL2. If the process can

operate at SIL2 for a short time, a failed pro-cessor could be hot swapped to restore SIL3 fail-safe coverage. Any failure of input or out-put modules would still require a shutdown.

By adding a redundant I/O to the design, a fully fault-tolerant SIL3 system can be achieved. While not as robust as a TMR system, this ap-proach has the beneft of graceful degradation on module faults and supports hot swapping.

This architecture is widely accepted in the topside process industries and is avail-able from many manufacturers.

Subsea control developments Earlier subsea production control and safety

systems were mounted primarily topside, with communication links to I/O installed subsea. The nature of these installations has evolved as more processes have moved underwater. Gas/liquid separation, pumping, and subsea compression re-quire high-speed response, so closed-loop control cannot be accomplished with the communication

delays inherent with topside mounting. This need for speed has helped delay the use of subsea ap-plications requiring these features. A number of issues must be resolved before a more autono-mous subsea control and safety system can be deployed.

Adapting topside technology All the architectures presented can provide

SIL2 or SIL3 coverage. The challenge is to adapt topside technology for subsea use. Sub-sea control and safety systems are housed in SEMs, which maintain a nitrogen atmosphere for the electronic components. Space is at a premium in SEMs and electrical wiring pen-etrations to the module are expensive. The redundant feld devices required to achieve a certain SIL rating doubles the number of wires and vessel penetrations.

It is also far easier to environmentally hard-en and miniaturize topside equipment than it is to design and build new subsea enclosures. Most topside systems are mounted in stan-dard cabinets, usually 19-in. (48¼ cm) wide. Box depths vary. Meanwhile, a SEM requires ROV installation and removal hardware and procedures. Topside installations do not suf-fer from the same vibration and environmen-tal extremes as the subsea equipment, but they are critical factors for subsea systems.

To ft SIL-rated topside systems into exist-ing subsea enclosures requires a redesign of topside hardware into a Eurocard form. Euro-card is a standard size electronic circuit board supported by all current SEM designs. It can meet the challenge of subsea requirements.

The reduced Eurocard size makes it dif-fcult to fnd space for hardware triplication, eliminating TMR architectures from consid-eration. Dual systems, while smaller, still are too large to deploy in a Eurocard SEM. The lowest level SIL3 architecture possible is the redundant CPU SIL3 fail-safe. This ar-

Typical triplicate SIL3 architecture (2oo3).

Redundant CPU SIL3 fail-safe architecture.

Simplex SIL2 1oo1D architecture.

Redundant SIL3 1oo2D fault-tolerant architecture.

1307off_80 80 6/28/13 2:18 PM

S U B S E A

chitecture requires only one additional mod-ule over a simplex design, so the additional space necessary to achieve SIL3 is minimal.

The requirement for redundant feld de-vices poses another problem for a subsea SIL3 system. Doubling I/O increases the size of the I/O modules and doubles the size of the wiring bundles. An obvious solution: Use two SEM enclosures, each with a redun-dant SIL3 fail-safe system.

By providing two independent SIL3 fail-safe systems, the required hardware can ft within existing SEM enclosures. The problem now becomes coordinating two independent sys-tems subsea.

Communications and diagnostics

The coordination of two independent SIL3-rated systems requires secure communica-tions. The dual SEM architecture shows SIL 3 “black channel” communications links. (While Ethernet is shown, the communications me-dia itself performs no safety functions and can be considered a “black box,” hence the name black channel.) TÜV requirements for black channel-certifed communications are designed to detect errors from loss, inser-tion, repetition, incorrect sequence, corrupted data, delay, and other communications faults.

The SIL 3 black channel allows I/O and diagnostic information to be exchanged be-tween SEM A and SEM B. Proper applica-tion design can use this to improve system availability. Each SEM exchanges all system health information, all I/O information, and the status of each feld device. If SEM A has a failed feld device, it can use the data from a healthy device connected to SEM B to continue operation. This exchange of infor-mation over black channel communications improves fault tolerance without impacting operation or safety. If an entire I/O module fails on SEM A, it can still continue operat-ing using data from SEM B.

Achieving fault toleranceWhile individual modules within an SEM

cannot be replaced, an entire SEM can be removed while the subsea production facil-ity remains in operation with no reduction in SIL rating. Fault-tolerant SIL3 hot swappable subsea control systems are feasible with the proposed architecture.

Hot swapping control modules subsea is only possible if each SEM is in a physically separate location. An ROV obviously must access a failed SEM to replace it. A subsea hot swappable system must include the abil-ity to gracefully remove and reinsert a SEM.

