OS_20120801_Aug_2012.PDF

August 2012

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:

FPSO poste

r,

MWD/LWD su

rvey

North Sea E&P trends Statoil’s IOR

strategy

GDF SUEZ expands UK presence

BalmoralOffshoreEngineeringBuoyancy, insulation andelastomer products

+44 (0)1224 859000 | [email protected]

Drilling riser buoyancy Distributed buoyancy

ROV/AUV buoyancy Surface/subsurface buoyancy

Insulation covers Cable and flowline protection

Bend restrictors/stiffeners Balmoral Subsea Test Centre

www.balmoraloffshore.com

qqM

Mq

qM

MqM

THE WORLD’S NEWSSTAND®

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

qqM

Mq

qM

MqM



http://www.balmoraloffshore.com

http://www.offshore-mag.com

http://www.qmags.com



August 2012

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:

FPSO poste

r,

MWD/LWD su

rvey

North Sea E&P trends Statoil’s IOR

strategy

GDF SUEZ expands UK presence

Click here to access

Spring 2012 Energy

Catalog

Contents | Zoom in | Zoom out Search Issue | Next PageFor navigation instructions please click here

Contents | Zoom in | Zoom out Search Issue | Next PageFor navigation instructions please click here


http://www.qmags.com/d?pub=BC&upid=17200&fl=others/Supp/Energy_Catalog_Spring2012.pdf

QUARTZ GAUGES

Signature

Sig

natu

re, b

e ce

rtai

n, a

nd M

easu

rabl

e Im

pact

are

mar

ks o

f S

chlu

mbe

rger

.

© 2

012

Sch

lum

berg

er.

12

-TS

-003

0

On a fifteen-day offshore well test with average temperature exceeding 400 degF,

Signature quartz gauges delivered continuous high-quality pressure measurements.

Rated to 30,000 psi and 410 degF, Signature gauges help you meet test objectives

by providing accurate, high-resolution measurements—for the duration of your test.

Be certain.

www.slb.com/Signature

Global Expertise | Innovative Technology | Measurable Impact

HPHT Measurements

Throughout Your Test

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.slb.com/Signature





qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________

http://www.dril-quip.com





International EditionVolume 72, Number 8

August 2012

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 2012 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

NORTH SEAStatoil leads overhaul of Norwegian development drilling, intervention fl eet ................... 32If the market does not provide the solution you need, the answer may be to pull a few strings to make sure it does. That is the proactive approach adopted by Statoil in its search for fi t-for-purpose rigs for improved oil recovery on Norwegian fi elds.

Confi dence returning among NW Europe operators ............. 36The energy industry, a strategic resource for security of supply across Northwest Europe, is faced with increasing commercial and technical challenges in its efforts to explore for and produce oil and gas. These include an extended period of economic turmoil, declin-ing production, and rising costs.

GDF SUEZ expanding operations in mature and emerging UK gas provinces ............................... 40After 15 years as a co-venturer or exploration operator on the UK continental shelf, GDF SUEZ is preparing for a leading development role. The company already runs numerous gas production centers offshore Norway and the Netherlands, but Juliet and Cygnus in the southern North Sea will be its fi rst major oper-ated UK projects.

ARCTICGas supply routes to determine future phases of Snøhvit development ...................... 42Snøhvit, Norway’s most northerly offshore fi eld development, has now been onstream for fi ve years. Gas and condensate from the subsea wells are piped to the single-train LNG processing plant on Melkøya Island off the port of Hammerfest. It remains the world’s most northern LNG facility, with scope for expansion of offshore production, although competing ter-minals are emerging elsewhere around Europe.

GULF OF MEXICOSEMS continues to shape the offshore regulatory environment ..................... 46Expectations have changed for oil and gas op-erators in the Gulf of Mexico over the last few years. Regulations from the Bureau of Safety and Environmental Enforcement, as well as increased scrutiny from investors and the public, have left companies searching for safer and more environmentally sound methods to extract oil and gas in deep and ultra-deepwater.

GEOLOGY & GEOPHYSICSEnhancing EOR through reservoir modeling ............................. 50Whether it is seismic interpretation, the build-ing of a structural model, fault and fracture model, or history matching and simulation, reservoir modeling provides operators with crucial information on oil and gas in place and the potential obstacles to accessing them.

DRILLING & COMPLETIONIntelligent wells offer completion solution for Lower Tertiary fi elds ....... 54This summer will mark 15 years since the industry’s fi rst intelligent well installation. What started out as a small niche in the completions segment has expanded to now offer solutions for a wide range of applications, many of them in the highly challenging environments.

Flow detection system saves time, money in record HP/HT Norwegian well ....................... 58While planning for an offshore Norwegian explor-atory well, surface pressure of nearly 15,000 psi and extremely high temperatures were anticipated.

Logging-while-drilling technology continues to reduce drilling risk ........ 62When logging-while-drilling (LWD) made its debut in the late 1980s, several advantages were touted. Chief among these was the potential elimination of wireline logs.

2012 MWD/LWD Services Directory .............................. 68Get the latest info on measurement-while-drilling (MWD) and logging-while-drilling (LWD) tools and services for 2012.

ENGINEERING,CONSTRUCTION& INSTALLATIONNew model predicts jackup weight and displacement ................... 80The weight of a rig is an important variable in cost estimation and determines the amount of steel required in construction. Rig weight is generally considered proprietary, however, be-cause it indicates design benchmarks and con-struction performance metrics that are central to the competitive nature of the industry.

New semisubmersible vessel redefi nes heavy transport .................. 84A new semisubmersible heavy-lift vessel will soon be available that is expected to redefi ne the limits of heavy marine transport. The larg-est semisubmersible ever built, the DockwiseVanguard is designed specifi cally to enable operators and contractors to consider opportu-nities for mega offshore units which were until now considered unthinkable.

EXMAR launches FLRSU to exploit stranded gas offshore Colombia ........ 86EXMAR NV plans to invest $300 million on the fi rst-ever fl oating liquefaction, re-gasifi cation, and storage unit in an effort to develop stranded gas worldwide.

New polyethylene fi ber suitable for deepwater mooring ropes ............ 90A new high modulus polyethylene fi ber (HMPE) with improved creep properties can be used in permanent offshore mooring systems. Testing shows that ropes made with the new fi ber type retain the properties characteristic of HMPE such as high static strength and stiffness and yarn-on-yarn abrasion resistance.

Innovation, teamwork key to safe and cost-effective decommissioning........ 94Decommissioning projects across the globe are on the rise despite the high oil price and drive to extract more reserves from existing fi elds.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.omeda.com/os





the heart of the matter

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







Personnel and asset protection

��

��

Detection and management with

��

!��"��"�� "�

Reservoir evaluation��#��

��

��"!��

Performance optimization��

��$��

�!��""��$�%�$%��!��$��"��

Find out how to change to the secure

way to drill—a better way to drill.

Secure DrillingSM

Services

Gain a sense of security with

Weatherford’s expanded range of

services that minimize risk and

optimize life-of-well performance.

Tactical Technology™

in action:

The change will do you goodSM

weatherford.com

Visit ��

�� &��$��!��'

© 2012 Weatherford. All rights reserved.

Incorporates proprietary and patented Weatherford technology.

International EditionVolume 72, Number 8August 2012

D E P A R T M E N T S

ENGINEERING, CONSTRUCTION & INSTALLATIONBuoyant Tower offers new platform for shallow-water fi eld development ............. 98BPZ Energy has selected the Buoyant Tower design by Horton Wison Deepwater to develop the Corvina fi eld offshore Peru. The design concept was selected because it is less expensive than the fi xed platform alternative, and the fabrication and installation schedules were attractive.

SUBSEAControlling tomorrow’s deepwater developments .................................................. 100To address the future subsea development challenges of remoteness, environmental safety, and reliability, the oil and gas industry needs to explore new technological avenues. For instance, all-electric control systems are believed to be one of the major technological steps that will help create new opportunities.

FLOWLINES & PIPELINESNew automation concept promises to enhance deepwater pipeline integrity ...... 104DNV engineers have developed the X-Stream concept to improve the viability of gas transport pipelines in deep and ultra-deepwater, a long distance from shore.

Operators planning some 5,800 mi of offshore pipelines through 2017 ................ 108The inaugural Global Offshore Pipeline Construction Survey – a detailed project-by-project listing of all the major large-diameter offshore oil and gas pipeline systems being built, planned and studied – makes its debut.

COVER: Exploration and production activities remain strong offshore Eu-rope. Statoil, one of the key North Sea players, says that the Oseberg area is one of the most promising exploration areas on the Norwegian Continental Shelf. The Oseberg fi eld center includes three platforms, Oseberg A, B and D, connected to one another with bridges, in the southern part of the Oseberg fi eld; and the Oseberg C platform, which lies 14 km (approx. nine mi) north of the fi eld center. Photo by Øyvind Hagen, courtesy Statoil.

Online .................................................... 6Comment ............................................... 8Data ..................................................... 10Global E&P .......................................... 12Offshore Europe .................................. 18Gulf of Mexico ..................................... 20Subsea Systems ................................. 22

Vessels, Rigs, & Surface Systems ...... 24Drilling & Production .......................... 26Geosciences ........................................ 28Offshore Automation Solutions .......... 30Business Briefs ................................. 118Advertisers’ Index ............................. 123Beyond the Horizon .......................... 124

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.weatherford.com

http://www.weatherford.com/microflux





The change will do you goodSM

weatherford.com

Control Change��™��!��

Our automated system measures, analyzes and controls

changing wellbore conditions in real time. Now you can drill wells

that were once considered undrillable.

Weatherford’s �� control system is more than managed

pressure drilling. It’s secure drilling.

We call it Tactical Technology.™ You’ll call it money

in the bank. Visit�� or talk to a

Weatherford representative. We might change the way you

look at all of your service needs.

© 2012 Weatherford. All rights reserved. Incorporates proprietary and patented Weatherford technology.

Drilling

Evaluation

Completion

Production

Intervention

Closed-loop drilling

�� !�� "��#��$��

3,281

1,000

0

6,562

2,000

9,842

3,000

13,123

4,000

16,404

5,000

19,685

6,0000 20 40 60 80 100 120 140 160 180 200 220

13-3/8 in.

20 in.

9-5/8 in.

7 in.

De

pth

(ft

/m)

Weatherford’s Microflux controlsystem enabled total depth to bereached ahead of schedule.

Days

Microflux system Conventional

2 Losses—slow rate of penetration

3 Stuck bottomhole assembly—fishing

4 Losses—stuck pipe

5 Plugged and abandoned, sidetrack, lose well

1 Wellbore ballooning

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



__________________

http://www.weatherford.com

http://www.weatherford.com/microflux





PennWell1455 West Loop South, Suite 400, Houston, TX 77027 U.S.A.

Tel: (01) 713 621-9720 • Fax: (01) 713 963-6296

SALESWORLDWIDE SALES MANAGER

HOUSTON AREA SALESDavid Davis [email protected] Tel: (713) 963-6206

Mitch Duffy [email protected]

CUSTOM PUBLISHINGRoy Markum [email protected]

Tel: (713) 963-6220

PRODUCTION MANAGERKimberlee Smith [email protected]: (918) 832-9252 • Fax: (918) 831-9415

REPRINT SALESRhonda Brown [email protected]

Tel: (219) 878-6094 • Fax: (219) 561-2023

SUBSCRIBER SERVICEContact subscriber service for subscription questions,

address changes and back issuesTel: (847) 559-7501 • Fax: (847) 291-4816

Email: [email protected]

OFFSHORE EVENTSDavid Paganie (Houston) [email protected]

Eldon Ball (Houston) [email protected] Killough (Houston) [email protected] Vrettos (London) [email protected]

Jenny Phillips (London) [email protected]

CORPORATE HEADQUARTERSPennWell; 1421 S. Sheridan Rd., Tulsa, OK 74112

MemberAll Rights reserved

Offshore ISSN-0030-0608Printed in the U.S.A. GST No. 126813153

CHAIRMAN:Frank T. Lauinger

PRESIDENT/CHIEF EXECUTIVE OFFICER:Robert F. Biolchini

CHIEF FINANCIAL OFFICER:Mark C. Wilmoth

Publications Mail Agreement Number 40052420GST No. 126813153

CONTRIBUTING EDITORSF. Jay Schempf (Houston)

Nick Terdre (Norway)Gurdip Singh (Singapore)

SENIOR EDITOR,TECHNOLOGY & ECONOMICS

Eldon R. [email protected]

EDITOR-EUROPEJeremy Beckman

[email protected]

PRESENTATION EDITORJosh Troutman

[email protected]

TECHNOLOGY EDITOR,SUBSEA & SEISMIC

Gene [email protected]

ASSISTANT EDITORJessica Tippee

[email protected]

POSTER EDITORE. Kurt Albaugh, P.E.

[email protected]

VICE PRESIDENT and GROUP PUBLISHERMark Peters

[email protected]

MANAGING EDITORBruce A. Beaubouef

[email protected]

CHIEF EDITOR/CONFERENCE EDITORIAL DIRECTORDavid Paganie

[email protected]

®

6 Offshore August 2012 • www.offshore-mag.com

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

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

New maps, posters, & surveys • 2012 MWD/LWD Services Directory• 2012 World Mobile Rig Construction Survey• 2012 World Survey of Stimulation Vessels• 2012 Rotary Steerables Survey• 2012 Worldwide Seismic Vessels Survey

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

New videos ➤ Cascade and Chinook

Petrobras began production from the Cascade and Chinook fi elds in early 22012. The project features the fi rst FPSO in the US Gulf of Mexico, and the ddeepest fl oating production unit in the world.

➤ Williams Gulfstar-1 ProjectWilliams Gulfstar-1 project involves the development of a standardized fl oat-

iing production facility for the Gulf of Mexico, using a “classic” spar hull form aand topsides. Designed to operate in water depths from 3,000 to 8,500 ft, it can aallow for multiple subsea developments to be tied back to the host facility.

http://www.offshore-mag.com/video.html

New interactive feature➤ Bridon’s Neptune Quay facility

As operators seek to reach lower depths in ever-more challenging conditions, tthe oil and gas industry is demanding lifting systems that can deploy heavier wweights at greater depths. Such systems require multi-strand ropes that are llong, strong, and highly engineered. To accommodate such demands, Bridon is cconstructing the “Bridon Neptune Quay,” a £30-million ($48-million) factory that bby the end of 2012 will produce multi-strand ropes in lengths of more than 7,000 mm (22, 965 ft) and gross package weights of up to 650 metric tons (717 tons).

http://www.offshore-mag.com/bridon-channel.html

New On Demand Webcasts ➤ Mobility for Real-time Asset

Management on the RigFrank Cummings and Darrel Fanguy discuss how to remotely access data

aand deploy personnel using DOFERO’s customized HMI solution and rug-ggedized Class 1/Div 2 modifi ed “fi t for purpose” iPad. Attendees will learn howwtto shorten turnaround time in diagnosing issues in the fi eld, and implement a ssolution in a timely fashion.

http://www.offshore-mag.com/webcasts/offshore/2012/05/mobility-for-real-time-asset-management-on-the-rig.html

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

www.offshore-magg.com

Available atOffshore-mag.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________________________________



http://www.offshore-mag.com/webcasts/offshore/2012/05/mobility-for-real-time-asset-management-on-the-rig.html

http://www.offshore-mag.com/bridon-channel.html

http://www.offshore-mag.com/video.html

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







Operators are moving into deeper water environments

and expanding oil and gas production into remote

regions such as the arctic. Siemens is a driving force in

making these field developments technologically and

economically possible. With power supply from topside

or onshore, in-field subsea power distribution, control,

surveillance and processing technologies, we are en-

abling field developments in the most challenging

locations while improving recovery rates.

www.siemens.com/oilgas

Solutions for the oil and gas industry

Combining this with advancements in engineering and

quality for improved realiability and advanced monitor-

ing, Siemens also offers best-in-class OPEX minimization.

As an example, our industry leading subsea power

systems integrate medium voltage switchgear, step-

down transformer and variable-speed drives, enabling

wider adoption of large-scale processing equipment in

the subsea domain.

Siemens Subsea SolutionsEnabling enhanced recovery and reduced lifting costs

E5

00

01

-E4

40

-F1

78

-X-4

A0

0

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.siemens.com/oilgas






To respond to articles in Offshore, or to offer articles for publication,contact the editor by email ([email protected]).

C O M M E N T David Paganie • Houston

Confidence returning to NW Europe?On the heels of record-breaking participation at the 27th Licensing Round of the

UKCS, in its latest economic report Oil & Gas UK stated that investment in UK offshoredevelopment projects this year should approach £11.5 billion ($17.8 billion). This is anincrease of more than 30% compared with the total committed to UK offshore fields in2011. This period of increasing interest is due, in part, to the new measures announced by the UK government in March. One measure is a pledge to improve clarity on tax re-lief for North Sea decommissioning programs. The UK government expects that thesenew measures will persuade companies to free up more capital for investment, in turnincreasing or extending production from UK fields. For more on these and other E&Ptrends across Northwest Europe, turn to page 36 for an exclusive report by DeloittePetroleum Services.

Speaking of the North Sea, Tyson Bridger of Emerson Process Management con-tends that for all the focus on EOR (enhanced oil recovery) in offshore operations, littleattention has been paid to the crucial role reservoir modeling plays in bolstering recov-ery rates. In his article which starts on page 50, he notes that reservoir modeling isplaying an important role in increasing recovery rates and supporting EOR programsin the Norwegian North Sea. One example is Statoil’s Statfjord field, one of the oldestproducing fields on the Norwegian continental shelf (NCS) that today delivers recoveryrates of up to 66% and is scheduled to remain active until 2019.

One company – GDF SUEZ – is testing its confidence in the long-term viability of theUKCS by stating its intent to become a leading operator in the region. After 15 years as aco-venturer or exploration operator on the UKCS, GDF SUEZ is preparing for a leading development role, according to Jeremy Beckman, Offshore Editor-Europe. The com-pany has interests in over 40 UKCS licenses, 16 as operator, and claims to be the UK’seighth-largest offshore acreage holder. But Juliet and Cygnus in the southern North Seawill be its first major operated UK projects. Beckman’s full report begins on page 40.

In the Norwegian sector of the North Sea, Statoil continues to advance its strategyto improve oil recovery (IOR) from new and existing fields. Part of its approach hasbeen to roll out a new fleet of rigs engineered to its specifications for cost savings anddrilling efficiencies. A category has been assigned to each new rig type: Category A, forlight well intervention; Category B, for heavier intervention and workover; CategoryD, for drilling and completing new development wells; and Category J, which refers tojackup rigs for development work. Offshore contributing editor Nick Terdre examinesStatoil’s ongoing IOR initiatives, beginning on page 32.

Inaugural pipeline surveyTo complement Offshore’s existing series of maps, posters, and surveys, I am pleased

to introduce in this issue the inaugural “Global offshore pipeline construction survey.”Prepared by Offshore managing editor Bruce Beaubouef, it includes the technical speci-fications and the latest updates on the status of the major offshore oil and gas export/transmission pipeline projects around the world. Approximately 5,840 mi (9,399 km) ofpipeline projects are represented in the survey. See page 108 for the complete survey.

The UK government expects that these new measures will persuade companies to free up more capital for investment, in turn increasing or extending production from UK fields.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM




http://www.nylacast.com





qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



__________

http://www.c-a-m.com





Worldwide day rates

Year/Month Minimum Average MaximumDrillship2011 July $90,000 $441,892 $690,0002011 Aug $90,000 $429,634 $690,0002011 Sept $155,000 $432,551 $690,0002011 Oct $155,000 $405,144 $690,0002011 Nov $155,000 $411,952 $690,0002011 Dec $155,000 $414,368 $690,0002012 Jan $155,000 $430,985 $690,0002012 Feb $155,000 $437,841 $671,0002012 Mar $155,000 $437,017 $671,0002012 Apr $157,000 $441,477 $671,0002012 May $157,000 $438,030 $671,0002012 June $90,000 $442,307 $671,000Jackup2011 July $35,000 $106,279 $339,0002011 Aug $35,754 $107,135 $339,0002011 Sept $35,754 $106,368 $339,0002011 Oct $20,000 $105,221 $339,0002011 Nov $20,000 $105,147 $339,0002011 Dec $36,000 $106,093 $339,0002012 Jan $36,000 $107,697 $339,0002012 Feb $36,000 $108,329 $339,0002012 Mar $36,000 $108,662 $358,0002012 Apr $30,000 $108,772 $358,0002012 May $36,000 $109,468 $358,0002012 June $30,000 $111,484 $358,000Semi2011 July $83,000 $359,489 $665,0002011 Aug $85,000 $364,189 $665,0002011 Sept $137,000 $366,983 $665,0002011 Oct $137,000 $366,962 $665,0002011 Nov $137,000 $363,352 $655,0002011 Dec $137,000 $361,232 $655,0002012 Jan $30,000 $361,367 $655,0002012 Feb $137,000 $362,962 $655,0002012 Mar $137,000 $358,403 $655,0002012 Apr $137,000 $362,958 $655,0002012 May $125,000 $362,215 $655,0002012 June $125,000 $363,267 $655,000Source: Rigzone.com

Worldwide offshore rig count & utilization rateJuly 2010 – June 2012

950

850

750

650

550

450

350

100

90

80

70

60

50

40

No

. of

rig

s

Fleet u

tilization

rate%

July

10

Oct10

Jan 11

April11

July

11

Oct11

Jan 12

April12

Contracted fleet utilization Total fleet Contracted Working

So

urc

e: I

HS

Total reserves onstream Arctic Ocean,Norway, and UK North Sea 2007-2017

100

90

80

70

60

50

40

30

20

10

0

Canada (Arctic Ocean)

Shtokman

UK

USA (Alaska)

Russia (FSU)

Norway

2007

Source: Infield Systems Ltd.

2008 2009 2010 2011 2012 2013 2014 2015 2016 2017

Per

cen

t

G L O B A L D ATA


This month Infield Systems looks at the expected reserves onstream in the North Sea, the NorwegianSea, and the emerging Arctic region. Between 2007 and 2011, new reserve additions were dominated by Norwayand the UK, holding a respective 69% and 28% of total reserves onstream. A small proportion of reserves alsoentered production offshore Alaska. Historically, key operators have included Statoil, holding a 48% share of new reserves onstream during the 2007-2011 period, and Shell with a 34% share of reserves onstream. Between 2007 and 2017, reserves are expected to come onstream offshore Norway, UK, Alaska, Russia, and the Canadian Arctic. The number of operators to bring fields onstreamwithin these waters has risen from 33 to an expected 63 by 2017. Leading players are expected to remain Statoil, Gazprom, and BP. Going forward, key developments in terms of reserve additions include Johan Sverdrup on the

Norwegian continental shelf, which Infield Systems forecasts to begin production in 2017. Gazprom’s Prira-zlomnoye field, expected to come onstream before the end of 2012, is to be the second largest development in terms of prospective reserves during the timeframe. Infield Systems also anticipates significant reserves to enter production on the delayed Skarv field offshore Norway by the end of 2012. However, the most signifi-cant development expected to enter production during the forecast timeframe is that of Gazprom’s Shtokman, holding 73% of total reserves onstream throughout the following five-year period. Within the Canadian Arctic,reserves are expected to be brought onstream toward the end of the current forecast timeframe by ExxonMo-bil and BP Canada Energy Co.

– Catarina Podevyn, Analyst, Infield Systems Ltd.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM




http://www.Rigzone.com





When Every Lift Counts

When your people, your project and yourreputation are on the line, you can’t affordlifting and rigging equipment that doesn’tmeasure up.

You can trust Delta Rigging & Tools will.

Every Lift. Every time.

Call us for complete lifting and rigging equipment, tools, service and support for any size project world wide.

Rentals • Sales • Service

• Safety• Service• Quality• Value

Delta Rigging & Tools • 1.877.408.8008 • Visit us on the web at: www.deltarigging.com

You Can Trust Delta Rigging & Tools

TM

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.deltarigging.com





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


Deepwater driving exploration drilling

Wood Mackenzie predicts a 15% increasein conventional exploration spending world-wide this year to about $85 billion. Accordingto Andrew Latham, VP Exploration Service,the industry is investing heavily because re-turns are so strong. Results from wells drilledduring the first half of 2012 suggest this couldbe the best year ever, he added with a rough-ly 50-50 split between oil and gas.

“Deepwater is the key to this success,”Latham said. “The total volume being foundin deepwater is now more than the yield fromonshore exploration or from shelf drilling. Anddeepwater is typically more oily. Fewer wellsare drilled in deepwater, but those drilled addmultiples to reserves, and that’s the reasonwhy deepwater remains so attractive.” East Af-rica and the eastern Mediterranean Sea haveprovided most of the major new gas finds.

Latin America/South AtlanticZarubezhneft has contracted the drilling rig

Songa Mercur for exploration offshore Cuba,starting in late November. The rig left Malay-sia last month for Trinidad where it is due toremain on standby until the program begins.

•••Chevron has agreed to take a 50% interest

in blocks 42 and 45 offshore Surinam fromKosmos Energy. Both are 155 mi (250 km)from the capital Paramaribo, and extend overwater depths of 650-8,500 ft (200-2,600 m).Kosmos will remain operator during the ex-ploration phase, handing the reins to Chev-ron in the event of a commercial discovery.

•••Petrobras has discovered heavy oil (15°

API) in the post-salt Grana Padano prospectin the Espirito Santo basin. The well wasdrilled in the BM-ES-24 concession in 1,208m (3,963 ft) of water, 58 km (36 mi) offshoreVitoria, and 64 km (40 mi) from the Golfinho

field. In the presalt Santos basin, Petrobrasfound much lighter oil via a well on thesouthern part of the Sapinhoa field in theSul de Guara region. The company planneda formation test to evaluate the productivityof the oil reservoirs.

In the Campos basin, Petrobras has agreedto transfer operatorship of the Xerelete conces-sion to Total, leaving both parties with a 41.2%interest, the balance held by BP. The permit in-cludes the 2001 heavy oil find Xerelete, 40 km(25 mi) west of the recent giant Pao de Azucardiscovery. Drilling on a presalt prospect be-neath Xerelete could start next year.

•••Premier Oil is to farm into 60% of Rock-

hopper’s license interests offshore the Falk-land Islands. These include the proposedSea Lion oil and gas development in theoffshore North Falkland basin. The entrypackage totals just over $1 billion, includinga carry of up to $722 million for Rockhop-per’s development costs. The parties havealso agreed to pursue exploration of analo-gous plays offshore southern Africa.

Italy’s Edison International is taking a 25%stake in Falkland Oil and Gas’ northern arealicenses and 12.5% of its southern area per-mits, and will pay its share of upcoming andhistoric drilling costs.

West AfricaSierra Leone’s government has issued

provisional awards for various explorationblocks under the country’s third offshorebid round. Blocks SL 8A-10 and SL 8B-10went to a consortium of Chevron Sahara,Noble Energy, and London-based ODYE.They cover a total area of 5,604 sq mi (14,514sq km) and contain leads in early to late Cre-taceous oil-prone marine source rocks. Af-rican Petroleum and Kosmos Energy wereprovisionally awarded block SL-4A-10.

•••Anadarko has discovered light oil in the

deepwater Paon structure off Cote d’Ivoire.Paon-1X was drilled in block CI-103 in 7,195ft (2,193 m) of water, encountering morethan 100 ft (31 m) of 40° API Turonian oilpay. It confirmed the extension of the UpperCretaceous fan system from offshore neigh-boring Ghana to the east.

•••Marathon Oil is re-entering Gabon. The

company has agreed to farm into a 25% inter-est in the Total-operated Diaba license G4-223 and related permit, which extends morethan 9,075 sq km (3,504 sq mi) offshoresouthern Gabon. Water depths range from100-3,500 m (328-11,483 ft). Late last year,Total processed data from a 6,000-sq km(2,316-sq mi) 3D seismic survey. The part-ners plan to start exploration drilling earlynext year on presalt targets.

•••Esso Exploration Angola (Block 15) has

started production from the Kizomba Satel-lites Phase 1 project, which entails drilling18 subsea wells tied back to the existingKizomba A and B FPSOs. The initial phaseof this program should deliver 100,000 b/dof oil and recover a total of 250 MMbbl fromthe Mavacola and Clochas fields, 95 km (59mi) offshore Angola in 4,500 ft (1,372 m) ofwater.

Mediterranean SeaItaly’s government has eased restrictions

on offshore exploration and production,imposed in August 2010 as a result of theMacondo blowout in the Gulf of Mexico. Al-though a range of conditions remain in placefor activities within 12 mi (19 km) of theItalian coastline, they no longer apply to ap-plications for production concessions underreview at the time the ban was introduced.

As a result, Medoilgas Italia believes theway is now open to request granting of aconcession for the Ombrina Mare oil andgas field in the central Adriatic Sea off east-ern Italy. The company had received tech-nical approval for its development plan in June 2009, and was awaiting environmentalapproval when restrictions came into force.

Another operator affected by the lockout,Dublin-based Petroceltic, has been awardedtwo new six-year exploration licenses closeto existing oil and gas fields in the centralAdriatic. B.R 270 and B.R.271 are in waterdepths of 30-150 m (98-492 ft), with pros-pects identified in at least three working hy-drocarbon plays.

•••BP has brought onstream the $334-mil-

lion Seth gas field development in Egypt’sRas El Bar concession, 60 km (37 mi) off-shore in the East Nile Delta. The locationis close to the producing Ha’Py and Denisefields. Development called for a six-slot,normally unmanned wellhead platformwith gas exported via the Denise (Pliocene)pipeline to the El Gamil terminal near PortSaid. Under a first phase, two wells in thewestern part of the Seth reservoir shouldproduce about 240 bcf (6.8 bcm). Phase2 involves two wells on the eastern part ofthe field which should both be onstream byend-2012, lifting total production above 250 MMcf/d (7 MMcm/d).

•••ATP East Med found gas with its first ex-

ploratory well offshore Israel in the deepwa-ter Levant basin. The Shimshon well, drilledin 3,622 ft (1,104 m) of water, encounteredmore than 62 ft (19 m) of pay in the Bet Gu-vrin sands.

Another deepwater rig, the semisubmersibleNoble Homer Ferrington, was due to start drill-

Global reservesadded per wellduring 2002-2011.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Explosion-protected pneumatic or hydraulic hoists and crane systems from J.D. Neuhaus can be wholly relied on. Under water or under other extreme conditions. In ship repair and 70 further industrial sectors. In 90 countries world-wide. www.jdngroup.com

ENGINEERED FOR

EXTREMESIN

TEV

I

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.jdngroup.com





G L O B A L E & P

ing the Myra-1 well last month for GeoGlobalResources. The location is 80 km (49.7 mi) off-shore Israel in 1,500 m (4,921 ft) water depth.The well was expected to take 50 days to drill.

Caspian SeaThe Shah Deniz consortium has selected

the Nabucco West route for exporting gas tosoutheast and central Europe from Stage 2 ofthe Shah Deniz field development offshoreAzerbaijan. Operator BP said one of the clinch-

ing factors was the greater maturity of the Na-bucco West proposal, which gave the partnersconfidence this pipeline project could be deliv-ered on the same timescale as the Stage 2 de-velopment. This will involve installation of twonew production platforms and 26 subsea wellson the Shah Deniz field, and 500 km (311 mi)of associated subsea pipelines.

Also in the Azeri sector, Total has submitteda “Notice of Discovery and Commerciality” forits Absheron gas/condensate discovery, drilled

last September 100 km (62 mi) southeast ofNaku. The company claims gas reserves couldbe in the range 5-10 tcf (142-283 bcm). Lastmonth a side track was under way from theAbsheron X-2 well toward the northern part ofthe elongated Abhseron structure. Further ap-praisal drilling could follow next year.

•••

Blue Water Shipping has been deliveringa newbuild jackup to the Astrakhan shipyardat Astrakhan on the northern coast. In orderto enter the land-locked sea the LeTourneauS116 (E) rig, built by Lamprell in the UAE, hadto be broken down into three main shipmentsthat were transported on barges through Rus-sia’s Volga-Don river system. The client is Eur-asia Drilling Co.

Middle EastTechnip has an EPIC contract from Dubai

Petroleum for the South West Fatah and Falahfields, both 90 km (56 mi) offshore Dubai inwaters up to 53 m (174 ft) deep. The contractscope covers replacement of a 12-in. (30.5-cm)gas pipeline and six 18-in. (45.7-cm) waterinjection lines. Technip will use the S-lay ves-sel G1201 for both pipelay and diver supportoperations.

East AfricaKenya has awarded production sharing

contracts for four ultra-deepwater blocks in theLamu basin. Eni was assigned 100% of L-21,L-23, and L-24 covering a total area of more than35,000 sq km (13,513 sq mi). Total gained 100%in L-22, where water depths range from 2,000-3,500 m (6,562-11,483 ft). In both cases, the ini-tial focus will be on seismic acquisition.

•••Statoil and ExxonMobil have another poten-

tially large gas discovery in ultra-deepwater off

Bluewater Caspian EDC transshipment.

®

t»

Rigless and Subsea P&A»

Wireline Services»

Topside and Subsea Cutting»

Diving and Marine»

Heavy Lift»

Installation & Construction»A TETRA Company

®

A TETRA Company

®

TETRA Technologies, Inc.

[email protected] www.tetratec.com +1.281.367.1983

PROVEN WELL ABANDONMENT &DECOMMISSIONING SOLUTIONS

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



Project Engineering and Managemen

http://www.tetratec.com





Please visit us at our standin hall C - 301

Frank Mohn Flatøy ASN-5918 Frekhaug - Norwaytel. +47 55 999 400 - fax. +47 55 999 [email protected]

Pumping Systems

- to the world oil & gas industry...

In the international oil and gas industry Frank Mohn Oil & Gasare recognised as a leading designer, manufacturer and supplierof complete pumping systems for both onshore and offshoreapplications.

Keywords are solid craftmanship combined withinnovation and world-wide service. One system,one supplier, time saving and cost effective.

- Firewater Pumps

- Seawater Lift Pumps

- Water Injection Pumps

- Crude Offloading Pumps

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.framo.com





Over 30 years Oil & Gas experience

• platforms

• jackets

• compression modules

• living quarters

• process modules

HSM Offshore BV

P.O. Box 212

3100 AE Schiedam NL

T +31 (0)10 - 427 92 00

F +31 (0)10 - 427 93 01

E [email protected]

I www.hsm.nl

Serving the industry

id no. 10041107 id no. 24073

ONS

Dutch Pavilion

Booth 996

G L O B A L E & P

Tanzania. The Ocean Rig Poseidon drilled thewell on the Lavani prospect in 2,400 m (7,874ft) of water, encountering 95 m (312 ft) of good-quality reservoir sandstone. Statoil estimatesin-place resources at 3 tcf (85 bcm).

In Mozambique’s Offshore Area 1 to thesouth, in the Rovuma basin, Anadarko main-tained its strike rate, finding more than 300 net ft (92 m) of net gas pay in the Atum pros-pect in two Oligocene fan systems. Earlyanalysis suggested a connection to the Gol-finho discovery drilled earlier in the year, 10 mi (16.5 km) to the northwest. The partnersplanned to follow up with appraisal drillingand drillstem testing on both structures.Anadarko believes this newly identifiedcomplex could hold recoverable reservesin the range of 10-30 tcf (283-850 bcm), withfurther exploration upside nearby.

Asia-Pacifi c/AustraliaThe jackup Kantan 6 started drilling a

third appraisal well last month on the North-Veninskaya formation in the Veninsky li-cense block, 7 km (4.3 mi) offshore SakhalinIsland, eastern Russia, in 25 m (82 ft) waterdepth. Venineft, a joint venture between Ros-neft and Sinopec, is operating the well on the block as part of the Sakhalin-3 project.Drilling and subsequent geological and geo-

physical surveys will continue through end-September.

•••Primeline Energy has signed a produc-

tion sharing contract with CNOOC for block33/07 in the East China Sea. The block is 390km (242 mi) offshore Shanghai and extendsmore than 8,877 sq km (3,427 sq mi) in a wa-ter depth of 90 m (295 ft). Primeline will ac-quire 3D seismic data and drill wells at its soleexpense during the exploration period, whileCNOOC can take an interest of up to 51% inthe event of any commercial discoveries.

•••Oil and gas has started flowing through

the H4 wellhead platform from the Te GiacTrang field in block 16-1 offshore southernVietnam. At peak, the facility will deliver55,000 b/d to the Armada TGT 1 FPSO. Con-currently, the PetroVietnam-owned jackupPVD-II is working on a four-well infield pro-gram at the H1 wellhead platform.

In the Gulf of Tonkin off eastern Viet-nam, Eni is teaming up with KrisEnergy andNeon Energy to explore blocks 105-110/04and 120 covering 15,600 sq km (6,023 sq mi) in the Song Hong and Phu Kanh basins. Re-cent drilling in the region suggests prospec-tivity for gas. Eni will operate and plans todrill at least two exploratory wells.

•••Petronas has signed an amended PSC and

two new exploration contracts with Hess inthe offshore North Malay basin for adjacentblocks PM302, PM325, and PM326B. Theagreement opens the way to development of nine stranded gas fields with combinedreserves of about 1.7 tcf (48 bcm) and con-struction of a new gas-gathering, process-ing, and transportation hub. The partnersplan an early production system phase, tar-geting first gas in early 2013, followed bya full-field development that should deliverabout 300 MMcf/d (8.5 MMcm/d) from 2Q2015 onward. Total investment is estimatedat $5.2 billion.

•••ConocoPhillips and Santos are farming

out a 37.5% interest to South Koreas’ SKGroup in the Caldita and Barossa gas discov-eries offshore northern Australia. In return,SK will fund the first $260 million of costsfor a three-well appraisal campaign slated tostart next year. Additionally, it will fund up to$90 million of pre-front-end engineering anddesign (pre-FEED) and FEED studies linedup for 2014. Development options include floating LNG, a tie-in to ConocoPhillips’ off-shore Bayu Undan complex, or a tieback toan existing LNG plant at Darwin. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.hsm.nl





Performance under pressure

LEARN MORE, VISIT WWW.DRAEGER.COM/PASLITE OR CALL: 1-800-858-1737

Made possible by the next generation of Dräger breathing apparatus

Sometimes, a single decision can mean the difference between uninterrupted operations and a plant closure. The

new Dräger PSS 3000 and Dräger PAS Lite industrial compressed air breathing apparatus protect your workers

as they do maintenance work – even in hazardous areas. By choosing Dräger breathing apparatus, you can enable

peak performance in the face of tremendous pressure – so that “uptime” means “all the time” at your plant.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________________

http://WWW.DRAEGER.COM/PASLITE





Tor

Statoil operatorStatoil partnerOther licensesOilGasGas andcondensate

Gyda Stavanger

King Lear

PL333PL333 PL146

2/4-18

2/4-14Albuskjell

Vest Ekofisk

Ekofisk

2/4-21 & 2/4-21A

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


UK investment climate improvesInvestment in UK offshore development projects this year should approach £11.5 billion ($17.8 billion), according to the latest Eco-nomic Report from Oil & Gas UK. This is an increase of more than 30% compared with the total of £8.5 billion ($13.1 billion) commit-ted to UK offshore fields in 2011.

Various large projects were launched last year, notably west of Shet-land, and others are close to moving forward. The feel-good factor ispartly due to the measures announced by the UK government in Marchto stimulate new activity. Oil & Gas UK’s chief executive Malcolm Webbsaid: “Following a period of sustained fiscal uncertainty, the industry isnow more confident that the government recognizes the maturity andcostliness of the province relative to other investment destinations.”

However, production from UK fields dropped unexpectedly by19% last year, due to lower gas demand and unplanned stoppages re-lated to asset integrity work, averaging about 1.8 MMboe/d. At thesame time, production costs rose by a quarter compared with 2010to $17/boe, while the number of exploration wells drilled was half the level of the previous year, although the success rate was high.