This removal and reinsertion must be bump-less, with automatic education and synchro-nization of the new SEM with current oper-ating data. Not a trivial task, but achievable.

Even though the SEMs are physically sep-arated, they still function as a single system. This requires that the application software in each SEM not only exchange diagnostic information, but be capable of both indepen-dent and combined operation.

Redundant topside communications chan-nels may or may not be black channel, but diagnostic data from each SEM can be trans-mitted topside. This provides redundancy in topside communications and offers an alter-native data path if topside links to one SEM fail.

If the SIL 3 black channel Ethernet between each SEM fails, then the topside monitoring system would need to look at the status of each SEM and decide which should continue operation. Loss of communications to a single SEM causes no degradation of system perfor-mance since communications topside is main-tained through the second SEM. Multiple data pathways increase overall system availability.

If both SEMs lose topside communica-tions, all subsea operations could be immedi-ately shut down, or a predetermined interval could elapse before shutdown occurred. •

1307off_81 81 6/28/13 2:18 PM

82 Offshore July 2013 • www.offshore-mag.com

S U B S E A

Employing a dynamic approach

to flow assurance modeling

Adding CFD improves accuracy and detail

Computational fuid dynamics (CFD) can combine with tradi-tional pipeline modeling software to improve detail and speed of both applications for accurate fow assurance modeling. Without CFD, some projects may not be as successful, or may not be able to commence at all. While computational powers at

present may limit the ability to use CFD across an entire system, this technology will play an increasingly important role in fow assurance.

Modeling the hydraulic and thermal relationships between fuids and gasses in a production environment can be an inexact science. As systems become more complicated, determining the impact of these interactions within oil and gas pipelines and infrastructure be-comes more challenging.

Traditional pipeline modeling systems have been around for almost 20 years, and a number of projects have presented fow assurance engineering challenges that could not adequately be resolved using standard multi-phase transient simulator modeling tools. In these in-stances, CFD modeling has been used in addition to standard tech-niques to achieve advanced fow assurance solutions. Some of these projects would not have been viable without the use of CFD, and it also has enabled pioneering subsea projects to take place.

The traditional approachCurrent common tools allow large, complex, full-scale network

modeling, with the ability to include wellbore, reservoir, and pro-cess equipment operations. An entire subsea pipeline network can be modeled, even with numerous wells and multiple lines.

This can be done in a reasonable timeframe. For example, a large model could run in a day, giving signifcant computational output. With this run time, software can play out 20 years of production of an oil well and calculate the temperature and hydraulic effects over time to aid optimum system design.

These programs also enable full multi-phase pressure, volume, temperature (PVT) capability, including component tracking through the network to calculate changing compositions. Transient operations are possible with some software which provides data on the change in hydraulic relationship with time as well as fow conditions. Therefore, many parameters can be analyzed from a single run.

However, there are limitations with this type of software. Detailed analysis of specifc points in the system is not possible due to the section resolution required to model large-scale networks. It can focus on 2- to 5-m (6½- to 14½-ft) long sections, but fdelity is lost trying to examine the frst 10 cm (4 in.) downstream of a mixing point, for example.

It is not possible to model complex geometries for specifc equip-ment such as valve internals, spools, manifolds, and process equip-ment. Traditional software only models round pipe, so it may miss

localized areas of concern and detail such as fow distributions, cold spots caused by fow paths, and erosion risks. Certain fow paths cause this, for example, where there is a tight elbow in a valve there can be an erosion risk at the edge of the elbow because of the signif-cant fow energy on that area.

Thermal models also are limited and are not always suffcient for use on complex pipe and equipment arrangements, or certain tran-sient events. Thermal models also work on a standard cylindrical shape, so calculating heat loss in a pipe that is part submerged is impossible as it is not universally cylindrical. Also, natural convec-tion (both internal and external) and radiation are not accounted for.

Using CFD in fow assurance Analysis of low material temperatures caused by rapid gas expan-

sion (JT cooling) is possible using CFD. This includes cold spots and thermal gradients which can exceed the design limits of the material, and traditional pipeline tools which do not give the distinc-tion required. Situations can be evaluated including choke valves and downstream pipework at start-up, and process equipment and pipework during blowdown.

CFD also offers detailed thermal modeling of part buried, back-flled, rock dump, and mattressed pipelines; complex pipelines; and subsea heat exchangers or cooling spools. Analysis of solids erosion is also possible at fow path deviations to identify erosion hot spots.

Flow distribution at fow path splits such as manifolds, metering skids, and fnger slug-catchers can be modeled. The last is the most important because without equal distribution there is no beneft in having fnger slug catchers. Other systems would just equally split the fow path without deriving the actual likely fow split.