Following a pledge in this year’s budget to improve clarity on taxrelief for North Sea decommissioning programs, the government haspublished a consultation, due to run untilOct. 1. This proposes the creation of De-commissioning Relief Deeds, to specifylevels of relief that oil companies may re-ceive. It also promises greater certaintyon the amount of relief they will be enti-tled to when faced with liability for decom-missioning costs of another party that hasdefaulted.

The aim is to reduce the level of secu-rity required when one party acquiresanother’s assets, or when companies op-erate fields jointly. That uncertainty hasbeen holding back offshore asset trans-actions and infrastructure upgrades, butthe government hopes the new initiativewill persuade companies to free up morecapital for investment, in turn increasingor extending production from UK fields.

Chevron, Shell launch field studies

March’s tax proposals appear to have had the desiredeffect, with two of the majors pressing forward with developmentsthat might otherwise have remained stalled. When the Treasury un-expectedly jacked up North Sea petroleum taxes last year, Chevronresponded by reporting a decrease in net value in its Lochnagar/Rosebank oil fields west of Shetland. It added that it was in discus-sions with the Treasury on field allowances to improve the project’seconomics.

This request has come to pass, and Chevron has initiated front-endengineering and design for the 240-MMboe Rosebank field, 80 mi(49.7 km) northwest of Shetland, close to the median line with theFaroe Islands. The water depth of 1,100 m (3,700 ft) is deeper thanany UK development to date, and the location is remote from existingoil pipelines or oil processing plants.

Chevron is working on a scheme involving an FPSO with waterinjection wells, subsea facilities, and a gas export pipeline. Accordingto analysts BritBoss, both a ship-shape and Sevan cylindrical-shapefloater have been under consideration. One of Chevron’s partners,OMV, also has a stake in the Hess-operated Cambo discovery, 25 km(15.5 mi) south of Lochnagar, which is close to a development deci-sion. One option could be a tie-in to the Lochnagar facilities.

Shell, which in recent years has been selling off its UK North Sea as-sets, has provisionally engaged SBM Offshore to lease and operate anFPSO for the Fram field development in the central North Sea, subjectto a final investment decision. This was another project apparently imper-iled by last year’s tax overhaul. The hull will be formed from a convertedAframax tanker, and will incorporate an internal turret mooring system,with the oil offloaded to shuttle tankers and the gas sent to Scotland viathe Fulmar pipeline. According to BritBoss, the FPSO will have produc-tion capacity for 40,300 b/d of oil and 220 MMcf/d (6.2 MMcm/d) of gasfrom eight subsea production wells at two separate drill centers.

Dana Petroleum has started detailed engineering for its $1.5-bil-lion Western Isles project that will extract 45 MMbbl of oil from theHarris and Barra fields, 160 km (99 mi) east of the Shetlands. SevanMarine, which has been working on the FEED for over a year, willwork with Dana on the FPSO hosting the nine-well development.

Norway wells open new provincesNineteen exploration wells were spudded offshore Norway dur-

ing the first half of this year, two down on the corresponding periodfor 2011. According to the Norwegian Petroleum Directorate, thefigure might have been higher, but some of the contracted rigs were

delayed finishing operations elsewhere.By mid-year there had been seven new

discoveries across the Norwegian conti-nental shelf. The largest in volume terms,both operated by Statoil, were the Havisoil find in the Barents Sea and more re-cently, the HP/HT King Lear deep gas/condensate find in the southern Nor-wegian North Sea, drilled by the jackupMaersk Gallant 20 km (12.4 mi) northof the Ekofisk complex. This well was afresh look at a structure Saga Petroleumpreviously attempted to drill in the 1990sbefore pulling out due to technical issues.

Statoil estimates potential reserves atKing Lear in the range of 70-200 MMboe,and says it will evaluate standalone andtieback development options in an areabetter known as an oil province. Alter-natively, it may bring in resources fromother gas fields in the area, which couldinclude Tommeliten, for a new gas hub.Partner Total was awarded two blocks

nearby under the last APA licensing round and is lining up an inven-tory of similar exploration prospects.

In the Danish North Sea, Maersk Oil plans to drill an HP/HT wellon the Maja license after securing a two-year extension for this andthe adjacent Gita concession from the Danish Energy Agency. Maja isclose to the Maersk-operated Harald field. The well will be drilled toa TD of about 5,000 m (16,404 ft). Drilling will start following comple-tion of pressure modeling studies. A typical Danish HP/HT well costsabout $100 million to drill, the company says.

Study highlights well control failingsPetroleum Safety Authority Norway is urging greater investigation

of well control incidents on the Norwegian continental shelf, in re-sponse to findings from a new study by technical institute SINTEF.Between 2008 and 2011, the number of well control incidents report-ed rose from 11 to 28, but during 2003-2010, only 10 out of a totalof 146 incidents were investigated. Respondents generally pointed totechnology as the main cause, and this was often the case, PSA said.But the percentage of technical measures implemented by the industryremains low, it concluded. �

Location of Statoil’s King Lear discovery.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








��

��

��

��

��

�� !" �� !�# �� $%��& �� '%��& �� (�� ) ��&%�� &��

��*� �� %+�� ,�-��

�� .�� &� ��

�� /��& ��0�� 1�� 2��

�� 3� � ��& ��

� � ��

��

)�� 4��

)��5 6,� 7�82� -29 9� ��

�� :��%��

��3 �� 3 ��

��

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_______________

__________

http://www.heerema.com

http://www.heerema.com





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


GoM deepwater outlook positive through 2016

E&P activity in the Gulf of Mexico contin-ues to rebound after its nadir in 2010, and arecent study by consulting firm Wood Mack-enzie confirms this positive outlook. The re-port, entitled “Deepwater GoM Production toRebound Strongly,” predicts that the produc-tion outlook will continue to improve through2016, but it also suggests that there will be afew more bumps in the road until productionreturns to pre-Macondo levels.

Wood Mackenzie observes that the deepwa-ter GoM will be a key production growth areafor a number of the majors’ portfolios over thenext four years. The report notes that BP standsout in this analysis, with the return of produc-tion from deepwater Gulf representing 45% ofits global increase over this period. The regionis also a key driver of near-term expansion forShell, Chevron, ExxonMobil, and Statoil.

If this growth is to be achieved, the recentdecline in deepwater GoM production will needto be reversed. The report notes that produc-tion declined by almost 18% to 1.4 MMboe/din 2011. Despite a relatively calm hurricaneseason, the decrease was expected due to per-mit-approval constraints and a tight rig marketwhich delayed development. Wood Mackenziesays that it expects production to continue de-clining this year before reversing course withsignificant year-over-year gains to a new peakof over 2.0 MMboe/d in 2016.

The report also notes that production wasexpected to drop in 2011, and in fact came inat 1.4 MMboe/d – a level not seen since 2008.This represents an 18% decrease from 2010.Production is expected to continue its decline in2012 by another 7%, to 1.3 MMboe/d, resultingin a loss of 0.5 MMboe/d since its peak in 2009.

Besides the slow-down in the permit-ap-proval process and a tight rig market, the re-port notes that most of the decline is due to afew fields. Atlantis, Mad Dog, Mars, and Thun-der Horse will account for 60% of the declinebetween 2009 and 2012, with Thunder Horsehaving the largest decline at around 95,000boe/d. These fields were some of the biggestproducers prior to Macondo.

Things are expected to get better over thenext few years. Production is expected to im-prove steadily post-2012 to 1.6 MMboe/d by2014. Activity at several key fields, includingthe four with the greatest declines, and addi-tional production from several new fields willbe key to reversing this trend.

The return to the pre-Macondo level is expect-ed by 2015 and a new high of over 2.0 MMboe/dis expected in 2016. Growth from 2014 to 2016will be spearheaded by many new, large fields,such as Hadrian, Jack/St. Malo, and Lucius, aswell as development activity at legacy assets.

Future production will be more challenging,as activity moves to deeper water. The report

states that the majority of the new fields willbe located in ultra-deepwater (> 1,500 m, or ap-prox. 4,921 ft) by 2015. It is also moving to theoil-rich subsalt Pliocene/Miocene and LowerTertiary plays. These frontier fields will requireinnovative advancements in engineering andtechnology, and will be more expensive to de-velop. High oil prices and lessons learned fromPerdido and Cascade/Chinook will facilitateprogress in these emerging plays.

Growth will be driven mostly by subsalt fields,which will account for over 65% of production by2016. Development work at the legacy subsaltMiocene Atlantis, Mad Dog, and Thunder Horsefields, as well as the supra/subsalt Mars project,will contribute a combined290,000 boe/dby 2016.

By 2016, production from the new subsaltPliocene/Miocene Hadrian and Lucius fieldsis expected to contribute a combined 175,000boe/d. Meanwhile, the subsalt Lower TertiaryJack/St. Malo and Cascade/Chinook develop-ments will add a combined 150,000 boe/d.

The report also projects that productionfrom conventional Pleistocene, Pliocene, andMiocene fields will remain relatively steadyfrom 2012 to 2014, and then decline. In theMississippi Canyon protraction area, LLOG’sWho Dat field and Noble’s Galapagos project– which includes the Isabela, Santa Cruz, andSantiago fields – will counter the trend andadd a combined 55,000 boe/d by 2016.

Eight companies – Anadarko, BP, Shell,Chevron, BHP Billiton, ExxonMobil, Statoil,and Petrobras – out of 63 with production indeepwater GoM are expected to account for93% of the growth from 2012 to 2016.

The consulting firm notes there is no guar-antee about the rebound, as several significantrisk factors remain. The most serious of therisks that could retard this positive predictionis in economics. Oil price declines to $70/bblor less would likely delay or even suspenddeepwater plans.

Danny II well discovers oilHelix Energy Solutions Group reports

an oil discovery at the Danny II explorationwell at the Bushwood field in Garden Banksblock 506, approximately 145 mi (233 km)offshore from Galveston, Texas, in the Gulfof Mexico. The Danny II exploration well en-countered more than 70 ft (21 m) of net pay.

The Danny II exploration well was drilled toa TD of 14,750 ft (4,496 m), in a water depth ofapproximately 2,800 ft (853 m). The well is be-ing completed and probably will be developedvia a subsea tieback to Helix’s East Cameronblock 381 platform 31 mi (50 km) to the northin 370 ft (113 m) of water. First productionfrom Danny II is expected in 4Q 2012.

Galapagos flows,Deep Blue appraisal stops

All three Noble Energy Inc. wells at the Gala-pagos development in the deepwater Gulf ofMexico are now producing and at rates greaterthan forecast. At the same time, Noble is dis-continuing appraisal of the Deep Blue prospect.

Production at Galapagos started from theBP-operated Isabela field in early June, followedby the Noble Energy-operated Santa Cruz andSantiago fields. With the addition of Galapagos,Noble Energy’s deepwater Gulf of Mexico pro-duction has increased to approximately 30,000boe/d, with more than 80% of that as oil.

On Deep Blue, Noble and partners will notcontinue with appraisal work even thoughthe initial well and a side track both encoun-tered hydrocarbons. The Deep Blue well orig-inally spudded late in 2009 and the side trackwas under way when the moratorium follow-ing Macondo became effective. Noble Energywas required to suspend operations, and therig working at that time was released. After themoratorium was lifted, another rig was certi-fied under new regulatory requirements andthe side track was finished. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________

http://www.wildwell.com





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


Contracts awarded for subsea workSubsea 7 S.A has won a SURF contract valued at $175 million from

ATP Oil & Gas (UK) Ltd. /Bluewater, the operator on the Cheviotfield, 120 km (75 mi) east of Shetland. The Cheviot development willuse a moored floating process facility which will import oil and gasfrom four satellite drill centers. Oil will be exported via shuttle tank-ers and gas will go to a third-party host facility.

Also at Cheviot, Duco Inc. has won a contract to engineer, projectmanage, and fabricate four static steel tube umbilicals, four dynamicthermoplastic umbilicals, and a thermoplastic subsea interventionvalve umbilcal. Total length is 12 km (7.5 mi) and the umbilicals areto control four drill centers. Duco also will provide the subsea dis-tribution system which includes umbilical termination assemblies,subsea distribution units, 64 hydraulic and electrical flying leads,and other equipment.

Norway approves subsea compression for Åsgard

Development of the Åsgard subsea gas compression was ap-proved in the Storting (Norwegian parliament). The new installationis expected to increase Mikkel and Midgard production by about280 MMboe. According to plan, Åsgard subsea gas compression willbe ready for start-up in the first half of 2015.

“Subsea gas compression is an important step on the road to-wards our ambition of installing the elements for a subsea plant by2020. Processing on the seabed could open up areas that are not cur-rently accessible with traditional technology,” said Anders Opedal,who leads the project technology and drilling.

Elsewhere on the Norwegian continental shelf, A/S Norske Shellhas named Aker Solutions to supply subsea connections for theDraugen field. Aker will deliver complete tie-in connection systems

for production flowlines and umbilicals in the field. Equipment deliv-eries will be made from 2012 to 2013. Draugen is in block 6407/9 inthe Haltenbanken area of the Norwegian Sea, about 140 km (87 mi)from Kristiansund, Norway, at a sea depth of 250 m (820 ft).

Subsea equipment advancesSubsea Vision has taken delivery of a Saab Seaeye Cougar XT

Compact, the low profile ROV specially designed for working inhigh current areas and where access is restricted. Subsea Vision’simmediate target market for the Cougar XT Compact is the NorthSea oil and gas industry. Saab Seaeye says the ROV comes with sixthrusters: four vectored horizontal and two vertical, each with veloc-ity feedback for control in all directions, and interfaced to a controlsystem and solid-state gyro for enhanced azimuth stability.

First Subsea has used its automatic release clamp connector forbend stiffeners to successfully attach six Technip bend stiffenersto risers for the Glas Dowr FPSO in Kitan oil field. The ARC tech-nology connected 2 in. gas lift risers, and 6-in. production risers tothe FPSO’s I-Tubes. Kitan is in the Joint Petroleum Development Area of the Timor Sea administered by Timor-Leste and Australia.Kitan is operated by Eni (40%) in permit JPDA 06-105, with INPEXTimor Sea, Ltd. (35%) and Talisman Resources (JPDA 06-105) PtyLtd. (25%) as joint venture partners.

Marathon to expand subsea drill centers in Alvheim

Marathon Oil Norge AS has awarded Technip a contract for on-going expansion of the subsea drill centers at Kneler B and Volundin the Alvheim area in the North Sea. The water depth is around120 m (394 ft) and the subsea work will be done using ROVs anddivers. �

Aker Solutions has sent subsea manifolds and riser bases to Eni Norge’s Goliat project in the Barents Sea. Aker’s Goliat contract covers engineer-ing, procurement, and construction of a complete subsea production system. Subsea hardware deliveries include eight overtrawlable four-slot subseatemplates with manifolds, wellheads system, 24 subsea trees, subsea and topside controls systems, 20 km (12.4 mi) of steel tube umbilicals, work-overequipment, and a tie-in and connection system.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








© Copyright 2011 Aker Solutions. All rights reserved. www.akersolutions.com/subsea

Be masterof the Arctic

Enter the Arctic with Aker Solutions, the only company

offering a full suite of technology to develop subsea

oil and gas assets stranded in harsh environments.

To succeed here, you need integrated solutions that

overcome the challenges of long-distance tie-backs in

remote parts of the world. We deliver, with world-leading

subsea compression and superior complimentary

technologies that include boosting, high-voltage

umbilicals, high-bandwidth controls, HIPPS and pipeline

Direct Electrical Heating (DEH) systems – everything

��

over far reaches. For years Aker Solutions has led the

way in an array of arctic solutions. We’re the natural

��

You also gain the advantages of E2E Subsea, which

integrates our technology, service and regional expertise

��

Rule the Arctic with Aker Solutions.Direct Electrical

HeatingUmbilicalsBoostingCompression Control System

Aker Solutions’ subsea technologyand experience get you there

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.akersolutions.com/subsea





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


Keppel FELS wins Lula-Iracema FPSO contract

Keppel FELS Brasil has won a $200-mil-lion FPSO topsides construction contractfrom Modec and Toyo Offshore ProductionSystems. It covers fabrication and integra-tion of topside modules for the FPSO Cidadede Mangaratiba MV24 at Keppel FELS Bra-sil’s BrasFELS yard in Angra dos Reis.

The new vessel, due to be completed by2Q 2014, is to serve for 20 years at the Lula-Iracema South Area in the Santos basin. Thevessel will be chartered to Tupi, the Dutch-registered company owned by PetrobrasNetherlands, BG Overseas Holding, andGalp Energias E&P Brasil. It will have an oil production capacity of 150,000 b/d, and stor-age capacity for 1.6 MMbbl.

Work at BrasFELS should start in 4Q 2012.The major work scope includes fabricationof a helideck, flare tower, risers, manifolds,waste heat recovery units, sulfate removalunit, water injection unit, and integration.

The first project between Keppel and Mo-dec/Toyo on fabrication and integration oftopside modules for the FPSO Cidade de Sao Paulo was contracted in February 2011.This program is on track for completion bythe end of 2012.

Songa Offshore providesupdate on rig fleet

Songa Offshore has provided an updateon its rig fl eet. Songa Venus continues tooperate for Petronas Carigali offshore Ma-laysia. Songa expects a one-year contract ex-tension to be confirmed this month, keepingthe rig in Malaysia until 3Q 2013.

Songa Mercur is in sheltered waters for lightmaintenance and an intermediate survey nearLabuan, Malaysia. The rig is being preparedfor float on and securing procedures on aheavy-lift vessel for transport to Trinidad. Es-timated departure was July 8 with a 40-45 daytransit time. On arrival in Trinidad, the rig willundergo contractual preparatory work for acontract with Zarubezhneft in Cuba this fall.

Songa Delta is operating under the Winter-shall/Det Norske Oljeselskap contract farmedout to Suncor. It is finishing a well, and thenwill head to the CCB yard near Bergen for ascheduled upgrade program prior to starting afour plus one-year contract for Statoil.

Songa Trym, which has been working forStatoil on the Troll field, also will head to theCCB yard next month for a Special PeriodicSurvey and upgrade program prior to start-ing a three plus two-year for Statoil underdirect Songa management.

Songa Eclipsestarted a one well plus 18-monthcontract for Total E&P Angola in May. Follow-ing initial downtime related to readying of theBOP following an acceptance test, the rig hasachieved 90% operational efficiency over thelast three weeks.

Rig secured to drill offshore Tunisia

Cooper Energy Ltd. and the Bargou JointVenture have signed a letter of intent with GrupServicii Petroliere SA to contract the GPS Ju-piter jackup rig to drill offshore Tunisia. TheHammamet West 3 well is scheduled to spud inDecember 2012, depending upon completion ofprior rig commitments.

Hammamet West oil find is on an anticlinein the Bargou Exploration Permit, Gulf of Ham-mamet in 50 m (164 ft) water depth. Two wellsdrilled to date indicate a gross oil column of atleast 190 m (623 ft) in the Abiod formation.

Participants in the Bargou Joint Ventureare Cooper Energy Bargou Ltd. (30% andoperator), Dragon Oil plc (55%), and Jacka Tunisia Bargou Pty Ltd (15%).

Lamprell to build new Seajacks jackup vessel

Lamprell has won a $120.9-million contractto design, construct, and deliver to Seajacks 4

Ltd. a modified Busto MSC NG 2500X jackupservice vessel. The Seajacks Hydra will be builtat Lamprell’s Hamriyah facility with deliveryscheduled in 2014.

The 7,000-metric ton (7,716-ton) vessel willhave dynamic positioning, high-speed jacking,400- metric ton (441-ton) crane, propulsion, ac-commodations for 100 people, and a 1,400-met-ric ton (1,543-ton) payload.

“Hydra will become the fourth vessel inour fleet and is part of our long-term growthplan following the acquisition of the companyby Marubeni and INCJ earlier this year,”said Kevin Alcock, VP New Build Projects,Seajacks. “As part of that plan, we are alreadyworking on the design and specification ofvessel five.”

NDC jackup overhaul completed

Drydocks World has completed a mainte-nance program on the jackup Delma for AbuDhabi-based National Drilling Co. (NDC).

Delma is a cantilever-type, self-elevatingdrilling platform built in Brazil in 1983. Thescope of work involved a complete overhaulof the starboard and port side cranes, steelrenewal in tanks, and improvements to thehigh-pressure mud lines, stand pipe mani-fold and various pipes.

Pipelines were hydro jetted, and the rigwas blasted and painted. The internal rig in-spection and painting of the legs and derrickwere performed using rope access.

Upgrade work included replacement of twolife boats and davits and shale shakers, fabri-cation and installation of a BOP trolley beam,and renewal of grasshopper cable trays.

NDC CEO Abdalla Saeed Al Suwaidi said:“A reliable, modern rig fleet is essential to sus-tainable success; therefore, NDC launched amajor asset renewal plan that involved invest-ment in new rigs, as well as the modernizationof existing ones.”

Endeavour jackup scheduled for trip to Cook Inlet

Kenai Offshore Ventures, LLC has ex-ecuted a contract to transport the Endeavourjackup drilling rig from Singapore to theCook Inlet, Alaska, using a heavy-lift vessel.The trip was expected to begin at the end ofJuly and take three weeks to complete. Onceat Cook Inlet, the rig will be offloaded andtowed to its first well location.

EMAS wins six vessel charter contracts

EMAS Marine has won six contracts foroffshore vessel support in Asia and Africa val-ued at $87 million. The contracts come froma variety of operators and service companiesand include platform supply vessels as well asanchor handling, towing, supply vessels. �

Songa Venus continues to operate for PetronasCarigali offshore Malaysia.

Cooper Energy and the Bargou Joint Venturehave signed a letter of intent with Grup ServiciiPetroliere SA to contract the GPS Jupiter jackuprig to drill offshore Tunisia.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________________

http://www.nov.com/xlsystems





End-of-year oil reserves

Integrateds Large independents Independents

Bb

bl

24

20

16

12

8

4

02007 2008 2009 2010 2011

D R I L L I N G & P R O D U C T I O N Eldon Ball • Houston


Rising development costsFor those who want to quantify how much

oil and gas development and operating costshave risen lately (as they always do duringgood times), IHS, the US-based energy thinktank, has developed a proprietary index totrack just such numbers. Their UpstreamCapital Cost Index (UCCI) rose 2.3% over the3Q 2011-1Q 2012 period to a new high indexscore of 227. Until you understand that thevalues are indexed to the year 2000, that maybe meaningless, so we’ll translate. It meansthat capital costs of $1 billion in 2000 wouldnow be $2.27 billion. Likewise, the UpstreamOperating Cost Index (UOCI) rose to 2.1%percent to 189 over the same period, mean-ing operating costs of $100 million in 2000 arenow a cool $189 million.

IHS says that the high rate of increase forthe UCCI can be attributed to increased dayrates for deepwater rigs. Despite new entriesinto the market, these rigs are in high de-mand and with rising fuel and labor costs cancommand premium rates. The unconvention-al drive in the US has put pressure on goodsand services although the drop in gas priceshas switched some of the drilling from gas totight oil. However, the high duty onshore rigsand fracing crews remain in high demand.

IHS expects upstream capital and operat-ing costs to continue to rise in 2012 driven byincreased costs in rig day rates, equipment,and oilfield services.

2011 banner year for US E&P growth

While costs may be rising, that fact is not in-hibiting spending in the US, and with good re-sults, according to a study by Ernst & Young.

As a result of strong oil prices and technolo-gy advances, the US oil and gas industry had abanner year for growth across several catego-ries. Combined exploration and developmentspending increased 38% in 2011, according toErnst & Young’s annual US E&P benchmarkstudy. Oil reserves grew by 9%, or 1.7 Bbbl in2011, while oil production increased 3%. Gasreserves and production rose 4% and 9%, re-spectively in 2011. Oil and gas revenues expe-rienced 23% growth in 2011.

Independents the driving force. As impres-sive as those numbers are, the success canbe attributed primarily to US-based indepen-dent operators. They were the pioneers whotested new technology and new geographiclocations.

US oil reserves grew by 23% from 2007 to2011, and as the accompanying chart shows,most of that growth came from independentoperating companies, not integrated oil com-panies or national oil companies. The resultis that independent operators now own themajority of US oil reserves, although thatmay change due to acquisitions by majors.

“Long thought of as an oil region in decline,the combination of strong prices for oil and ever-improving technology has turned the US into agrowth market,” said Marcela Donadio, Ameri-cas oil & gas sector leader for Ernst & Young.

Long-term implications. The abundant sup-ply and cheap prices for natural gas will have astimulating effect on both petrochemicals andmanufacturing in the US. Expect to see thistrend growing as the word spreads. Addition-ally, natural gas may emerge as a transporta-tion fuel as infrastructure for delivery grows.It is an economic and environmental winnercompared to any other fuel choice.

LNG markets will feel the impact. Once thought of as an LNG importer, the US couldeasily become an LNG exporter as soon as liquefaction facilities are available. That sce-nario can spread geographically, given theright political climate.

Exploration spending to hit $85 billion in 2012

Energy analyst Wood Mackenzie predictsa 15% increase in conventional explorationspending this year to about $85 billion.

In the past two to three years, the volumes ofthe new “conventional” finds have been gettingbigger, and results so far in 2012 suggest thisyear could be the best ever, with a roughly 50/50split between gas and oil, the company says.

The main source of new oil finds contin-ues to be the presalt plays in the deepwaterSantos basin offshore Brazil. The roughly 30wells drilled to date in this region have prov-en 30 Bboe, according to Andrew Latham,VP exploration service for Wood Mackenzie.By comparison, it has taken around 900 wellsover the past decade to discover similar vol-umes in the Gulf of Mexico, and around 700wells offshore Australia, he said.

East Africa and the eastern MediterraneanSea have provided most of the major new gasfi nds.

“Deepwater is the key to this success,” Lathamobserved. “The total volume being found in deep-water isnow morethan the yield from onshore ex-

ploration or from shelf drilling. And deepwater istypically more oil. Fewer wells are drilled in deep-water, but those drilled add multiples to reserves,and that’s the reason why deepwater remains soattractive.”

Elsewhere, Wood Mackenzie sees 10-15 ex-ploration wells being drilled annually in Arcticregions, but at much higher cost.

Latham says that independents have openedplays off nine previously untapped countries. Inthe past, the majors would have driven theseprograms, but most of the top 10 oil compa-nies have collectively experienced a decade ofrelatively flat growth, he said, not replacing lostproduction with significant new discoveries.That should change going forward to 2020, heclaimed, as the majors commit more funds toexploration.

“As a group, they have posted an average in-crease in their global expenditure of 15%, simi-lar to the rest of the industry. However, theirspend-per-barrel of production has been lowerthan for many of the independents – around$3/bbl compared with $5/bbl. We predict themajors will increase their exploration spend-ing to 20% per year.”

Aker to buildequipment site in Brazil

Aker Solutions is building a $100-millionmulti-purpose service site for its drilling equip-ment business in Brazil. The development willinclude production, assembly and testing ca-pacity, to provide local content to support thecountry’s large drilling rig-building program.

The 335,000-sq m (3.6-million sq ft) facilityin Macaé on Brazil’s east coast is about eighttimes bigger than Aker Solutions’ current facil-ity in nearby Rio das Ostras, reflecting expectedgrowth in the company’s activities in the country.

The new Macaé facility will host drillingriser production and maintenance services,including about 20,000 sq m (215,278 sq ft) ofindoor mechanical workshop space for riserand topside equipment, with full crane andtesting capabilities. The site will have capaci-ty for about 700 employees. The site is sched-uled to be fully operational in early 2014. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








WHY NOT?

The Evolution® high-performance, water-based fl uids system is ready for your most extreme

challenges no matter where they are. Proven in more than 1,100 wells of North America’s harshest

shale plays, our advanced system runs cleaner, faster, and smarter than oil-based counterparts.

Wherever in the universe you explore, let Newpark Drilling Fluids help you evolve in unexpected ways.

Learn more at www.newparkdf.com/evolution.

EVOLUTION IS A REGISTERED TRADEMARK OF NEWPARK DRILLING FLUIDS LLC IN THE UNITED STATES. THE EVOLUTION TRADEMARK MAY ALSO BE REGISTERED IN OTHER COUNTRIES.

THE HIGH-PERFORMANCE,

WATER-BASED FLUIDS SYSTEM

READY FOR

THE NEXT

FRONTIER.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.newparkdf.com/evolution





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


Arctic and northernNorth Sea seismic surveys in the news

The Norwegian Petroleum Directorate isscheduled to start acquiring 2D seismic inthe southeastern part of the Barents Sea asof this April 26. The M/V Artemis Atlantic isacquiring 6,000 km (3,728 mi) of seismic datain the southeast Barents Sea for the Norwe-gian Petroleum Directorate. Last year NPDacquired 2D seismic in the formerly disputedoffshore area near the Russian maritime bor-der. The results will assist in determiningwhether to explore in the region. This sum-mer, NPD expects to acquire a total of 30,000km (18,641 mi) of seismic in the Barents Sea,off Jan Mayen (between Norway and Ice-land), and in the Nordland IV and V areas.

TGS is acquiring a 3D multi-client surveycovering 2,400 sq km (927 sq mi) in the Nor-wegian Barents Sea. The Finnmark Platform2012 survey is in five blocks in the southwest-ern Barents Sea, four in quad 7017 and oneis in quad 7018. All blocks are proposed bythe Ministry of Petroleum and Energy to beincluded in the 22nd licensing round on theNorwegian continental shelf. Fasttrack datashould be available for interpretation aheadof the licensing round. The M/V Polar Duch-ess towing 10 x 6,000 m streamer with 75 mseparation is acquiring the survey. Data pro-cessing will be by TGS and available to clientsin 3Q 2012.

Ekofisk surveyexpected soon

CGGVeritas should have the raw data in hand from a fourth survey on the Ekofiskfield in the North Sea as part of the multi-year life-of-field seismic (LoFS) program.The data comes from a four-componentfiber-optic permanent reservoir monitor-ing system with 16,000 Sercel OPTOWAVEocean-bottom channels.

Quality control and data processing ofeach repeat survey is done by CGGVeritas’personnel in Tananger, Norway. In additionto the optical sensor network trenched atthe seafloor, a fiber-optic connection to theshore allows real-time remote operation.

Nyuni seismic surveylaunched offshore Tanzania

Aminex PLC has started a 335 km (208mi) 2D seismic survey in the Nyuni AreaLicence, offshore Tanzania. The survey tar-gets the transition zone between the coastand the deepwater section of the block. Acombination of ocean-bottom cable and ma-rine seismic source will be used in the shal-low water and a land-based seismic sourceon the emergent reefs and islands. This isthe first time OBC technology has beenused for a license-wide survey in the transi-

tion zone in this part of East Africa. Aminexsays conventional shallow-water seismic hasproven less effective because of the numberof reefs and islands restricting access toseismic vessels towing streamers.

Aminex is also planning a program ofmore than 500 km (311 mi) of 2D seismic inthe deepwater portion of the Nyuni licencein the second half of this year. The combinedtransition zone and deepwater seismic pro-grams will fulfill the seismic work require-ment of the Nyuni Area PSA which extendsthrough October 2013.

Partners in the Nyuni Area PSA are Ndo-vu Resources Ltd. (Aminex), 70%; RAK GasCommission, 25%; and Bounty Oil and Gas NL, 5%.

Serica starts 3D surveyin Luderitz basin, offshore Namibia

The Polarcus Nadia 10-streamer seismicvessel should be wrapping up a 3D surveyfor Serica in Luderitz basin blocks 2512A,2513A, 2513B, and 2612A offshore Namibia.The survey area totals 4,150 sq km (1,603 sqmi) and has three objectives:

• Delineate a four-way dip closed struc-ture which underlies the survey area

• Map potential pinch out prospects whichare expected to have formed in conjunc-tion with a large channel sand featurecrossing the survey area

• Demonstrate hydrocarbon potential throughthe presence of hydrocarbon indicators.

Geology business headlinesCGGVeritas opens Melbourne Pro-

cessing & Imaging Center: CGGVeritashas opened a new processing and imagingcenter in Melbourne, Australia. The remit ofthe new center is to serve clients in easternAustralia and the expanding New Zealandmarket.

Sercel SeaPro Nav selected by Seabird:SeaPro Nav, Sercel’s integrated navigationsystem for all in-water seismic equipment,has been selected by Seabird Explorationas the master system for two vessels in itsmarine seismic fl eet, the Harrier Explorerand the Aquila Explorer. Graham Knight,department manager Technology, SeabirdExploration, said: “Seabird’s deployment ofSeaPro Nav on its vessels is a natural pro-gression, further cementing our commit-ment to the use of Sercel products acrossour fleet.”

Spectrum completes purchase of CG-GVeritas library: Spectrum has completedthe purchase of the marine 2D multi-clientlibrary of CGGVeritas. The combined size ofSpectrum’s library now exceeds 1.1 millionkm (683,508 mi) of 2D multi-client seismicdata. The new data complements Spec-trum’s existing library in key areas such asthe Gulf of Mexico, South and Central Amer-ica, the Mediterranean Sea, and northwestEurope. As part of the agreement, CGGVeri-tas takes a 25% stake in Spectrum and will fo-cus its marine 2D multi-client activity mainly through its shareholding in Spectrum. �

TGS adds 2D seismic data in the Barents Sea and northern North Sea. North Sea Renaissance 2012is infill west of Shetlands covering 8,200 km (5,095 mi) using the Akademik Shatskiy. The NorwegianBarents Sea 2012 survey covers 12,000 km (7,456 mi) using the Osprey Explorer.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Name your challenge.

Subsea Technologies

Drilling Technologies

Well Construction & Completion Tools

Stimulation & Intervention Products

Surface Production & Process Equipment

Valve Solutions

Forum brings together well-known, trusted brands with an extensive range of mission critical products and

services for the subsea, drilling and production sectors. Our experienced people and proven technologies are

ready to meet any challenge.

Smart Solutions. Powerful Products.

To find the products to meet your challenges visit www.f-e-t.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



__________

http://www.f-e-t.com





120,000

100,000

80,000

60,000

40,000

20,000

050 100 150

Temperature (C)

Tim

e (h

r)

200 250 300

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


Ian VerhappenYokogawa Canada

There are a number of television shows about “extreme” events, sports, and other activities, but what is not shown is how the equipment is managed to operate for ex-tended periods in those environments. Off-shore certainly qualifi es as an extreme en-vironment. With the temperature extremes that are experienced in the North Sea, Arc-tic, and equatorial settings, the challenges of operating offshore increase.

Installations in the Arctic, at least in Can-ada, are based on a design spec of -50°C (-58°F) to 40°C (104°F) for the following reasons. The -50°C design spec requires the devices to “start cold” at this temperature when power is reapplied after an outage. It does not mean that the local display needs to work, but that the device must power up and start providing useable measure-ments at this temperature. Liquid crystal display is no longer liquid at approximately -25°C (-13°F). The 40°C design spec is for the summer. Because the sun does not set during this time, there is no evening cool-ing affect. So when a warm spell comes, the temperature continues to increase until the weather system changes.

When it comes to temperature, most in-stallations and designs are more concerned with the upper temperature specifi cation be-cause of the potential impact on electronics reliability.

A common “rule of thumb” states that ev-ery 10°C increase in temperature cuts com-ponent life in half. This “rule” comes from basic chemistry, where there is a general principle that chemical reactions go faster

with higher temperatures. Years ago, the military adapted that concept to predict how temperature leads to electronic component failure. They gathered tons of questionable data from the fi eld, correlated the data with this iffy assumption about chemical reaction rates, and came up with MIL-HDBK-217, the military handbook on electronic reliability. MIL-HDBK-217 quickly became an industry standard, and hence, the source of the myth. However, MIL-HDBK-217 states that long-term nominal operating junction tempera-tures operating lower than 70°C (158°F) have zero effect on reliability. Therefore, it is unlikely that failure rates will follow an expo-nential curve based on Life Equivalent to 40 Years in Hours at a relative to temperature basis of 60°C (140°F) Ambient.

In addition to temperature, electronic products and mechanical devices that are exposed to any environment (indoor or out-door) are commonly also exposed to intru-sions by dirt, dust, and insects; sprayed/dripped/directed moisture; and curious poking fi ngers.

Ingress Protection (IP) is the industry standard term created by the International Electrotechnical Commission (IEC), while in North America, the NEMA (National Electrical Manufacturers Association) rat-ing is commonly used. It is not possible to directly correlate NEMA numbers with IP numbers, but there are many tables avail-able on the internet that show the equiva-lency. Since many devices are manufactured for global distribution, they will display both ratings.

In the IP system, the fi rst number indi-cates the degree of protection both from in-trusion of objects and protection to the user

from hazardous parts or mechanisms inside the product. The second digit in the IEC assigned IP-number indicates protections from liquids. Unfortunately, the NEMA sys-tem is less rigorous in its method of number assignment.

In many cases, the integrity of the enclo-sure also relies on the correct installation of cable glands/seals to prevent ingress of liq-uids (corrosion or short circuit) and gases (explosion). Breathers/drains should be in-stalled on all enclosures to manage not only changes in temperature but also the associ-ated potential condensation.

In addition to condensation, offshore in-stallations are exposed to severe storms and salt water, so in addition to protection from the standard water, dust, and oils, the ma-terials of fabrication also need to consider materials compatibility.

The most widely selected choice for en-closures is metal, and in the offshore en-vironment this is typically stainless steel. However, many types of stainless steel are susceptible to stress corrosion cracking when exposed to chlorides such as the salt in sea water, so it is important to select the correct version of stainless steel for the envi-ronment. Onshore installations typically use lower cost epoxy coated steel, but coastal facilities often also need to design for the salinity.

One alternative to steel at least for enclo-sures is fi berglass or glass fi ber reinforced polyester (GRP). GRP enclosures have the additional benefi t that should an insulated enclosure be needed they can be made with a typically foam insulation between two lay-ers of GRP or fi berglass with suitable heat-ers and windows included. The gaskets and mechanical closures must still be selected for the environment.

If the device, its packaging, and installa-tion are not properly specifi ed and installed for the environment, the signals and control-lers used to monitor and control a process could fail at the most inopportune time. Just like many control and automation items, it is the small details that make a big difference to how effective a system will operate. �

The author Ian Verhappen, P. Eng. is an ISA Fellow, ISA Certifi ed Automation Professional (CAP), and a recognized au-thority on Foundation Fieldbus and industrial commu-nications technologies. Verhappen is managing director of Yokogawa Canada, a global supplier of instrumenta-tion products and advanced control systems. He can be reached at [email protected].

Electronic component life as a function of temperature.

Equipment management for extreme environments

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________

http://www.pwpglobal.com






N O R T H S E A

Statoil leads overhaul of Norwegiandevelopment drilling, intervention fleet

If the market does not provide the so-lution you need, the answer may be topull a few strings to make sure it does.That is the proactive approach adoptedby Statoil in its search for fit-for-purpose

rigs for improved oil recovery (IOR) on Nor-wegian fields.

In Norway, IOR is acknowledged as play-ing a vital role in squeezing the most benefitfrom the country’s oil endowment. Even inthis golden era for exploration with success-es such as Johan Sverdrup in the North Seaand other finds in the Barents Sea, the au-thorities continue to bang the IOR drum. It’sa message that Statoil is totally in tune with,as operator of some of the largest maturing fields on which the country’s oil wealth isfounded.

The key to improving recovery lies indrilling and well management – drilling ac-curately into small pockets, drilling later-als from existing boreholes, and keepingthe wells functioning in prime condition.On platforms with fixed drilling rigs, thesetasks are relatively straightforward, and it isin such conditions that Statoil has posted itsbiggest IOR gains.

Fields developed with subsea wells, how-ever, have proved a greater challenge. Theseconstitute a significant part of Statoil’s port-folio on the Norwegian continental shelf (NCS) – they include large fields such asTroll Oil, with close to 120 subsea wells,Åsgard with 50-plus wells, Heidrun, Norne,Kristin, Tyrihans, Snøhvit, Gjøa, Snorre, Vi-sund, and Tordis/Vigdis, not to mention the

subsea satellites around Statfjord,Gullfaks, Oseberg, Sleipner, andseveral smaller fields. It all addsup to a stock of almost 500 subseawells.

But when Statoil began to lookfor equipment to maintain these wells, itfound that the market had little to offer oth-er than full-scale semisubmersible drillingrigs. Although appropriate for drilling newwells, for both lighter and heavier forms of intervention, they are over-dimensioned andover-expensive.

Mid-depth solutions “The market was not coming up with what

we needed for the NCS,” observed ØysteinHåland, senior vice president, drilling andwell. “Its primary focus is on deepwater drill-ing rigs, when what we need is drilling andcompletion rigs for medium water depths.”

Adapting rigs for this role is expensive, soStatoil decided that designing from scratchwas the best way forward, says Håland. The company’s attentions have focused onthree types of rig: Category A, for light wellintervention; Category B, for heavier inter-

vention and workover; and Category D, fordrilling and completing new development wells. Work is now under way on a fourthcategory, J, which refers to jackup rigs for

development work.Statoil first implemented this

strategy in light well intervention(LWI), awarding its first contractsin the mid 2000s. Most of the workhas gone to monohull vessels de-signed specifically for this type oftask. At present the company hasthree vessels from Island Offshoreunder contract for this purpose –Island Frontier, Island Wellserver, and

Island Constructor.In May, Statoil awarded two contracts worth

a total NOK 9.4 billion ($1.5 billion), both dueto come into force when the current LWIcontracts end in 2015. One, with a fixed five-year term, has gone to Island Offshore forthe continued hire of Island Frontier and IslandWellserver. “Island Offshore has delivered solidservices and we expect the same going for-ward,” a Statoil executive commented.

The other contract, with a fixed term ofeight years, went to Eide Marine Serviceswhich offered a newbuild semisub hull. “Thisinvolves new marine technology,” said Håland.“It’s a small semisub which is stable when op-erating and can move fast.” Both contractshave two additional two-year options.

While monohulls have the advantage ofbeing able to transit rapidly between onewell and another, they are prone to weather-induced disruption. “In winter it is often verydifficult to land a helicopter on one of theseunits,” Håland observed. “They may have togo to shore to perform a crew change. Therecan be a substantial number of days lost.”

The company expects the Eide unit – EideWell Intervention – to be less vulnerable toweather interruption, while still moving be-tween wells at a fair pace. With subsea develop-ments stretching from the North Sea throughthe Norwegian Sea to the Barents Sea, a unitmay have long distances to travel between as-signments, so transit speed is important.

Achieving agreement between the differ-ent licenses for use of the units was a chal-lenge in the early days, said Håland. “It wasreally tough to get LWI going,” he recalled.“Setting up a risk-sharing agreement be-tween different licenses with an obligation

Nick TerdreContributing Editor

Øystein Håland, Statoil’s senior vicepresident, drilling and well. (Photo:Haagen Tangen Eriksen/Statoil)

Eide’s concept for light subsea well intervention. (Image: Statoil)

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








World class axial on-off valves. Balanced piston valves for special applications. Proven in use.

other masterpieces? www.mokveld.com

axial on-off valve (HIPPS) by Mokveldsunfl owers by Vincent van Gogh

Excellent valvesonly the looks can be improved

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.mokveld.com






N O R T H S E A

to use the unit for a certain number of days was not easy.” Good results, however, have won over the skeptics, and now each license insists on its right to have a contracted unit for its share of days.

LWI is performed without a riser, instead using a lubricator and wireline to run equip-ment or tools downhole and conduct repair and maintenance operations. The vessel oper-ators work in established consortia – Island, for example, with FMC for well control equip-ment, and Aker Well Services for downhole operations; while Eide plans to work with a Halliburton-led team that includes Subsea Technologies, Advantec, and Oceaneering.

The vessels and equipment packages are custom-built for the application, therefore incurring much lower capex than a standard drilling rig and delivering much lower oper-ating costs. The result, according to Håland, is a 50-60% reduction in overall costs, more than suffi cient to make these operations economically viable.

Heavy-duty interventionAnother contract awarded by Statoil in

May covers heavier forms of subsea well intervention. Aker Oilfi eld Services will build, own, and operate a Category B semi-submersible rig specially designed for riser-based well intervention and light drilling tasks, including through-tubing rotary drill-ing, coiled tubing, high-pressure pumping, well-testing, and cementing services. The contract runs for eight years with three two-year options, and is valued at around $1.9 billion for the fi xed term. The rig, which is due to start operations in 2015, will operate in water depths up to 500 m (1,640 ft). Statoil expects it to cut its intervention costs by up to 40%.

Aker Oilfi eld Services already has a dedi-cated heavy intervention vessel, the monohu-ll Skandi Aker, which has worked almost ex-

clusively in the more benign waters of West Africa and Brazil. As regards the North Sea, however, the weather conditions are unfavor-able for a monohull operating with a fi xed riser, says Håland – the more stable platform offered by a semisub is therefore preferable.

As for drilling new development wells, Statoil has focused on a unit specially de-signed for drilling and completion – the Category D rig. Currently the market offers almost exclusively generic rigs intended for all types of drilling, including exploration and development. However, they are not op-timized for development drilling tasks, such as handling the large volumes of materials needed for well completion.

“From the market we weren’t getting the fi t-for-purpose solution that we wanted,” said Håland. “So we went to the industry to en-gineer the new design, and paid for FEED and detailed engineering.” Representatives of all relevant disciplines were invited to par-ticipate, including drilling contractors, hull and topside designers, equipment vendors, and fabricators. “We were very pleased to see their response,” Håland noted. “There was a lot of interest and many companies were willing to get involved. Not all the play-ers are able to fund this kind of work them-selves, but we were willing to help.”

Workhorse roleBased on the resulting design, drilling

contractors were invited to submit bids, and last year – two years after the process had been initiated – Statoil awarded the contract to Songa Offshore. The contractor will provide two Category D rigs for a fi xed eight-year term with four three-year exten-sion options – so if all options are exercised, the contract will run for an unusually long period of 20 years. The deal is worth $2.47 billion for the fi xed term, equivalent to a day rate for each unit of about $420,000. The

rigs, which Statoil describes as workhorses, will be capable of operating in waters of 100-500 m (328-1,640 ft) and of drilling to a depth of 8,500 m (27,887 ft).

Both rigs, which have a GVA hull design, are under construction at the Daewoo Ship-building and Marine Engineering (DSME) yard in South Korea, with Aker Solutions supplying the drilling equipment. Following delivery in 2014, both units will be deployed on the Troll Oil fi eld, where the drilling need is so great that ever since start up in 1995, two, three, and even four rigs have been employed at any one time.

This year Statoil followed up on a nego-tiated option for two additional Category D rigs, awarding a further contract to Songa. Again the contract – this time worth $2.66 billion – is for a fi xed term of eight years with four three-year options. One of these rigs, which are scheduled for delivery in 2015, will serve on the Norne, Heidrun, and Åsgard fi elds in the Norwegian Sea. The other will be engaged for year-round opera-tions in the Barents Sea.

Although Statoil is supplying a bridge loan to Songa to help with fi nance construction of the second two rigs, it has no fi nancial inter-est or ownership in any of the four category A, B or D units so far contracted. But in the case of the Category J rigs, it has taken the position of suggesting license ownership, Håland says. Some relevant licenses have very long drilling programs, and if a license has the need for a full-time rig on a long-term basis, ownership could be justifi ed. This would be a similar situation to the drill-ing facilities on fi xed platforms, which are owned by the licensees, he points out.

In the Category J project, a fi t-for-purpose design has been developed for drilling and completion of production wells. As with the Category D project, this has taken place in cooperation with the relevant supply-side players. Statoil now plans to present the design to the industry at a workshop, after which it will issue a tender, probably for two units, on a long-term basis. Its intention is to award a contract before year-end and have the units in operation in 2015.

Historically jackups have been confi ned to the shallower waters of the southern North Sea, but the latest designs have extended the operational envelope to depths of up to 150 m (492 ft), thus opening the way for jackups to operate more widely in central areas of the North Sea. Where possible, jackups are often the rig of choice for development drill-ing – this is the case with major new develop-ment projects on central Norwegian North Sea fi elds such as Total’s Martin Linge, Statoil’s Dagny, Lundin’s Edvard Grieg, Det norske oljeselskap’s Draupne, and potentially Statoil/Lundin’s Johan Sverdrup. �

(Left) Aker Solution’s Category B rig for heavy subsea well intervention. (Right) Songa’s design for a drilling and completions semi – Category D. (Images: Statoil)

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







Exploration

UK

Num

ber

of E

&A

wel

ls

35

30

25

20

15

10

5

0Norway Netherlands Denmark

Appraisal Completions

January

Num

ber

of E

&A

wel

ls

12

10

8

6

4

2

0February March

Month

April May June

Discoveries

E&A wells by sector during 1Q 2012.

Month-by-month breakdown of completions and discoveries.Exploration wells per sector in 2012.


N O R T H S E A

Confidence returningamong NW Europe operators

Elizabeth LloydAndré Sharma

Deloitte’s Petroleum Services

High oil prices, incentives stimulate exploration and development

The energy industry, a strategic resourcefor security of supply across NorthwestEurope, is faced with increasing com-mercial and technical challenges to ex-plore for and produce oil and gas. These

include an extended period of economic tur-moil, declining production, and rising costs.However, sustained high oil prices, and incen-tives such as the UK government’s recent fieldand tax allowances, are stimulating explora-tion drilling and development.

During the first six months of 2012, a totalof 53 exploration and appraisal (E&A) wellswere spudded across the UK, Norway, theNetherlands, and Denmark, compared to 54spudded over the same period last year. Ofthose drilled so far in 2012, 31 (59%) havebeen exploration wells and the remaining 22appraisal wells (41%).

Following the low levels of drilling duringthe winter months of the first quarter, activityon the UK continental shelf (UKCS) and theNorwegian continental shelf (NCS) during2Q 2012 have picked up to more consistentlevels. The depressed activity earlier was dueto the current economic and market factors,rig and crew availability, and adverse weatherconditions affecting operations, with a num-ber of rigs unable to move off locations fol-lowing the completion of drilling operations.

Compared with the first six months of 2011,

the UK has seen an increase of nine explorationand appraisal wells, while those drilled offshoreNorway decreased by six. The Netherlands hasseen a decline of three wells, and Denmark hashad one well drilled in the same period.

Drilling levels across the UK and Norwayare expected to be relatively high through-out the summer months. There are at least10 proposed drilling locations for exploration

and appraisal wells in the UK for the remain-ing half of 2012. Offshore Norway, there areplans to drill six exploration wells.

Completionsand discoveries

Between January and June of this year, 44exploration and appraisal wells were complet-ed across the NCS, including wells spudded

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








www.hardbandingsolutions.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.hardbandingsolutions.com





Introducing the Influx Volume Reductionsystem (IVR) featuring MPO’s patented QuickClose Annular (QCA). Designed to counterthe slow actuation times of conventionalBOP technologies that allow pressures andkick volumes to exceed safe handling ranges,and prevent the risks of volume and pressurebuildup with conventional BOPs.

The QCA responds in as little as five secondsto shut in your well, stop flow and deliver anorder of magnitude reduction in kick volume.

On a HP/HT well, MPO’s QCA technology will:

��

��

��

!�� "#$%��&�'(�)��

Safely secure your assetand protect the environmentin as little as 5 seconds

Take Total Control of Your Well .

* ��+��,��


N O R T H S E A

before the start of the year. Of these, 13 (30%)encountered hydrocarbons and can be classi-fied as successful. May brought the highestnumber of completions, although only two ofthese wells successfully discovered hydro-carbons. Of the 13 discoveries in 2012, ninewells encountered oil and the remaining fourencountered oil and gas. It should be noted,however, that a number of the completed wellresults have yet to be announced by their re-spective operators or partners.

Field start ups and developments

Since 2009, the number of fields approvedfor development by the Norwegian and UKgovernments has increased. In 2009, onlyeight fields were awarded development ap-proval, but last year 18 projects were approved.In the first six months of 2012, 12 fields havebeen approved – a positive indicator for the fu-ture of the industry across the North Sea.

Britain’s Department of Energy ClimateChange (DECC) has approved eight field devel-opment plans (FDPs) while the Norwegian Pe-troleum Directorate has granted four plans fordevelopment and operations (PDOs). Amongthe more successful operators were Ithaca En-ergy and Centrica, respectively awarded threeand two FDPs by DECC.

Despite the maturity of the region, a rangeof companies have committed to making sig-nificant investments in the area in the comingyears, thus highlighting the confidence in theregion’s oil and gas potential.

The correlation between field developmentapprovals and the oil price has been strongsince the financial recession in 2008. As theoil price has increased, so has the numberof field approvals. With the sustained highoil price and the evolution of new technolo-gies, companies are now able to develop whatwould in the past have been considered sub-commercial developments. These factors,coupled with the announcement of decom-missioning tax relief by the UK governmentin the March 2012 budget, should incentivizefurther investment and greater commitmentto development in the North Sea.

During the first half of 2012, three Norwe-gian fields came onstream. First was the BG-operated Gaupe in the North Sea in March,followed by Marulk and Oselvar in April,respectively in the Norwegian Sea and theNorth Sea. Five fields in the UK started pro-duction during the second quarter of 2012,namely Bacchus, Islay, Lybster, Athena, andEnsign.

There are positive signs. The total of eightnew fields onstream is higher than the totalnumber of field start ups in 2011 and morethan double the number of fields that cameonstream in 2009 and 2010.

The majority of field start ups were located

across the Central Graben, Moray Firth, andnorthern North Sea basins. Outside these ar-eas were the Centrica-operated Ensign, andthe ENI Norge-operated Marulk gas fields lo-cated respectively in the UK southern NorthSea and Norway’s Voering basin.

Strong licensing activity In May 2012, DECC announced that the

27th licensing round had attracted the larg-

est number of applications received of anyUK bid round to date. A total of 224 appli-cations were submitted covering 418 blockson the UKCS, 37 more applications than theprevious high established in the 26th round.The increase may partly have been stimu-lated by more favorable tax and field allow-ances announced in the 2012 budget.

The 27th round has attracted seven fron-tier license applications compared to three

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








TakeTotal Control

of YourWell

Contact MPO today, 1.832.448.1251 or go to www.managed-pressure.com

MANAGED PRESSURE OPERATIONS

-*+,.�* ��+��,��— 5 Seconds —

Pressure Below Annular =�200�� Volume Below Annular =�/�13��

�4��4��+��5��

+�� 6$#�,��— 45 Seconds —

Pressure Below Annular =�2000�� Volume Below Annular =�/3�133��

7��5��

*+,�)��+�� 6$#�4��8�+��

9#:94�; ��

<��<� ��

��&��5�� =�>?�$��#&77�=

?��5�� =�?@)&�$@"?@4,7��&�;�=

As part of the Riser Gas Handling (RGH) system, the QCA ensures that mud is not lost to the environmentleading to substantial litigation and penalties. Also,as the kick volumes are significantly reduced, post event recovery and the ability to avoid the risk of sidetracking is enhanced.

Re-calculate kick tolerances for your well design with the ability to close your wellbore in less than five seconds with the patented Quick Close Annular!

The Influx Volume Reduction system and QuickClose Annular are two new examples of how MPOis continuing to help you take better control of yourdrilling operations.

See what “Total Control” means.

www.offshore-mag.com • August 2012 Offshore 39

N O R T H S E A

in the previous round, underlining the inter-est in frontier areas such as west of Shetland.Compared to the number of applicationsmade last year, there has been a reductionin the number of promote licenses in favorof traditional license applications. Promotelicenses are designed to allow small andstart-up companies to enter a productionlicense and attract the necessary operatingand financial capacity at a later stage. The

decrease in applications of this type shows that large players are still willing to invest inthe North Sea.

At the end of March, the Norwegian gov-ernment announced the Awards in PredefinedAreas (APA) 2012. Compared with APA 2011,this year’s licensing round has expanded incoverage with an additional 48 blocks or part-blocks offered. Of these additional blocks, 13are in the Norwegian Sea and 33 are in the Bar-

ents Sea. In June the Norwegian 22nd licens-ing round was unveiled, offering 86 blocks inthe Norwegian and Barents seas, with a focuson frontier areas with potential for oil and gas,but which are less explored and where infra-structure is not well established.

Looking aheadThe results of the 27th UKCS licensing

round and the Norwegian APA 2012 are ex-pected later this year and following the highnumber of applications, results will be great-ly anticipated. A high number of successfulawards could result in a positive numberof well commitments to ensure explorationactivity continues across the region in thecoming years. Exploration may spread intoareas previously considered underexploredsuch as west of Shetlands and the BarentsSea.

In the UK, the positive announcements inthe budget 2012 with regards to the decom-missioning tax relief may also help to stimu-late activity. Companies hope to be able torecover cash flow currently tied up in finan-cial guarantees related to decommissioning,and direct these funds to exploration and appraisal.

In Norway, a number of factors suggestthat levels of exploration and appraisal activ-ity will remain attractive and consistent overthe coming years. The Norwegian govern-ment currently offers favorable conditionsfor exploratory drilling. Companies are ableto claim 78% of their exploration costs in adry hole case, substantially reducing therisk associated with drilling new explorationwells. Furthermore, unlike the UK, Nor-way is viewed as a fiscally stable regime, al-though companies still have to consider thehigher overall tax regime.

Increasing demand from China and otheremerging economies, coupled with politicalupheaval in North Africa and the MiddleEast, and the ongoing Eurozone crisis, hasresulted in a sustained high oil price. Thishas had a positive effect on the industry, en-couraging investment as manifested by E&Adrilling and field development activity.

One limiting factor on drilling activity inthe region is the fierce competition to securerig slots across the North Sea. According topublished reports, average rig utilizationacross the North Sea in the first half of 2011was 79%. This has now increased, with 2012levels for the same period at 88% utilization.

As technology develops and the complex-ity of rigs follows suit, there will be a chal-lenge to hire technically qualified personnelto operate the rigs. The next generation ofdrilling rigs will be technologically more ad-vanced following ongoing improvements, sothere will be a need for more highly trainedcrew. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM




http://www.managed-pressure.com






N O R T H S E A

GDF SUEZ expanding operationsin mature and emerging UK gas provinces

After 15 years as a co-venturer or ex-ploration operator on the UK conti-nental shelf, GDF SUEZ is preparingfor a leading development role. Thecompany already runs numerous gas

production centers offshore Norway and theNetherlands, but Juliet and Cygnus in thesouthern North Sea will be its first major op-erated UK projects. Cygnus will be one of thecompany’s largest developments anywhere,supplying around 5% of the UK’s future do-mestic gas production in 2016.

Government sanction for Juliet, a subseatieback to Perenco’s Pickerill A platform, camethrough in June, and authorization for Cygnuswas expected this summer. To support theseprojects and four others close to development inthe UK North Sea, the company has com-missioned a new office complex in Aber-deen.

“Our aim is to be a leading UKCS op-erator, not just in the southern gas basin,but in the mid-term also in the centralNorth Sea, and in the longer term Westof Shetland,” said Jean-Claude Perdigues,managing director of GDF SUEZ E&PUK. “We believe there is still a lot of po-tential to tap into on the UK shelf, eventhough it appears mature.”

Since entering the UK sector in 1997,the company has amassed interests inover 40 offshore licenses, 16 as opera-tor, and claims to be the UK’s eighth-largestoffshore acreage holder. It currently has netproven (2P) reserves of 65.5 MMboe, mainlyin the southern gas basin, and 88 MMboe ofnet contingent (2C) resources in the centralNorth Sea.

Juliet-Pickerill linkJuliet was discovered in 2008 in 58 m (190

ft) water depth in southern North Sea block47/14b. The location is close to the English eastcoast and the Amethyst offshore productioncomplex. According to analysts BritBoss, thecompany originally applied to develop the 100-bcf field in 2010 via the nearby Amethyst fieldcomplex, but planning had to be put on hold tofind a new offtake route for the gas. It will betied-back to Perenco’s Pickerill A platform tothe east via a 22-km (13.7-mi), 12-in. (30.5-cm)pipeline and control umbilical.

Development and Operations ManagerMike Robertson said a jackup supplied by the

company’s Dutch affiliate GDF SUEZ E&PNederland will start drilling the first of Ju-liet’s two horizontal subsea wells next spring– these will be connected to a 170-t template/manifold. The subsea contract, which shouldby now have been awarded, covers installationof the control umbilical and export pipeline,which will be laid in separate trenches andbackfilled. At Pickerill A, modifications willinclude installation of a new riser and J-tube.

First gas is slated for late 2013, with pro-duction transported from Pickerill A to theTheddlethorpe terminal on the east coast. At

peak, Juliet should deliver 80 MMcf/d. “Theplan is that Juliet will come off plateau fairlyquickly,” Robertson said, “but the templatewill allow tie-ins from other discoveries in thearea.” With this in mind, GDF SUEZ aims todrill one exploration prospect in the vicinity in2013/4. The company has a 51.6% interest inthe project, in partnership with First Oil Expro(29.44%) and Hansa Hydrocarbons (19%).

In 2014, the company aims to bring Orca,another southern sector gas field, onstreamvia a wellhead platform tied-back cross-border to GDF Suez E&P Nederland’s D15platform. Orca has changed hands varioustimes over the past few decades. Accordingto GDF SUEZ E&P UK Subsurface ManagerAndy Spencer, it took time to understand howto develop the field economically. “Orca’svolumes are fairly modest, and the calorificvalue of the gas, which contains 20% nitrogen,is not suitable for the UK distribution system,although it is acceptable for the Dutch mar-

ket. So getting an economic solution for Orcahas solved a long-standing problem.”

Reassesing CygnusOonagh Werngren, Business Manager, Sup-

ply Chain, said the Cygnus field in blocks 44/12aand 44/11a is the largest discovery in the UKsouthern gas basin of the last 25 years, with 2Precoverable reserves estimated at 720 bcf. Interms of the UK’s remaining reserves it is thesixth largest gas field, she added.

Marathon Oil drilled the original discoverywell in 1989, but back then it looked small,with a poor reservoir and no local infrastruc-ture. After acquiring the license in 2002, GDFSUEZ E&P UK as the new operator appliedits experience in marginal Rotliegendes res-

ervoirs to drill five successful appraisalwells from 2006 onwards. Assuming sanc-tion this summer, the company hopes tobring Cygnus onstream in late 2015 via 10horizontal wells.

The target date is a year later thanscheduled in the original EnvironmentalStatement for the project. This is partlydue to a change in development scopefollowing further appraisal drilling suc-cess, but also – according to Perdigues– because of the industry’s current infla-tionary cost environment. “So we havefocused in the FEED on optimizing engi-neering, trying to keep costs manageable.

Cygnus is not a very complicated project tech-nically, but due to the field’s very large extentand the shallow water, we need to invest more.There has to be four platforms and 10 wells,and that all pushes up the cost.”

The finalized scheme calls for a main Cyg-nus Alpha hub on the eastern part of the fieldcomprising three bridge-linked platformsproviding drilling, accommodation, process-ing and gas export, and another wellheadplatform (Cygnus Bravo) on the western partof the field. This will be linked to Cygnus Avia a 5.9-km (3.6-mi), 12-in. pipeline, with thecommingled production sent through theEagles Transport System pipeline that runsbetween Perenco’s Trent platform and theBacton terminal on the Norfolk coast.

GDF SUEZ sees further reserves upside inthe area, particularly in undrilled lobes on thenorthern flank of Cygnus. The company hopesto drill a well here next year, Spencer said, us-ing the jackup Ensco 80. �

Jeremy BeckmanEditor, Europe

Artist’s impression of the Juliet subsea facilities.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.orrsafety.com/KONG






A R C T I C

Gas supply routes to determinefuture phases of Snøhvit development

Snøhvit, Norway’s most northerly offshore field development,has been onstream for five years. Gas and condensate fromthe subsea wells are piped to the single-train LNG process-ing plant on Melkøya Island off the port of Hammerfest. Itremains the world’s most northern LNG facility, with scope

for expansion of offshore production, although competing terminalsare emerging elsewhere around Europe.

Recently, the partners opted to postpone a decision on a secondLNG train, despite the upsurge in exploration in the Barents Sea thathas brought several new gas discoveries. Production from these andfurther developments in the Snøhvit license could instead head laterthis decade via Hammerfest through a new long-distance offshorepipeline linked to the trunkline system in the Norwegian Sea. Butexpansion of the LNG facilities remains a possibility as the partnersseek new markets, particularly in the Asia/Pacific region.

Wellstream issuesSnøhvit comprises three offshore gas/condensate fields close togeth-

er in water depths of 250-340 m (820-1,115 ft). Askeladden was the first tobe discovered in 1981, although the phase 1 development has focused onthe other two, Snøhvit and Albatross. Nine subsea production wells con-nected to four seabed templates are controlled remotely from Melkøya.

Commingled production heads directly to the LNG plant via a 143-km(89-mi), 65.5-cm ID multi-phase subsea pipeline, claimed to be the world’slongest. This also transports 700,000 metric tons/yr (771,617 tons/yr) ofassociated CO2 to Melkøya which is stripped out and sent back throughanother pipeline to a dedicated injector well at the offshore field centerfor storage in a reservoir below the Snøhvit field. Another parallel line

transports MEG for hydrates control. Statoil op-erates all aspects of the project, in partnershipwith Petoro, Total, GdF Suez, and RWE Dea.

The liquefaction processed, licensed byLinde, is designed to cool methane gas to -163°C(-261°F) under normal atmospheric pressure,reducing the original volume of gas 620 timesand thereby minimizing storage requirements.“Along the way,” said Oyvind Nilsen, Vice Presi-dent for the Snøhvit LNG plant, “we first have tostrip out the mercury, water, CO2, propane, eth-ane, and condensate. For this reason, geologistssay the Barents Sea is a candy store, although wesay that Melkøya is a candy store for the technol-ogies too.” The plant’s LNG storage tanks caneach hold 125,000 cu m of gas, offloaded at thequayside to three dedicated LNG carriers, withseparate tanks to store 75,000 cu m (2.65 MMcf)of condensate and 45,000 cu m (1.59 MMcf) ofLPG.

In 2002, midway through the development,the estimate of recoverable resources was 193

Jeremy BeckmanEditor, Europe Integrated power, controls for Goliat

ABB supplied the integrated power, automation and controlsystems for the Snøhvit LNG plant and offshore facilities.Thecompany is currently working on another comprehensive pro-gram for Goliat, the second field development in the BarentsSea, 85 (53 mi) km northwest of Hammerfest.This will produceoil and gas through a Sevan 1000 circular FPSO in 400 m(1,312 ft) water depth, due to start operations in 2013.

ABB is providing a comprehensive range of electrical, auto-mation, instrumentation and telecommunications equipment and systems.The package includes intelligent operations, withremote diagnostics available from the offshore process plantlive to ABB specialists worldwide, allowing them to diagnoseand fix problems that may arise. “This is a huge benefit tocustomers,” said Per Erik Holsten, who heads up the compa-ny’s Process Automation division in Norway. “It changes theirwhole operating philosophy on offshore installations.

“At Goliat, we will also have an onshore control room. Inan extreme situation, the team there could sit onshore and supervise the entire operation. In addition, we will provide anonshore control room to Eni’s office in Hammerfest, givingthem access to the same data as is available on the platform.”

Another highlight of ABB’s contract is the world’s longestand highest-output AC power cable (123 kV/75MW) to anoffshore installation, running 106 km (66 mi) from an onshoresubstation near Hammerfest to the platform, with integrated fi-ber optics for communications purposes.The remainder of theFPSO’s 100 MW power requirements will come from onboardgas turbines – these and the combined AC electrification sys-tem will help reduce Goliat’s CO2 emissions by 50% comparedwith a conventional power supply arrangement, thereby lower-ing the partners’ Norwegian CO2 taxes.

Snøhvit’s wells are controlled remotely from the Melkøya LNG plant.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








��!"#$%��&'�*�+//��

!"3��

��45678�9*9�*///�

HORNBECK OFFSHOREService with Energy

:��;<��+//��

��!��=��>"� ��?��$��&'�*�!"3��

��@��B��G��

��J��

��K��

=��!"#$%��**�///�

��K��G��<�///��

=��L��

��

=��!"#$%� ��

��!��

��

HOSMAX

300DP-2 OSV

310DP-2 OSV

HOSMAX

320DP-2 OSV

HOSMAX

INTRODUCING THENEW HOSMAX FLEET.BIGGER AND GREENER.DYNAMICALLY POSITIONING HORNBECKOFFSHORE AS THE LEADER IN NEXT-GENERATION OFFSHORE SUPPLY VESSELS.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



____________________

http://www.hornbeckoffshore.com





CONFERENCE 2012

INSTRUMENTED

INDENTATION

TECHNIQUE

CONFERENCE 2012

am

JW Marriott Hotel in Houston, TX

27, September, 2012, 10:00am

IIT?

Instrumented Indentation Testing (IIT) is a mechanical test method that can evaluate tensile properties, re-sidual stress and fracture toughness in the field with-out damaging assets or requiring destructive sam-ples. IIT can be effectively applied to welds or parts of unusual shape or size where traditional sampling is difficult.

Hosted by Frontics America, Inc.Contact Hamee ChoiP H O N E (224) 220-0745E M A I L [email protected]

contact us to register and receive a free gift

The Conference

The growing demand for this technology, its technical development, and information on actual application cases will be discussed at IITC September 27th, in Houston TX. Join us for these informative discussions and a chance to meet various enterprises involved in the technology and its application.

A R C T I C

bcm of gas and 34 MMcm of condensate. “Lastyear, we upgraded gas reserves by 20 bcm,”Nilsen said, “and we also believe emergingnew technologies, such as subsea compres-sion, will lift the recovery factor significantly.”

“This project opened up the Barents Sea,and is by far Norway’s largest industrial de-velopment to date, at a cost of NOK 48 bil-lion,” Nilsen continued. “It pushed the limit in several areas, not just in liquefaction, butin terms of long-distance multi-phase trans-port and the CO2 solution. The cooling, per-formed by large, electrically-driven coolingcompressors, is unique too.”

“But we had to establish a brand new con-cern in this area, in a latitude of almost 71 degrees N,” Nilsen explained. “During the design phase there were a lot of discussionson concept selection, and there were con-cerns about the prevailing strong winds andtemperatures that can dip to -22°C [-8°F] – we call that harsh conditions.”

The partners opted to maximize prefabri-cation for the LNG plant, which was built innorthern Spain in the form of a barge andtowed to Melkøya, where it was loweredinto a specially excavated site on the island.“There were space and weight challenges,”Nilsen said, “and in retrospect, we shouldmaybe have had two barges, as we ended up

with a very compact layout with space andweight challenges. But this also provideslessons for floating LNG developments.”

On a limited number of days, the plantmust be able to cope with severe conditionssuch as icing caused by massive snowdriftsand frozen seawater, but sometimes theimpact is hard to predict. In January, therewas a -20°C temperature drop in less than24 hours, Nilsen recalled. As a result, oneof the valves started to behave abnormally,constraining production.

There have also been shutdowns caused

by internal issues. Earlier this year, the en-tire plant at Melkøya was down for a weekdue to a breakage in the firewater system,which is made of GRC fi ber pipes. Lastmonth, operations had to be halted againdue to water ingression in the natural gasdryers and the associated risk of ice forma-tion in the cooling circuit.

“At Melkøya, we have had to push the lim-its of several items of equipment,” Nilsen ex-plained. “For instance, we are operating theworld’s largest electrically-driven motors [65 MW, supplied by Siemens] and the larg-

Night time view of Melkøya, with LNG carrier in the distance.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







A versatile partner

Jumbo Offshore safely transports and installs subsea structures and mooring systems at water depths up to 3,000m. Our versatile vessels are equipped with two 900t mast cranes and fitted with a Dynamic Positioning system (DP2). They can be equipped with various types of equipment such as ROVs, pile hammers, heave compensation and much more to suit your project requirements.

Over the last 10 years Jumbo has built up a solid and reliable reputation as a safe transport and offshore installation contractor. Our concept

“Lift. Ship. Install. All in one go.” continues to provide an extremely efficient solution.

www.jumbo-offshore.nl

A R C T I C

est sea water heat exchangers with titaniumpipes. We have experienced breakages as aresult of temperature-induced fatigue, butthis has since been resolved.”

“Now it’s a question of optimizing the feedgas process,” Nilsen elaborated. “We haveimplemented changes to the software sys-tem, which has led to significant improve-ments in the efficiency and robustness ofthe plant. We’re still not where we would liketo be in terms of regularity, but this is stillthe most energy-efficient LNG facility in theworld, with specified power for the liquefac-tion process of 243 kWhr/t LNG.”

CO2 disposalThe CO2 content in Snøhvit’s wellstream

is 5-6%. Following extraction, this is disposedof via injection directly into the main Snøhvitfield, at a subsurface depth of around 2,500m (8,202 ft). The behavior of the CO2 is moni-tored using seismic instrumentation – perfor-mance so far has generally been in line withpredictions, Nilsen said, although at one pointpressure development in one of the forma-tions necessitated a light well intervention toput in isolation plugs at several levels. Statoilhas selected a new area for a second CO2 injec-tor well which is likely to be drilled in 2016.

Theoretically, Snøhvit could remain at pla-

teau production through to 2040-50, Nilsensaid, although this will depend on the scope of future subsea development in the area,and whether the partners commit to con-struction of a second LNG train on Melkøya.

Currently, Snøhvit’s 5 bcm of year of pro-cessed LNG comprises 5% of Norway’s an-nual gas exports. Prior to start-up in 2007,the partners acquired a stake in the CovePoint regasification terminal in Marylandwith a view to addressing the shortfall inLNG in the US at the time.

Markets have since changed, and theplant is now sending shipments to southernEurope, India, and the Far East, via the Suez Canal. There are also discussions with Rus-sia about opening up a northeast passageover the next few years through the Arcticto Japan and South Korea.

According to Nilsen, this would be ashorter journey than LNG from Qatar toJapan, although at that point there wouldbe 70 bcm/yr of capacity from Australia tocompete with. Hence the potential need tooptimize or double capacity at Melkøya.

If the proposed Polarpipe project goesahead, taking gas from Melkøya through anew 1,000-km (621-mi) offshore pipeline con-necting to the rich gas Aasgard TransportSystem in the Norwegian Sea, a dewpoint

facility could be installed at Melkøya to stripout condensate prior to gas feedthrough.

Increased throughput could be achievedby expanding the subsea facilities at Snøhvitin up to three further development phases,with the second phase taking in gas fromAskeladden. After five years of production“we have a better understanding of thereservoirs, and we know we could recovermore via new technology,” Nilsen said.

In time, gas from the nearby Torneroseor other discoveries in the region such asLundin’s Skalle could also be directed toMelkøya, along with associated gas from theGoliat oilfield project, which is due onstreamin 2013, and where Statoil is a partner.

In the early years of production, Goliat’sgas will be reinjected or used for power gen-eration on the FPSO, but the Snøhvit part-ners are in discussions with Goliat operatorEni, Nilsen says, about processing the gas atMelkøya at a future date.

Another long-term candidate could beStatoil’s Skrugard oil discovery to the north,which has limited quantities of associated gas.During the first 10-15 years of production,these would probably be needed for injectionto boost oil recovery, Nilsen says, but somegas might then be available for export througha new 100-km pipeline to Melkøya. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.jumbo-offshore.nl






G U L F O F M E X I C O

SEMS continues to shapethe offshore regulatory environment

Current rule applies to operators, but contractors must comply as well

Pisces CarmichaelMatt Beltz

Lloyd’s Register

A Safety and Environmental Management Systems program is based onthese elements from API RP 75.

Expectations have changed for oil and gas operators in the Gulf of Mexico over the last few years. Regulations from the Bu-reau of Safety and Environmental Enforcement (BSEE), aswell as increased scrutiny from investors and the public, haveleft companies searching for safer and more environmentally

sound methods to extract oil and gas found in deep and ultra-deep-water.

The regulator, BSEE, proposes having a proper Safety and Environ-mental Management Systems (SEMS) program in place not only ful-fills the regulatory requirements, but provides a performance-basedapproach to mitigate some of the risk inherent to working offshore.

Introduction to SEMSSEMS is designed to help operators and contractors identify and

manage the safety hazards and environmental impacts occurringduring the design, construction, start-up, operation, inspection, andmaintenance of all new and existing facilities. SEMS applies to alldrilling, production, construction, well workover, well completion,well servicing, mobile offshore drilling unit, and Department of In-terior pipeline activities.

In 2010, the BSEE released the Workplace Safety Rule, whichmandated that all operators working in the outer continental shelf(OCS) develop, implement, and maintain a SEMS program.

SEMS was launched as 30 CFR 250, Subpart S and based upon thepreviously voluntary 13 element system from API RecommendedPractice 75. Earlier this year, BSEE released the SEMS PotentialIncident of Noncompliance List (PINC), which highlights BSEE’s key enforcement approach for SEMS.

The regulations require formal audits within two years of Novem-ber 2011, and then every three years thereafter. According to BSEE,an operator’s SEMS plan must be formally audited by an indepen-dent third party. The plans for these audits must be submitted toBSEE for approval.

When designing current SEMS regulations, BSEE set out to:• Focus attention on influences that human error and poor orga-

nization have on incidents• Continuously improve the offshore industry’s safety and envi-

ronmental record• Encourage the use of performance-based operating practices• Collaborate with industry in efforts that promote the public in-

terests of offshore worker safety and environmental protection.Continual improvement requires best practices followed by implemen-

tation and evaluation. It is the responsibility of operator management toensure that goals and performance measures are established for their

SEMS program. These goals and performance measures should then bemade clear to all personnel working on their OCS facilities.

Specifically, operators must:• Verify that personnel, including contractors, have received

proper training and have the skills and knowledge to performtheir assigned duties

• Conduct design suitability studies when the original mechani-cal or process design information no longer exists

• Ensure a contractor’s hazard assessment and JSA documents arerevised and updated to reflect changes in their SEMS program

• Have a copy of all of the contractor’s Safe Work Practices (SWPs)and ensure they cover all SEMS-covered tasks and operations.

A strong safety culture“It is important to remember that SEMS regulations are a mini-

mum requirement,” said Danny Walker, vice president of Compli-ance, Lloyd’s Register. “Operators should strive to set their stan-

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Lloyd’s Register, ModuSpec and WEST Engineering Services are trading names of Lloyd’s Register Group Limitedand its subsidiaries. For further details please see http://www.lr.org/entities

Integrating ModuSpec and WEST Engineering Servicesto advance excellence in drilling safety, integrity and performance.To learn more visit us at www.lr.org/energy

Are you prepared for a SEMS Audit?Ensure compliance, secure your future

ModuSpec provides a comprehensive suite of services to assess, strengthen and ensure the adequacy of your safety and environmental management system (SEMS) plan.

We can perform a gap analysis of your existing HSE plan against BSEE’s requirements, train your staff on SEMSregulations or help you develop your SEMS plan.

�� and manage your drilling risks.

Contact your ModuSpec representative today to get theright solution for your drilling and safety needs.Visit www.moduspec.com or e-mail [email protected]

Visit us at the 2012 Lloyd’s RegisterEnergy Conference, October 18-19,in Houston, TX

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.lr.org/entities

http://www.lr.org/energy

http://www.moduspec.com





Master of the Oceans

GVA 7500

INNOVATIVESOLUTIONS FORCHALLENGINGREQUIREMENTSGVA Drilling Semi-submersiblesinclude shallow water and deep water variants. Innovative design features include the rigid upper hull deck box – a safe, robust and easy to maintain solution. GVA Drilling Semi-submersibles have excellent motion characteristics and favour-able deck payload/steel weight ratios and are designed to cope with the harshest conditions.