For rapid valve closures, CFD enables analysis of peak pressure pulses close to valves. This water hammer effect causes localized high-pressure waves which cannot be analyzed in systems that smooth out the hydraulics.

Chris SmithXodus Group

Subsea cooling

coil piping.

1307off_82 82 6/28/13 2:19 PM

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84 Offshore July 2013 • www.offshore-mag.com

S U B S E A

CFD and full network modeling Although CFD modeling is powerful and suitable for precise

evaluation of specifc areas, it is not viable for modeling large-scale networks or life-of-feld analysis due to its computational intensity.

In some instances, it is useful to combine the analysis carried out in CFD with pipeline modeling tools to allow full network analysis using CFD derived results. It combines the accuracy of CFD with the speed of pipeline modeling.

The combined effort can result in accurate overall heat transfer coeffcient (U value) for complex pipeline systems or partial burial to determine the heat loss coeffcient. Accurate cool-down rate can also be calculated by tuning heat loss parameters – especially vital during shutdowns.

Application of maximum erosion velocities for solids laden fuids can be done to determine what gas velocities will cause an erosion risk. CFD also allows for detailed analysis of phase distribution in through pipe to demonstrate dispersal in gas/water mixes.

Case study: Thermal modeling In a subsea oil development in the Norwegian North Sea, the en-

gineering consultancy worked on a tieback to an FPSO project from multiple well pads. The specifc challenges for thermal modeling in OLGA included the subsea cooling coils or spools, and the fact that the pipeline was partially embedded in soil.

It also involved bundles of pipelines from wells to risers. Each bundle had two production lines and one water injection line. The multi-dimensional heat transfer mechanisms in the bundled pipeline system were complex and not adequately captured using standard OLGA modeling.

Another challenge was heat loss during shutdown, and concerns about survival time due to wax and hydrate.

CFD software Star-CCM+ modeled a short section of the pipeline bundle and derived the U value. This considered conduction; the K values for aged and un-aged insulations and effect of spacers, as well as convection; the interactions between bundle pipelines; and the effect of flm coeffcient.

The U value changed through feld life and along the length of the bundle. The cool-down response was analyzed with CFD. OLGA parameters, U value, heat capacity, and effective annulus current speed were tuned to match the response of CFD analysis. Those combined parameters were analyzed in CFD and then put into the pipeline software to model the whole system.

Heat loss in the cooling coil was analyzed in STAR-CCM+, and the effective U value was calculated and applied in the OLGA model. The effect of seawater current speed was minimal as natural convection caused a chimney effect and drew cool seawater up through the coil.

Pipeline modeling tools do not accommodate natural convection which means inaccurate results. CFD allows the thermal losses from this complex pipeline system to be modeled more accurately.

The OLGA models were tuned to match the heat transfer coeffcient

supported by detailed CFD analysis rather than from published stan-dards. This accounted for all thermal interaction mechanisms and accu-rately simulated the cool-down response of the overall bundle system. Life-of-feld and transient analyses then were performed on this basis.

In this case, due to the complex thermal system and because the fuid temperature was critical, without use of CFD it may have ap-peared uneconomic to produce this well. The lack of accuracy would have meant engineering with large safety margins. Using this high-fdelity analysis removed some of the conservatisms and enabled a tightly engineered design.

Case study: Mixer design This case study focuses on the design of a simultaneous water and

gas injection (SWAG) system in a subsea oil feld where production wells were tied back to an FPSO. This was a particularly unusual system and a subsea frst.

The water and gas injection fuids are delivered to a subsea injec-tion well in separate fowlines and combined immediately upstream of the well prior to injection. This design demanded that the gas be fully dispersed within the water stream so no separation occuredin the wellbore to elevate hydrate risk.

The injection system, including the well, was modeled using OLGA. Because detailed analysis was required at the co-mingling of the fuids, STAR-CCM+ was used to analyse gas dispersion in a range of available mixing technologies.

OLGA analysis of the system showed combined fuid would oper-ate in the slug regime at expected process conditions, resulting in poor injection and possible well damage. Xodus was tasked to de-sign a mixing device to overcome this problem.

Initially a simple T-piece mixing solution was explored, but with poor results as the gas and water separated quickly. Peak mixing oc-curred 6 m (19½ ft) downstream of the mixer with stratifcation 40 m (131 ft) downstream.

A collar system was considered, where gas fows around the met-al collar and is then injected in multiple points around the circumfer-ence of the water pipe. This proved more effective with improved mixing which was enhanced further when the injection points were situated only on the bottom of the pipe.