K12094 © 2012 GVA, All Rights Reserved. Photo: Odfjell Drilling

www.gvac.se

developing

for frontier regionsTechnologies

27 – 29 November 2012

Perth Convention Exhibition CentrePerth, Australia

www.deepoffshoretechnology.com

For more than 30 years Deep Offshore Technology International hasbeen showcasing pioneering technology that has been shaping thefuture of the deep and ultra-deepwater industry. Showcasing the mostinnovative technologies designed to withstand hostile and ultra-deepwaterenvironments. Discussing the specific challenges of the region and thelatest groundbreaking solutions.

Hosted By:

Owned & Produced By: Presented By: Supported By:

G U L F O F M E X I C O

dards above the minimum safety standards set by BSEE.”

An operator’s SEMS program should be the basis of a mature and continually improv-ing safety culture. A safety culture cannot improve without management accountabil-ity. Therefore, management has responsibil-ity and discretion to maintain and improve the safety culture across the organization.

Operators with a strong safety culture typically benefi t from:

• Low accident rates• Low turn-over• Few at-risk behaviors • Low absenteeism• High productivity.

SEMS and contractors While the current SEMS regulations are

specifi c to operators, for an operator to com-ply its contractors must be aligned with their SEMS plan. To continue providing services to operators in the OCS, contractors must prepare their people and processes to match an operators’ SEMS plan, or they risk losing business to SEMS-compliant competitors.

It is also apparent that BSEE may hold con-tractors accountable to a documented SEMS plan in the future.

At the 2012 Offshore Technology Confer-ence, James Watson, director of BSEE, said: “Safety is the responsibility of everyone at every level at all times.”

When asked about contractor accountabili-ty specifi cally, Watson responded: “In the past, the Minerals Management Service chose not to apply the authority at hand to contractors. [BSEE] is going to use all our authorities, all the areas that are available through the legisla-tion that we operate, which does, actually, in-clude contractors. We’re going to take a mea-sured approach … and I think the outcome is going to be a better, safer, industry when we apply our authorities, whether it’s the operator or the contractors.”

Operatorrequirements

Operators are required to maintain a writ-ten record of criteria for selecting a specifi c contractor. Operators also must maintain doc-umented contractor safety evaluations, and a signed SEMS contractor bridging document must be on fi le prior to any work. This docu-ment spells out an operator’s SEMS expecta-tions for the contractor. These expectations must then be communicated to all involved contractor personnel.

Proactive contractors should be prepared to aid the operator in preparing these documents and be equipped to be audited by BSEE, the operator, or an independent third party.

Contractors who have an effective HSE process in place and on fi le with an operator

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.deepoffshoretechnology.com

http://www.gvac.se





YOUR NEED FOR

PURE WATER IS CRITICAL.

MECO PROVIDES THE CRITICAL SOLUTION FOR

SEAWATER DESALINATION.

We’ve designed, constructed and serviced

seawater desalination systems since 1939.

Today, we meet your needs with a variety

of field-proven technologies: solutions

engineered to match your requirements.

That’s why we’re unique in our industry.

And yours.

In construction, performance and quality,

our systems define excellence. We back

them with total-response service—from on-line

access to on-site presence—that recognizes no

boundaries to your satisfaction.

Pure water is our one focus and our only product. Pure water

for your people. Pure water for your processes. Wherever you

are, we’re there, transforming the water around you into the

water you need. Simply. Efficiently. Cleanly. Dependably.

MECO. EXPECT MORE. GET MORE THAN YOU EXPECT.

Vapor Compression Desalination

Units (M3C Series)

Waste Heat Evaporators

(ST Series)

Enhanced Membranes Systems

(UF/MMRO Series)

United States: 1.800.421.1798 | [email protected]

Singapore: 65.6836.7500 | [email protected]

www.meco.com

are best prepared to meet expectations andto help their client meet BSEE requirements.

Challenges for contractors Contractors are going to face many new

challenges as they try to operate within thenew SEMS regulations.

With new documentation and training needs,contractors will need to maximize internal re-sources. Such programs as the Lloyd’s RegisterSEMS webinar series tell contractors look at ex-isting documentation, records, HSE programs,and personnel to leverage these resources in-stead of starting from a new slate.

Personnel management is another areacontractors must attend. Employees and subcontractors must be verified as knowl-edgeable and competent to perform theirtasks. This will affect the hiring process ascompanies seek qualified candidates thatare both competent and understand theirpersonal responsibilities under SEMS.

A contractor’s HSE and other trainingprograms must undergo continual mainte-nance to stay effective. This will take time,resources, and a management commitmentto be fully functional and effective.

Contractors also need to be sure personnelcontinue to maintain their safety culture whileexecuting work for an operator. Each operatorand facility may have a different safety culture.Contractors spread among multiple clientfacilities will have multiple SEMS bridgingdocuments signed and in place. Each operatorlikely will have slightly different expectations,making it difficult for a contractor’s personnelto effectively transition from one operator’sfacilities to the next while keeping their owncompany’s safety culture constant.

The risk of noncomplianceAccording to the SEMS Potential Incident

of Noncompliance (PINC) list, incidentsof noncompliance carry potential fi nes of$35,000/day as well as having to shut in theoffshore facility in question until the prob-lem is fixed.

For several items on the SEMS PINC list,failure to comply results in a warning, butif an operator fails to develop, implement ormaintain a SEMS program, or there is an un-safe situation that poses an immediate dan-ger, a facility shut in will occur.

BSEE can also shut in a facility if duringa SEMS audit the operator does not providethe necessary documentation for a facility-level hazards analysis.

It should be the goal of everyone workingin the OCS to provide a safe and responsibleworking environment. As SEMS programsare implemented across the industry, oper-ating conditions will continue to improve asrisks are mitigated and individual responsi-bilities heightened. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.meco.com






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

Enhancing EOR through reservoir modelingNew model conditioned for well observations,

with accurate volume calculations

For all the focus on EOR (enhanced oil re-covery) in offshore operations over thelast few years, little attention has beenpaid to the crucial role reservoir model-ing plays in bolstering recovery rates.

Reservoir modeling today is the standardplatform to map, understand, and predictoil and gas reservoir behavior. Whether itis seismic interpretation, the building of astructural model, fault and fracture model,or history matching and simulation, reser-voir modeling provides operators with cru-cial information on oil and gas in place andthe potential obstacles to accessing them.

Embracing seismicReservoir modeling can only be truly ef-

fective in increasing oil and gas recoveryand providing input to EOR programs if it isable to incorporate 3D and 4D seismic data.

The better that the user is able to incor-porate 3D seismic and reservoir heteroge-neities and extend the depth of static mod-eling, the more accurate and realistic thereservoir models are likely to be. In additionto 3D seismic, 4D seismic can be highlyeffective in mapping and monitoring fluidmovements.

All too often, however, the tendency is tosimplify, and err on the side of compromisewhen addressing seismic-derived geologi-cal complexities and reservoir heterogene-ities. The reasons for this might include theneed for an easier workflow or the obviouschallenges of modeling seismic. The resolu-tion of the seismic, for example, is often toocoarse to resolve the true geometries of theheterogeneities, or uncertainty in depth canmake it difficult to represent wells correctly.

While these rationales and the challenges are understandable, there remains a realdanger that oversimplified reservoir modelswill not deliver the vital information opera-tors require to improve recovery rates.

The ability to integrate seismic more tightlyinto reservoir models can be achieved in anumber of ways. Property modeling, for ex-ample, is one area where seismic data can becombined with other data, such as well data, to

generate accurate and well-constrained reser-voir models.

Emerson’s reservoir modeling software,Roxar RMS includes an object-based, faciesmodeling tool that incorporates informationderived from seismic directly into the faciesmodel. In this way, data extracted from seismiccan be blended with geostatistical tools, suchas guide lines and trends, to generate well-con-strained sedimentary bodies, a more realisticproperty model conditioned to well observa-tions, and accurate volume calculations.

Other recent technology developments thatenable 3D and 4D seismic data to be incorpo-rated into the reservoir model alongside exist-ing data types, such as geological, geophysi-cal and simulation data, include new seismicinversion and seismic attribute tools.

The inversion tool, for example, allowsgeoscientists to use seismic data to create arock property model quickly and accuratelyusing high-frequency information from welllogs combined with band-limited frequencyinformation from the seismic data.

In addition, Emerson has a new visualiza-tion toolkit to enable modelers to extractmaximum value from seismic data throughthe creation of attributes that more clearly

Tyson BridgerEmerson Process Management

New seismic inversion and attribute tools can improve reservoir visualization.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








The Emerson logo is a trademark and service mark of Emerson Electric Co. ©2012 Fisher Controls International LLC. D352080X012 MY124 (H:)

Third party certification means no time wasted on completing vendor product inspections.

Every Fisher® control valve received Lloyd’s Register’s Marine Type Approval for process

applications within the offshore oil and gas production industry and for those high integrity control valve applications that

could potentially affect the safe operation of the offshore installation. In fact, all Fisher products have been thoroughly

tested per Lloyd’s Register requirements to confirm compliance with marine industry standards.

All product designs have been certified to meet rigorous offshore codes and standards. In addition

to Marine Type Approval, Fisher facilities in all world areas have been approved to manufacture

products certified to Lloyd’s Register Marine rules. And one more thing—no other control valve

supplier in the world can say the same. Now, you can spend your time on...well, whatever you need

to. Click on the QR code below or visit www.Fisher.com/Approved. Verify the facts.

YOU CAN DO THAT

I spend too much money completing vendor product inspections. I wish I knew that my control valve supplier produced its products to meet marine specifications and standards.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



__________________

http://www.Fisher.com/Approved







define reservoir structure and guide the userthrough the facies modeling process.

Key features include importing tools forSEG-Y data sets, and the fast and accuratevisualization of seismic data sets of any sizethrough interactive opacity control and col-or manipulation capabilities.

The net result is a realistic property modelconditioned to well observations and with accu-rate volume calculations – all vital informationwhen looking to extend the life of the reservoir.

Improving North Sea recovery rates

Reservoir modeling plays an important rolein increasing recovery rates and supportingEOR programs in the Norwegian North Sea.

One example is Statoil’s Statfjord field, oneof the oldest producing fields on the Norwe-gian continental shelf (NCS) that today deliv-ers recovery rates of up to 66% and is sched-uled to remain active until 2019.

According to INTSOK, a joint partnership

between the Norwegian oil and gas indus-try and the Norwegian government, RoxarRMS has played a crucial role in generatingpredictive models for the field and providinginput to well intervention, 4D seismic, and water management decisions. Furthermore,any improved oil recovery efforts for thefield, such as injecting water, also depend onthe predictive model developed.

Statoil’s Gullfaks field in the North Sea isanother example where recovery rates arenow approaching 60%.

What characterizes a strong and effectivereservoir model today is one that can builda realistic representation of the reservoirgeometry with fluid flow and volumes repre-sented as accurately as possible.

With average global oil and gas recoveryrates in the 20% range, the smallest percent-age improvements can have a significant im-pact on both future oil and gas productionstrategies and operators’ bottom lines.

Pemex caseOne example of how reservoir modeling

contributes to field development and EORstrategies is on Pemex’s Kutz field, part ofthe Cantarell asset, offshore Mexico in theGulf of Mexico.

The geological complexities and reser-voir heterogeneities within the field requirethe latest in fracture, fault, and object-basedfacies modeling tools, simulation-friendlygrids, and uncertainty analysis features tocreate a robust and reliable reservoir modelon which to make future production deci-sions.

The field was placed on nitrogen injec-tion in 2000 with production having declinedsince 2003. There was a need for a 3D modeltackle the fi eld’s geological complexities,leading to a greater understanding of the as-set and its reserves, and helping support up-dated field development plans based aroundits 12 existing wells. The reservoir modelalso can provide input to further simulationsand decisions when considering EOR.

With these goals in mind and with itsability to enable direct reference betweenthe model and the 3D seismic, the programhelped develop a high resolution modelinggrid of 13 million cells using corner-pointgeometry and incorporating 10 faults. Thefault modeling tool also allows geologistsand reservoir engineers to quickly and eas-ily analyze the fault sealing properties andfluid flow properties across faults in the 3Dreservoir model.

Reservoir properties in the Kutz fieldwere also distributed using 3D modelingtools for both the modeling of the facies andin developing a petrophysics model.

Finally, uncertainty and probability analy-sis estimated recovery from the field and

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________


http://www.wascoenergy.com





KaMOS® Gaskets for sealing and surveillance

Selected references:

BP, ExxonMobil, Total, Saipem, Shell, Hyundai, ConocoPhillips,

Chevron, PTTEP, Halliburton, AMEC Paragon, Technip Offshore UK Ltd

“KaMOS® Gaskets to be used, when having too many leakages in flanged connections...”

KaMOS® Gaskets verifies correct installation by pressure

testing the ring room in flanges.

Time, cost and safety efficient

leakagetest solutions

KaMOS® Kammprofil Gasket

KaMOS® RTJ GasketP.O.Box 484, N-4291 Kopervik, Norway • Tel +47 52 84 43 40 • Fax +47 52 84 43 41 • [email protected] • www.kamos.no

- the efficient solution for flanged connections


future production trends with 50 realizations taking place.The result was a robust and accurate model of the Kutz field that

addressed all geological complexities and honored reservoir hetero-geneity. The model will be used for the further development of thefield, in future simulation processes, and to maximize oil recoverythrough water, gas, CO2, and nitrogen injection.

Creating an integrated reservoir modelReservoir models can be fully effective only if they are fully inte-

grated and capture all the field’s complexities and heterogeneities.

Another example is in a giant, mature offshore field with a geolog-ically complex setting. Here, an integrated reservoir model was re-quired as a platform to develop an EOR program to help rejuvenatethe field – a field that was delivering low production rates despite itsgood reservoir quality.

In this case, RMS and its Structural and Uncertainty modules de-veloped an integrated, static model for the field comprising morethan 100 zones and wells and up to 1,000 different reservoir com-partments. The operator has subsequently used the model to sup-port field rejuvenation and EOR strategies. �

Reservoir properties in Pemex Kutz field in the Gulfof Mexico, distributed using 3D modeling tools forboth the modeling of the facies and in developing apetrophysics model.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.kamos.no






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

Intelligent wells offer completion solutionfor Lower Tertiary fields

Ultra-deep HP/HT environments raise new challenges

This summer will mark 15 years since the industry’s first intel-ligent well installation. What started as a small niche in thecompletions segment has expanded to now offer solutions fora range of applications, many of them in the highly challeng-ing environments.

Remote-operated interval control valves (ICVs) and real-time datafrom permanent downhole gauges (PDGs) allow well performanceto be optimized without intervention. Hydraulic and electrical con-trol lines strapped to the production tubing permit the use of mul-tiple ICVs and PDGs in the completion sting. These control linesoperate and communicate with the ICVs and PDGs remotely fromsurface.

Direct Hydraulics using the N+1 methodology (with “N” being the number of dedicated open lines for each ICV and “1” being thecommon close line to all ICVs) is the widely used downhole controlarchitecture. Today, a single well or an entire field’s performancecan be monitored in real time and controlled using intelligent welltechnology. As operators move into more complex and deeper wa-ter projects around the world, the benefits of intelligent wells areincreasingly necessary to the oil and gas industry to economicallyproduce reserves and maximize recovery.

Intelligent wellsA growing number of installations and diverse product offerings

among service companies demonstrate the industry’s acceptance and growing use of intelligent well technology. Operators who arewell aware of the advantages of intelligent wells are looking for waysto better integrate the remote operating and monitoring capabilityinto their more difficult subsea completions.

In the Gulf of Mexico (GoM), new well targets in excess of 30,000ft (9,144 m), such as in the Lower Tertiary Wilcox formation, arecreating new completions challenges for both operators and oilfieldservice companies alike. With planned multi-zone producers or in-jectors in some of these ultra-deep HP/HT environments, methodsof effective zonal control, equipment reliability, and minimizing thenumber of trips in the well are at the forefront of completion designdiscussions. The desire for solutions that reduce rig operating andintervention costs in these tough environments presents new oppor-tunities for efficient completions using intelligent tools.

For service companies, there are several technical hurdles to beovercome to achieve marketable solutions in these deeper subseawells. Accommodating the required pressure and temperature rat-ings is a major challenge when bottomhole pressures are in excessof 20,000 psi and temperatures in some areas are over 400° F (204°C). Technical advances will need to be made concerning elastomers

and metallurgy for tools to operate reliably in these demanding en-vironments.

These new tool designs must still allow sufficient annular andtubing flow areas for high-rate pumping and production, have long-term service capability, and be compatible with standard equipmentand tubular sizes. It will be a balancing act between cross-sectionaltool geometries and material yield strength. Thinner cross-sectionalparts would need to be made of high-yield strength material to com-bat the high bottomhole pressures.

Again these parts would need to be made of corrosion-resistantalloys (CRA) to combat the corrosion effects of the completion andproduced fluids that will be used to complete these deep wells. SomeCRA materials have a certain yield strength limit beyond which theytend to corrode.

Technology limitsLikewise conventional chevron-style dynamic seal stacks for

downhole equipment such as ICVs are not suitable in these HP/HT environments. A combination of elastomers, thermoplastics andsteel will be required for dynamic seal stacks to provide the resil-ience and rigidity required to withstand high pressure differentialat temperature.

The Lower Tertiary rock formations encountered in the GoMtend to be comparatively high-pressure and high-temperature res-ervoirs, often with high sand content (+70%) and usually underlie

Savio SaldanhaHalliburton’s Completion Tools

Enhanced single-trip multi-zone system.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








„Some conditions leave no

room for choice…”

TMK PF and ULTRA QX Premium

Connections have been successfully tested

for conformance with the international SO

13679 standard, level CAL V*

*CAL– Connection Application Level

CAL IV is the highest level

Trade House TMK

40, bld. 2a, Pokrovka Street

Moscow, 105062, Russia

TMK Premium Service

20, bld. 1, Podsosensky Lane,

Moscow, 105062, Russia

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



________

http://www.tmk-group.com






a thick layer of salt sediments. The play isexpected to feature long, continuous payzones as long as 3,000 ft (914 m). High- ratefracture stimulation techniques along withscreens will be the sand control methodthat will be widely employed. As a result,

operators may have to adopt multi-zone,single-trip fracturing strategies.

The stimulation technologies employed would need to have the flexibility to addressvarious interval lengths and at the sametime provide effective zonal isolation in or-der to initiate effective frac stimulations.The system would need to handle proppantconcentrations ranging from 1-12 ppg, prop-pant loading in excess of 500,000 lb per in-terval, and rates in excess of 50 bpm.

The system would need to provide asuitable barrier to prevent proppant flow-

back, be tolerant of formation compaction,and most of all be able to handle fluid lossor charged up zones while completing theintervals. Current single-trip multi-zonetreatment methods such as Halliburton’sEnhanced Single-Trip Multi-Zone (ESTMZ)

system provide the consistency and reliabil-ity needed to develop similar tools with evenhigher pressure and temperature ratings.

Where flow control is concerned, cur-rently available intelligent completion tech-nology limits the completion of these lowertertiary wells to effectively two zones. Atypical intelligent completion in the GoM in-volves installing ICVs in the upper comple-tion. These ICVs are stacked one on top ofthe other with the lower shrouded ICV con-trolling the bottom zone. Zones with similarpressure regimes or those with similar injec-

tivity indexes are comingled. As discussed, sand control involving

screens would be essential in almost all wells being completed in the lower tertiary.Placing the current ICVs inside the screenassembly severely restricts the flow rate

involved in these highly prolifi c producers.Moreover, the OD of the tungsten carbide-lined deflector valves required in high-ratewater injectors hampers installing these valves inside gravel pack screens.

Optimum performanceMonitoring the pay zone is essential for

optimizing reservoir performance. Moni-toring downhole activity can provide goodinformation in and around the wellboreas well as across the reservoir. A detailedmapping of the hydrocarbon behavior can

Discussions are under way between oil companies and service companies alike to bring the intelligent flowcontrol and reservoir monitoring to the sandface.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.delmarus.com






provide a meaningful indication of how thereservoir is overburdened under the influ-ence of production and secondary recoveryphases. Currently single point, quartz crys-tal pressure and temperature sensors arewidely used to monitor these reservoirs.

Fiber-optic sensors provide a better reso-lution of the reservoir interval (1 m inter-val). However, interface issues downhole aswell as at the subsea pod are a challenge toinstalling fiber optic in these subsea wellsat the current point in time. The size of thegauge mandrels involved in deploying thequartz gauges requires installing the gaugeassembly outside the gravel pack assembly,at times placing these gauges hundreds offeet away from the pay zone. Thus the pres-sure being monitored is not only measuringcomingled pressure but is also not repre-sentative of the true pressure from eachinterval.

Discussions are under way between oilcompanies and service companies alike tobring the intelligent flow control and res-ervoir monitoring to the sandface. Innova-tive technology will be required not only tomeet the HP/HT requirement of the lowertertiary, but also to maintain tool designswithin the drilling and completions current

space envelope (i.e., hole/casing sizes) andat the same time provide higher productionor injection flow rates.

The ICVs, PDGs, and screen designs would need to be optimized to provide an in-tegrated solution or a concentric intelligentcompletion solution. A reduction in screeninternal diameter has a domino effect on therating of the frac service tool. A reductionin the outer diameter of the service tool willpermit faster erosion requiring an additionaltrip in hole with a new service tool. More-over, the pressure drop created at 50-bpmflow rate in the service tool may be exces-sive and could be a limitation to the fractreating pressure. The number of controllines required for operating and communi-cating to the ICVs and PDGs would need to be minimized as these lines would either be installed on the screen outer diameter or in-stalled on the concentric string.

Enabling technologyIn either case the space envelope involved

limits the applicability of the direct hydraulicsN+1 downhole control system. Interfacing thesecontrol lines with the upper completion or pro-duction string may require an electro-hydraulicdownhole wet connect. This key enabling tech-

nology is currently in the infancy stage.Reliable mating and de-mating is essential

to the success of these extremely expensivewells. Incorporating fi ber-optic technologyacross the sandface level would require afiber-optic disconnect tool. Various servicecompanies are working to develop a solutionthat would bring the benefi ts of fi ber tech-nology in long horizontal dry tree applica-tions to the subsea environment.

Again, all these solutions would need toconsider future secondary recovery meth-ods; such as electric submersible pumpsfrom an up-hole interface standpoint.

Thus, several technical hurdles need to be overcome to provide a robust and reli-able completion solution that will unlockthe potential of the Lower Tertiary. Currenttechnology would need to be re-engineeredor optimized. Radical changes to the way we drill and complete these wells may be required to develop technology that wouldallow us to reach the goal without being costprohibitive. Certain compromises will needto be made as the technology evolves. Theoil companies and service companies willneed to work together to develop the nextgeneration technology to maximize the val-ue offered by the Lower Tertiary. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________

______

http://www.iogm.no

http://www.stxosv.com







Flow detection system saves time, moneyin record HP/HT Norwegian wellAutomated MPD system mitigates drilling hazards

While planning for an offshore Norwegian exploratory well,surface pressure of nearly 15,000 psi and extremely hightemperatures were anticipated.

To understand and control wellbore dynamics whilemaintaining an overbalanced wellbore, the operator in-

stalled a managed pressure drilling (MPD) system to provide earlykick detection and to allow for wellbore breathing mitigation.

A key objective of using MPD was to set the 9 7/8-in. production-casing shoe as close to the reservoir as possible to allow the optimal 8½-in. section to be drilled to total depth (TD) within a very narrow, 0.4ppg drilling window. A significant challenge was presented with wellbreathing events in the difficult wellbore environment, which madepore pressure evaluation and kick detection critical to drilling the well.

The operator selected Weatherford’s automated MPD system tomitigate the drilling hazards, which allowed the entire 8 ½-in. sectionto be drilled to 5,933 m (19,465 ft) TD. The system saved the client anestimated $7.5 million and 10 days of rig time while reducing risk andimproving safety. Weighting up the mud system and controlling gasinfluxes accounted for approximately five of those saved days.

Planning processExisting MPD procedures could not be directly applied to the

well, and the extreme HP/HT environment prompted a cautious ap-proach.

A project team formed by the operator and MPD personnel wasestablished roughly four months ahead of the spud date. A rig surveydetermined that some major rig modifications were required, becausethe area between the rig’s annular preventer and the diverter couldnot accommodate the rotating control device (RCD). As a result, theriser had to be nippled down in the yard and a new, shorter overshotmandrel and packer assembly were manufactured to provide thenecessary space between the annular and the diverter.

Underbalanced drilling techniques could not be applied at anystage and surface backpressure would only be applied ifan influx was detected. It was necessary to includethe MPD procedures in the conventionalHP/HT procedures and establishguidelines for the use of MPDand conventional rig equipment.Several workshops and HP/HTtraining sessions were conduct-ed for rig and MPD personnel.

A full suite of integrated procedures and decision trees were pre-pared. It was decided that any kicks above 1 bbl would be handled bythe standard rig equipment due to a risk of taking a secondary kickif a kick greater than 1 bbl was circulated undetected to the surface.

MPD operations Two rig surveys were conducted to determine where the MPD

equipment would be placed. Due to limitations on variable deckload, space, and overshot mandrel modifications, none of the MPDequipment could be rigged up before the intermediate 13 5/8-in.casing had been run and cemented in place. Norwegian regulationsalso specified that electric cabling on the rig be upgraded to Norsokstandards. A total of 2 km (1.25 mi) of new cables had to be installedbefore the equipment could be installed.

The MPD equipment package featured an MPD manifold unitthat included computer-controlled chokes, Coriolis fl ow meters,and an intelligent control unit. A passive, self-lubricating, large-boreRCD (able to handle pipe up to 6 5/8-in. OD) was connected to theBOP annular. A removable bearing assembly for the RCD allowedfor an 18.69-in. ID when the bearing was removed. The RCD modelthat was used is the first certified to API 16D specification. Its pres-sure rating is 2,000 psi static and 500 psi at 200 rpm.

The equipment package also included various MPD sensors inthe MPD flowlines and mud pits. Hard and flexible piping was usedto connect the MPD equipment to the RCD, the rig’s choke mani-fold, the trip tank, and the rig’s poor-boy degasser.

A top flange tied the RCD back to the rig’s bell nipple. This equip-ment was rigged up prior to drilling out of the 13 5/8-in. casing.

Executing the plan Prior to drilling, an extensive flushing, pressure testing and finger-

printing program was conducted. The MPD system was engaged fromthe bottom 600 m (1.968 ft) of the 12 ¼-in. hole to ac-

quaint crews with new procedures and equipmentin advance of the lower, more difficult section.

After a series of tests to finger print the well,a 10% increase in the gas level was observed at5,562 m (18,248 ft). Drilling was stopped and the

well was circulated without any sig-nificant decrease in the gas levels.

Surface backpressure (SBP)was added in 100-psi incre-ments until the gas flowstopped. The flow and den-sity parameters stabilized at

350 psi SBP, indicating a porepressure of 18.5-18.6 ppg. To

verify an underbalanced state, theMPD choke was opened briefl y, and

conditions were confirmed.The bit was held stationary at 5,562 m (18,248

Brian GraysonWeatherford International Ltd.

MPD rig up schematic.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








seabed-to-surface

�� ! ��"��#��$�� !�� $� ��%�&�� ! ��'�� $��()&$��"

The sheer diversity of our projects means an engineering career at Subsea 7 can take you just about anywhere.

Technology makes our work possible, but it’s our people who bring it to life.

We are currently recruiting the following disciplines to be part of our ambitious future:

� ��

For more information on our North Sea projects or to apply, please visit www.subsea7.com/epic

www.subsea7.com

��

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.subsea7.com

http://www.subsea7.com/epic





��

��

��

��

��

��

�� !�"��#�

$%�&'�(��)��#�

*� ��&#�)��+��,'

�� -(�(�� .��#�

&/�0$��.��#

��1#�)��2�1334


ft) and the mud weight was increased from17.5 ppg to 18.0 ppg in one circulation cycle toslowly reduce the SBP on the MPD system toan equivalent 18.6-ppg dynamic mud weight.To confirm that formation integrity had notchanged at the casing shoe (19.5 ppg), theMPD equipment was used to perform anopen hole leak-off test.

The 19.1 ppg test figure indicated the pore-pressure/fracture gradient window had beenreduced to only 0.5 ppg. Mud weight wasramped up to 18.2, 18.3, 18.4, and 18.6 ppg to

carefully maintain a bottomhole circulatingpressure less than 19.0 ppg, ensuring a 0.1ppg safety margin.

Total rig time was only 40 hours from theinitial small gas influx at 5,562 m through asequence of steps that accurately determinedthe pore pressure (at 18.6 ppg) with full pres-sure control, weighted up from 17.5 ppg to18.6 ppg, and accurately determined the newformation integrity. Handled conventionally,the process might have taken five to six days.

Keeping ECD below 19.0 ppg required

the flow rate be maintained below 200 gal-lons per minute (gpm) for the remainderof the well. Small losses were experiencedthrough the sandy intervals.

After the gas incident had been resolved,confidence in the system increased, and itwas decided to apply SBP on connection in order to reduce wellbore breathing and thetime required to circulate the gas out of thehole. The available pressure window did notallow for a trip margin when pulling the BHAfor bit changes and coring.

Swabbing the well was avoided by strip-ping out the pipe through the RCD with abackpressure equivalent to 19.0 ppg from TDto approximately 1,400 m (4.593 ft) inside theproduction casing. A heavy, 20.0-ppg mud cappill was placed at 4,000 m (13.123 ft) to give thenecessary trip margin for the remainder of thetrip. When tripping back in it was discoveredthat the pill had not strung out much in thewellbore and had to be circulated out in stepscarefully to avoid losses. Although some loss-es were experienced, they decreased towardthe bottom of the pill and completely stoppedonce the pill was out of the hole.

Extensive use of the MPD system and theapplication of new techniques for trippingenabled the 8 ½-in. hole to reach TD at 5,932 m (19,463 ft) in 8 to 10 days sooner than off-

Automated MPD system.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



__________

http://www.ihcmerwede.com





Hydratight sets international standards in joint integrity on aglobal scale. With a team of over 1,000 employees operatingfrom 35 global locations, Hydratight has the engineering technology and expertise to offer safe, fast, accurate leak-free connections and pipeline integrity solutions.

To find out more atwww.hydratight.com/oilandgas

INNOVATION AS STANDARD


set wells where an intermediate liner was re-quired. The 8 ½-in. hole size benefited wire-line logging, coring, fi shing operations andDST testing compared to carrying out thesame operations in a 6 or 5 5/8-in. hole. TheMPD stripping technique was much fasterthan the standard process. It is estimatedthat a minimum of 12 hours were saved onevery trip using the technique.

The MPD operations were also used inthe P&A phase of the well. With a solid floatin the cement string, the MPD system held approximately 50 psi backpressure on theplugs when pulling out of the cement. In ad-dition, the 2,000 psi static pressure rating ofthe MPD equipment allowed its use to pres-sure test the cement plugs after tagging,which was significantly faster than riggingup to the cement unit for testing.

Lessons learnedUsing MPD and sophisticated fl ow de-

tection equipment allowed the well to besafely drilled to TD in an 8-½ in. hole witha 0.4 ppg pressure window. Doing so addedsignificant value to the formation evaluationprogram and with the DST.

The MPD system accurately determinedthe pore pressure in the well without theneed for any wireline tools, and this included

a sudden rise in pore pressure from 17.5 to18.6 ppg. Locking in the ECD pressure dur-ing connections in a controlled and safe wayeliminated all extra circulation time resultingfrom gas from wellbore breathing duringconnections.

It was shown that MPD procedures can betailored for the application and can be used tosave time and cost without placing the well-bore in an underbalanced state. Using MPDcontrolled stripping techniques can eliminatethe need for the conventional “pump out tothe shoe” check trip.

Savings experiencedUsing MPD led to operational and econom-

ic advantages. In total, using the MPD systemsaved 18.5 days or about $13.9 million. MPDrig-up and testing the net savings was 10 days($7.5 million).

Four days, or about $3 million, was savedcompared to a conventional set up when con-trolling gas influxes, determining the porepressure and enabling controlled weightingup. About 10 days ($7.5 million) were savedby successfully drilling the 8 ½-in. hole to TDin the narrow pore pressure/fracture gradi-ent margin.

The elimination of gas check trips whenpulling out for bit changes and coring saved

two days ($1.5 million). The MPD system al-lowed stripping out with backpressure to con-trol swabbing.

Other benefits included saving two days,because no dummy connections were re-quired; and another half day which wouldhave involved conducting open hole LOTsand pressure tests of cement plugs with theMPD equipment.

Significant time savings were achievedby locking in the ECD pressure during con-nections, which eliminated long circulationperiods following the connections. However,this is difficult to quantify and has not beenincluded in the time calculation. Lastly, atotal of eight and a half days were spent onrigging up, flushing, pressure testing, andfingerprinting the well

Moving to a closed loop, managed pressuredrilling system provided the data and controlto drill within a very narrow window in this ex-treme HP/HT well and still maintain an over-balanced mud weight throughout the opera-tion. Understanding pore pressure and welldynamics provided information for correctdecisions to be made and for an automatedcontrol system using annular backpressure toeffectively manage small influxes and losses.This capability allowed the well to reach TDexpediently with the optimal hole diameter. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________

http://www.hydratight.com/oilandgas

http://www.astican.es







Logging-while-drilling technologycontinues to reduce drilling risk

When logging-while-drilling (LWD)made its debut in the late 1980s,several advantages were touted.Chief among these was the poten-tial elimination of wireline logs.

In addition, it was postulated that LWD toolsarrived at target formations only a few min-utes after they had been penetrated by thebit, thus avoiding, for the most part, invasionof mud filtrate that might flush hydrocarbonsaway from the sandface.

But early LWD log quality, resolution anddepth accuracy were not up to the same levelof that offered by popular wireline logs thatwere in use at the time. LWD telemetry band-width limited real-time transmission of logdata. That was then.

Today, modern LWD logs rival their wire-line counterparts in most categories. Newtools measure nearly every formation param-eter with comparable precision. Telemetrybandwidth has been boosted, and downholeprocessing has reduced the amount of dataso decision-critical information is available tothe logging engineer in real time.

As the perceived value of LWD/MWD dataescalated, operators who once were not satis-fied by the cost have come increasingly to ac-cept that the cost is more than offset by thevalue of timely drilling and reservoir informa-tion. As more extended-reach wellbores areconstructed, operators are not comfortable ex-trapolating formation information from verticalpilot holes that could be thousands of feet away.They demand accurate data in these wellbores.This has leveled the playing field for LWD ver-sus wireline. The ability to reduce risk and steerwellbores precisely into formation sweet spotstranscends the cost in many cases.

Deliveringquantitative solutions

Akshay Sagar, Global Business Develop-ment Manager for Schlumberger Drilling& Measurements, explained his company’sposition. “Schlumberger is committed to de-livering quantitative solutions through highquality measurements using a completeportfolio of formation evaluation servicessupported by geographically dispersed cen-ters strategically located worldwide withhighly skilled technical experts to supportthese services.” He continued: “Two newmeasurements have been launched to kick

off an aggressive campaign of new technol-ogy introduction—the NeoScope sourcelessformation evaluation while drilling serviceand the MicroScope resistivity- and imaging-while-drilling service,” he said.

Both new members of the Scope family ofLWD services provide formation evaluationfor various targeted applications. The Neo-Scope tool is the first system able to provide acomprehensive multi-function formation eval-uation without a chemical radioactive source.Using a unique application of nuclear physics,the high-energy electronic neutron generatorprovides 2.5 times deeper reading formationdensity, neutron porosity, Sigma, and elemen-tal spectroscopy with repeatable accuracy.Interpretation of the resulting logs benefitsfrom a new algorithm that translates data intoactionable information in real time.

The MicroScope service helps in accurateformation evaluation and well placement inreservoir sweet spots. Operating equally wellin clastics and carbonates, it maps naturalfracture networks to support the completiondesign. Recently, in China, the tool maintained91% coverage in a 3 ft to 7 ft (1 m to 2 m) thindolomite bed over a 3,600-ft (1,095 m) lateraldespite numerous faults and dip variations.

“The new services work well in combina-tion with other members of the Scope Familyof LWD services in the respective hole sizes,”

said Sagar. “NeoScope is especially useful incountries with strict rules that limit transpor-tation of traditional radioactive sources,” heexplained. “Also, in high risk areas, such asdeepwater, customers no longer risk losinga radioactive source in the hole and all themandatory and costly procedures that ac-company such incidents.” The added reliabil-ity is paying off.

Obtaining essential information

Baker Hughes has replicated most of the fea-tures of its popular Reservoir CharacterizationInstrument (RCI) in the new FASTrak LWDfluid analysis sampling and testing-while- drill-ing service. This new service is capable of mak-ing an unlimited number of pressure and fluidanalysis tests; it can also capture and recover upto 16 fluid samples under pressure-volume-tem-perature (PVT) conditions. The advantages oftaking samples while drilling include obtaininga higher quality sample with less contamina-tion, and reduced pump-out times due to less in-vasion of the drilling fluid into the newly drilledreservoir. Combined, this results in better sam-ples at a reduced overall cost. This service wasdeveloped to help gather formation pressuredata and samples in environments that cannotbe tested with wireline tools, such as in highlydeviated or extended-reach wells.

In addition to the RCI-type sensors, thenew LWD sample service offers automaticsequencing during pressure testing, pump-through operations and sampling. Duringthese operations, quality data bits are sent upto the surface to ensure everything is goingaccording to plan.

Dick GhiselinSpecial Correspondent

(Left) Schlumberger engineer inspects the Micro-Scope resistivity and imaging-while-drilling tool.(Above) Schlumberger engineers download datafrom the NeoScope sourceless logging-while-drilling formation evaluation tool.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








© 2

012

Bake

r H

ughe

s In

corp

orat

ed. A

ll Ri

ghts

Res

erve

d. 3

5511

Welcome to the Pay Zone. Finish strong.When you’ve gone this far to reach your deepwater

pay, you need a completion that meets the challenges

of your reservoir.

With unrivaled deepwater experience and industry-

leading technical capabilities, we design, test, and

certify advanced systems for HP/HT pay zones, for sand

control and high-rate frac pack applications, and to

boost production from the seabed to the surface—

safely and reliably. Plus, our experts work with you

throughout your deepwater project to minimize NPT

and maintain peak production from your pay zone.

5,000 feet of water. 17,500 feet of hole. Hostile reservoir.

With testing capabilities

of 40,000 psi and 700°F,

our Center for Technology

Innovation enables us to go

well beyond the industry’s

current HP/HT requirements.

0

200

400

600

800

10,000 20,000 30,000 40,000

Tem

pera

ture

(°F

)

Pressure (psi)

North Sea

GoM Lower Tertiary

GoM Shelf

Baker HughesHP/HT Tool Rating

Baker HughesTest Cell Rating

bakerhughes.com/pzm-dw

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.bakerhughes.com/pzm-dw







The new LWD sampling service of-fers SmarTest optimized pressure test-ing, as employed by the Baker Hughes TesTrak formation pressure-while-drilling service. The SmarTest feature, vital in determining fl uid pressure and mobility, is performed automatically, and the test parameters are monitored by the engineer at the surface. Subse-quently, the tool selects the optimum pre-test and prepares to take a sample on the command of the engineer.

During the FASTrak clean-up activity, fl uid is pumped through the tool where it is ana-lyzed in real time and its degree of contamina-tion is assessed by the engineer before a sam-ple is captured. Contaminated fl uid is pumped through the tool and back into the mud col-umn. Only when the contamination level is acceptable will a sample be captured. Among the fl uid parameters continuously measured are viscosity, pressure, temperature, sound velocity, density, and refractive index. Calcula-tions of compressibility and the gas-to-oil ratio (GOR) are also performed during the fl uid clean-up stage.