In this case, some level of stratifcation occurred 40 m down-stream of the mixer regardless what design was in place. The sleeve mixer design was signifcantly more effective than the simple T-piece, which the client had initially pursued.

Locating the gas injection holes only at the bottom of sleeve in-creased the mixing. Bubble diameter was the most signifcant factor in successful mixing, and reducing the velocity had little impact on mixing uniformity.

These modeling outcomes allowed the functional design to be specifed, ensuring that mixing occurred as close as possible to the injection point. Small holes were used to decrease bubble diameter when using holes only on the bottom of sleeve of the mixer. •

(Left) Gas flow into a continuous water stream through a simple T piece.

(Above) Water and gas stream mixing collar.

1307off_84 84 6/28/13 2:19 PM

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

86 Offshore July 2013 • www.offshore-mag.com

PeopleJeff Shellebarger has been named presi-

dent of Chevron North America Exploration

and Production Co., effective Aug. 1. He suc-

ceeds Gary Luquette, who will retire from the

company after 35 years of service.

Songa Offshore SE has elected Michael

Mannering as chairman of the board of direc-

tors.

PA Resources has appointed Philippe R.

Probst as CEO.

CGG has appointed Christophe Barnini as

senior vice president,

group communica-

tions.

David Brunnert

has joined Express

Energy Services as ex-

ecutive vice president

and COO.

Jee Ltd has ap-

pointed Nigel Ross as

business development

director.

Thomas K. Sneed,

vice president and chief information offcer

of Marathon Oil Corp., has elected to retire

effective Sept. 1, following more than 32 years

of service. He is succeeded by Bruce A. Mc-

Cullough.

Giovanni Corbetta has joined DOF Subsea

UK as managing director.

The nomination committee in Statoil has

recommended that the company’s corporate

assembly elects Catherine Hughes and

James J. Mulva as new members of its board

of directors.

The ASCO Group

has appointed Derek

Smith as CEO. He

succeeds Billy Allan,

who has become the

group’s executive

chairman. The compa-

ny has appointed Matt

Thomas as CEO of its

Australasia region.

Aquaterra En-

ergy has appointed

Martin Bolton as sales manager to develop

new growth for the company’s products and

services in the Middle East. Stewart Maxwell

has joined the company as technical director.

Exxon Mobil Corp. has elected William C.

Weldon to its board of directors.

Transocean has elected Ian C. Strachan

as chairman of the board of directors. He suc-

ceeds J. Michael Talbert.

Claxton Engineering Services Ltd., an

Acteon company, has appointed Nicholas

Dale as business development manager for

Southeast Asia.

Michael G. France, N. John Lancaster,

and Scott L. Lebovitz have resigned from

Cobalt International

Energy’s board of

directors.

The Energy

Industries Council

has elected The Right

Honourable the Lord

Howell of Guildford

as president. Howell

succeeds The Rt. Hon.

the Lord Jenkin of

Roding, who has held

the position since October 2009.

Rowan has appointed Tore I. Sandvold to

its board of directors.

Anadarko Petroleum Corp. has pro-

moted James J. Kleckner to executive vice

president of international and deepwater

operations. Kleckner will join the company’s

Executive Committee.

Willbros Group has appointed Earl Collins

as president of its oil and gas segment. The

company has reelected John T. McNabb II,

Robert L. Sluder, and S. Miller Williams as

Class II directors to its board.

Baker Hughes has named Mike Sumruld

vice president and treasurer.

NCS Survey Ltd., an Acteon company,

has appointed John Meaden as managing

director.

Strategy Engineer-

ing & Consulting LLC

has named James

Burke director of

projects, and has pro-

moted Craig Matus to

manager of mechani-

cal engineering and

Cameron Tempest

to manager of pipeline

engineering.

Fabricom Offshore

Services has ap-

pointed Mike Grant

as Aberdeen projects

development manager

and Pat Martin as the

Aberdeen offce engi-

neering manager.

Sandvik Materi-

als Technology has

appointed Michael

Andersson as the new

head of product area

tube.

Saab Seaeye

has promoted Terry Wood to engineering

manager and Chris Henderson to customer

support manager.

Peter Roberts has joined Andrews Kurth

LLP as a partner in the London offce.

Megan Bel has joined the National Ocean

Industries Association as senior director,

government and political affairs.

ValvTechnologies Inc. has named Edward

Ferris as vice president of human resources.

Greene’s Energy

Group has appointed

Juan Gonzalez Jr. as

western regional man-

ager for the Testing

and Services business

unit.

Gary Yeoman has

joined Balmoral Off-

shore Engineering as

SURF sales director.

Faroe Petroleum

has appointed Jona-

than Cooper as CFO.

Gulfstream Services has named Robert

Bates vice president of global business

development, Billy Marcel manager of global

operations – decommissioning services

division, and Dale Broussard as manager

– quality assurance and health, safety, and

environment.

Parker Drilling Co. has hired Christopher

T. Weber as senior vice president and CFO.

Ian Pownall has joined UTEC Survey JLT

as general manager.

Senergy has ap-

pointed Lesmana

Djayapertapa as

senior computational

fuid dynamics con-

sultant.

Omni Helicopters

International S.A has

appointed Richard

Burman as group

CEO.

Tom Bower has

joined Viking SeaTech

as Gulf of Mexico

managing director.

Breitling Oil and

Gas Corp. has ap-

pointed Joseph Simo

as vice president of

exploration.

Tony Sage has

resigned as non-exec-

utive deputy chairman

of African Petroleum.

Company newsTechnip has opened its new Innovation and

Technology Center near Paris. Its purpose is to

centrally manage the company’s technological

development, and to coordinate all relevant

research and development centers and regional

entities.

FEI and the University of Oklahoma (OU)

have commenced a research collaboration

agreement to establish an oil and gas center of

excellence, the “FEI-OU Pore Scale Characteriza-

tion Laboratory,” at the OU Mewborne School

Brunnert

Howell

Gonzalez Jr.

Burman

Bower

Tempest

Andersson

Smith

1307off_86 86 6/28/13 2:19 PM

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

of Petroleum and Geological Engineering. The research will focus on the development of routine quantitative methods to classify shales in the economic assessment of tight oil and gas plays.

T.D. Williamson has opened a new mainte-nance center for pressurized piping systems in the Musaffah Industrial Area of Abu Dhabi.

Precision Polymer Engineering has opened its new Houston facility.

Sakhalin Energy has committed to roll out OPITO IMIST (International Minimum

Industry Safety Training) Online across the Sakhalin-2 project over the next three years. More than 2,000 staff and contractors will complete the online safety training program.

Danos has selected a Bayou Region site in Houma, Louisiana, for its new $10-million cor-porate headquarters facility. The company also is evaluating multiple Louisiana port locations to select where it expects to invest $20 million in a new waterfront fabrication facility.

Produced Water Absorbents has estab-

lished its frst international entity, PWA Eu-

rope Ltd., in Buchan House, in the Northfeld area of Aberdeen.

Aquaterra Energy has opened an offce in Dubai.

Oil Consultants Ltd. has established sup-port operations in Malaysia and Indonesia.

Scientifc Drilling International has opened its new northeast Asia facility in Manila, the Philippines.

Houlder has announced plans to open Houlder Americas Inc. in Houston.

First Minister of Scotland, Alex Salmond, of-fcially opened Bibby Offshore’s new purpose-built headquarters, Atmosphere One. The company recently relocated from Aberdeen Harbour to the new offce facility at Prospect Park, Westhill.

Unique Hydra has signed an agency agree-ment with EIVA to represent its products and services in the southern part of Africa.

Forum Energy Technologies Inc. has entered into a defnitive agreement to acquire Blohm + Voss Oil Tools from STAR Capital

Partners Ltd.

Cameron has opened its new CAMSERV aftermarket drilling facility in Singapore. While the facility will primarily serve major shipyards and offshore drilling contractors across Asia, it will also provide aftermarket support for Cameron’s global customer base.

EFC Group has launched a new manufac-turing plant in Moray, Scotland. The base in Enterprise Park, Forres marks the group’s second phase of expansion in the area and a £100,000 ($151,000) investment.

Lloyds Register has joined ITF, the global technology facilitator.

Jee Ltd has been re-certifed for ISO 14001 Environmental management, and OHSAS 18001 Safety management, and has transferred its ISO 9001 Quality management certifcation, held since 1995, to DNV to bring the three accreditations into one integrated business management system.

Vallourec and its various entities will be adopting a single brand and common identity, Vallourec, with a modernized logo. V&M USA

Corp. becomes Vallourec USA Corp.; V&M

STAR, LP becomes Vallourec Star, LP; and V&M TCA, a division of V&M Star, becomes Vallourec Star, LP.

Fine Tubes has partnered with Superior

Tube. The companies will share a new global association while maintaining their own names and specialties.

For the fourth consecutive year, Conduc-

tor Installation Services Ltd., an Acteon company, has received the Gold Award for Oc-cupational Health and Safety 2013 from the UK’s Royal Society for the Prevention of Accidents.

Ned-Deck Marine has united with Palfn-

ger Marine under the new company name Palfnger Ned-Deck.