Seal integrity is maintained automatically using the unique SmartPad feature. When the tool sets, it adjusts its setting pressure to maintain a seal. If during the course of the test the sealing pressure bleeds down below a certain threshold, the pump automatically initiates to restore and maintain the required sealing pressure. If the probe reaches full stroke and sealing pressure continues to bleed, a potential loss-of-seal warning is sent to the engineer so no time is wasted.

The potential of the tool becoming stuck is minimized because it is designed so the rig can maintain circulation the entire time the tool is set. To take advantage of this, Baker Hughes engineers have equipped the tool with a mud turbine to generate the necessary electrical power to oper-ate the tool. Since the tool activities are electro-mechanical rather than hydrau-lic, they were designed to be simpler and more robust with greater reliability, and under a wide range of environmen-tal conditions.

The LWD system uses the same single-phase sample tanks as in the RCI wireline tool. To ensure single-phase samples are obtained, the test tanks are pre-charged with nitrogen to keep the samples above their bubble points. After 450 cc to 830 cc samples are taken, the pump over pressures the tank before it

is sealed to ensure the sample is maintained above the bubble point. Filled test tanks are approved by the US Department of Transpor-tation for air, land or sea transport. A unique optical fi eld analysis can be made to ensure the tank contains a representative sample be-fore it is transported.

This service has acquired wireline-quality measurements in extremely challenging bore-hole environments. In Europe, an operation was performed in a 4,287 ft (1,307 m) tangent section at 73° inclination. The service accu-rately measured gradient quality formation pressures and collected six oil, two water, and three gas samples.

High-fi delity rock musicHalliburton has doubled down on its Bimodal

AcousTic (BAT) tool success by launching the QBAT multipole LWD sonic tool. With signifi -cant design improvements, the new tool helps deliver accurate shear and compressional veloc-ity measurements in a wider range of formation types than its predecessor. Very soft formations, like those often found just beneath the mudline in deepwater wells, are targeted by the QBAT sensors, and the tool provides geomechanics and wellbore stability parameters for determina-

tion of rock mechanical properties that are essential for successful completion designs.

Fourteen wideband piezoelectric receivers form an array that has an im-proved upper limit of slow shear mea-surement of over 600 μsec/ft; this is at least 50% better than previously pos-sible. The receivers are much less sen-sitive to drilling noise and have a much wider frequency response than standard ones. When coupled with four tunable axial transducers, positioned at 0°, 90°, 180°, and 270° around the collar’s circumference, the combination deliv-ers monopole, dipole, and quadrupole measurements under noisy drilling en-

vironments and/or poor borehole conditions. Translating tool description to delivered wave types, this means the tool can acquire Stoneley, fl exural, and screw waves for comprehensive acoustic interpretations that include synthetic seismograms and amplitude variation with off-set (AVO) reconciliation. The ability to tune the transducers allows the engineer to optimize the frequency to match the resonant frequency of each formation being drilled for higher quality compressional and shear-wave detection. Shear wave velocity is more accurate because of si-multaneous multipole inversion, paying off in demanding borehole conditions.

The tool has numerous applications. Besides traditional outputs like formation porosity, the tool can provide a cement bond indicator and deter-mining cement top of surface or intermediate cas-ing as the tool string traverses the upper portion of the hole. It has the high resolution to identify natural fracture swarms and evaluate them for possible subsequent completion decisions. And it can discriminate the presence of gas in the forma-tion using Vp/Vs ratios.

Available in 4.75-in., 6.75-in., 8-in., and 9.50-in.sizes, the QBAT tool is compatible with all Halli-burton LWD tools so custom confi gurations can be specifi ed. The 8-in. size is also available in a

high-fl ow version with 25% greater fl ow di-ameter. This doubles the maximum mass mud-fl ow rate to 20,000 lbm/min over the standard 8-in. size. A major benefi t of the new acoustic confi guration is a signifi cant boosting of signal-to-noise ratio which over-comes drilling noise that often compromis-es sonic measurements.

Baker Hughes has replicated most of the features of its popular Reservoir Charac-terization Instrument in the new FASTrak LWD fluid analysis sampling and testing-while-drilling service.

Halliburton has doubled down on its Bimodal AcousTic (BAT) tool success by launching the QBAT multipole LWD sonic tool. Tracks 1 and 2 show the high frequency response for the QBAT sensor wideband receiver (Track 1) versus a standard receiver (Track 2). Tracks 3 and 4 show the same comparison for the low frequency response. The receivers were all mounted on the same tool, operating in extremely poor hole conditions.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








HALLIBURTONSolving challenges.™

© 2012 Halliburton. All rights reserved.

CEMENTING SERVICES

“ What if, for cementing depleted zones, there were a predictive analysis service that could model the precise placement of your lightweight cement?”

iCem®

service answers

questions before the job.Find out how athalliburton.com/icem

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________________

http://www.halliburton.com/icem





IPLOCA - Connecting the pipeline

construction industry

Unique Business

Networking

HSE Monitoring &

Awards

Construction

Innovation & Awards

Industry-specific

Training

INTERNATIONAL PIPE LINE & OFFSHORE CONTRACTORS ASSOCIATION

240 corporate members from more than 40 countries

www.iploca.com


Big bang sonic toolWeatherford’s ShockWave sonic tool addresses the industry

need for reliable, real-time access to reservoir information whiledrilling. The tool provides high-quality sonic data continuously.According to Mohamed Diab, Weatherford ShockWave SonicProduct Champion, “We chose an LWD design to provide maxi-mum benefit to the driller. A high-quality signal delivered from anLWD tool removes the need to run a separate wireline sonic tool,saving money and time,” he explained.

The essence of the new tool was to create a device that wouldmaximize formation signals while minimizing drilling noiseevents. The goal of the design group was to develop a high-accu-racy downhole measurement to deliver real-time data under anydrilling conditions. The team was aided by the initial develop-ment of a software modeling program that allows them to testand qualify designs of individual tool components and the entiretool itself on paper, eliminating the need to build and test pro-totypes. A key objective was to design effective sound isolationbetween the tool transmitter and its receivers while maintainingstrength of the drill collar.

Diab elaborated: “Our transmitter enables a high-strengthsignal that can be easily differentiated from the drilling noiseassociated with the LWD environment. It provides good signaldirectionality to focus the signal into the formation with nominalsonic energy being transmitted to the tool body.” Diab continuedto explain how engineers and scientists were able to design andtest several transmitter/receiver concepts to achieve maximumsignal-to-noise ratio. The final transmitter design delivers about0.87 psi of pressure which is 50% more than the tool’s wirelinecounterpart. He claimed the LWD transmitter output was two to

three times greater than that of conventional LWD sonic devices inthe industry. The design is scalable, and can be configured to fit dif-ferent collar sizes as needed. Currently 6.75-in. and 8.25-in. tools areavailable with other sizes under development. The tough ShockWavesonic tool has pressure and temperature ratings of 30,000 psi and329°F (165°C) respectively.

The receiver array has high sensitivity in the axial direction andlow sensitivity in the radial direction making it particularly sensitiveto formation signals and less sensitive to collar signals or mud flownoise. Receivers are acoustically isolated from the collar to mini-mize direct coupling of transmitted signals through the collar. Pro-cessed data is available in the field within a few hours after the bit run.

Successful applications have been achieved in the Gulf of Mexico,the North Sea the Middle East and China. In the North Sea, a par-ticularly challenging job required logging through 9 5/8-in. casing. Ac-cording to Diab, the tool correctly identified the casing and presenteda continuous compressional sonic log of the formation behind the pipe.

Continuous technical improvementsOver a period spanning three decades, the capabilities and quality of

LWD solutions has steadily increased. LWD tool strings have playedan enabling role in all the recent world record extended reach drilling(ERD) wells and in the world’s ultra deepwater discoveries. Today, theproviders of modern LWD tool strings can truly live up to the promisemade decades ago. “If the drillers can drill it, we can log it.” �

Weatherford’s ShockWave sonic tool addresses the industry need for reli-able, real-time access to reservoir information while drilling.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.iploca.com





ShawCor’s new Simulated Service Vessel (SSV), winner of the 2012 OTC Spotlight on New Technology Award, is the industry’s largest and most advanced deepwater test chamber for end-to-end thermal insulation systems. It accommodates pipe samples up to 6 m long and 910 mm external diameter, and simulates water depths to 3,000 m and temperatures up to 180°C. The innovative SSV helps validate your subsea insulation design through accurate determination of U-value, cool-down and compressive creep; precise control of testing process; real-time data acquisition and expert analysis.

ShawCor – when you need to be sure

When your pipeline is 3,000 meters subsea, you can’t afford uncertainty

2012 Award Winner

shawcor.com

Watch the SSV video:www.shawcor.com/ssv

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.shawcor.com

http://www.shawcor.com/ssv






Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min

2012 MWD/LWD Services Directory

Directional

APS Technology (Rental Division) Brian A. Stroehlein 7 Laser Lane Wallingford, CT 06492 (860) 613-4450 [email protected]

APS SureShot 3 1/8, 3 1/2, 4 3/4,6 1/4,

6 3/4, 8, 9 1/2+

25* Collar-limited Collar-defined 150 and175

20 and 25 (3 1/2) 27,(4 3/4 - 6 3/4) 6,

(8) 3,(9 1/2) 2

(3 1/2) 150,(4 3/4 - 6 3/4) 35,

(8) 20,(9 1/2) 10

(6 1/2 - 6 3/4) 114,(8) 61,

(9 1/2) 32

(9 1/2) 220 (3 1/8, 3 1/2) 70 - 250(4 3/4) 150 - 350

(6 1/4, 6 3/4) 150- 750(8) 300 - 1,100

(9 1/2+) 650 - 1,200

APS SureShot with Gamma 3 1/8, 3 1/2, 4 3/4,6 1/4,

6 3/4, 8, 9 1/2+


20 and 25 (3 1/2) 29,(4 3/4 - 6 3/4) 6,

(8) 3,(9 1/2) 2

(3 1/2) 165,(4 3/4 - 6 3/4) 40,

(8) 20,(9 1/2) 10

(6 1/2 - 6 3/4) 114,(8) 61,

(9 1/2) 32

(9 1/2) 225 (3 1/8, 3 1/2) 70 - 250(4 3/4) 150 - 350

(6 1/4, 6 3/4) 150- 750(8) 300 - 1,100

(9 1/2+) 650 - 1,200

APS SureShot Gamma + WPRPropagation Resistivity

3 1/2, 4 3/4, 6 3/4, 8 59 (2 pcs.)* Collar-limited Collar-defined 150 and175

20 and 25 Configuration-dependent

Configuration-dependent Configuration-dependent

Configuration-dependent (3 1/2) 190 max. (4 3/4) 350max. (6 3/4) 700 max. (8)

1,200 max.

APS Push-the-Bit RotarySteerable Motor (RSM)

6 3/4(blades and stabilizers

for 8 1/2 and 8 3/4holes)

17* Programmable build rates of 0.5to 5.5. Also, vertical and tangent

angle hold modes.

150 20 250 psi @ 600gal/min

300 - 600 gal/min

Baker Hughes Dana Morrison - 2929 Allen Parkway, Suite 2100, Houston, TX 77019, (713) 439-8254, [email protected] / [email protected]

AutoTrak Curve (High-build rate Rotary

Steerable System, includingMWD)

6 3/4 6 3/4in = 37.8 6 3/4in = 30/15 BHA-dependent Standard150

Standard20

(a) (a) (a) (a) 6 3/4in = 300-750

AutoTrak G3(Rotary Steerable System,including OnTrak MWD or

AziTrak Integrated MWD/LWD)

4 3/46 3/48 1/49 1/2

4 3/4in = 50.86 3/4in = 49.98 1/4in = 56.99 1/2in = 58.1

4 3/4in = 30/106 3/4in = 20/138 1/4in = 9/6.59 1/2in = 13/6.5

BHA-dependent Standard150;

Optional175 for 63/4in, 81/4in, 91/2in

Standard20

Optional 25& 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-900 8 1/4in

= 300-1290 9 1/2in =300-1,600

AutoTrak X-treme (RotarySteerable System, including

OnTrak MWD or AziTrakIntegrated MWD/LWD andhard-wired, precontoured

modular X-treme mud motor)

4 3/46 3/49 1/2

4 3/4in = 72.66 3/4in = 709 1/2in = 82

4 3/4in = 25/106 3/4in = 16/79 1/2in = 8/3.8


Optional175 for6 3/4in,9 1/2in

Standard20

Optional 25& 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

AutoTrak eXpress (RotarySteerable System includingMWD, can be run with hard-

wired modular X-treme motor)

4 3/46 3/49 1/2

4 3/4in = 56.86 3/4in = 58.2 Version 6 3/4in

High Dog Leg = 709 1/2in = 64.6

4 3/4in = 30/106 3/4in = 23/8 Version 6 3/4in

High Dog Leg = 23/129 1/2in = 13/6.5

BHA-dependent 150 20 (a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

AutoTrak V (Rotary Steerable System that

does not require MWD)

4 3/46 3/49 1/2

4 3/4in = 23.16 3/4in = 19.79 1/2in = 22.3

4 3/4in = 30/106 3/4in = 23/8

9 1/2in = 13/6.5


Optional175 for6.3/4in,9.1/2in

Standard20

Optional 25& 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

Advanced SLIM MWD system 3 1/8 26.4 50° sliding , Rotation BHAdependant

N/A 150 20 (a) (a) (a) (a) 79 - 180

CoilTrak - Coiled Tubing DrillingSystem

2 3/8in and 3in on CT 49.5, typical BHA includingmotor

2 3/8in 50, 3in 45 - sliding only N/A 150 14.5 (a) (a) (a) (a) 2 3/8in max 80, 3in max 211

CoilTrak Rib-Steered Motor(Extended Reach/Straight

Trajectory drilling module foruse in conjunction with

CoilTrak system)

3in on CT 19.6 10 - sliding only N/A 150 14.5 (a) (a) (a) (a) 40 - 120

GyroTrak 9.5in 8.25in 6.75in(OnTrak) 3.125in

and larger (NaviTrak/TeleTrak)

16.0 (OnTrak) 29.0 NMDC(NaviTrak/TeleTrak)

Probe limits: (1 3/4) 115/51 N/A 125 20 (a) (a) (a) (a) 300 - 1600 (OnTrak) 100-1600(NaviTrak)

Gyro-Guide 9.5in 8.25in 6.75in(OnTrak)

16.3 Drill Collar Specs Drill Collar Specs 150 20 (a) (a) (a) (a) 300 - 1600 (OnTrak)

NaviTrak 1 3/4 OD probe; (13/4) 3 1/8 and larger

collars

(1 3/4) 22 Probe limits: (1 3/4) 115/51 NMDC Specs 150 20 (a) (a) (a) (a) 75-1600

OnTrak (integrated directional,gamma ray and formationresistivity at mutiple depths

of investigation)

4 3/4, 6 3/4, 81/4, 9 1/2

OTK (4 3/4) 20.2, (6 3/4)17.0, (8 1/4) 19.0, (9

1/2) 18.1

(4 3/4) 33/12, (6 3/4) 25/15, (81/4) TBD, (9 1/2) 10/7

NA Standard.150,

Optional175

Standard20; (4-3/4,

6-3/4 &8-1/4,9-1/2)

Optional25; (4-3/4,

6-3/4 &8-1/4)

Optional 30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4) 200-900, (8 1/4) 300-1295, (9 1/2)

300-1,600

AziTrak (integrated directional,gamma ray and azimuthal

formation resistivity at mutipledepths of investigation)

4 3/4, 6 3/4 (4 3/4) 40.4, (6 3/4) 35.3 (4 3/4) 33/12, (6 3/4) 25/15,(8 1/4) TBD, (9 1/2) 10/7

NA Standard.150,

Optional175

Standard20; (4-3/4,

6-3/4)Optional

25; (4-3/4,6-3/4)

Optional 30

(a) (a) (a) (a) (4 3/4) 125-350, (6 3/4)200-900

E-MTrak 4 3/4, 6 1/2 (4 3/4, 6 1/2) 39.6 Slick collar: (4 3/4) 21/7,(6 1/2) 12.5/6.5

Flexible collar: (4 3/4) 58/32,(6 1/2) 48/25

NMDC Specs 150 20 (a) (a) (a) (a) (4 3/4) max 350, (6 1/2)max 660

TruTrak (Non-rotating Automated

Drilling System including MWDand Optionalional Gamma)

4 3/46 3/4

89 1/2

4 3/4in = 28.36 3/4in = 31.0

8in = 36.19 1/2in = 36.1; Excluding

MWD

4 3/4in = 56 3/4in = 3

8in = 29 1/2in = 2

N/A 150 20 (a) (a) (a) (a) 4 3/4in = 125-3176 3/4in = 264-660

8in = 395-9009 1/2in = 528-1162

TeleTrak (highly LCM tolerantsystem)

4 3/4,6 1/2, 6 3/4

(4 3/4) 44.5 (6 1/2, 6 3/4) 39.83

Probe limits: (1 3/4) 115/51 NMDC Specs 150 20 (a) (a) (a) (a) (4 3/4) 120- 350 (6 1/2, 6 3/4) 240-750

SDL(Steerable Drilling Liner

including Rotary SteerableSystem, OnTrak MWD or

AziTrak Integrated MWD/LWDand hard-wired, precontouredmodular X-treme mud motor)

4 3/4in BHA with7in liner

6 3/4in with 95/8in liner

User defined 3, rotating only BHA-dependent 150 Standard20;

Optional 25& 30

(a) (a) (a) (a) (4 3/4) 125-350, (6 3/4)200-900

To download the full survey free of charge, please visit our website: www.offshore-mag.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________________







Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


DrilTech LLC Brad Vincent - 248 Rousseau Road, Youngsville, LA 70592, (337) 837-1219, [email protected]

Positive Pulse MWD ProbeBased

1 7/8 tool OD, 4 3/4 -8 collars

18-25 60/30 As applicable to standard NMDC 150 -175

20 (137mpa)

50 (NMDCdependent)

100 (NMDC dependent) 150 (NMDC dependent) N/A (3 1/2) 50-130, (4 3/4)130-275, (6 3/4) 235-600,

(8) 400-800

GE Oil & Gas Chau Nguyen - 4424 W. Sam Houston Parkway N. 10th Floor, Houston, TX 77041, (713) 458 3629, [email protected]

Pilot 3 1/2, 4 3/4, 6 1/2,8, 9 1/2

Shortest probe length 17.8 (4 3/4) 30/15(6 3/4)21/10

(8)14/8

(9 1/2)7/4

(4 3/4) 4.75x2.81, (6 3/4) 6.71x2.81, (8)7.93x2.81, (9 1/2) 9.42x2.81

150 20 (4 3/4 - 6 3/4) 8 (4 3/4 - 6 3/4) 47 (4 3/4 - 6 3/4) 153 (9 1/2) 450 130-1060

Tensor 3 1/2, 4 3/4, 6 1/2,8, 9 1/2

Shortest probe length 25.2 (3 1/2) 100/50(4 3/4) 30/15

(6 3/4)21/10

(8)14/8

(9 1/2)7/4

(3 1/2) 2.96x2.25, (4 3/4) 4.75x2.81, (6 3/4)6.71x4.00, (8) 7.93x2.81, (9 1/2) 9.42x4.00

175 20 (4 3/4 - 6 3/4) 6 (4 3/4 - 6 3/4) 39 (4 3/4 - 6 3/4) 127 (9 1/2) 373 75-1200

Halliburton/Sperry Drilling Billy Hendricks - P.O. Box 60070, Houston, Texas 77205, (281) 871-5396, [email protected]

Electromagnetic TelemetrySystem

3 1/2, 4 3/4, 6 1/2 (3 1/2) 33.9, (4 3/4) 33.5, (61/2) 35.6 (t)

35/14 (3 1/2 flex) 2.9x1.5, (4 3/4 flex) 4.06x2.25, (61/2 flex) 4.63x2.81

150 15 (3 1/2) 171, (4 3/4) 139,(6 1/2) 40

(4 3/4) 400, (6 1/2) 150 N/A N/A

Negative Pulse TelemetrySystem

6 3/4, 8, 9 1/2 9.2 (6 3/4) 21/10, (8, 9 1/2) 14/8 (6 3/4) 6.54x2.81, (8) 7.76x2.81, (9 1/2) 9.35x3 150 18 std., 25opt.

(6 3/4, 8) 17, (9 1/2) 4 (6 3/4, 8) 31, (9 1/2) 7 (6 3/4, 8) 182, (9 1/2) 36 (x)

Positive Pulse TelemetrySystem

3 3/8, 3 1/2, 4 3/4,6 1/2, 6 3/4, 7 1/4,

8, 9 1/2

(3 3/8, 3 1/2) 21, (4 3/4 - 91/2) 26

(3 3/8 - 4 3/4) 30/14, (6 1/2 - 71/4) 21/10, (7 3/4 - 9 1/2) 14/8

(3 3/8) 3.21x1.5, (3 1/2) 3.35x1.5, (4 3/4)4.66x2.25, (6 1/2 - 9 1/2) Equivalent to a

standard NMDC

150 std.175opt.

20, 22.5,25, 30

(3 3/8, 3 1/2) 120at 150 gal/min

(4 3/4) 140 170 380 (3 3/8, 3 1/2) 90-200, (43/4) 150-350, (6 1/2 -9 1/2)

225-650, (7 1/4 - 9 1/2)400-1,500

MWD Gyro 6 3/4, 8, 9 1/2 25.8 (6 3/4) 21/10, (8) 14/8, (91/2) 14/8

Equivalent to standard NMDC 150 20 (6 3/4, 8) 17, (9 1/2) 4 (6 3/4, 8) 31, (9 1/2) 7 (6 3/4, 8) 182, (9 1/2) 36 225-1500

MWD Services LLC. Clyde Cormier - P O Box 750, or 219 Griffin Rd, Youngsville, LA 70592, (337) 856-5965, [email protected]

MWD Shuttle 1 7/8 tool OD, 31/8 - 9 1/2

22.7 w/single battery, 29.1 w/dual battery

60/30 As applicable to standard NMDC 150 20 40 80 150 75-1,000

Navigate Energy Services Steve Krase - 15700 International Plaza Drive, Suite 150, Houston, TX 77032, 832-300-0030, [email protected]

Drift 6 1/2, 8, & 9 1/2 8 ft API conn limited TBD 150 20 N/A 60 125 N/A 250-1300

Directional 4 3/4, 6 1/2, 8available Q4 ‘09

(4 3/4) 10, ( 6 1/2 & 8) 10 (4 3/4) 32/16, (6 3/4) TBD,(8) TBD

As applicable to standard NMDC 150 20 N/A 60 125 N/A 225-1000

PathFinder, a Schlumberger company Allan Rennie - 23500 Colonial Pkwy, Katy, TX 77493, (281) 769-4501, [email protected]

HDS-1L Directional Survey 4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

30 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.98x2.81,

(9 1/2) 9.5x3

150 20 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45, ( 8 HF,

9 1/2) N/A

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

HDS-1M Directional 6 3/4, 8 LF, 8 HF, 9 1/2 26.6 (6 3/4) 17/9, (8 LF) 18/10, (8 HF)18/10, (9 1/2) 12/6

(6 3/4) 6.43x2.81, (8 LF) 7.85x2.81, (8 HF)7.60x2.81, (9 1/2) 9.36x3.00

150 20 (6 3/4, 8 LF, 8 HF,9 1/2) N/A

(6 3/4) 50, (8 LF, 8 HF,9 1/2) N/A

(6 3/4) 90, (8 LF) 90, (8HF, 9 1/2) 40

(6 3/4, 8 LF, 8 HF), N/A (91/2) 200

(6 3/4) 315-750, (8 LF) 315-950, (8 HF) 375-1125, (9 1/2)

500-1500

HDS-1R Directional 3 1/8 - 9 1/2 30 60/30 Dependant on drill collar As applicable to standard NMDC 150 20 250 250 250 250 (2 1/4) 60-180, (2 1/2) 140-280, (2 11/16) 180-350, (2

13/16) 250-550, (3 1/4) 300-1,000 (3 1/2) 600-1,500

HDS-1S Directional 4 3/4, 6 3/4, 8LF, 8 HF

16 (4 3/4) 31/17,(6 3/4) 17/9, (8 LF)18/9, (8 HF) 18/9

(4 3/4) 4.69x2.25, (6 3/4) 6.74x2.81, (8 LF)7.98x2.81, (8 HF) 7.98x2.81

150 20 (4 3/4) 40, (6 3/4,8 LF, 8 HF) N/A

(4 3/4) 50, (6 3/4, 8 LF)45, (8 HF) N/A

(4 3/4) N/A, (6 3/4) 50,(8 LF) 50, (8 HF) 45

(4 3/4, 6 3/4, 8 LF) N/A,(8 HF) 200

(4 3/4) 125-375, (6 3/4) 250-750, (8 LF) 250-950, (8 HF)

375-1,125

Survivor HDS-1 Directional 4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

30 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.95x2.81,

(9 1/2) 9.5x3.0

175 25 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45,( 8 HF,

9 1/2) NA

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

Survivor HDS-1R Directional 3 1/8 - 9 1/2 30 60/30 Dependant on drill collar As applicable to standard NMDC 175 25 250 250 250 250 (2 1/4) 60-180, (2 1/2) 80-280,(2 11/16) 100-350, (2 13/16)

150-550, (3 1/4) 300-1,000 (31/2) 600-1,500

Survivor HDS-1S Directional 4 3/4, 6 3/4, 8LF, 8 HF

16 (4 3/4) 31/17,(6 3/4) 17/9, (8 LF)18/9, (8 HF) 18/9

(4 3/4) 4.69x2.25, (6 3/4) 6.74x2.81, (8 LF)7.98x2.81, (8 HF) 7.98x2.81

175 25 (4 3/4) 40, (6 3/4,8 LF, 8 HF) N/A

(4 3/4) 50, (6 3/4, 8 LF)45, (8 HF) N/A

(4 3/4) N/A, (6 3/4) 50,(8 LF) 50, (8 HF) 45

(4 3/4, 6 3/4, 8 LF) N/A,(8 HF) 200

(4 3/4) 125-375, (6 3/4) 250-750, (8 LF) 250-950, (8 HF)

375-1,125

Payzone Inclination Gamma 4 3/4, 6 3/4 7.13 upper, 2.7 lower (4 3/4) 31/17, (6 3/4) 17/9 (4 3/4) 4.66x2.25, (6 3/4) 6.57x2.81 150 20 N/A (4 3/4) 70, (6 3/4) 20 (4 3/4) N/A, (6 3/4) 35 N/A (4 3/4) 125-375, (6 3/4)250-750

Imaging Payzone InclinationGamma

4 3/4, 6 3/4, 8 7.13 upper, 3.33 lower, 5.92upper, 3.66 lower, 5.92

upper, 3.66 lower

(4 3/4) 31/17, (6 3/4) 16/10,(8) 16/10

(4 3/4) 4.43x2.25, (6 3/4) 5.99x2.81, (8)6.99x2.81

175 (4 3/4), (63/4) 25,(8) 20

N/A (4 3/4) 70, (6 3/4) 20 (4 3/4) N/A, (6 3/4)35, (8) 20

N/A (4 3/4) 125-375, (6 3/4) 250-750, (8) 250-1125

Gyro HDS1 4 3/4, 6 3/4, 8LF, 8HF, 9 1/2

30 (4 3/4) 31/17, (6 3/4) 17/9, (8 LF)18/9, (8 HF) 18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/4) 6.74x2.81, (8 LF)7.98x2.81, (8 HF) 7.98x2.81, (9 1/2) 9.39x3

150 20 (4 3/4) 40 (63/4, 8 LF, 8 HF, 9

1/2) N/A

(4 3/4) 50, (6 3/4, 8 LF)45, (8 HF, 9 1/2) N/A

(4 3/4) N/A, (6 3/4, 8 LF)50, (8 HF, 9 1/2) 50

(4 3/4, 6 3/4, 8 LF) N/A, (8HF, 9 1/2) 200

(4 3/4) 125-375, (6 3/4) 250-600, (8 LF) 250-950, (8 HF)375-1,125 (9 1/2) 500-1,500

Gravity HDS1 4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

46 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.98x2.81,

(9 1/2) 9.5x3

150 20 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45, (8 HF,

9 1/2) N/A

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

Survivor Gravity HDS1 4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

46 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.98x2.81,

(9 1/2) 9.5x3

175 25 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45,( 8 HF,

9 1/2) N/A

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

Slim Array Wave Resistivity 4.75 20 30/15 4.72x2.25 150 25 6 29 N/A N/A 120-375

Survivor Slim Array WaveResistivity

4.75 20 30/15 4.72x2.25 175 25 6 29 N/A N/A 120-375

Array Wave Resistivity 6 3/4, 8, 9 1/2 20 (6 3/4) 16/10, (8, 9 1/2) 16/10 (6 3/4) 6.4x2.81, (8) 8.9x3, (9 1/2) 8.9x3 150 (6 3/4, 8, 91/2) 25

N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750,(8) 250-1,125,

(9 1/2) 250-1,500

Survivor Array Wave Resistivity 6 3/4, 8, 9 1/2 20 (6 3/4) 16/10, (8, 9 1/2) 16/10 (6 3/4) 6.4x2.81, (8) 8.9x3, (9 1/2) 8.9x3 175 (6 3/4, 8, 91/2) 25

N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750,(8) 250-1,125,

(9 1/2) 250-1,500


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


Ryan Directional Services Randy Starnes - 19510 Oil Center Blvd., Houston, TX 77073, (281) 443-1414, [email protected]

Ryan EM 4 3/4, 6.5, 6 3/4 34 (4 3/4) 75° / 20° (6 3/4) 28°/11° (4 3/4) 4.75x2.81 (6 3/4) 6.71x3.25 175C 20K PSI(137 mpa)

8 47 153 450 (4 3/4) 100-350(6 3/4) 150-800

Ryan Mud Pulse 3 1/8, 4 3/4, 6.5,6 3/4, 8, 9.5

20-30 (3 1/8) 100°/ 50°(4 3/4) 40° / 15°(6 3/4) 28°/11°

(8) 15°/9°(9.5) 8°/ 5°

(3 1/8) 2.96x2.25 (4 3/4) 4.75x2.81(6 3/4) 6.71x3.25 (8) 7.93x4.00

(9.5) 9.42x4.00

175C 20K PSI(137 mpa)

8 47 153 450 (3 1/8) 50-175(4 3/4) 100-350(6 3/4) 150-800

(8) 400-925(9 1/2) 400-1200

Schlumberger Mike Williams - 281-285-8500

PowerDrive X5Rotary Steerable Tool

4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4) 14.95, (6 3/4 ) 13.48,(8 1/4 , 9 ) 14.6, (11 ) 15.1

Capability (°/100 ft) : (4 3/4 , 63/4) 8, (8 1/4 ) 6, (9 ) 5, (11 ) 3Pass Through (°/100 ft): (4 3/4)30/15, (6 3/4 , 8.25 , 9 ) 20/10,

(11 ) 15/8

150 20 std,30 opt. (43/4, 6 3/4)

N/A 36(600 - 750 psi required

across bit)

30(600 - 750 psi required

across bit)


across bit)

220-1,900


4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4) 14.95, (6 3/4 ) 13.48,(8 1/4 , 9 ) 14.6, (11 ) 15.1

Capability (°/100 ft) : (4 3/4 , 63/4) 8, (8 1/4 ) 6, (9 ) 5, (11 ) 3Pass Through (°/100 ft): (4 3/4)30/15, (6 3/4 , 8.25 , 9 ) 20/10,

(11 ) 15/8

150std., 175

opt.

20 std,30 opt. (4

3/4),35 opt. (63/4, 8 1/4)

36(600 - 750psi requiredacross bit)


across bit)


across bit)


across bit)

100-2,000

PowerDrive ArcherRotary Steerable Tool

6 3/4 (6 3/4 ) 16.64 Capability (°/100 ft) : (6 3/4) 15 Pass Through (°/100 ft): (63/4) , >15 Based on fatigue

management

150 20 N/A N/A 30(600 - 750 psi required

across bit)

N/A 250-650

Power Drive XceedRotary Steerable Tool

6 3/4 , 9 (6 3/4 ) 25, (9) 28 Capability (°/100 ft) : (6 3/4)8, (9) 6.5

Pass Through (°/100 ft): (6 3/4)15/8, (9) 12/6.5

(6 3/4) 31, (9) 35.9 150 20 N/A N/A 60 N/A 290-1800

PowerVVertical drilling

Rotary Steerable Tool

4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4 ) 14.95, (6 3/4 ) 13.48,(8 1/4 , 9 ) 14.6, (11 ) 15.1

Capability (°/100 ft) : (4 3/4 , 63/4 , 8 1/4 ) 8, (9 ) 5, (11 ) 4

Pass Through (°/100 ft): (4 3/4) 30/15, (6 3/4 , 8.25 , 9 ) 20/10,

(11 ) 15/8

150std., 175

opt.

20 std,30 opt. (4

3/4),35 opt. (63/4, 8 1/4)


across bit)


across bit)


across bit)

100-2,000

PowerDrive vorteX Xceed 6 3/4 , 9 (6 3/4) 55, (9) 58 Capability (°/100 ft) : (6 3/4)8, (9) 6.5

Pass Through (°/100 ft): (6 3/4)15/8, (9) 12/6.5

N/A 150 20 N/A 235 N/A N/A 290-1800

PowerDrive vorteX 4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4) 30, (6 3/4) 43, (8 1/4)49.6. (9, 11) 50.6

Capability (°/100 ft) : (4 3/4 , 63/4) 8, (8 1/4, 9) 6, (11) 3

Pass Through (°/100 ft): (4 3/4)30/15, (6 3/4 , 8 1/4, 9) 20/10,

(11) 15/8

N/A 150 std.,175 opt.(4 3/4.6 3/4, 8

1/4)

20 std,30 opt. (4

3/4),35 opt. (63/4, 8 1/4)

N/A 235 250, 200 350 130 - 2,000

PowerPak ERT highperformance positivedisplacement motors

4 3/4, 6 3/4, 8, 9 5/8 17.3 (4 3/4), 16.3 (6 3/4),30.2 (8), 30 (9 5/8)

As per motor specification forbend setting

N/A 175 30 Dependent onspecific model

Dependent on specificmodel



125-325 (4 3/4), 300-650 (63/4), 300-900 (8), 600-1200

(9 5/8)

PowerPak HR higher torquepositive displacement motors

4 3/4, 6 3/4,7, 8,9 5/8, 11 1/4

Dependent on specific model As per motor specification forbend setting

N/A 175 30 Dependent onspecific model




125-325 (4 3/4), 300-600(6 3/4 and 7), 300-900 (8),

600-1200 (9 5/8), 800-1800(11 1/4)

ImPulse 4.75 32 30/15 4.75x2.25x38.5 150std., 175

opt.

20 std.,27.5 opt.

N/A 125 (varies withModulator gap)

N/A N/A 130-400

ShortPulse 4 3/4 27.3 30/15 4.75x2.25x34.8 -OR-

4.59x2.25x30.3

150std., 175

opt.

20 N/A 125 (varies withModulator gap)

N/A N/A 130-400

PowerPulse 6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56(8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)

(8 1/4, 9 1/2) 595 (varieswith modulator gap)

(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

TeleScope 6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56 (8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)


(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

SlimPulse 1 3/4 tool OD3 1/8 to 9 1/2 collars

Collar based probenormally 30

(4 3/4 and smaller) 145/40(6 3/4) 28/10(8 1/4) 20/8(9 1/2) 19/7

(4 3/4) 4.75x2.81x33(6 3/4) 6.75x2.81x32

150std., 175

opt.

22 (4 3/4) 68(6 3/4) 16

(6 3/4) 100(8 1/4) 18

(6 3/4) 324(8 1/4, 9 1/2) 58

(8 1/4, 9 1/2) 411 Multiple configurations:35-1,200

GyroPulse 6 3/4”,8 1/4, 9, 9 1/2 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

(8 1/4) 8.25x3.5x26.2 (9) 9x3.5x28 (9 1/2)9.5x3.5x26.2

150 25 N/A N/A 4 26 (6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

Sharewell Energy Services Heather Heacock - 12200 W. Little York Rd., Houston, TX 77041, [email protected]

Directional Electro-TracEM MWD

4 3/4 6 1/2 6 3/47 3/4

25.5’ (adjusted to Monellength)

collar limited Collar-defined 150 20 25 100 100 100 50-1200

Weatherford Jeff Whitney - 16178 West Hardy Rd., Houston, TX 77060, [email protected]

Revolution Rotary Steerable 4 3/4, 6 3/4, 8 1/4, 9.5 (4-3/4”) 12’, (6-3/4”) 14’,(8 1/4”) 17’

(4 3/4) 10, (6 3/4), 8, (8 1/4) 7 150 20 std.25 opt.

20 35 55 N/A (4 3/4) 350; (6 3/4) 750; (81/4) 1,500

High Temperature RotarySteerable (Revolution HT)

4 3/4, 6 3/4, 8 1/4, 9.5 (4-3/4”) 12’, (6-3/4”) 14’,(8 1/4”) 17’

(4 3/4) 10, (6 3/4), 8, (8 1/4) 7 165 std.180opt.

25 20 35 55 N/A (4 3/4) 350; (6 3/4) 750; (81/4) 1,500

MotarySteerable

4 3/4, 6 3/4, 77/8, 8 1/4

65.0 (4 3/4) 25/16, (6 1/4) 20/14, (63/4) 18/13, (8) 15/10

150 std.180opt.

20 std.25 opt.

(4 3/4) 150-300; (6 3/4, 7 7/8,8) 200-600; (8 1/4) 300 -900

EMpulse (Electromagnetic) All sizes (3 1/16) 28.4, (4 3/4) 33.1,(6 3/4) 34.8, (8) 35.4, (9

1/2) 36.4

(3 1/6) 116/38, (4 3/4) 25/16,(6 1/4) 20/14, (6 3/4) 18/13, (8)

15/10, (9 1/2) 14/7.5

(3 1/16) 3.06x2.16, (3 3/8) 3.38x2.16, (4 3/4)4.53x2.25, (6 3/4) 6.59x2.81, (8) 7.78x2.81,

(9 1/2) 9.69x3

150 15 (3 1/16, 3 3/8, 3 1/2)100; (4 3/4) 8; (6 1/4) 9

(4 3/4) 20; (6 1/4) 25, (63/4, 8) 7; (9.5) 4

(6 3/4, 8) 20; (9.5) 13 (3 1/16, 3 3/8, 3 1/2) 160; (43/4, 6 1/4) 350; (6 3/4) 800

HEL (Hostile EnvironmentLogging)

4-3/4, 6-3/4, 8, 8-1/4,9-1/2

(4-3/4) 19.5, (6-3/4) 19.7,(8-1/4) 20.0, (9-1/2) 20.0

(4-3/4) 30/15, (6-3/4), 16/8, (8,8-1/4) 14/7, (9-1/2) 12/6

(4 3/4) 4.75x3.22, (6 3/4) 6.75x4.20, (8 1/4)8.25x5.17, (9 1/2) 9.50x5.16

150 std.180opt.

(4.75, 6.75,8”) 20 std.,

30 opt.(8.25, 9.5)20 std., 25

opt.