Meet the Tugs that Do It All.

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with fuel to spare, Crowley’s ocean class tugs are highly maneuverable, with 165 ST

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That’s why from fabrication yard to offshore fi eld, the best in the world turn to Crowley.

Just ask the people who know.

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1307off_88 88 6/28/13 2:19 PM

The 18th edition of Offshore West Africa will return to Accra, Ghana on 21-23 January 2014, delivering the premier technical forum focused exclusively on West African

offshore exploration and production. The conference will deliver the latest technological innovations, solutions and lessons learned from leading industry professionals.

Offshore West Africa Conference and Exhibition remains the leading source of information on new technology and operating expertise for this booming deepwater

and subsea market. Having Offshore West Africa take place in Ghana is of high interest to national and international oil companies that are familiar with the

outstanding conferences held by PennWell worldwide.

For further information please visit: www.offshorewestafrica.com

For more information on exhibiting and sponsorship please contact:

21-23 JANUARY 2014

International Conference Centre, Accra, Ghana

INVITATION TO EXHIBIT

WWW.OFFSHOREWESTAFRICA.COM

EXPANDING WEST AFRICAíS

OFFSHORE POTENTIAL

CONFERENCE AND EXHIBITION

Presented by:Owned & Produced by: Supporting Publication:

18TH EDITION

Follow Offshore Events on:

Europe, Africa & Middle East:Tony B. Moyo

T: +44 (0) 1992 656 658F: +44 (0) 1992 656 700E: tonybm@pennwell.com

Nigeria:Dele Olaoye

T: +234 802 223 2864E: q-she@inbox.com

The Americas:Desiree Reyes

T: +1 713 963 6283F: +1 713 963 6212

E: desireer@pennwell.com

South East AsiaMike Twiss

T: +61 437 700 093E: mike@energy-pubs.com.au

1307off_89 89 6/28/13 2:19 PM

August 22-24, 2013

Conference & Exhibition

Bombay Exhibition Centre

Mumbai, India

www.petroworldindia.com

CO-ORGANIZED BY: SUPPORTED BY: SPONSORED BY: PRESENTED BY:

INVITATION TO ATTEND

PRE SHOW GUIDE NOW AVAILABLE

For further information on exhibiting and sponsorship, please contact:

REST OF THE WORLD

Jane Bailey

T: +44 (0) 1992 656 651

F: +44 (0) 1992 656 700

E: janeb@pennwell.com

SOUTH EAST ASIA

Mike Twiss

T: +61 437 700 093

E: mike@energy-pubs.com.au

USA (COMPANIES A-L)

Desiree Reyes

PennWell Corporation

T: +1 713 963 6283

F: +1 713 963 6212

E: desireer@pennwell.com

USA (COMPANIES M-Z)

Kelsey Stretch

PennWell Corporation

T: +1 918-832-9343

E: kelseys@pennwell.com

����������������������

Government Of India

Ministry Of Petroleum and Natural Gas

PetroWorld India is a unique annual forum for the industry, with both a world class conference combined with the exhibition showcasing the latest technological developments, within the oil & gas industry.

WHY ATTEND?

���"���������������� ���������������������������������������engineers from major and independent E&P companies focusing on ��������������������������

��"�������������������������������� �������������

���"��������������������������������������������������������������������������������� !����������

������������������������������������������������������������associated with the expanding Indian exploration & production industry

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1307off_90 90 6/28/13 2:19 PM

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)

davidd@pennwell.comShelley Cohen (Regional Sales Manager)

shelleyc@pennwell.comGrace Jordan (Classified Sales) gracej@pennwell.com

GREATER HOUSTON AREA, TXDavid Davis davidd@pennwell.com

USA • CANADA

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PHONE +44 1622 721222 • FAX +44 1622 721333 Roger Kingswell rogerk@pennwell.com

FRANCE • BELGIUM • PORTUGAL •

SPAIN • SOUTH SWITZERLAND • MONACO

• NORTH AFRICA

Prominter 8 allée des Hérons, 78400 Chatou, France

PHONE +33 (0) 1 3071 1119 • FAX +33 (0) 1 3071 1119 Daniel Bernard danielb@pennwell.com

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• 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 wilhelms@pennwell.com

ITALYSILVERA MEDIAREP

Viale Monza, 24 - 20127 Milano, ItalyPHONE +39 (02) 28 46716 • FAX +39 (02) 28 93849

Ferruccio Silvera info@silvera.it

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Smartpublishing Ltd/ OGJLA Pennwell BrazilHEADQUARTERS: Rua Raimundo Chaves 2182, L5

Natal RN 59064-390, BRAZILRIO OFFICE: Ave. Erasmo Braga 227, 11th foor

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FAX +55 (21) 2533 4593Jean-Paul Prates adm@pennwell.com.br

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 konishi-manami@ics-inc.co.jp

SOUTHEAST ASIA • AUSTRALIA

13 Langrune Grove,Port Kennedy, WA, Australia 6172

PHONE +61 8 9593 4405 or +61(0) 437 700 093FAX +61 8 9593 3732

Mike Twiss miket@pennwell.com

INDIA

Interads Ltd., A-113, Shivalik, New Delhi 110 017 PHONE +91 11 628 3018 • FAX +91 11 622 8928

Rajan Sharma rajan@interadsindia.com

NIGERIA/WEST AFRICA

Flat 8, 3rd foor (Oluwatobi House) 71 Allen Ave, Ikeja, Lagos, Nigeria

PHONE +234 805 687 2630 or +234 802 223 2864 Dele Olaoye q-she@inbox.com

SALES OFFICES

A

Aegion ..........................................................6www.aegion.com

Aker Solutions ...........................................25www.akersolutions.com

ATI Allegheny Ludlum ...............................56www.alleghenyludlum.com

Avondale .....................................................35www.hii-avondale.com

AXON Energy Products .............................59axonep.com

B

Baker Hughes Incorporated ......................13www.bakerhughes.com

Bredero Shaw .............................................23brederoshaw.com

C

Cameron .......................................................9www.c-a-m.com

Canusa-CPS ...............................................63canusa.com

CJ Winter ....................................................16cjwinter.com

Clover Tool Company ............................... C3www.clovertool.com

Crowley Maritime Corporation..................88www.Crowley.com

Curoil NV ....................................................18www.curoil.com

D

Delta Rigging & Tools ................................61www.deltarigging.com

Dril-Quip .......................................................1www.dril-quip.com

F

FloaTEC ......................................................15www.floatec.com

FMC Technologies .................................... C4www.fmctechnologies.com

G

Greene’s Energy Group .............................53www.GreenesEnergy.com

K

KOBELCO / Kobe Steel Ltd. ......................39www.kobelcocompressors.com

L

Lincoln Electric ..........................................37www.lincolnelectric.com

M

M-I SWACO ...................................................5www.miswaco.com

MCCOY .......................................................69www.mccoyglobal.com

Mokveld Valves BV .....................................21www.mokveld.com

N

Nalco Champion. ....................................... 11nalcochampion.com

National Oilwell Varco. ...............................27www.nov.com/rig

National Oilwell Varco. ...............................41www.nov.com/tuboscope/C3

National Oilwell Varco. ...............................75www.nov.com/ICT

Newpark Drilling Fluids. ............................29www.newparkdf.com

O

Oceanic Marine Contractors .....................17www.oceanicmc.com

OneSubsea .................................................43www.onesubsea.com

P

PennWell Deep Offshore Technology Conference & Exhibition ......................65

www.deepoffshoretechnology.com

Deepwater Operations Conference & Exhibition ................33, 83

www.deepwateroperations.com

Offshore Group .....................................77www.offshore-mag.com

Offshore West Africa Conference & Exhibition ...........................................89

www.offshorewestafrica.com

PetroWorld India Conference & Exhibition ...........................................90

www.petroworldindia.com

Subsea Tieback Forum & Exhibition .....................................33, 85

www.subseatiebackforum.com

Topsides, Platforms & Hulls Conference & Exhibition ................33, 87

www.topsidesevent.com

Pneumatic and Hydraulic Company ........79www.pneumaticandhydraulic.com

R

REPSOL ......................................................81www.repsol.com

S

Sembcorp Marine ......................................51www.sembcorpmarine.com.sg

Spectrum Geo, Inc. ....................................31www.spectrumasa.com

Superior Energy Services .........................71www.superiorenergy.com

T

T-REX Engineering & Construction..........49trexec.com

T.D. Williamson, Inc. ..................................2-3www.tdwilliamson.com

Tendeka ......................................................67www.tendeka.com

Tiger Offshore Rentals ..............................47tigeroffshorerentals.com

TIW Corporation.........................................36www.tiwtools.com

Tracerco ......................................................45tracerco.com

Transocean ................................................ C2www.deepwater.com

V

Van Oord Offshore BV ...............................73www.vanoord.com

Vard AS .......................................................19www.vard.com

Variable Bore Rams, Inc. ...........................57www.vbri.com

W

Weatherford ..................................................7weatherford.com

Well Control School ...................................10www.wellcontrol.com

The index of page numbers is provided as a service. The publisher does not assume any liability for error or omission.