(4 3/4) 12, (63/4, 8) 2, (8 1/4,

9-1/2) 1

(4 3/4) 64, (6 3/4, 8) 9,(8 1/4, 9-1/2) 2

(4 3/4) 193, (6 3/4, 8)26, (8 1/4, 9 1/2) 2

(6 3/4, 8) 170, (8-1/4,9-1/2) 33

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


HyperPulse All sizes 31 (3 1/6) 116/38, (4 3/4) 25/16,(6 1/4) 20/14, (6 3/4) 18/13, (8)

15/10, (9 1/2) 14/7.5

(4 3/4) 4.75x2.69, (6 1/4) 6.25x3.25, (6 3/4)6.75x3.25

150 15 100 140 200 70-1,000

TrendLine 6-3/4, 8-1/4, 9-1/2 Dependent on drill collarlength - 26’ minimum

(6-3/4) 8/16, (8-1/4) 7/14,(9-1/2) 6/12

150 20 (4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

Drill String Dynamics

Ryan Directional Services

Ryan Dynamic Module 3 1/8, 4 3/4, 6.5,6 3/4, 8, 9.5

16.4 (3 1/8) 100°/ 50°(4 3/4) 40° / 15°(6 3/4) 28°/11°

(8) 15°/9°(9.5) 8°/ 5°

(3 1/8) 2.96x2.25, (4 3/4) 4.75x2.81, (6 3/4)6.71x3.25, (8) 7.93x4.00, (9.5) 9.42x4.00

175C 20K PSI(137 mpa)

8 47 153 450 (3 1/8) 50-175, (4 3/4) 100-350, (6 3/4) 150-800, (8)

400-925, (9 1/2) 400-1200

Drilling Mechanics

APS Technology (Rental Division)

APS SureShot with Gamma +VMM + PWD

3 1/8, 3 1/2, 4 3/4,6 1/4,

6 3/4, 8, 9 1/2+


20 and 25 (3 1/2) 29,(4 3/4 - 6 3/4) 6,

(8) 3,(9 1/2) 2

(3 1/2) 165,(4 3/4 - 6 3/4) 40,

(8) 20,(9 1/2) 10

(6 1/2 - 6 3/4) 114,(8) 61,

(9 1/2) 32

(9 1/2) 225 (3 1/8, 3 1/2) 70 - 250(4 3/4) 150 - 350

(6 1/4, 6 3/4) 150- 750(8) 300 - 1,100

(9 1/2+) 650 - 1,200

APS SureShot Gamma + VMM+ PWD + WPR Propagation

Resistivity





1,200 max.

Drilling Dynamics Monitor(DDM)

6 3/4, 8 6 14,10 (6 3/4)10, 8 (8)

150 20

Vibration Memory Sub (VMS) 4 3/4, 6 3/4, 8 5.5 150 20

Magnetorheological ActiveVibration Damper (AVD)

6.75 32 10 150 20

Baker Hughes

Acoustic Caliper 4 3/4, 6 3/4, 8 1/4 As per LithoTrak service As per LithoTrak service As per LithoTrak service As perLithoTrakservice

As perLithoTrakservice

(a) (a) (a) (a) As per LithoTrak service

Vibration Stick Slip (AutoTrakeXpress and AutoTrak-V

systems)

4 3/46 3/49 1/2

As per directional toolspecification


As per directional tool specification As perdirec-tionaltool

specifi-cation

As perdirectional

toolspecification

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

Annular Pressure plus VibrationStick Slip (AutoTrak G3,

AutoTrak X-treme, AziTrak andOnTrak systems)

4 3/4in - 9 1/2in, asper directional tool

specification




specifi-cation

As perdirectional

toolspecification

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-900 8 1/4in

= 300-1290 9 1/2in =300-1,600

Annular Pressure plus VibrationStick Slip (E-MTrak, NaviTrak

and TeleTrak systems)

3 1/8in - 6 3/4in, asper directional tool

specifications




specifi-cation

As perdirectional

toolspecification

(a) (a) (a) (a) As per directional toolspecification

CoPilot (DrillingOptionalimisation andDownhole Analysis)

4 3/4, 6 3/4, 81/4, 9 1/2

(4 3/4) 8.9, (6 3/4) 7, (8 1/4) 8.1, (9 1/2) 7.5


N/A 150 Standard20, Optional

25

(a) (a) (a) (a) (4 3/4) 100-350, (6 3/4) 200-800, (8 1/4) 300-1,600

Drilling Performance Sub(CoilTrak system and Advanced

SLIM MWD system)

2 3/8 ; 3 (CoilTrakonly), 3 1/8

49.5, typical BHA includingmotor

(2 3/8) 50, (3) 45 - sliding only N/A 150 14.5 (a) (a) (a) (a) 2 3/8in max 80, 3in max 211

Halliburton/Sperry Drilling

AcoustiCaliper 6 3/4, 8 (6 3/4) 6, (8) 7.7 (6 3/4) 21/10, (8) 14/8 (6 3/4) 6.45x2.81, (8) 7.81x2.81 150 18 (6 3/4) 3, (8) 4 (6 3/4) 10, (8) 12 (6 3/4) 57, (8) 73

Drillstring Dynamics 4 3/4, 6 3/4, 8, 9 1/2 Part of some dual gamma raytools, see below

150

Pressure While Drilling 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 10.8, (6 3/4, 8) 4.51,(9 1/2) 4.45

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.66x2.25, (6 3/4) 6.54x2.81, (8)7.76x2.81, (9 1/2) 9.35x3

175 18 - 25 (4 3/4) 70, (6 3/4, 8) 2,(9 1/2) 1

(4 3/4) 190, (6 3/4, 8) 7,(9 1/2) 2

(6 3/4, 8) 42, (9 1/2) 14

Vibration Severity 4 3/4, 6 3/4, 8, 9 1/2 Part of pressure-while-drillingtool (see above) as well as

some other tools

175

Annular Mud Temperature 8 25.3 (part of EWR-M5 tool) 14/8 7.65 x 2.81 150 25 N/A 5 13 75

Drilling Downhole OptimizationCollar (DrillDOC)

6 3/4, 8 7.36 (6 3/4) 21/10, (8) 14/8 (6 3/4) 6.63x2.81, (8) TBD 175 25 (6 3/4) 4, (8) 2 (6 3/4) 11, (8) 4 (6 3/4) 59, (8) 22

PathFinder, a Schlumberger company

Drilling Formation Tester 6.75 37 16/7 6.37x2.81 150 20 N/A N/A 70 N/A 275-750

Dynamic Pressure Module 4 3/4, 6 3/4, 8, 9 1/2 4.7 (4 3/4) 30/16.6, (6 3/4) 17.5/9,(8) 19/11, (9 1/2) 13/7

(4 3/4) 4.5x2.25, (6 3/4) 6.44x2.81, (8)7.18x2.81, (9 1/2) 8.82x2.81

150 20 (4 3/4) 22 at 150gal/min

(4 3/4) 58, (6 3/4) 26, (8,9 1/2) N/A at 400

(4 3/4) N/A (6 3/4)49, (8) 39, (9 1/2)

39 at 750

(4 3/4) N/A (6 3/4) 65, (8)52, (9 1/2) 52 at 1000

(4 3/4) 125-375, (6 3/4) 250-750, (8) 400-1,500, (9 1/2)

500-1,500

Survivor Dynamic PressureModule

4 3/4, 6 3/4 8.5 (4 3/4) 30/17, (6 3/4) 18/9 (4 3/4) 4.5x2.25, (6 3/4) 6.44x2.81 175 25 (4 3/4) 22 at 150gal/min

(4 3/4) 58, (6 3/4) 26 (4 3/4) N/A (6 3/4) 49, N/A (4 3/4) 125-375, (6 3/4)250-750




upper, 3.66 lower

(4 3/4) 31/17, (6 3/4) 16/10,(8) 16/10

(4 3/4) 4.43x2.25, (6 3/4) 5.99x2.81, (8)6.99x2.81

175 (4 3/4), (63/4) 25,(8) 20

N/A (4 3/4) 70, (6 3/4) 20 (4 3/4) N/A, (6 3/4)35, (8) 20

N/A (4 3/4) 125-375, (6 3/4) 250-750, (8) 250-1125

Schlumberger

ImPulse*Downhole shocks

*Downhole flow/washout*APWD (with VisionPWD sub)

4.75 32 30/15 4.75x2.25x38.5 150std., 175

opt.

20 std.,27.5 opt.

20 125 (varies withModulator gap)

N/A N/A 130-400


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


ShortPulse*Downhole shocks

*Downhole flow/washout*APWD (with VisionPWD sub)

4.75 27.3 30/15 4.75x2.25x34.8 -OR-

4.59x2.25x30.3

150std., 175

opt.

20 20 125 (varies withModulator gap)

N/A N/A 130-400

VisionPWD *APWD *IPWD 4.75 13.6 30/15 4.75x2.25x38.5 150std., 175

opt.

25 5 29 N/A N/A 0-400

PowerPulse*APWD

*3 axis Vibrations (MVC)*Downhole WOB*Downhole TORQ

*Downhole flow/washout

6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56(8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)


(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

TeleScope*APWD

*3 axis vibrations (MVC)*Downhole WOB*Downhole TORQ


6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56 (8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)


(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

SlimPulse*Shocks

*Stick Slip

1 3/4 tool OD3 1/8 to 9 1/2 collars


(4 3/4 and smaller) 145/40(6 3/4) 28/10(8 1/4) 20/8(9 1/2) 19/7

(4 3/4) 4.75x2.81x33(6 3/4) 6.75x2.81x32

150std., 175

opt.

22 (4 3/4) 68, (63/4) 16

(6 3/4) 100, (8 3/4) 18 (6 3/4) 324, (8 3/4,9 3/4) 58

(8 3/4, 9 3/4) 411 Multiple configurations:35-1200

EcoScope*APWD dynamic and static

*Multi-axis shock & vibration(MVC)

*Ultrasonic caliper (UCAL) *Density caliper (DCAL)

6 3/4 with 7 7/8, 83/8, or 9 3/8 Stabilizer

Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

NeoScope*APWD dynamic and static

*Multi-axis shock & vibration(MVC)

*Ultrasonic caliper (UCAL)

6 3/4 with 8 3/8stabilizer

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

proVISION (MagneticResonance while Drilling)*3 axis motion detection

*Shocks*Stick Slip


6 3/4 with Slick, 81/4, or 9 3/8 Stabilizer

Options

37.3 16/8 6.5x2.81x36.5 150 18 4 25 81 N/A 300-800

Weatherford

BAP (Borehole/AnnularPressure)

4-3/4, 6-3/4, 8, 8-1/4,9-1/2

Added to HEL length - (4-3/4)2.71, (6-3/4) 2.67, (8-1/4,

9-1/2) 2.67

(4-3/4) 30/15, (6-3/4), 16/8, (8,8-1/4) 14/7, (9-1/2) 12/6

(4-3/4) 4.75x3.22, (6-3/4) 6.75x4.24, (8-1/4)8x4.28, (9-1/2) 9.5x5.16

150 std.180opt.

(4.75, 6.75,8”) 20 std.,

30 opt.(8.25, 9.5)20 std., 25

opt.

(4 3/4) 12, (63/4, 8) 2, (8 1/4,

9-1/2) 1

(4 3/4) 64, (6 3/4, 8) 9,(8 1/4, 9-1/2) 2

(4 3/4) 193, (6 3/4, 8)26, (8 1/4, 9 1/2) 2

(6 3/4, 8) 170, (8-1/4,9-1/2) 33

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

TVM (True Vibration Monitor) 4-3/4, 6-3/4, 8, 8-1/4,9-1/2

No additional Length N/A, Electronic Boards N/A, Electronic Boards 150 std.180opt.

N/A,ElectronicBoards

N/A, ElectronicBoards

N/A, Electronic Boards N/A, Electronic Boards N/A, Electronic Boards N/A, Electronic Boards

ESM (Environmental SeverityMeasurement)

4-3/4, 6-3/4, 8, 8-1/4,9-1/2

No additional Length N/A, Electronic Boards N/A, Electronic Boards 150 std.180opt.

N/A,ElectronicBoards

N/A, ElectronicBoards

N/A, Electronic Boards N/A, Electronic Boards N/A, Electronic Boards N/A, Electronic Boards

RAT (Rapid AnnularTemperature)

4-3/4, 6-3/4, 8, 8-1/4,9-1/2

No additional Length N/A, External Sensor N/A, External Sensor 150 std.180opt.

(4-3/4,6-3/4,8-1/4,

9-1/2) 20std., 30

opt.(8.25, 9.5)20 std., 25

opt.

N/A, ExternalSensor

N/A, External Sensor N/A, External Sensor N/A, External Sensor N/A, External Sensor

Gamma Ray


APS SureShot 3 1/8, 3 1/2, 4 3/4,6 1/4,

6 3/4, 8, 9 1/2+


20 and 25 (3 1/2) 27,(4 3/4 - 6 3/4) 6,

(8) 3,(9 1/2) 2

(3 1/2) 150,(4 3/4 - 6 3/4) 35,

(8) 20,(9 1/2) 10

(6 1/2 - 6 3/4) 114,(8) 61,

(9 1/2) 32

(9 1/2) 220 (3 1/8, 3 1/2) 70 - 250(4 3/4) 150 - 350

(6 1/4, 6 3/4) 150- 750(8) 300 - 1,100

(9 1/2+) 650 - 1,200

APS SureShot with Gamma 3 1/8, 3 1/2, 4 3/4,6 1/4,

6 3/4, 8, 9 1/2+


20 and 25 (3 1/2) 29,(4 3/4 - 6 3/4) 6,

(8) 3,(9 1/2) 2

(3 1/2) 165,(4 3/4 - 6 3/4) 40,

(8) 20,(9 1/2) 10

(6 1/2 - 6 3/4) 114,(8) 61,

(9 1/2) 32

(9 1/2) 225 (3 1/8, 3 1/2) 70 - 250(4 3/4) 150 - 350

(6 1/4, 6 3/4) 150- 750(8) 300 - 1,100

(9 1/2+) 650 - 1,200

APS SureShot Gamma + WPRPropagation Resistivity





1,200 max.

APS SureShot Gamma +PWD + WPR Propagation

Resistivity





1,200 max.

Baker Hughes

AutoTrak Curve (High-build rate Rotary

Steerable System, includingMWD)

6 3/4 6 3/4in = 37.8 6 3/4in = 30/15 BHA-dependent Standard150

Standard20

(a) (a) (a) (a) 6 3/4in = 300-750

AutoTrak G3 and AutoTrakX-treme

(Rotary Steerable System,including OnTrak MWD or

AziTrak Integrated MWD/LWD,+/- hard-wired precontoured


4 3/46 3/4

8 1/4 (ATK G3 only)9 1/2

ATK G3 4 3/4in = 50.86 3/4in = 49.98 1/4in = 56.9

9 1/2in = 58.1 ATK X-treme 43/4in = 72.66 3/4in = 709 1/2in = 82

ATK G3 4 3/4in = 30/106 3/4in = 20/138 1/4in = 9/6.5

9 1/2in = 13/6.5 ATK X-treme 43/4in = 25/106 3/4in = 16/79 1/2in = 8/3.8


Optional.175 for6.3/4in,8.1/4in,9.1/2in

Standard. 20Optionalional

25 & 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-900 8 1/4in

= 300-1290 9 1/2in =300-1,600

AutoTrak eXpress (RotarySteerable System includingMWD, can be run with hard-

wired modular X-treme motor)

4 3/46 3/49 1/2

4 3/4in = 56.86 3/4in = 58.2 Version 6 3/4in

High Dog Leg = 709 1/2in = 64.6

4 3/4in = 30/106 3/4in = 23/8 Version 6 3/4in

High Dog Leg = 23/129 1/2in = 13/6.5

BHA-dependent 150 20 (a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


AutoTrak V (Rotary Steerable System that

does not require MWD)

4 3/46 3/49 1/2

4 3/4in = 23.16 3/4in = 19.79 1/2in = 22.3

4 3/4in = 30/106 3/4in = 23/8

9 1/2in = 13/6.5


Optional.175 for6.3/4in,9.1/2in

Standard. 20Optionalional

25 & 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-9009 1/2in = 300-1600

DGS (CoilTrak system andAdvanced SLIM MWD system)

2 3/8 (CoilTrakonly), 3 1/8

49.5, typical BHA includingmotor

(2 3/8) 50, (3) 45 - sliding only N/A 150 14.5 (a) (a) (a) (a) (2 3/8) max 80, (3) max 210

OnTrak (integrated directional,gamma ray and formation

resistivity at mutiple depths ofinvestigation)

4 3/4, 6 3/4, 81/4, 9 1/2

(4 3/4) 20.2, (6 3/4) 17.0, (81/4) 19.0, (9 1/2) 18.1

(4 3/4) 33/12, (6 3/4) 25/15, (81/4) TBD, (9 1/2) 10/7

NA Standard.150,

Optional.175

Standard20 (4-3/4,

6-3/4 &8-1/4,9-1/2)

Optional.25, (4-3/4,

6-3/4 &8-1/4)

Optional.30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4) 200-900, (8 1/4) 300-1295, (9 1/2)

300-1,600



4 3/4, 6 3/4 (4 3/4) 40.4, (6 3/4) 35.3 (4 3/4) 33/12, (6 3/4) 25/15 NA Standard.150,

Optional.175

Standard20 (4-3/4,

6-3/4)Optional.

25, (4-3/4,6-3/4)

Optional.30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4)200-900

E-MTrak 4 3/4, 6 1/2 (4 3/4, 6 1/2) 39.6 Slick collar: (4 3/4) 21/7, (61/2) 12.5/6.5

Flexible collar: (4 3/4) 8/32,(6 1/2) 48/25

NA 150 20 (a) (a) (a) (a) (4 3/4) max 350, (6 1/2)max 660

NaviTrak 1 3/4 OD probe; 3 1/8and larger collars

(1 3/4) 4 Probe limits: (1 3/4) 115/51 NA 150 20 (a) (a) (a) (a) (1 3/4) 75-1600

Near Bit Gamma 4 3/4, 9 1/2 4.77 (z) N/A 150 Standard20, Optional

25

(a) (a) (a) (a) 300-1,600, function of MWDplatform

TruTrak (Non-rotating Automated

Drilling System including MWDand Optionalional Gamma)

4 3/46 3/4

89 1/2

4 3/4in = 28.36 3/4in = 31.0

8in = 36.19 1/2in = 36.1 Length does

not consider MWD

4 3/4in = 56 3/4in = 3

8in = 29 1/2in = 2

N/A 150 20 (a) (a) (a) (a) 4 3/4in = 125-3176 3/4in = 264-660

8in = 395-9009 1/2in = 528-1162

DrilTech LLC

Positive Pulse MWD andGamma Ray Probe Based

1 7/8 tool OD, 4 3/4 -8 collars

23-28 60/30 As applicable to standard NMDC 150 -175

20 (137mpa)

50 (NMDCdependent)

100 (NMDC dependent) 150 (NMDC dependent) N/A (3 1/2) 50-130, (4 3/4)130-275, (6 3/4) 235-600,

(8) 400-800

GE Oil & Gas

Pilot Gamma 3 1/2, 4 3/4, 6 1/2,8, 9 1/2

Shortest probe length withMWD 20.84

As Per Pilot MWD As Per Pilot MWD 150 20 As Per Pilot MWD As Per Pilot MWD As Per Pilot MWD As Per Pilot MWD As Per Pilot MWD

Scinturion Gamma 3 1/2, 4 3/4, 6 1/2,8, 9 1/2

Shortest probe length withMWD 30.4

As per Tensor MWD As per Tensor MWD 175 20 As per TensorMWD

As per Tensor MWD As per Tensor MWD As per Tensor MWD As per Tensor MWD


Dual Gamma Ray (DGR) 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 7.5, (6 3/4, 8) 4.5,(9 1/2) 4.4

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.66x2.25, (6 3/4) 6.54x2.81, (8)7.76x2.81, (9 1/2) 9.35x2.81

150 18 std. 25opt.

(4 3/4) 68, (6 3/4, 8) 2,(9 1/2) 1

(4 3/4) 184, (6 3/4, 8)7, (9 1/2) 3

(6 3/4, 8) 43, (9 1/2) 16

Gamma Ray Probe Depends on hang-offcollar OD

Depends on hang-off collar Depends on hang-off collar Depends on hang-off collar 150 std.175opt.

20 std. 30opt.

Depends on hang-off collar ID

Depends on hang-offcollar ID

Depends on hang-offcollar ID

(3 3/8, 3 1/2) 90-200, (43/4) 150-350, (6 1/2 - 91/2) 225-650, (7 1/4 - 9

1/2) 400-1,500

Azimuthal Gamma Ray (AGR) 6 3/4, 8, 9 1/2 (6 3/4) 23.6, (8) 25.3, (9 1/2)25.4 (part of EWR-M5 tool)

(6 3/4) 21/10, (8, 9 1/2) 14/8 (6 3/4) 6.60 x 2.81, (8) 7.65 x 2.81, (9 1/2)9.23 x 3.00

150 25 N/A (6 3/4) 12, (8, 9 1/2) 5 (6 3/4) 35, (8, 9 1/2) 13 (6 3/4) 200, (8, 9 1/2) 75

Geo-Pilot Gamma Ray (ABG) 6 3/4, 9 5/8 (6 3/4) 20, (9 5/8) 22 (partof GeoPilot RST)

(6 3/4) 21/10, (9 5/8) 14/8 Depends on rotary steerable tool mode 150std., 175

opt.

20 std. 30opt.

(6 3/4) 38, (9 5/8) 6 (6 3/4) 105(9 5/8) 17 (9 5/8) 96

Gamma Ray/At-Bit Inclination(GABI)

4.75 Part of Mud Motor 30/14 Depends on mud motor 150 20 Depends on mudmotor

Depends on mud motor 100-265

MWD Services Inc.

MWD Shuttle Sub dia: 3 1/8 - 9 1/2,tool dia: 1 7/8

29.1 w/single battery, 35.5 w/dual battery

60/30 As applicable to standard NMDC 150 20 40 80 150 75-1,000

Navigate Energy Services

Directional Gamma 4 3/4, 6 1/2 & 8available QI ‘10

(4 3/4) 10, ( 6 1/2 & 8) 10 (5 3/4) 32/16, (6 3/4) TBD,(8) TBD

As applicable to standard NMDC 150 20 N/A 60 125 N/A 225-1000


HDS-1L Directional Gamma

4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

30 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.95x2.81,

(9 1/2) 9.5x3

150 20 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45,( 8 HF,

9 1/2) N/A

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

HDS-1S Directional Gamma

4 3/4, 6 3/4, 8 LF, 8HF, 9 1/2

16 (4 3/4) 31/17, (6 3/4) 17/9, (8 LF)18/9, (8 HF) 18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/4) 6.74x2.81, (8 LF)7.98x2.81, (8 HF) 7.95x2.81, (9 1/2) 9.5x3

150 20 (4 3/4) 40, (63/4, 8 LF, 8 HF, 9

1/2) N/A

(4 3/4) 50, (6 3/4, 8 LF)45,( 8 HF, 9 1/2) N/A

(4 3/4) N/A, (6 3/4) 50,(8 LF) 50, (8 HF) 45,

(9 1/2) 45

(4 3/4, 6 3/4, 8 LF) N/A, (8HF) 200, (9 1/2) 200

(4 3/4) 125-375, (6 3/4) 250-750, (8 LF) 250-950, (8 HF)375-1,125 (9 1/2) 500-1,500

HDS-1R Directional Gamma

3 1/8 - 9 1/2 30 60/30 Dependant on drill collar As applicable to standard NMDC 150 20 250 250 250 250 (2 1/4) 60-180, (2 1/2) 80-280,(2 11/16) 100-350, (2 13/16)150-550, (3 1/4) 300-1,000

Survivor HDS-1L DirectionalGamma

4 3/4, 6 3/8, 6 3/4, 8LF, 8 HF, 9 1/2

30 (4 3/4) 31/17, (6 3/8) 24/11.5,(6 3/4) 17/9, (8 LF) 18/9, (8 HF)

18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/8) 6.47x2.81, (6 3/4)6.74x2.81, (8 LF) 7.98x2.81, (8 HF) 7.95x2.81,

(9 1/2) 9.5x3

175 25 (4 3/4) 40, (6 3/8)40, (6 3/4, 8 LF, 8

HF, 9 1/2) N/A

(4 3/4) 50, (6 3/8) 50,(6 3/4, 8 LF) 45,( 8 HF,

9 1/2) N/A

(4 3/4, 6 3/8) N/A, (63/4) 50, (8 LF) 50, (8

HF) 45, (9 1/2) 45

(4 3/4, 6 3/8, 6 3/4, 8LF) N/A, (8 HF) 200, (9

1/2) 200

(4 3/4, 6 3/8) 125-375, (63/4) 250-750, (8 LF) 250-950,

(8 HF) 375-1,125 (9 1/2)500-1,500

Survivor HDS-1S DirectionalGamma

4 3/4, 6 3/4, 8 LF, 8HF, 9 1/2

16 (4 3/4) 31/17, (6 3/4) 17/9, (8 LF)18/9, (8 HF) 18/9, (9 1/2) 15/8

(4 3/4) 4.69x2.25, (6 3/4) 6.74x2.81, (8 LF)7.98x2.81, (8 HF) 7.95x2.81, (9 1/2) 9.5x3

175 25 (4 3/4) 40, (63/4, 8 LF, 8 HF, 9

1/2) N/A

(4 3/4) 50, (6 3/4, 8 LF)45,( 8 HF, 9 1/2) N/A

(4 3/4) N/A, (6 3/4) 50,(8 LF) 50, (8 HF) 45,

(9 1/2) 45

(4 3/4, 6 3/4, 8 LF) N/A, (8HF) 200, (9 1/2) 200

(4 3/4) 125-375, (6 3/4) 250-750, (8 LF) 250-950, (8 HF)375-1,125 (9 1/2) 500-1,500

Survivor HDS-1R DirectionalGamma

3 1/8 - 9 1/2 30 60/30 Dependant on drill collar As applicable to standard NMDC 175 25 250 250 250 250 (2 1/4) 60-180, (2 1/2) 80-280,(2 11/16) 100-350, (2 13/16)150-550, (3 1/4) 300-1,000


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



www.offshore-mag.com







Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min





upper, 3.66 lower

(4 3/4) 31/17, (6 3/4) 16/10,(8) 16/10

(4 3/4) 4.43x2.25, (6 3/4) 5.99x2.81, (8)6.99x2.81

175 (4 3/4), (63/4) 25,(8) 20

N/A (4 3/4) 70, (6 3/4) 20 (4 3/4) N/A, (6 3/4)35, (8) 20

N/A (4 3/4) 125-375, (6 3/4) 250-750, (8) 250-1125

Compensated Wave Resistivity 6 3/4, 8, 9 1/2 25 (6 3/4) 14/5, (8) 12/4, (9 1/2) 8/2 (6 3/4) 5.94 x2.81, (8) 6.9x2.81, (9 1/2) 8.49x3 150 20 N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 80, (8) 80, (91/2) 80

(6 3/4) n/a, (8) n/a, (91/2) 300

(6 3/4) 250-750, (8) 250-1,125, (9 1/2) 250-1,250



4.75 20 30/15 4.72x2.25 175 25 6 29 N/A N/A 120-375


N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750,(8) 250-1,125,

(9 1/2) 250-1,500


N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750,(8) 250-1,125,

(9 1/2) 250-1,500


Ryan Gamma Ray w/Electromagnetic

4 3/4, 6.5, 6 3/4 34 (4 3/4) 75° / 20°(6 3/4) 28°/11°

(4 3/4) 4.75x2.81 (6 3/4) 6.71x3.25 175C 20K PSI(137 mpa)

8 47 153 450 (4 3/4) 100-350(6 3/4) 150-800

Ryan Gamma Ray w/Mud Pulse

3 1/8, 4 3/4, 6.5,6 3/4, 8, 9.5

20-30 (3 1/8) 100°/ 50°(4 3/4) 40° / 15°(6 3/4) 28°/11°

(8) 15°/9°(9.5) 8°/ 5°

(3 1/8) 2.96x2.25 (4 3/4) 4.75x2.81 (6 3/4)6.71x3.25 (8) 7.93x4.00 (9.5) 9.42x4.00

175C 20K PSI(137 mpa)

8 47 153 450 (3 1/8) 50-175(4 3/4) 100-350(6 3/4) 150-800

(8) 400-925(9 1/2) 400-1200

Schlumberger

PowerDrive X5 4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4 ) 14.95, (6 3/4 ) 13.48,(8 1/4 , 9 ) 14.6, (11 ) 15.1

Capability (°/100 ft) : (4 3/4 , 63/4 , 8 1/4 ) 8, (9 ) 5, (11 ) 4

Pass Through (°/100 ft) : (4 3/4)30/15, (6 3/4 , 8.25 , 9 ) 20/10,

(11 ) 15/8

150 20 std,

30 opt. (43/4, 6 3/4)


across bit)


across bit)


across bit)

130-1,900


4 3/4 , 6 3/4 , 8 1/4,9 , 11

(4 3/4) 14.95, (6 3/4 ) 13.48,(8 1/4 , 9 ) 14.6, (11 ) 15.1

Capability (°/100 ft) : (4 3/4 , 63/4) 8, (8 1/4 ) 6, (9 ) 5, (11 ) 3Pass Through (°/100 ft): (4 3/4) 30/15, (6 3/4 , 8.25 , 9 ) 20/10,

(11 ) 15/8

150std., 175

opt.

20 36(650 - 750psi requiredacross bit)


across bit)


across bit)


across bit)

100-2,000

PowerDrive ArcherRotary Steerable Tool

6 3/4 (6 3/4 ) 16.64 Capability (°/100 ft) : (6 3/4) 15 Pass Through (°/100 ft): (63/4) , >15 Based on fatigue

management

150 20 N/A N/A 30(600 - 750 psi required

across bit)

N/A 250-650

ShortPulse 4.75 27.3 30/15 4.75x2.25x34.8 -OR-

4.59x2.25x30.3

150std., 175

opt.

20 20 515 - medium flow(varies with modulator

gap)

N/A N/A 130-360

ImPulse 4.75 32 30/15 4.75x2.25x38.5 150std., 175

opt.

20 std.,27.5 opt.

20 515 - medium flow(varies with modulator

gap)

N/A N/A 130-360 (20 kpsi tool)130-310 (25 kpsi tool)

PowerPulse 6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56(8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)


(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

TeleScope 6 3/4, 8 1/4, 9, 9 1/2 24.7 (6 3/4) 16/8(8 1/4) 12/7

(9, 9 1/2) 10/6

(6 3/4) 6.75x2.81x31.5(8 1/4) 8x2.81x26.2(9 1/4) 9.25x3x28

(9 1/2) 9.5x3.5x26.2

150std., 175

opt.

25 std., 30opt.

N/A (6 3/4) 56 (8 1/4) 32 (varies with

modulator gap)

(6 3/4) 151(8 1/4, 9 1/2) 84 (varies

with modulator gap)


(6 3/4) 250-800(8 1/4) 300-1,200

(8 1/4) opt. 800-1,400(9 1/2) 400-2,000

(9 1/2) opt. 400-1,600

SlimPulse 1 3/4 tool OD3 1/8 to 9 1/2 collars


(4 3/4 and smaller) 145/40(6 3/4) 28/10(8 1/4) 20/8(9 1/2) 19/7

(4 3/4) 4.75x2.81x33(6 3/4) 6.75x2.81x32

150std., 175

opt.

22 (4 3/4) 68, (63/4) 16

(6 3/4) 100, (8 3/4) 18 (6 3/4) 324, (8 3/4,9 3/4) 58

(8 3/4, 9 3/4) 411 Multiple configurations:35-1200

geoVISION675 6 3/4 10.12 16/8 6.5x2.81x10 150 18 0.9 5.5 18 N/A 0-800

geoVISION825 8 1/4 12.72 13/7 8x2.81x13.5 150 15 0.15 0.95 3 21.8 0-1,200

arcVISION312 3.125 23.5 100/30 3x1.75x33 150 20 112 N/A N/A N/A 0-160

arcVISION475 4.75 21 30/15 4.75x2.81x22 150 25 3 30 N/A N/A 0-400

arcVISION675 6 3/4 18 16/8 6.5x2.81x19 150 std.175opt.

20 std.,25 and 30

opt.

1 9 20 N/A 0-800

arcVISION825 8 1/4 18 14/7 8.25x2.81x19.8 150 std.175opt.

25 std., 30 opt.

0.12 1.5 2.5 17.8 0-1,950

arcVISION900 9 18 12/6 9x3x20.7 150 25 0.12 1.5 2.5 17.8 0-1,950

EcoScope 6 3/4 with 7 7/8, 83/8, or 9 3/8 Stabilizer

Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

NeoScope 6 3/4 with 8 3/8stabilizer

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

MicroScope 4 3/4 with 5 3/8 slick sleeve

18 30/15 4.75x2.25x18 150 20 9.8 61 198 N/A 0-500

PeriScope 4 3/4, 6 3/4 18.3 (6 3/4), 23.5 (4 3/4) (4 3/4) 30/15, (6 1/2) 16/8 4.75x2.25x27 (4 3/4), 6.5x2.81x19.3 (6 3/4) 150 25 (4 3/4) 10, (6 3/4) 0.7

(4 3/4) 65,(6 3/4) 4

(6 3/4) 14 N/A 0-400 (4 3/4), 0-800 (6 3/4)

Sharewell Energy Services

Gamma Ray Electro-Trac EMMWD with Gamma

4 3/4 6 1/2 6 3/47 3/4

28.0’ collar limited Collar-defined 150 20 25 100 100 100 50-1200

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


Weatherford

EMpulse (Electromagnetic) All Sizes 31 (3 1/6) 116/38, (4 3/4) 25/16,(6 1/4) 20/14, (6 3/4) 18/13, (8)

15/10, (9 1/2) 14/7.5

(4 3/4) 4.53 x 2.25, (6 1/4) 6.09 x 2.25),(6 3/4) 6.59 x 2.81, (8) 7.78 x 2.81

150 15 (4 3/4) 50 (4 3/4) 80-350; (6 3/4,8) 80-800; (8 1/4, 9 1/2)

80-1,800

HyperPulse All sizes 31 (3 1/6) 116/38, (4 3/4) 25/16,(6 1/4) 20/14, (6 3/4) 18/13, (8)

15/10, (9 1/2) 14/7.5

(4 3/4) 4.75x2.69, (6 1/4) 6.25x3.25,(6 3/4) 6.75x3.25

150 15

HAGR (High-temperatureAzimuthal GR)

4 3/4, 6 3/4, 8, 81/4, 9 1/2

(4 3/4) 12.5 (6 3/4, 8, 8 1/4,9 1/2) 12.3

(4-3/4) 30/15, (6-3/4), 16/8, (8,8-1/4) 14/7, (9-1/2) 12/6

(4 3/4) 4.75x3.22(6 3/4) 6.75x4.24 (8, 8 1/4) 8x4.28 (9 1/2) 9.5x5.16

150 std.180opt.

(4.75, 6.75,8, 8.25,

9.5) 20 std.30 opt.,

(4 3/4) 12, (63/4, 8) 2, (8 1/4,

9-1/2) 1

(4 3/4) 64, (6 3/4, 8) 9,(8 1/4, 9-1/2) 2

(4 3/4) 193, (6 3/4, 8)26, (8 1/4, 9 1/2) 2

(6 3/4, 8) 170, (8-1/4,9-1/2) 33

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

SAGR (Spectral Azimuthal GR) 4 3/4, 6 3/4 (4-3/4)13.08, (6 3/4) 12.83 (4 3/4) 30/15, (6 3/4) 16/8 (4-3/4) 4.75x3.125(6-3/4) 6.75x4.44 150Std. 165opt.

20 4-3/4: 19 6-3/4: 8

4-3/4: 19 6-3/4: 2

4-3/4: 19 6-3/4: 2

4-3/4: 19 6-3/4: 2

(4 3/4) 80-350; (6 3/4) 80-700;

At-Bit Measurement System 4 3/4, 6 3/4 NOMTOOL SIZE (5.60” and

7.325” max)

(4 3/4) 2.83 ft., (6 3/4)3.01 ft.

(4 3/4) 30/15 (6 3/4) 16/8

(4 3/4,6 3/4)150

(4 3/4) 10(6 3/4) 10

estimates (4 3/4)12, (6 3/4) 2

estimates (4 3/4) 64,(6 3/4) 9

estimates (4 3/4)exceeds flow rate, (6

3/4) 26

estimates (6 3/4) 170 (4 3/4) 80-350; (6 3/4,8) 80-800; (8 1/4, 9 1/2)

80-1,800

Resistivity


APS SureShot Gamma +WPR 3.5

3 1/2 59 (2 pcs.)* Collar-limited Collar-defined 150 and175




1,200 max.






1,200 max.






1,200 max.


8 59 (2 pcs.)* Collar-limited Collar-defined 150 and175




1,200 max.

Baker Hughes

AutoTrak G3 and AutoTrakX-treme

(Rotary Steerable System,including OnTrak MWD or

AziTrak Integrated MWD/LWD,+/- hard-wired precontoured


4 3/46 3/4

8 1/4 (ATK G3 only)9 1/2

ATK G3 4 3/4in = 50.86 3/4in = 49.98 1/4in = 56.9

9 1/2in = 58.1 ATK X-treme 43/4in = 72.66 3/4in = 709 1/2in = 82

ATK G3 4 3/4in = 30/106 3/4in = 20/138 1/4in = 9/6.5

9 1/2in = 13/6.5 ATK X-treme 43/4in = 25/106 3/4in = 16/79 1/2in = 8/3.8


Optional.175 for6.3/4in,8.1/4in,9.1/2in

Standard.20

Optional25 & 30

(a) (a) (a) (a) 4 3/4in = 125-3506 3/4in = 200-900 8 1/4in

= 300-1290 9 1/2in =300-1,600

USMPR (CoilTrak systemand Advanced SLIM MWD

system)

2 3/8, 3 1/8 (2 3/8) 9.6, (3 1/8) 17 (z) N/A 150 20 (a) (a) (a) (a) System dependent

OnTrak (integrated directional,gamma ray and formation

resistivity at mutiple depths ofinvestigation)

4 3/4, 6 3/4, 81/4, 9 1/2

(4 3/4) 20.2, (6 3/4) 17.0, (81/4) 19.0, (9 1/2) 18.1

(4 3/4) 33/12, (6 3/4) 25/15, (81/4) TBD, (9 1/2) 10/7

NA Standard.150,

Optional.175

Standard20 (4-3/4,

6-3/4 &8-1/4,9-1/2)

Optional.25, (4-3/4,

6-3/4 &8-1/4)

Optional.30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4) 200-900, (8 1/4) 300-1295, (9 1/2)

300-1,600



4 3/4, 6 3/4, 8 1/4 (4 3/4) 40.4, (6 3/4) 35.3 (4 3/4) 33/12, (6 3/4) 25/15, (81/4) TBD, (9 1/2) 10/7

NA Standard.150,

Optional.175

Standard20 (4-3/4,

6-3/4)Optional.

25, (4-3/4,6-3/4)

Optional.30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4)200-900

StarTrak (high resolutionborehole imaging)

4 3/4, 6 3/4 (4 3/4) 9.8, (6 3/4) 8.3 (z) (4 3/4) 5.25 x 3.13, (6 3/4) 7.25 x 4.6

150 Standard20, Optional

25

(a) (a) (a) (a) (4 3/4) 125-350, (6 3/4) 265-900, function of

MWD platform

ZoneTrak (at-bit boundarydetection system)

6 3/4, 9 1/2 (6 3/4) 6.3, (9 1/2) 5.7 (z) (6 3/4) 7.25 x 3.64, (9 1/2) 9.63 x 3.7 150 Standard20, Optional

25

(a) (a) (a) (a) (6 3/4) 200-900 (9 1/2) 300-1,600

function of MWD platform

GE Oil & Gas

Centerfire PropagationResistivity Tool

4 3/4, 6.91, 8 1/4 (4 3/4, 6.91) 14.5

(8 1/4) 15.17

(4 3/4) 25/12 (6.91) 17/8

(8 1/4) 14/7

(4 3/4) 5.0x2.81, (6 3/4) 6.58x2.81, (8 1/4)8.25x2.81

175 20 As per TensorMWD

As per Tensor MWD As per Tensor MWD As per Tensor MWD (4 3/4)100-350(6.91)

300-750 (8 1/4)

450-1200


EWR-PHASE 4 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 12.5, (6 3/4) 12.1, (8,9 1/2) 12.2

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.66x2.25, (6 3/4) 6.54x2.81, (8)7.76x2.81, (9 1/2) 9.35x3

150 std.175opt.