ADVERTISERS INDEX

1307off_91 91 6/28/13 2:19 PM

This page refects 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 davidp@pennwell.com.

92 Offshore July 2013 • www.offshore-mag.com

B E Y O N D T H E H O R I Z O N

At the SPE Annual Conference last October, Ed Merrow of IPA (Independent Project Analysis Inc.) presented data that showed that 20 years ago 50% of megaprojects in E&P failed to meet the IPA def-nition of success. Today, that number has increased to 75%. At the same time, the failure ratio for megaprojects in other industries has stayed pretty much constant at 50%. Could part of this failure rate and the growing difference from other industries be attributed to the way in which our industry assures technical competence in the conceptual and detail designs of major projects?

Today, to a large extent, the industry focuses on policies, proce-dures, and audits to assure the quality and safety of projects. This appears to be working with regard to the safety aspect of our proj-ects, but is it suffcient to assure the quality of the decision making that goes into our projects? Does the industry also need to focus on competence, motivation, and behavioral norms of the individuals involved in concept analysis, project defnition, and detail design?

In the past, many major oil companies had extensive training pro-grams for a class of in-house engineers variously called facilities en-gineers, infrastructure engineers, etc. These engineers were given extensive formal training by experienced subject matter experts. In their early careers, they were also given temporary assignments in various engineering groups to better understand the validity and un-certainties in data, and assignments in operating groups. This was designed to help them get a better understanding of the practical aspects of how their designs interfaced with real-world operational problems. They learned the technology of facilities engineering by performing small projects under the tutelage of mentors who were knowledgeable in the technology of facilities engineering, and they learned the discipline of project management by working as team members on larger projects. A number of the engineers so trained eventually migrated to engineering frms and formed the technol-ogy backbones of these companies.

Over time, many oil companies have decided that facilities engi-neering is not a “core competence” and are relying on engineering frms, or non-employee contractors, for the facility expertise needed. However, engineering frms are faced with a problem of providing their staff with the same training and experience building opportuni-ties that was once the norm in oil companies. Due to business de-mands, often the selection of an engineering frm cannot follow the quality-based process that is recommended by the National Society of Professional Engineers. Oil companies tend to ask engineering frms to provide a bid. Selections are not only based on personnel capability but they are also dependent on cost estimates, rate sheets, or multipliers. The engineering frm must strive to ensure that its rates are comparable to the competition, and that it does the work

with a comparable amount of engineering hours. The result is that the engineering frm must keep its non-billable time, including time spent on competency building, to a minimum, and must perform the work with the least amount of re-work to develop a better solution.

More importantly, engineering frms have limited opportunities to provide the informal training that was once available to oil com-pany engineers. They cannot give their engineers the same level of experience of working with other petroleum disciplines to better understand the limitations that are inherent in the basis of design. Nor can they offer them the opportunity to interface regularly with operating personnel to understand practical considerations, which can greatly impact the quality of the design. It is becoming more dif-fcult for engineering frms to arrange for trips offshore and to visit fabrication yards to obtain this tacit knowledge.

Many engineers (and oil company consultants) working on proj-ects are employed to be billable. As the job winds down, other op-portunities need to be found. Management has limited incentive to invest deeply in their training, and engineers have limited incentive to fnd ways to work more effciently. Thus, engineering frms must rely on the competency of their staff, yet the realities of the con-tractual business relationship limits their ability to build that compe-tence to a level that once was commonplace.

Engineering frms have developed an extensive array of poli-cies, procedures, and quality control checks through such things as hazards analysis, standardized sizing procedures, and risk man-agement studies. Oil companies have defned detailed stage gate processes to ensure the quality of this work. If the right procedures are followed, it is assumed that the results will be correct. Whether engineers today have the same level of ability to actually exercise proper professional judgment and develop designs that are effcient, constructible, and easy to operate and maintain is open to debate. This could tend to lead to a conclusion that engineering is no lon-ger a profession requiring informed judgment, but rather a series of defned work processes that can be accomplished by technicians performing routine tasks.

This author believes that if we are to make a signifcant impact in the quality of our projects, we must consider changing the structure of the oil company/engineering frm relationship, and the way both oil companies and engineering frms interact with the engineers defning and designing our projects. Only then can we address the competencies, motivations, and behavioral norms of the individuals involved.

Ken Arnold

K Arnold Consulting Inc.

Assuring technical competence

on facilities projects

1307off_92 92 6/28/13 2:19 PM

With over 150 BOP test units on offshore platforms and rigs throughout the world,

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