18 or 25 (4 3/4) 90, (6 3/4, 8) 7,(9 1/2) 2

(4 3/4) 250, (6 3/4, 8)19, (9 1/2) 7

(6 3/4) 114, (8) 115,(9 1/2) 40

EWR-PHASE 4D 9.5 12.2 14/8 9.35x3 150 18 2 7 40

SuperSlim EWR-PHASE 4 3.125 11.3 30/14 2.63x1.25 150 16 213 at 150 gal/min

SuperSlim EWR-PHASE 4 3.625 12.9 30/14 TBD 150 20 TBD

EWR-M5 6 3/4, 8, 9 1/2 (6 3/4) 23.6, (8) 25.3, (91/2) 25.4

(6 3/4) 21/10, (8, 9 1/2) 14/8 (6.75) 6.60 x 2.81, (8) 7.65 x 2.81, (9 1/2)9.23 x 3.00

150 25 N/A (6 3/4) 12, (8, 9 1/2) 5 (6 3/4) 35, (8, 9 1/2) 13 (6 3/4) 200, (8, 9 1/2) 75

Azimuthal Focused Resistivity(AFR)

4 3/4, 6 3/4, 8 (4 3/4) 10.0, (6 3/4) 10.8,(8) 8.5

(4 3/4) 30/14, (6 3/4) 21/10,(8) 14/8

(4 3/4) 4.74x2.25, (6 3/4) 6.56x2.81, (8) TBD 150 (4 3/4)24.5, (6

3/4) 22, (8)24.5

(4 3/4) 78, ( 6 3/4)6, (8) 2

(4 3/4) 214, (6 3/4)17, (8) 5

(6 3/4) 101, (8) 25

Azimuthal Deep Resistivity(ADR)

4 3/4, 6 3/4 (4 3/4) 25.5, (6 3/4) 24.3 (4 3/4) 30/14, (6 3/4) 21/10 (4 3/4) 4.76x2.25, (6 3/4) 6.71x2.81 150 25 (4 3/4) 152, (6 3/4) 14 (4 3/4) 419, (6 3/4) 38 (6 3/4) 229


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM










Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min



Compensated Wave Resistivity 6 3/4, 8, 9 1/2 25 (6 3/4) 14/5, (8) 12/4, (9 1/2) 8/2 (6 3/4) 5.94 x2.81, (8) 6.9x2.81, (9 1/2) 8.49x3 150 20 N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 80, (8) 80, (91/2) 80

(6 3/4) n/a, (8) n/a, (91/2) 300

(6 3/4) 250-750, (8) 250-1,125, (9 1/2) 250-1,250

Slim Compensated WaveResistivity

4.75 29.8 34/17 4.36 x2.25 150 20 8 40 N/A N/A 120-275



4.75 20 30/15 4.72x2.25 175 25 6 29 N/A N/A 120-375


N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750, (8) 250-1,125, (9 1/2) 250-1,500


N/A (6 3/4) 30, (8) 30, (91/2) 30

(6 3/4) 75, (8) 75, (91/2) 75

(6 3/4) N/A, (8) N/A, (91/2) 300

(6 3/4) 250-750, (8) 250-1,125, (9 1/2) 250-1,500


Ryan Propagation Resistivity 4 3/46 3/4

14.5 (4 3/4) 25/12.2(6.91) 17.8

(4 3/4) 5.0x2.81,(6 3/4) 6.58x2.81

175C 20K PSI(137 mpa)

8 47 153 450 (4 3/4) 100-350(6.91) 300-750

Schlumberger

mcrVISION 4 3/4, 6 3/4, 8 1/4 19.4 (4 3/4), 22.8 (6 3/4),21.2 (8 1/4)

(4 3/4) 30/15(6 3/4) 15/8(8 1/4) 14/7

22 (4 3/4), 25.8 (6 3/4), 21 (8 1/4) 150 20 (4 3/4) 12, (6 3/4)1, (8 1/4) 1

(4 3/4) 79, (6 3/4) 8,(8 1/4) 8

(4 3/4) 250, (6 3/4) 25,(8 1/4) 25

N/A (4 3/4) 0-400(6 3/4) 0-800(8 1/4) 0-800

ImPulse 4.75 32 30/15 4.75x2.25x38.5 150std., 175

opt.

20 std.,27.5 opt.

N/A 125 N/A N/A 0-400

geoVISION675 6.75 10.12 16/8 6.5x2.81x10 150 18 0.9 5.5 18 N/A 0-800

geoVISION825 8 1/4 12.72 13/7 8x2.81x13.5 150 15 0.15 0.95 3 21.8 0-1,200


arcVISION475 4.75 21 30/15 4.75x2.81x22 150 25 3 30 N/A N/A 0-400

arcVISION675 6.75 18 16/8 6.5x2.81x19 150 std.175opt.

20 std.,25 and 30

opt.

1 9 20 N/A 0-800

arcVISION825 8.25 18 14/7 8.25x2.81x19.8 150 std.175opt.

25 std, 30 opt.

0.12 1.5 2.5 17.8 0-1,950

arcVISION900 9 18 12/6 9x3x20.7 150 25 0.12 1.5 2.5 17.8 0-1,950

PeriScope 4 3/4, 6 3/4 18.3 (6 3/4), 23.5 (4 3/4) 30/15 (4 3/4) , 16/8 (6 3/4) 4.75x2.25x27 (4 3/4), 6.5x2.81x19.3 (6 3/4) 150 25 (4 3/4) 10, (6 3/4) 0.7

(4 3/4) 65,(6 3/4) 4

(6 3/4) 14 N/A 0-400 (4 3/4), 0-800 (6 3/4)


Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800


25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

MicroScope 4 3/4 with 5 3/8 slick sleeve

18 30/15 4.75x2.25x18 150 20 9.8 61 198 N/A 0-500

Weatherford

Multi-Frequency Resistivity(MFR)

4 3/4, 6 3/4, 8, 81/4, 9 1/2

(4 3/4) 28.0, (6-3/4) 28.1’,(8-1/4, 9-1/2) 28.3

(4-3/4) 30/15, (6-3/4), 16/8, (8,8-1/4) 14/7, (9-1/2) 12/6

(4 3/4) 4.75x2.29; (6 3/4) 6.75x3.06; (8 1/4)8.25x5.28, (9 1/2) 9.5x6.08

150Std.

180opt.

(4.75,6.75”) 20std. 30

opt.(8.25, 9.5)20 std, 25

opt.

4 3/4 - 19 6 3/4, 8 - 2

8 1/4, 9 1/2 - 2

4 3/4 - 1056 3/4, 8 - 11

8 1/4, 9 1/2 - 2

4 3/4 - 320 6 3/4,8 - 328 1/4, 9 - 6

6 3/4, 8 - 2088 1/4 , 9 1/2- 45 psi

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

Multi-Frequency Resistivity(MFR) - High Temperature

4 3/4, 6 3/4, 8, 8 1/4 (4 3/4, 6 3/4, 8, 8 1/4) 29.5 (4-3/4) 30/15, (6-3/4), 16/8, (8,8-1/4) 14/7, (9-1/2) 12/6

(4 3/4) 4.75x2.29; (6 3/4) 6.75x3.06; (8, 81/4) 8x4.20

150 std.180opt.

(4.75, 6.75)20 std. 30

opt.(8.25, 9.5)20 std, 25

opt.

4 3/4 - 19 6 3/4 - 2

8, 8 1/4 - 2

4 3/4 - 1056 3/4 - 11

8, 8 1/4 - 11

4 3/4 - 320 6 3/4, 8 - 32

8 1/4 - 32

6 3/4, 8 - 208 8 1/4- 45 psi

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

Multi-Frequency Resistivity-PLUS(MFR-PLUS)

38080 34.7 30/15 4.75x2.29 150 20 Std.,30 opt.

19 105 320 n/a 80-350

GWAR (GuideWave AzimuthalMulti-Frequency Resistivity)

4.75, 6.75 34.7 30/15 4.75x2.29 150 20 Std.,30 opt.

19 105 320 n/a 80-350

Porosity

Baker Hughes

LithoTrak 4 3/4, 6 3/4, 8 1/4 (4 3/4) 16.1, (6 3/4) 17.6, (8 1/4) 18.2

(z) (4 3/4) 4.82x1.87, (6 3/4) 6.87x2, (8 1/4)8.25x2.813

150 Standard20 (4 3/4)Optional.25, (6 3/4& 8.1/4)Optional.

30

(a) (a) (a) (a) (4 3/4) 100-320, (6 3/4) 200-900, (8 1/4) 300-1,300


SoundTrak 6 3/4, 8 1/4, 9 1/2 (6 3/4 - 9 1/2) 32.8 (z) (6 3/4) 7.1x5.5, (8 1/4) 8.4x6.3, (9 1/2) 9.7x7.6 150 Standard25 Optional.

30

(a) (a) (a) (a) (6 3/4) 200- 900(8 1/4) 300-1,300(9 1/2) 450-1,560


MagTrak (Advanced MagneticResonance While Drilling)

4 3/4, 6 3/4 (4 3/4) 27.7(6 3/4) 29.9

(z) n/a 150 Standard20, Optional

25

(a) (a) (a) (a) (4 3/4) 125-406(6 3/4) 264-660


Bi-modal AcousTic (BAT) 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 28, (6 3/4, 8,9 1/2) 21

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.65x2.25, (6 3/4) 6.43x2.81, (8)7.65x2.81, (8 HP/HF) 7.53x2.81, (9 1/2) 8.98x3

150, 175 (All) 25,(6 3/4, 8,9 1/2) 30

opt.

(4 3/4) 161, (6 3/4, 8)11, (6 3/4 HP) 12, (8 HP/

HF, 9 1/2) 4

(4 3/4) 458, (6 3/4, 8)33, (6 3/4 HP) 35, (8

HP/HF, 9 1/2) 13

(6 3/4, 8) 198, (6 3/4 HP)208, (8 HP/HF, 9 1/2) 76

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


Quadrupole Acoustic (QBAT) 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 28, (6 3/4, 8,9 1/2) 21

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.65x2.25, (6 3/4) 6.43x2.81, (8)7.65x2.81, (8 HP/HF) 7.53x2.81, (9 1/2) 8.98x3

150,175 (All) 25,(6 3/4, 8,9 1/2) 30

opt.

(4 3/4) 161, (6 3/4, 8)11, (6 3/4 HP) 12, (8 HP/

HF, 9 1/2) 4

(4 3/4) 458, (6 3/4, 8)33, (6 3/4 HP) 35, (8

HP/HF, 9 1/2) 13

(6 3/4, 8) 198, (6 3/4 HP)208, (8 HP/HF, 9 1/2) 76

Azimuthal/Crossed-DipoleAcoustic (XBAT)

4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 28, (6 3/4, 8,9 1/2) 21

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.65x2.25, (6 3/4) 6.43x2.81, (8)7.65x2.81, (8 HP/HF) 7.53x2.81, (9 1/2) 8.98x3

150 (All) 25,(6 3/4, 8,9 1/2) 30

opt.

(4 3/4) 161, (6 3/4, 8)11, (6 3/4 HP) 12, (8 HP/

HF, 9 1/2) 4

(4 3/4) 458, (6 3/4, 8)33, (6 3/4 HP) 35, (8

HP/HF, 9 1/2) 13

(6 3/4, 8) 198, (6 3/4 HP)208, (8 HP/HF, 9 1/2) 76

Compensated Neutron Porosity 6 3/4, 8 7.65 (6 3/4) 21/10, (8) 14/8 (6 3/4) 6.54x2.81, (8) 7.76x2.81 150 18 4 12 72

Compensated ThermalNeutron (CTN)

4 3/4, 6 3/4, 8 (4 3/4) 11.1, (6 3/4) 11.8,(8) 17.5

(4 3/4) 30/14, (6 3/4) 21/10,(8) 14/8

(4 3/4) 4.72x2.25, (6 3/4) 6.62x2.81, (8)8.04x2.81

150, 175 (4 3/4) 20,25 (6 3/4,8) 25, 30

(4 3/4) 72, (6 3/4)4, (8) 3

(4 3/4) 193, (6 3/4)12, (8) 11

(8) 63

Magnetic Resonance ImagingLogging While Drilling

(MRIL-WD)

6.75 39 21/10 6.35 x 2.81 150 20 20 58


Compensated Long-SpacedSonic

4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 31.5, (6 3/4, 8,9 1/2) 29

(4 3/4) 32/17.5, (6 3/4) 18/9.5,(8) 17/9, (9 1/2) 10/5

(4 3/4) 4.4x2.25, (6 3/4) 6.25x2.81, (8)7.2x2.81, (9 1/2) 9.2x3.00

150 20 (4 3/4) 36, (6 3/4)n/a, (8) N/A, (9

1/2) N/A

(4 3/4) 80, (6 3/4) 50, (8)20, (9 1/2) 20

(4 3/4) n/a, (6 3/4) 115(8) 35, (9 1/2) 35

(9 1/2) 60 (4 3/4) 120-300, (6 3/4) 250-750, (8) 250-1,125, (9 1/2)

250-1,500

E Sonic 6 3/4, 8 (6 3/4, 8) 29 (6 3/4) 18/9.5, (8) 17/9 (6 3/4) 6.25x2.81, (8) 7.2x2.81 150 20 (6 3/4) N/A,(8) N/A

(6 3/4) 25, (8) 15 (6 3/4) 45 (8) 18 N/A (6 3/4) 250-750, (8) 250-1,125

Slim Density/Neutron Stand-off Caliper

4.75 15.6 30/15 4.93x2.25 150 25 6 29 N/A N/A 120-375

Survivor Slim Density/NeutronStand-off Caliper

4.75 15.6 30/15 4.93x2.25 175 25 6 29 N/A N/A 120-375

Density/Neutron Stand-offCaliper

6 3/4, 8 25 (6 3/4) 16/8, (8) 12/6 (6 3/4) 6.69 x2.81, (8) 9.2x2.81 150 18 n/a (6 3/4) 20, (8) 10 (6 3/4) 45, (8) 25 N/A (6 3/4) 250-750, (8) 275-1,125

iFinder Density Imaging 4 3/4, 6 3/4 19.6, 19.8 (4 3/4) 30/15,(6 3/4) 16/10

(4 3/4) 4.92 x 2.25, (6 3/4) 6.68 x 2.81 175 25 6 29 65 N/A (4 3/4) 120-375, (6 3/4)250-750

Schlumberger

SonicScope475 4.75 30 30/154.75x2.25x33.7

150 std.175opt.

25 11.1 69.6 N/A N/A 0-400

sonicVISION675 6.75 23.8 16/8 6.5x2.81x35 150 std.175opt.

25 std. 30 opt.

0.3 2.0 6.6 N/A 0-800

sonicVISION825 8.25 22.6 14/6 8.0x2.81x32 150 std.175opt.

25 std. 30 opt.

0.1 0.7 2.3 16.0 0-1,200

sonicVISION900 9 22.6 12/4 9x2.81x27 150 25 0.1 0.7 2.3 16.0 0-1,400

adnVISION475 4 3/4 with Slick, 57/8, or 6 1/4 Stabilizer

options

23.6 30/15 4.75x2.25x24.7 150std., 175

opt.

20 35 220 N/A N/A 0-400


Options

20.5 16/8 6.5x2.25x27.4 150 std.175opt.

20 std., 30opt.

1 4 10 N/A 0-800

adnVISION825 8 1/4 with Slick or10 3/8 Stabilizer

Options

22.3 14/7 8.25x2.81x26.1 150 20 std., 30opt.

1 2 6 41 0-1,600

adnVISION825s 8 1/4 with 12stabilizer

31 12/4 8.0x2.81x21.0 150 20 1 7 22 90 0-1,000

proVISION 6 3/4 with Slick, 81/4, or 9 3/8 Stabilizer

Options

37.3 16/8 6.5x2.81x36.5 150 18 4 25 81 N/A 300-800


Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800


25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

Weatherford

TNP (Thermal NeutronPorosity)

4-3/4, 6-3/4, 8-1/4 24.5 all sizes (includes AZD) (4 3/4) 30/15, (6 3/4) 16/8,(8.25) 14/7

(4 3/4) 4.75x3.28 (6 3/4) 6.75x4.24 (8.25)8.25x5.17

150Std.

180Opt.

(4-3/4 &6-3/4) 20std., 30

opt., (8-1/4)20 std., 25

opt.

(4 3/4) 16(6 3/4) 2(8 1/4) 2

(4 3/4) 87 (6 3/4) 10 (8 1/4) 2

(4 3/4) 265 (6 3/4) 27 (8 1/4) 11

(6 3/4) 205(8 1/4) 43

(4 3/4) 80-350; (6 3/4,8) 80-800; (8 1/4, 9 1/2)

80-1,800

SST (ShockWave Sonic Tool) 4-3/4, 6-3/4, 8-1/4,9-1/2

(4-3/4) 29.7, (6-3/4) 26.0,(8-1/4) 26.5’, (9-1/2) 26.75’

(4-3/4) 20/12, (6-3/4”) 11/5,(8-1/4”) 10/4, ( 9-1/2”) 10/4

(6-3/4) 6.75 x 3.06, (8-1/4) 8.25 X 4.20,(9-1/2) 9.5x8.8

150Std.

165Opt.

(4-3/4 &6-3/4) 20std., 30

opt., (8-1/4& 9-1/2)

20 std., 25opt.

4 3/4 - 19 6 3/4, 8 - 2

8 1/4, 9 1/2 - 2

4 3/4 - 1056 3/4, 8 - 11

8 1/4, 9 1/2 - 2

4 3/4 - 320 6 3/4,8 - 328 1/4, 9 - 6

6 3/4, 8 - 2088 1/4 , 9 1/2- 45 psi

(4 3/4) 80-350; (6 3/4,8) 80-700; (8 1/4, 9 1/2)

80-1,600

Density

Baker Hughes

LithoTrak 4 3/4, 6 3/4, 8 1/4 (4 3/4) 16.1, (6 3/4) 17.6, (8 1/4) 18.2

(z) (4 3/4) 4.82x1.87, (6 3/4) 6.87x2, (8 1/4)8.25x2.813

150 Standard20 (4 3/4)Optional.25, (6 3/4& 8.1/4)Optional.

30

(a) (a) (a) (a) (4 3/4) 100-320, (6 3/4) 200-900, (8 1/4) 300-1,290



Azimuthal Lithodensity (ALD) 4 3/4, 6 3/4, 8 (4 3/4) 14.3, (6 3/4) 12.4,(8) 13.6

(4 3/4) 30/14, (6 3/4) 21/10,(8) 14/8

(4 3/4) 4.6x2.25, (6 3/4) 6.54x2.81, (8)7.76x2.81

150, 175 (4 3/4) 20,25, (6 3/4,8) 18, 25

(4 3/4) 86, (6 3/4, 8) 7 (4 3/4) 237, (6 3/4)19, (8) 21

(6 3/4) 117, (8) 128


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


Stabilized Lithodensity (SLD) 4 3/4, 6 3/4, 8 (4 3/4) 14.3, (6 3/4) 12.4,(8) 13.6

(4 3/4) 30/14, (6 3/4) 21/10,(8) 14/8

(4 3/4) 4.6x2.25, (6 3/4) 6.54x2.81, (8)7.76x2.81

140 (4 3/4)20, (6 3/4,

8) 18

(4 3/4) 86, (6 3/4, 8) 7 (4 3/4) 237, (6 3/4)19, (8) 21

(6 3/4) 117, (8) 128


Slim Density/Neutron Stand-off Caliper

4.75 15.6 30/15 4.93x2.25 150 25 6 29 N/A N/A 120-375

Survivor Slim Density/NeutronStand-off Caliper

4.75 15.6 30/15 4.93x2.25 175 25 6 29 N/A N/A 120-375

Density/Neutron Stand-offCaliper

6 3/4, 8 25 (6 3/4) 16/8, (8) 12/6 (6 3/4) 6.69 x2.81, (8) 9.2x2.81 150 18 N/A (6 3/4) 20, (8) 10 (6 3/4) 45, (8) 25 N/A (6 3/4) 250-750, (8) 275-1,125

iFinder Density Imaging 4 3/4, 6 3/4 (4 3/4) 19.6, (6 3/4) 19.8 (4 3/4) 30/15, (6 3/4) 16/10 (4 3/4) 4.92 x 2.25, (6 3/4) 6.68 x 2.81 175 25 6 29 65 N/A (4 3/4) 120-375, (6 3/4)250-750

Schlumberger


options

23.6 30/15 4.75x2.25x24.7 150std., 175

opt.

20 35 220 N/A N/A 0-400


Options

20.5 16/8 6.5x2.25x27.4 150 std.175opt.

20 std., 30opt.

1 4 10 N/A 0-800


Options

22.3 14/7 8.25x2.81x26.1 150 20 std, 30opt.

1 2 6 41 0-1,600


31 12/4 8x2.81x21 150 20 1 7 22 90 0-1,000


Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800


25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

Weatherford

AZD (Azimuthal DensitySensor)

4-3/4, 6-3/4, 8-1/4 24.5 all sizes (includes TNP) (4-3/4) 30/15 (6-3/4) 16/8,(8-1/4) 14/7

(4-3/4) 4.75x3.28 (6-3/4) 6.75x4.24 (8-1/4)8.25x5.17

150Std.

165Opt.

(4-3/4 &6-3/4) 20std., 30

opt., (8-1/4)20 std., 25

opt.

(4 3/4) 16 (6 3/4) 2 (8 1/4) 2

(4 3/4) 87 (6 3/4) 10 (8 1/4) 2

(4 3/4) 265 (6 3/4) 27 (8 1/4) 11

(6 3/4) 205(8 1/2) 43

(4 3/4) 80-350; (6 3/4) 80-700;(8 1/4) 80-1,600

Formation Pressure Testing

Baker Hughes

TesTrak 4 3/4, 6 3/4, 8 1/4 (4 3/4) 23.0, (6 3/4) 24.3, (8 1/4) 24.4

(z) N/A 150 Standard20 (4

3/4, 6 3/4& 8 1/4)Optional.

30

(a) (a) (a) (a) 125 - 1600, function of MWDplatform


GeoTap 4 3/4, 6 3/4, 8, 9 1/2 (4 3/4) 24, (6 3/4) 28.4, (8,9 1/2) 26.7

(4 3/4) 30/14, (6 3/4) 21/10, (8,9 1/2) 14/8

(4 3/4) 4.76 x 2.25, (6 3/4) 6.4x2.81, (8) 7.9 x2.81, (9 1/2) 9.18 x 3

150 4 3/4, 25(6 3/4,

8, 9 1/2)25, 30

(4 3/4) 20, (6 3/4)19, (8, 9 1/2) 15

(4 3/4) 120, (6 3/4) 39,(8, 9 1/2) 31

(6 3/4) 75, (8, 9 1/2) 60 (8, 9 1/2) 350

PathFinder

Drilling Formation Tester 6.75 37 16/7 6.37x2.81 150 20 N/A N/A 70 N/A 275-750

Schlumberger

StethoScope 675 6 3/4 w/ 8 1/4 stab 6 3/4 w/ 9 1/4 stab

(Optional)

31 16/8 31 150 std. 165opt.

20 std.25 opt.30 opt.

MW x Q2/CMW = mud weight

in ppg Q = Flowrate

in gpmC = 58,620

0-800

StethoScope 825 8 1/4 w/ 12.0 stab8 1/4 w/ 10 3/8 stab

(Optional)

31.5 13/7 35 150 20 std.25 opt.30 opt.


in ppg Q = Flowrate

in gpmC = 79,439

0-1,600

StethoScope 475 4 3/4 w/ 5 3/4 stab 4 3/4 w/ 5 1/2 stab

(Optional)

26 30/15 43.5 150 20 std.25 opt.30 opt.


in ppg Q = Flowrate

in gpmC = 6000

0-400

Weatherford

PFT (PressureWave FormationTester)

6-3/4, 8-1/4 24.3 (6 3/4) 16/8,(8.25) 14/7

(6 3/4) 6.75x4.24 (8.25) 8.25x5.17 150 20 std.(6.75), 30 opt.(6.75)

(6 3/4) 2 (6 3/4) 10 (6 3/4) 27 (6 3/4) 80-800

Seismic

Schlumberger

seismicVISION675 6.75 14 16/8 13.8 150 25 0.4 2.4 7.8 N/A 800

seismicVISION825 8.25 13.84 14/7 14.4 150 23 std., 27.5 opt.

0.1 0.7 2.2 15.6 2,000

seismicVISION900 9 13.84 12/4 14.8 150 23 0.1 0.7 2.2 15.6 2,000

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Servi

ce lin

e (s)

Tool

OD, i

n.

Leng

th, ft

Max. D

LS, °

100 ft

(slidi

ng, r

otatio

n)

Equiv

alent

bend

ing st

iffnes

s

Max. o

p. te

mpera

ture (

°C)

Max. o

p. pr

ess,

kpsi

Pres

sure

drop

, psi

at

100 g

al/min

Pres

sure

drop

, psi

at

450 g

al/min

Flow

rang

e,ga

l/min

Pres

sure

drop

, psi

at

250 g

al/min

Pres

sure

drop

, psi

at

1,20

0 gal/

min


Well Placement Technology

Baker Hughes

AziTrak (azimuthal formationresistivity at multiple depths ofinvestigation plus real-time 3D

geospatial modelling)

4 3/4, 6 3/4 (4 3/4) 40.4, (6 3/4) 35.3 (z) TBD 150 Standard20 (4 3/4)Optional.

25, (6 3/4)Optional.

30

(a) (a) (a) (a) 4 3/4) 125-350, (6 3/4)265-900

ZoneTrak G (near bitgamma ray)

9.5 4.79 (z) TBD 150 Standard20, Optional

25

(a) (a) (a) (a) 300-1,600, function of MWDplatform

ZoneTrak (at-bit boundarydetection system)

6 3/4, 9 1/2 (6 3/4) 6.3, (9 1/2) 5.7 (z) (6 3/4) 7.25 x 3.64, (9 1/2) 9.63 x 3.7 150 Standard20, Optional

25

(a) (a) (a) (a) (6 3/4) 200-900 (9 1/2) 300-1,600


DeepTrak (very deep resistivity) 6.75 Transmitter Sub : 6.9 ftReceiver Sub:

22.4 ft

(z) TBD 150 Standard20, Optional

25

(a) (a) (a) (a) 200-900, function of MWDplatform

StarTrak (high resolutionborehole imaging)

4 3/4, 6 3/4 (4 3/4) 9.8, (6 3/4) 8.3 (z) (4 3/4) 5.25 x 3.13, (6 3/4) 7.25 x 4.6


25

(a) (a) (a) (a) (4 3/4) 125-350, (6 3/4) 265-900, function of

MWD platform

SeismicTrak (boreholeseismic tool)

6 3/4, 9 1/2 (6 3/4) 10.73, (9 1/2 11.35 (z) (6 3/4) 7 x XX, (9 1/2) 9.5 x XX


25

(a) (a) (a) (a) (6 3/4) 265-900, (9 1/2in)530-1270


Azimuthal Deep Resistivity(ADR)

4 3/4, 6 3/4 (4 3/4) 25.5, (6 3/4) 24.3 (4 3/4) 30/14, (6 3/4) 21/10 (4 3/4) 4.76x2.25, (6 3/4) 6.71x2.81 150 25 (4 3/4) 152, (6 3/4) 14 (4 3/4) 419, (6 3/4) 38 (6 3/4) 229

Azimuthal Focused Resistivity(AFR)

4 3/4, 6 3/4, 8 (4 3/4) 10.0, (6 3/4) 10.8,(8) 8.5

(4 3/4) 30/14, (6 3/4) 21/10,(8) 14/8

(4 3/4) 4.74x2.25, (6 3/4) 6.56x2.81, (8) TBD 150 (4 3/4)24.5, (6

3/4) 22, (8)24.5

(4 3/4) 78, ( 6 3/4)6, (8) 2

(4 3/4) 214, (6 3/4)17, (8) 5

(6 3/4) 101, (8) 25

At-Bit Inclination (ABI) 4 3/4, 6 3/4, 8, 9 5/8 Part of Mud Motor (4 3/4) 30/14, (6 3/4) 21/10, (8,9 5/8) 14/8

Depends on mud motor 150 18 Depends on mudmotor

Depends on mud motor Depends on mud motor Depends on mud motor Depends on mud motor





upper, 3.66 lower

(4 3/4) 31/17, (6 3/4) 16/10,(8) 16/10

(4 3/4) 4.43x2.25, (6 3/4) 5.99x2.81, (8)6.99x2.81

175 (4 3/4), (63/4) 25,(8) 20

N/A (4 3/4) 70, (6 3/4) 20 (4 3/4) N/A, (6 3/4)35, (8) 20

N/A (4 3/4) 125-375, (6 3/4) 250-750, (8) 250-1125

Schlumberger

PeriScope 4 3/4, 6 3/4 23.5 (4 3/4), 18.3 (6 3/4) 30/15 (4 3/4) , 16/8 (6 3/4) 4.75x2.25x27 (4 3/4), 6.5x2.81x19.3 (6 3/4) 150 25 (4 3/4) 10, (6 3/4) 0.7

(4 3/4) 65,(6 3/4) 4

(6 3/4) 14 N/A 0-400 (4 3/4), 0-800 (6 3/4)

geoVISION675 6.75 10.12 16/8 6.5x2.81x10 150 18 0.9 5.5 18 N/A 0-800

geoVISION825 8 1/4 12.72 13/7 8x2.81x13.5 150 15 0.15 0.95 3 21.8 0-1,200


Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800



Options

20.5 16/8 6.5x2.25x27.4 150 std.175opt.

20 std., 30opt.

1 4 10 N/A 0-800


Options

22.3 14/7 8.25x2.81x26.1 150 20 std, 30opt.

1 2 6 41 0-1,600


31 12/4 8x2.81x21 150 20 1 7 22 90 0-1,000


Options

25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800


25.2 16/8 6.5x2.81x24.5 150 std.175opt.

20 std., 25opt.

2 10 32 N/A 250-800

MicroScope 4 3/4 with

5 3/8 slick sleeve

18 30/15 4.75x2.25x18 150 20 9.8 61 198 N/A 0-500

Weatherford

MFR+Plus (Multi-FrequencyResistivity PLUS)

4.75 34.7 30/15 4.75x2.29 150 30 19 105 320 n/a 80-350

GWAR (GuideWave AzimuthalMulti-Frequency Resistivity)

4.75, 6.75 34.7 30/15 4.75x2.29 150 20 Std.,30 opt.

19 105 320 n/a 80-350

At-Bit Measurement System 4 3/4, 6 3/4 NOMTOOL SIZE (5.60” and

7.325” max)

(4 3/4) 2.83 ft., (6 3/4)3.01 ft.

(4 3/4) 30/15, (6 3/4) 16/8 (4 3/4,6 3/4)150

(4 3/4) 10(6 3/4) 10

estimates (4 3/4)12, (6 3/4) 2

estimates (4 3/4) 64,(6 3/4) 9

estimates (4 3/4)exceeds flow rate, (6

3/4) 26

estimates (6 3/4) 170 (4 3/4) 80-350; (6 3/4,8) 80-800; (8 1/4, 9 1/2)

80-1,800

Formation Fluid Identification and Sampling


GeoTap IDS 6 3/4 34.7 + 11.8 per sample collar 21/10 6.89x2.81 (with one sample collar) 150 20 TBD TBD TBD TBD


qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Distribution of rigs in the sample.


E N G I N E E R I N G , C O N S T R U C T I O N , & I N S TA L L AT I O N

New model predicts jackupweight and displacement

Analytical tool offers additional metric for design and benchmarking

The weight of a rig is an important vari-able in cost estimation and determinesthe amount of steel required in con-struction. Rig weight is generally con-sidered proprietary, however, because

it indicates design benchmarks and construc-tion performance metrics that are central tothe competitive nature of the industry. Severalmethods can be used to predict ship weight,but given the structural differences betweenjackup rigs and ships, these techniques arenot adequate to predict rig weight. The pur-pose of this article is to construct a jackuplightweight displacement function based onempirical analysis of a random sample of rigs.

Weight managementWeight is an important design factor and

a primary feature in determining the physi-cal characteristics of a rig. Larger rigs havegreater variable loads, can support more pow-erful drilling equipment, and operate in moresevere conditions. Weight is linked to fabrica-tion costs. As more steel is added, materialcosts and fabrication expenses increase, butcomplex tradeoffs are involved with weightmanagement, and because so many interde-pendent factors are involved, it is difficult toquantify the effects of weight on cost. Weightis also a critical factor in determining rig stabil-ity and the size and design of spudcans.

Weight factorsThe weight of a jackup rig is primarily

determined by the water depth, drilling, andenvironmental capability, and rig design.

Water depth. As the water depth capabil-ity of a rig increases, the length of the legs in-crease. At some point, incremental leg lengthcannot be added to a given hull design andthe hull must be enlarged. As a result, waterdepth is correlated with a number of physicaldescriptors including leg length, hull breadth,hull depth, deck area, and hull volume.

Drilling depth. In order to increase the drill-ing depth capability of a rig, designers make al-lowances for more powerful drilling equipment,stronger cantilevers, and greater variable loads.Larger and heavier rigs are required to accom-modate more numerous and powerful drillingsystems and heavier cantilever loads.

Environmental capability. Harsh envi-ronment rigs are heavier than moderate en-vironment units. For the same water depthcapability, harsh environment rigs must havelonger legs than moderate environment unitsto increase the air gap. The legs and spud-cans of harsh environment rigs are built toa more robust standard than moderate en-vironment rigs and use higher quality andthicker steel. Harsh environment units mayalso have greater variable loads than moder-ate units to reduce the frequency of resupply,and this requires a larger, heavier rig.

Since jackups are particularly well suitedto harsh environment operations, some contractors have built harsh environmentjackups with 500-ft (152-m) water depth ca-pabilities to extend the use of jackups into waters typically limited to semis. Ultra-high specification jackups are much heavier thanmoderate environment units. For example,the Gusto MSC CJ 70 weighs 28,000 tons,approximately twice the weight of a typicalmoderate environment unit.

Rig design. The tradeoffs designers makebetween the grade and quantity of steel impactrig weight. Either larger quantities of lowergrade steel or smaller quantities of highergrade steel may be employed. For example, arig designer may increase the number of brac-

es in each leg, but decrease the yield strengthof the steel. Using lower grade steel will in-crease weight, but may result in lower costs.

Rigs may employ rack chocks. Rack chocksare inserted after jacking to transfer the verticalload from the leg racks to the hull. Without rackchocks, the load is held by the pinions in thejacking system. The use of chocks increasesthe fixity between the hull and the legs, and al-lows for a reduction in the bracing in the legs toreduce leg weight. Most F&G, Baker Marine,Keppel, and Gusto MSC rigs utilize chocks,while most Letourneau rigs do not.

Data sourceInformation on rig weights is not widely

available and is generally considered pro-prietary. We assembled data from 31 rigsrepresenting 21 designs and three harshenvironment units. Water depth, hull length,hull width, build year, and designer datawere collected from the academic and tradeliterature, specification sheets, and industrypersonnel. The sample includes most of therigs commonly built in shipyards, includingthe F&G L780 Mod II, the LeTourneau Su-per 116, the Baker Marine 375 and the Gus-to CJ 70 X 150. In a few cases, lightweightdisplacements were estimated as the transitdisplacement minus the transit variable load

Mark J. KaiserBrian F. Snyder

Center for Energy StudiesLouisiana State University

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Canusa-CPS is the industry leader in fi eld-applied coatings for corrosion, mechanical and thermal protection of both onshore and offshore pipelines. Our advanced technology heat-shrinkable sleeves, high-build liquid epoxy coatings and adhesive-based products provide excellent functionality through a broad range of applications and temperatures.

Our primary manufacturing facilities in Canada are supported by a network of warehousing and fi nishing locations throughout North and South America, Europe, the Middle East and Asia-Pacifi c. We continually invest in research and development to expand our product and installation capabilities, and the level of protection for our customers’ assets in extreme conditions around the world.

ShawCor – when you need to be sure

TOBE SUREAdvanced, fi eld-applied pipeline protection coatings

shawcor.comcanusa.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.shawcor.com

http://www.canusa.com





www.stauff.com/act

Visit our Anti-Corrosion Technology Website at

Relationship between water depth and rig weight.


to supplement the dataset. When more than one data point was avail-able from a single rig design, the displacements were averaged toensure that the data points were independent.

Summary statisticsThe distribution of lightweight displacement from the rig sample

has an average of 11,479 tons (range 5,569-28,600 tons) and an aver-age water depth capability of 314 ft (range 250-450 ft/76-137 m). For harsh and moderate environment rigs, the average displacementwas 17,575 and 10,195 tons, respectively. The age distribution wasbimodal with 10 of the 31 rigs built after 2008, and 19 of 31 built be-fore 1985. The average age of all the rigs was 22 years.

Single factor modelsOne key issue is the relationship between displacement and water

depth. Water depth explains 57% of the variation in lightweight, butwater depth squared turns out to be a slightly better predictor. In

a regression analysis, the three harsh environment designsweigh more than average moderate environment rigs for thesame water depth capability.

Another key issue is the relationship between hull dimen-sions and rig weight. Hull dimensions predict about half ofthe variation in rig weight, but unlike the water depth rela-tionship, there is no trend of harsh environment rigs beingheavier than moderate environment rigs for a given hull di-mension.

Weight relationA linear regression model was developed to predict rig

weight using hull length and breadth (width), water depthcapability, designer, environmental class (harsh versus mod-erate) and build year as predictor variables. Hull length timeshull breadth entered the model as an interaction term toproxy the area of the hull. Designer and environmental classwere modeled as indicator variables. Variables were checkedfor multicolinearity, and because breadth was correlated withlength and environmental class, these variables were not per-mitted to enter the same model.

The best model included terms for water depth, water depthsquared, and hull length times hull width:

D = 49,316 – 3,233WD + 0.563(WD)2 + 0.12LB

where D is lightship displacement (tons), WD is water depth capa-bility (feet), and L and B are the length (feet) and breadth (feet) ofthe rig, respectively. Environmental class, designer and build yearwere not significant predictors.

The model explained 91% of the variations in displacement and allterms were significant. The inclusion of the length and width inter-action term explained slightly more variation than either the lengthor width terms individually, and the coefficients were insignificantwhen the interaction term and the length or width terms were in-cluded together.

Water depth is positively correlated with weight, and as waterdepth increases, the slope of the relationship increases because of

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



Prevent Crevice Corrosion � Innovative design and material selection prevents

the accumulation of water between the clamps

and the tubing whilst forming drainage channels

� Fully compliant with Norsok Z-010 standard

� Interchangeable with all regular STAUFF clamps

� Suitable for tubing diameters up to 1in / 25,4mm

STAUFF Germany

Phone: +49 23 92 / 9 16 - 119

Email us at [email protected]

Globally available through

branches and distributors in all

major oil and gas regions

28 – 31 August 2012 � Stavanger (Norway)

Meet STAUFF at Booth No. 340/3 in Hall CColour of rubber strips

for illustrative purposes only

http://www.stauff.com/act





Relationship between hull dimensions and rig weight.


the squared term. In reality, width and breadthare not constant with increasing water depth, butenter the model relative to their physical charac-teristics.

The harsh environment indicator variable wasnot a significant predictor of weight. This is likelydue to the fact that only three designs were harshenvironment units. Data restrictions limit the abil-ity of the model to accurately predict the weight ofharsh environment rigs. Build year and designerwere also not significant predictors, which couldindicate physical similarity in rig designs over timeand between designers.

LimitationsSmall sample size reduces the confidence in

the results and inflates model fit. However, be-cause the total number of rig designs in the world is limited and our sample includes the most popu-lar, the relations are expected to be reasonablyrobust. Additional predictor variables could beexamined in re-specified models, but since themodel already predicts over 90% of the variationin weight, the weight relation is considered ad-equate for aggregate assessments and gross benchmarking studies.

Additional error may be introduced because the lightweight dis-placement of some vessels was based on estimated values, and anumber of different sources were utilized which may estimate light-weight displacement differently. When multiple records for a singlerig design were available, the reported weights matched closely, and

deficiencies in the weight reporting may be partly offset by the aver-aging of multiple records. �

Editor’s note: This article is the second of a five-part series by Mark Kaiser andBrian Snyder on rig construction costs, weight specifications, and market day rates.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



FEBRUARY 5 – 7, 2013

MOODY GARDENS CONVENTION CENTER

GALVESTON, TEXAS, USA

WWW.TOPSIDESEVENT.COM

Engineering, design, construction and installation of offshore production systems will continue to expand as the number of offshore installations increases worldwide. Focusing specifi cally on this important market, TOPSIDES, PLATFORMS & HULLS CONFERENCE & EXHIBITION is the offshore industry’s only event dedicated to the topsides, platforms and hulls for both deep and shallow water. A comprehensive technical program presented concurrently with an exhibition, TOPSIDES, PLATFORMS & HULLS CONFERENCE & EXHIBITION focuses on offshore oil and gas resources worldwide. The exhibition fl oor was completely sold out in 2012 so reserve your booth space today, you can’t afford to miss this growing event.

SUPPORTED BY HOSTED BYPRESENTED BYOWNED &

PRODUCED BY

OPENING NIGHT RECEPTION SPONSOR

GOLF TOURNAMENT BEVERAGE CART SPONSOR

GOLD SPONSORPLATINUM SPONSOR

COFFEE BREAK SPONSOR DELEGATE BAGS SPONSOR SILVER & WEDNESDAY LUNCH SPONSOR

C O N F E R E N C E & E X H I B I T I O N







New semisubmersible vesselredefines heavy transport

Anew semisubmersible heavy-lift ves-sel will soon be available that is ex-pected to redefine the limits of heavymarine transport. The largest semi-submersible heavy-lift vessel ever

built, the Dockwise Vanguard is designed spe-cifically to enable operators and contractorsto consider opportunities for mega offshoreunits which were until now considered un-thinkable.

Transport requirementsThe next decade is expected to see grow-

ing demand for transportation and installa-tion projects, particularly for the transportof mega units to remote offshore locations.Today, fully integrated offshore units suchas TLPs and semisubmersibles are currentlytransported separately. Other units, such asspar buoys and FPSOs, can only be trans-ported up to a certain size and are usuallywet-towed to their destination.

Existing semisubmersible heavy-lift vesselscannot transport the next generation of plat-forms. The world’s current largest semisub-mersible heavy-lift vessel, the Blue Marlin (alsoowned by Dockwise), can carry structures ofup to 76,000 metric tons (83,775 tons). Whilecapable of transporting some mega structures(such as BP’s Thunder Horse), the Blue Mar-lin is limited in its ability to transport largerand heavier units. Many of these newer unitsrequire a new type of vessel with a significantlyincreased carrying capacity. In light of currentlimitations, Dockwise decided to invest in acompletely new vessel design to transport thesuper-sized offshore structures.

Innovative design The vessel was engineered to surpass

current heavy marine transport limita-tions. The vessel’s deck covers a surfaceof 275 m x 70 m (902 ft x 230 ft) and isequipped with movable casings. In ad-dition, the accommodation block andnavigation bridge are on the extremestarboard side. The vessel has no bow,and this, along with other design features,gives the vessel a unique appearance.

In addition, the vessel has a dedicated

design for ultra heavy units weighing up to110,000 metric tons (121, 254 tons). Optimizeddeck strength and extreme wide-load capabili-ties are at the heart of the design philosophy,as are the vessel’s stability characteristics. It isequipped with a 27 MW redundant propulsionsystem consisting of two fixed propellers at theaft and two retractable azimuth thrusters at thebow. It can reach a maximum transit speed of14 knots, which translates to average servicespeeds of 11-13 knots with cargo. In addition,the vessel allows for 16 m (53 ft) water abovedeck, accommodating cargoes with a higherdraft.

New opportunitiesThe vessel’s capabilities present new oppor-

tunities previously unthinkable. Companiesin the oil and gas industry can now specifymuch larger and heavier offshore structures,and these can be integrated at a single fabrica-tion site. These mega structures can then betransported onboard the vessel to remote off-shore locations, even in harsh climates whereno commissioning facilities are available. Thiscan help reduce costs and optimize the overallproject. In essence, the new vessel will play animportant role in the field development phi-losophy of oil and gas majors, since it will becapable of transporting fully integrated megaoffshore units.

The vessel’s design is also expected to helpoperators and developers create value. With itscapabilities, timely and risky phases of offshoreprojects can be managed prior to hookup andcommissioning. Interface optimization, higher

degree of risk mitigation, lower insurance pre-miums, improved schedule flexibility, and re-duced time-to-production – as well as reducedoffshore man-hours – are a few examples of op-portunities. In addition, the vessel’s advancedtechnical capabilities enable it to offer a com-pletely new service: offshore dry-docking.

Offshore dry-dockingIncreasingly, FPSOs are being located in re-

mote areas which lack support infrastructure. Inthis circumstance, an offshore dry-docking ser-vice can be specially valuable. The vessel’s FPSOdry-docking capacity offers inspection, mainte-nance, and repair opportunities (amongst oth-ers) at different conditional modes. The FPSOcould remain connected to its mooring andturret system while keeping the riser systemsintact, with the possibility of continuing limitedproduction. In this scenario, the FPSO will stillbe able to freely weathervane around the turretmooring, with controlled heading made possibleby the vessel’s propulsion system.

In order to fully realize this new offshore ser-vice, Dockwise received an “approval in princi-ple” from ABS following the commissioning ofa hazard identification (HAZID) safety assess-ment. This assessment took place in the pres-ence of a multi-disciplinary team of experts andrepresentatives from two oil and gas majors.

Industry recognitionThe vessel’s design philosophy has received

two awards by maritime organizations. The firstaward was from the Royal Association of DutchShip Owners for the KVNR Shipping Award

2011. This award recognized the DockwiseVanguard as the most innovative vessel,and was listed in the jury report underthe “big, bigger, biggest” category. Thesecond recognition, an OTC Spotlight onNew Technology Award bestowed at thisyear’s conference, also recognized thevessel’s innovative design. In selecting anew technology winner, the jury’s deci-sion was based on the following criteria:new, innovative, proven, broad interest,and significant impact.

Looking to the futureWith its innovative designs, the vessel

is uniquely capable of transporting thenext generation of fully integrated megaunits offshore. Delivery of the vessel isplanned for 4Q 2012. �

Jonathan MartinezDockwise

With the Dockwise Vanguard’s dry-dockingservice, the FPSO remains connected toits mooring and turret system while keep-ing the riser systems intact.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








[email protected]

www.mustangeng.com

www.alliance-engineering.com

THE LEADER for a reason...

Setting the standard in topsides design

First Largest Deepest and

Lightest

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.alliance-engineering.com

http://www.mustangeng.com







EXMAR launches FLRSU to exploitstranded gas offshore Colombia

First-ever facility to go on-stream in 2014

EXMAR NV plans to invest $300 millionon the first-ever fl oating liquefaction,re-gasification, and storage unit (FLR-SU) in an effort to develop strandedgas worldwide. Under a 15-year con-

tract with Rubiales Energy Corp., EXMARwill operate the FLRSU in the Caribbean Sea offshore Colombia starting in 4Q 2014. The facility will be a non-propelled bargeequipped to convert natural gas into LNG,and to store for offloading to a permanentlymoored storage unit or shuttle tankers. The jetty moored barge will receive gas from theonshore La Creciente field.

The floating plant will process 69.5 MMcf/dof natural gas, and produce 500,000 metric tons(551,155 tons) of LNG per annum. The FLRSUwill process piped gas with less than 1% of CO2

content, but will not process sour gas. The fa-cility will be 140 m (459 ft) long, 32 m (105 ft)wide, 18 m (59 ft) deep, and have a normal draftof 5 m (16 ft).

EXMAR officials are confident the FLRSU

will be at the jetty for another 15 years giventhe potential of the field reserves. The LaCreciente field has 6 tcf (170 bcm) of gasreserves, and ongoing studies estimate a po-tential of 30-43 tcf (850 bcm-1.2 tcm).

“We wanted to show some innovation inthe LNG market,” said EXMAR CEO Nico-las Saverys. “We are the first one to do re-

gasification onboard a ship, and we are thefirst one doing ship-to-ship liquid transfer.Now we will be the first one to do ship-to-ship transfer of LNG.”

Supplying the gas marketSaverys dismissed criticism about the proj-

ect being too small. “The world gas market isregulated and this small-scale project is set tocontribute to the global gas market,” he said.“We are on the verge of a very fast growinggas market. We are bringing this first projectto increase gas supply to that market.”

Assuring the simple system and safe ap-proach, Saverys said he sees a huge poten-tial in exploiting stranded gas globally. “Theenergy markets are short of gas suppliesand EXMAR’s FLRSU-based approach offersthe opportunity to add stranded gas to thesemarkets, and correct the current imbalancein trade, both price and supply wise.”

Saverys noted that “there is enoughstranded gas worldwide, some of which isvery often flared and or some of which is notreadily available because of technology lim-its. We think that there are plenty of oppor-tunities in the world and plenty of gas which,at the moment, is untouched because thereare no means to bring it to the markets.”

At the launch of the project in Shanghai

Gurdip SinghContributing Editor

Rendering of the FLRSU.

The FLRSU under construction at Wison Offshore & Marine’s new shipyard in Nantong, China.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



________________________

http://www.uscortec.com





qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



C O N F E R E N C E & E X H I B I T I O N

FEBRUARY 5 – 7, 2013

MOODY GARDENS CONVENTION CENTERGALVESTON, TEXAS, USA

WWW.TOPSIDESEVENT.COM

SUPPORTED BY HOSTED BYPRESENTED BYOWNED &

PRODUCED BY

OPENING NIGHTRECEPTION SPONSOR

GOLF TOURNAMENTBEVERAGE CART SPONSOR

GOLD SPONSORPLATINUMSPONSOR

COFFEE BREAK SPONSOR DELEGATE BAGS SPONSOR SILVER & WEDNESDAY LUNCH SPONSOR

Join hundreds of colleagues and exhibiting companies for this high-level technical conference and exhibitionand connect with key decision makers and technical experts directly involved in the topsides industry.

Over three days, TOPSIDES, PLATFORMS & HULLS will feature presentations covering technical issues, businesschallenges and future trends, plus showcase an exhibition of products and services from dozens of keyengineering firms, contractors, suppliers and service providers. Join us in Galveston, February 5-7, 2013!

__________________________





http://WWW.TOPSIDESEVENT.COM

Roald Amundsen

South Pole Expedition 1911

originally developed by VICINAY,

is nowadays an offshore industry standard

because it delivers higher strength with less

weight.

Because the original is always best, most

companies rely on Vicinay for the supply of R5

chain.

Our production from four factories in three

continents covers the global market.

R5

Pioneering, astate of mind

www.vicinaycadenas.com

Visit us at booth D416

E N G , C O N S T, & I N S TA L L

on June 1, Saverys called on China’s state energy companies to con-sider EXMAR’s FLRSU concept for exploiting gas deposits. EXMAR is building the facility at Wison Offshore & Marine Ltd.’s new ship-yard in Nantong, China.

The FLRSU project highlights the business potential and invest-ment in Colombia. EXMAR has worked in the South American coun-try handling coal exports for more than a decade. “Colombia has the fastest growing economy in South America, and one of the fastest in the world,” he said. Colombia is ramping up oil production to 1 MMb/d this year. The country’s current gas production is estimated at 1 bcf/d (28 MMcm/d) of gas. The company is training 28 Colom-bian nationals to manage and operate the FLRSU.

The future appears to be bright for FLRSU projects, but EXMAR is taking one project at a time. As for the company’s future, Saverys said: “There are places where gas production is just impossible. Indeed I can share with you that my ambition is to produce gas from those areas in the next decade. I would like to see that we are the fi rst one doing more complicated projects by going into harsher environments and handling gas which comes with a sludge, which will need to be cleaned and purifi ed. We will have a real cracking system out there.”

Engineering the vessel In June, Shanghai-based Wison Offshore & Marine Ltd. signed an

engineering, procurement, construction, installation, and commis-sioning contract (EPICI) to design and build the fl at-bottom barge for the project. “We bring quality Chinese fabrication and international project management to this project,” said Dwayne Breaux, executive vice president of Wison. “The contract is fi rst of its kind in the indus-try, and has put the new yard in a great burgeoning market.”

Black & Veatch is providing the detailed design of the topside LNG production facilities to Wison for the FLRSU. Through a global design team led from its Beijing offi ce, Black & Veatch will also supply all LNG process equipment and provide installation and start-up over-sight services to Wison, said David E. Kerns, executive vice president, director for strategic planning and risk management at B&V Energy.

The equipment will utilize the company’s patented PRICO technol-ogy, which employs a single-mixed refrigerant system to accomplish the gas liquefaction with a refrigerant that is a mixture of nitrogen and hydrocarbons ranging from methane to isopentane, Kerns explained. By using a single-mixed refrigerant process with one refrigeration loop startup, Black & Veatch aims to achieve high reliability and availability.

Underlining the risk sharing pact between EXMAR, Wison, and Black & Veatch, Saverys said he plans to discuss future projects with the two partners. “We are talking about complex construction with certain risks,” he said. “And these risks are shared in equitable man-ners with different parties.” �

EXMAR CEO Nicolas Saverys at the project launch in Shanghai.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________________

http://www.vicinaycadenas.com







New polyethylene fiber suitablefor deepwater mooring ropes

Improved creep properties make permanent installation possible

Anew High Modulus Polyethylene fiber(HMPE) with improved creep prop-erties allows its use in permanentoffshore mooring systems. Testingshows that ropes made with the new

fiber type retain the properties characteristicof HMPE such as high static strength and stiffness and yarn-on-yarn abrasion resis-tance.

HMPE is suitable for longer, ultra-deepwa-ter mooring lines beyond 2,000 m (6,562 ft).The fibers are characterized by high strengthand high modulus, producing lighter andsmaller diameter high-stiffness ropes com-pared with polyester mooring lines for thesame MBL (minimum breaking load). Howev-er HMPE’s creep performance has preventedits use in long-term deepwater moorings. Sys-tematic improvements in creep performancehave led first to the development of SK78 fiberfor semi-permanent MODU moorings, andnow DM20 fiber for offshore permanent pro-duction moorings.

The long-term creep properties of DM20match industry requirements for durationof permanent moorings. A creep estimationmodel based on fiber data has been developedfor DM20 to demonstrate the fiber’s ability tomeet creep performance requirements, andthus limit the need for full size rope testing.

The fiber creep rate properties were con-firmed by creep tests on subropes. Becauseof its extreme low creep elongations, thediscard criterion of 10% perma-nent elongation – suggested inindustry guidelines and standardsfor general HMPE types and MODU grade SK78 – needs to bereconsidered for DM20. Dynamicstiffness of DM20 equals SK78,while secant stiffness of DM20 is higher than SK78, confi rming thereduced creep of this new fiber. Itis advised to determine stiffnessvalues on (sub)rope level.

Beyond 2,000 m (6,562 ft) waterdepth, high stretch of polyesterrope becomes a problem as thelonger mooring lines allow greaterhorizontal offsets. A 2,000 m poly-ester line may have 40 m (131 ft)

elongation, while a 3,000 m (9,842 ft) linewould allow 60 m (197 ft) elongation underthe same environmental conditions. This creates horizontal offsets which may exceedthe limits of risers. Using HMPE with simi-lar break load, these offsets would be only12 m (40 ft) for a 3,000 m line.

In addition, HMPE is now consideredsuitable for these longer deepwater mooringline lengths. Because the fi bers are charac-terized by high strength and high modulus,resulting in lighter and smaller diameterhigh-stiffness ropes, there are both techni-cal and operational advantages over tradi-tional polyester mooring lines. HMPE ropestypically have an extension at break of 2%-2.5% for a worked rope.

During station-keeping, wave movementsimpose cyclic loadings on mooring lines,causing fluctuating fiber elongation. The

mooring lines are subject to tension-tensionfatigue loads. HMPE fiber ropes have showna longer fatigue life compared to polyesterropes for the same rope construction andare not vulnerable to axial compression fa-tigue compared to aramid fiber.

However, the high stiffness of HMPE alsocan be a limiting factor. In high storm andhurricane risk areas the mooring systemneeds stretch to survive. Hybrid mooringlines combining HMPE rope segments withpolyester rope segments provide the stiff-ness needed to handle maximum loads dur-ing station-keeping in storm, while ensuringsufficient elasticity to damp peak loads in-duced by waves.

Pretension is responsible for long-termloading of mooring lines. HMPE fi bers aresensitive to long-term static loads, and irre-versibly elongate proportionally with time.This is known as creep. All synthetic ropesexperience some creep – defined as the per-manent elongation of the rope under load.The rope will not fully recover once the loadis removed.

Excessive creep increases offset of themoored vessel. The degree of creep dependson HMPE type, operating temperature, meanload, and loading time. Recent fiber develop-ments aim to reduce the creep rate (% elonga-tion/time unit), as well as developing a model toaccurately predict creep rate and creep elonga-tion, and thus provide better estimates of creep

lifetime.In 2003, SK78 fiber, a low-creep

HMPE, was introduced for semi-permanent mobile operating drillingunit (MODU) moorings. PetróleoBrasileiro SA recently ordered aset of SK78 mooring ropes with 630metric ton (694 tons) MBL for deep-water MODU projects offshore Bra-zil. Further research on creep ratereduction has resulted in the devel-opment of the DM20 fiber grade,especially designed for deepwaterpermanent mooring.

Predictive modelingFollowing DSM Dyneema’s

modeling of HMPE fiber creep,

M.P. VlasblomJ. Boesten

DSM Dyneema

S. LeiteLankhorst Euronete Ropes

P. DaviesIFREMER

Rope creep testing at Lankhorst Ropes.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________






RIGHTDESIGNTM

Making the RIGHTCHOICES

ww

w.p

ola

rcus.c

om

At Polarcus we operate the most

��

3D seismic vessels in the industry.

��

��

environmental footprint, our vessels

��

��

tions in the harshest of climates.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________

http://www.polarcus.com





E&P_Seismic_1_2_042011

www.rolls-royce.com

Our ship design and integrated system solutions are results of targeted

research and development over many years. Our designs and solutions meet

the challenging combination of high performance and flexibility, reduced fuel

consumption and optimised life-cycle costs.

Our wide range of system solutions includes systems for seismic operations,

safer deck operations, propulsion and manoeuvring, stabilisation, dynamic

positioning and automation and control. Trusted to deliver excellence

Fully optimisedfor the mission– and the environment


industry guidelines for mooring ropes now specify a variety of creep-related documen-tation including validation of creep mod-els, creep failure safety factors, and creep monitoring tasks. Nearly all mooring system standards state that creep estimation mod-els based on fi ber test data can be used to support the mooring system’s creep perfor-mance requirements and thus limit the need for full size (sub)rope testing. Typically creep rate analyses, creep failure analyses, and rope creep tests predictions are required.

For creep analyses, the long-term envi-ronmental events can be represented by a number of discrete design conditions from which the annual creep elongation is calcu-lated, and a predicted total creep strain for the design service life determined. During prototype evaluation, a test is performed to either verify or calibrate long-term rope creep rates with data from the fi ber creep model.

Creep monitoringMonitoring the elongation of HMPE rope

is used to measure the extent of creep. How-ever, there is a lack of consensus among stan-dards bodies on test methodologies. Some mooring standards require creep monitoring

of the rope in use in the most critical section, usually the top part or top section closest to the water surface because of the higher tem-peratures. A few standards specify a HMPE rope replacement criterion of 10% creep strain of the total length of the HMPE rope.

Where indicated, the creep safety fac-tor for HMPE ropes is different for mobile moorings and long-term moorings. It also differs on how it is applied. In the norms and guidelines for HMPE ropes, the safety fac-tors are based on either creep failure, creep rupture life, or design service life, which, by defi nition, are not consistent. Furthermore, the factor of safety for a monitored rope can be lower than that for an unmonitored moor-ing rope. There are also practical issues to be considered when a creep model is based on rope data. For extrapolation over longer times, creep tests on HMPE ropes should be carried out into the “steady-state creep re-gime,” to determine the plateau in the creep rate. Since creep rate is load and tempera-ture dependent, testing until creep failure within an acceptable time frame can only be performed at high loads or high tem-peratures which do not represent offshore operating conditions. The cost of rope test facilities to perform these tests at operating

loads and temperatures can be high. As a re-sult, rope creep tests are normally limited to rope creep rate tests to verify the fi ber creep model used for the analysis.

As required by several of the industry norms and guidelines, the DM20 rope creep rates were compared with creep model pre-dictions to verify the fi ber creep model.

The creep model predictions are very close for normal loading ranges, and conser-vative for load ranges which are signifi cantly over normal operating conditions for the off-shore mooring lines. In all tested conditions, the rope showed a creep rate lower than esti-mated. Although the relative differences be-tween predicted and measured creep rates seem high, a certain inaccuracy is inevitable in predictions of long-term endurance. DSM Dyneema has ensured that model estimates of creep rate always err on the conservative side of the expected creep lifetime.

It should also be noted that the accuracy of the current creep model, based on limited creep rate and creep rupture data, will im-prove over time.

Stiffness measurementsTo verify the offsets under heavy load con-

ditions, the creep of fi bers has to be taken

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



________________

http://www.rolls-royce.com





• Shaft-less – low investment costs

• Machine room-less

• Unique safety features

• Capacities between 300 kg to 7,000 kg

• Forklift loading – class A, B, C1, C2, (C3)

• Remote monitoring keeps down-time to a minimum

• Fully compliant with EU and US regulations

• Over 30,000 rack & pinion solutions installed since 1948

• Explosion protected for EU and US regulations

www.alimakhek.com

Visit us at

ONS

Stand No. B 266/12

Elevatorsfor tough environments

28-31 August 2012

Stavanger, Norway

into account. Equivalent secant stiffness, incorporating creep of the most tensioned and most slack lines for storm durations of 24 to 72 hours, are relevant to a mooring analysis and show how yarn results can be used to produce estimates of rope properties. Dynamic yarn stiffness testing involves preliminary cycling followed by the actual stiffness cycling measurement. From this, yarn creep is estimated based on changes in elongation at pre-defi ned steps for periods up to 72 hours.

Yarn stiffness Following this test, measurements were performed on DM20 and

SK78 fi bers to determine the quasi-static stiffness for wind and lee-ward mooring lines. After an initial pre-loading (10-30%YBL), wind-ward is defi ned from the delta elongation between 20%YBL (yarn breaking load) and 45%YBL over 24 hours (incorporating creep) and leeward is defi ned from the delta elongation between 20%YBL and 5%YBL over 24 hours (incorporating creep recovery).

Rope stiffness HMPE is visco-elastic and its stiffness characteristics vary with

load intensity and duration, and number of cycles. During early loading cycles, the bedding-in of the rope results in some initial elongation. The equivalent secant stiffness and dynamic stiffness of DM20 in a rope construction was measured on the 52 mm diameter Gama98 rope construction subrope produced by Lankhorst Ropes, and compared with data derived on a full size MODU rope made from SK78

Rope realization factorAlthough tested at same temperatures, the equivalent secant stiff-

ness values of the yarn, experiments based on the yarn break load are lower than the values derived from the rope experiment. When stiffness data is to be determined on a yarn, the test load should be comparable to the application load on the rope. This means that to compare fi ber and rope stiffness data on a relative load basis, the fi ber/rope break strength conversion factor, or realization factor, must be taken into account.

In summary, the fi ber and rope stiffness measurements have il-lustrated that:

• Secant stiffness of DM20 is higher than SK78 when measured on fi ber or rope level

• Dynamic stiffness of DM20 is in line with SK78 at rope level• Preferably stiffness values are to be determined on (sub)rope

levelAs creep is a function of temperature, secant stiffness is a function

of temperature as well.

Yarn-on-yarn abrasionThe American Bureau of Shipping specifi es that HMPE fi ber should

pass the minimum requirement of the yarn-on-yarn abrasion test, ac-cording to CI-1503 (19). At the Tension Technology Internal test lab (Arbroath, UK), the DM20 fi ber was tested at 1%-5% BL and compared to SK75 fi ber test results from 2009. It was determined that DM20 will pass the minimum requirements and no signifi cant difference was de-tected between DM20 and SK75 fi ber and indicated that a comparable tension fatigue can be expected.

Further workIn addition to additional creep characterization of the DM20 fi ber

for more accurate creep model predictions, laboratory testing in a wide variety of fi ber and rope tests including fatigue testing will con-tinue to reinforce confi dence on the suitability of this new HMPE fi ber type for the intended markets. �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________

http://www.alimakhek.com







Innovation, teamwork key to safeand cost-effective decommissioning

Decommissioning projects across theglobe are on the rise despite the highoil price and drive to extract more re-serves from existing fields. Douglas-Westwood and Deloitte predicted in

the North Sea Decommissioning MarketReport, released in November 2011, that thecost of North Sea decommissioning couldexceed £47.5 billion ($72.7 billion) over thenext 40 years.

While operators in the UKCS now achievehighly respectable asset recycling rates ofup to 97%, the potential environmental andcost benefits of reusing plant, equipment,or entire facilities, rather that defaulting toscrap, means a number of major operatorsin the UKCS have committed funds to inves-tigate this further.

When the decision is taken to cease produc-tion and decommission an asset, it is essentialthat, in the effort to reduce costs, projects arecarried out safely, efficiently, and competently.An installation may have been producing for30 years with the same core workforce oper-ating on it since hook-up and commissioning.For these individuals in particular, and the restof the offshore team, it is important to realizethat it is not “business as usual.”

An important difference from “steadystate” producing operations to the decom-missioning process is that the physical op-erating environment is constantly changing.Dropped objects, such as detached cabletrays, may also pose a serious risk, sincecorrosion can increase as the heat supplydrops with cessation of production.

A platform’s risk profile changes whenthe production of hydrocarbons has ceasedand the installation moves into the engineer-ing down and cleaning, and module processand utility separation phases. The move fromhydrocarbon production to an active reduc-tion in the hydrocarbon inventory changesthe working practices and other specialistservice providers, such as waste handlingspecialists and heavy-lift contractors, becomeinvolved in the project.

Clarifying the work scopes, developing themethodology, working practices and quanti-fying the resources required to progress theproject will help ensure it is delivered in a safeand efficient manner. The detailed plans devel-oped as a result of this process will allow thework to be scheduled to maximize resource

utilization, optimize activity, and improve logis-tics. Integrated project plans with multi-skilledteams is one way to improve efficiency whilereducing the numbers of personnel offshore;for example, mobilizing multi-disciplined tech-nicians that utilize rope access solutions.

With separation, lifting, and removal tak-ing place in various areas across the installa-tion, safety escape routes may not be avail-able as they were during the operationalphase and it is not uncommon for them tochange on a daily basis. Work will also be un-dertaken in modules that have been partlydecommissioned and work may be requiredto enhance the working environment forsafe operations, such as walkway enhance-ment work scopes. As walkways and escaperoutes can regularly change when modulesare removed, repainting yellow walkwaylines is a visual reminder for those on boardof where it is safe to walk on any given day.

The introduction of many new personnelwho are unfamiliar with the installation canoften be perceived as a potential risk by the ex-isting platform team. However, personnel that

are new to the installation can offer a differentperspective and see potential hazards that mayhave not been immediately obvious to the in-cumbent platform team. Feedback from newpersonnel should be actively encouraged toensure the points highlighted are acted upon.

Stork’s decommissioning philosophy andoperations center around its REACH HSEQinitiative. REACH was originally developedby RBG, the company acquired by Stork in2011, where it had a major impact on HSEQperformance, evidenced by over 70% reduc-tion in UK lost time incident frequency, andover 60% globally, from 2009 to 2011.

REACH is now at the heart of the com-pany’s decommissioning activity and is acrucial focus for all project planning, train-ing, and operations, from competency evalu-ations to in-depth inductions and preparingwork packs. By placing safety unequivocallyas the number one priority, employees un-derstand the importance of achieving thehighest safety standards and everybody go-ing home safely at the end of their trip.

Decommissioning innovationDeveloping and deploying innovative tech-

nology also plays a major role in delivering de-commissioning projects cost-effectively and tothe highest HSEQ standards. Stork is involved

John McQueenieBas Pauwels

Stork Technical Services

Deploying multi-skilled teams can reduce the number of personnel required onboard an installation.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________






qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________

http://www.oceanicmc.com





qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________________________





http://www.nov.com/fps



in a major North Sea decommissioning project and recently saved its cli-ent almost £5 million ($7.7 million) on an upcoming fabric maintenance work scope through the use of innovative inspection and coatings tech-nologies.

Stork inherited a number of substantial drill derrick painting work scopes after winning the contract, but as the asset will be fully decommissioned by 2015, the company’s project delivery team chal-lenged the requirement to deliver these as agreed.

A comprehensive close visual inspection reduced the quantity of sur-face area to be treated from 4,365 sq m (46,984 sq ft) to 2,553.43 sq m (27,484 sq ft), a saving of 42%. In addition, the introduction of a wax oil preservative coating to treat the drill derrick realized further sav-ings of 1,725 man-hours. The wax oil will allow the coating works to be completed in around 14 days compared with six weeks for conventional paint treatment. The reduction in time means it can also be delivered during a planned pause in drilling operations rather than an unplanned shutdown, which can cost up to £100,000 ($154,679) per day.

Internal leg inspection presents another opportunity for safety inno-vation on the project. Two of the asset’s legs are used for drilling and have a high number of conductors running through them. The conduc-tors have to be removed as part of the decommissioning project, but prior to this is the requirement to survey and quantify the work that is involved. Rather than put an operative into this hazardous environment, Stork will use a pan/tilt/rotate camera system, with additional lighting, to determine the related work scopes.

Platform reuse The reuse and relocation of production facilities is not new to the

oil and gas industry, with around 20-30% of platforms removed from the Gulf of Mexico being reused. With many assets that are relative-ly small, light, and operating in often benign conditions (apart from the hurricane season), it is easy to see how a regional reuse industry has developed. While this activity is still in its infancy in the UKCS, last year saw the topside of a Southern North Sea platform being refurbished and redeployed for a new development in North Africa.

Compared with the current recycle and scrapping decommis-sioning process, relocating and reusing has the potential to deliver signifi cant environmental benefi ts. During recycling, platforms gen-erate a signifi cant carbon footprint as vast amounts of energy are expended to melt the steel. While only 2%-3% of the asset is being disposed in a landfi ll, this can equate to hundreds of tons of waste. It is estimated that between 8 and 20 tons of carbon emissions is saved from every ton of steel that is reused.

Cost is also a crucial issue and with potential savings varying from around a few hundred thousand pounds for smaller platforms to poten-tially tens of millions for large installations, the reuse of an asset could be the deciding factor that makes a small, marginal fi eld economical.

However reusing a platform is not without its issues and ensuring the asset is safe to operate is the absolute priority. Full and compre-hensive checks on NORM (naturally occurring radioactive material) waste and asbestos are vital as the new platform owner takes these on as a liability. Fatigue is also a crucial issue and with aging plat-forms it could take some time to gain the appropriate safety certifi -cation and ensure an asset is safe to operate.

Onshore relocation The impact and delivery of relocating an asset must also be con-

sidered. Stork has more than 20 years experience relocating entire onshore production facilities on a global basis and the company’s skills, expertise, and experience can be transferred to the offshore industry. In 2009-10, the company managed and delivered the entire relocation of OCI Nitrogen’s nitric acid plant.

An in-depth feasibility study was carried out and engineering prepa-ration planned out the entire project, with particular emphasis placed

on a safe, effi cient, and cost-effective service delivery. The plant was dismantled at Ijmuiden, the Netherlands, and transported to the new site at Geleen, the Netherlands, where it was successfully re-commis-sioned. More than 9,100 m tons (10,031 tons) of freight, including 60-m-long (196.8-ft) steel columns, was transported throughout the project.

While widespread reuse of North Sea production facilities may be some years away, a potential area for signifi cant growth in the short-term is the reuse of major deck equipment such as gas compressor machinery, generators, and valves. There is anecdotal evidence that equipment such as this, which can cost millions of pounds, is often removed from a platform with no identifying documentation and ends up at waste facilities for scrapping.

Working with operators, it is possible to identify and protect plant and equipment that may have resale value, which could reduce the fi nal cost of decommissioning. While a platform’s plans may identify the majority of material that can be reused, a full inventory should be created to take into account plant and equipment that may have been installed or removed, but not fully documented, as part of brownfi eld modifi cations.

Assessing the state of the identifi ed materials while operational is crucial, and once a decision has been taken that it can be reused, so-lutions should be developed to protect the equipment in late life op-erations ahead of cessation of production. For its part, Stork can cer-tify that the equipment meets the necessary regulatory and industry standards and ensure it will operate to the highest safety standards.

ConclusionAs the North Sea’s aging infrastructure nears the end of its de-

sign life, the requirement for expert decommissioning services has never been greater and will increase signifi cantly over the coming decades. While the majority of these original assets are likely and rightly to be consigned to scrap, reusing the major equipment, such as deck machinery and turbines, is a possibility given the preva-lence of new marginal developments that need to minimize costs to make the fi elds profi table.

Regions such as the Gulf of Mexico have already adopted the reloca-tion and reuse of entire assets; however, to introduce it widely in the UKCS would require collaboration throughout the supply chain and a change in mindset from “default to scrap.” It is clear that the industry must move to reduce its energy footprint, improve its environmental performance, and help reduce the overall costs of the decommission-ing program over the next 20 to 30 years. The relocation and reuse of smaller, satellite assets should be seriously considered to deliver this. �

Industrial relocations are a complex process, from feasibility studies to transport and re-commissioning.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________

_______

________

___________________

____





http://www.modec.com

http://www.sofec.com

http://www.xenongroupdesign.com



http://www.excelmarco.com

http://www.solarturbines.com

http://www.keppelshipyard.com

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________

_________

____

_____

___





http://www.eagle.org

http://www.sbmoffshore.com

http://www.kbr.com

http://www.topsidesevent.com

http://www.fgspipe.com

http://www.doris-engineering.com



Buoyant Tower offers new platformfor shallow-water field development

Lower fabrication and installation costs make concept attractive

BPZ Energy has selected the Buoy-ant Tower design by Horton WisonDeepwater to develop the Corvinafield offshore Peru. The design con-cept was selected because it is less

expensive than the fixed platform alterna-tive, and the fabrication and installationschedules were attractive. The fabricationcontract was awarded in the fall of 2011, and the tower and topside are scheduled to beinstalled in 3Q 2012. The tower and topsideare presently being fabricated in Nantong,China.

The Buoyant Tower falls in the categoryof a compliant structure. A compliant struc-ture is allowed to move in response to envi-ronmental forces. Many offshore structuressuch as the guyed tower, compliant piledtower, spar, and TLP are compliant struc-tures.

The Buoyant Tower is basically a cell sparthat rests on the seafloor. The main body ofthe tower consists of four cylindrical tubescalled “cells.” The cellular approach is scal-able, and designs for other locations and applications have been made with seven, nine, and 12 cells. In effect, the HWD Buoy-ant Tower design team has taken deepwatertechnology and applied it to shallow water.

The tower supports both drilling and production. In the BPZ case, oil and gas areexported to an FPSO. A tender vessel willassist in drilling. The buoyant tower conceptcan be designed to support full drilling andprocessing, depending on the client’s needs.For the BPZ design, the wells are supportedby conductor pipes that are self-standingon the seafloor, and supported laterally byguides on the side of the tower. Top ten-sioned risers are also possible and may bethe preferred option in the deeper end of thedesign’s water depth range.

Tower fabricationIn some offshore arenas, the Buoyant

Tower is cost-effective for developing shal-low-water fields because both the fabricationand installation costs are reduced. The fab-rication cost is reduced because of the sim-plicity of the cellular components of the hull. The cell fabrication of the BPZ tower was

completed in about three months by pres-sure vessel shops in the Nantong area. Thecellular construction proceeded rapidly inpart because many of the welds (about 80%)can be done with machines (sub arc andtrack welders). The cell segments then weretransported to the assembly site where out-fitting, stacking, and assembly is proceedingand expected to take another three months.

Tower installationThe fabricated tower and the topsides will

be loaded on a heavy-lift vessel for transportto Peru. Near shore, the heavy-lift vessel willsubmerge to allow the tower to float off. Thetopside is supported on a truss system thatwill keep it above the water during tower

float off. Once the tower is floating in thehorizontal position, it will be towed to nearthe final installation site where it will be up-ended using proven procedures. Magnetitefixed ballast material will then be pumpedinto the bottom end of each cell to furtherstabilize the tower and increase its draft.

The truss system on the heavy lift-vesselsupporting the topside extends over the sideof the vessel. The floating hull will then bepulled into the gap in the extended trusssystem and secured lateral to the vessel.The topside will be skidded outboard of theheavy-lift vessel and positioned over the tow-er. The tower will be deballasted, causing itto rise and mate with the topside. Furtherdeballasting will lift the topside clear of the supporting truss system. The tower with itstopside will then be towed to the installa-tion site and set on bottom by deballasting.Mooring lines are not required to keep thetower on station, so the entire installationproceeds rapidly.

The Buoyant Tower is held in position bya suction can foundation (SCF) located atthe bottom end of the main cells. During in-stallation, this can is forced into the seafloor.The necessary forces can be generated byballasting some of the tanks in the tower andallowing the tower weight to push the caninto the soil. An additional suction embed-ment force can be generated by loweringthe water pressure inside the SCF. Once theSCF fully penetrates and the inside is fi lledwith soil, the vertical bearing capacity in-creases substantially. The downward load onthe SCF is then reduced for the long term.

The SCF has three main functions:• To provide lateral support to the tower

and ensure it stays in position• To provide vertical support with mini-

mal long-term settlement• To permit the tower to rotate in re-

sponse to the environment.The tower is held upright by the buoy-

ancy of the cells, and thus the foundation is not required for tilt stability. Like a spar, thecenter of the buoyancy is above the center of weight so the structure is unconditionallystable. To be compliant with the wave forces,the tower must be able to dynamically tilt as

Lyle FinnHorton Wison Deepwater

Artist’s rendering of the Horton Wison Deepwa-ter buoyant tower for BPZ Energy’s Corvina fieldoffshore Peru.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








LIKETO

STRETCHYOUR LEGS

?

Effectivedesign

Creativethinking

Reliableequipment

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


the wave pass through. The rotational restraint of the SCF is smallrelative to the moment of the wave forces.

The calculated lateral and vertical load capacities for the SCF areadequate to keep the tower on station. A detailed ABAQUS finite ele-ment model of the soil and SCF is used to confirm the load capacitycalculations. A series of model tests further confirms that the SCFwill allow the tower to tilt in response to waves and at the same timekeep the tower from excessive lateral or vertical displacement.

The wells are supported by conductor pipes that are jetted,drilled, or driven into the seafloor. These conductor pipes are sup-

ported laterally by a series of guides placed along the length of thetower. Drilling is done by a rig on the top deck of the topside, similarto fixed platform drilling. The BOP is located below the drilling rig.Because the wells are some distance from the center of the tower,there is a small amount of relative vertical displacement between thewellhead and topside as the tower tilts in response to the environ-ment. To accommodate this relative motion, a short, flexible jumperbetween the wellhead and the manifold is required.

ApplicabilityDesign studies confirm that the HWD Buoyant Tower concept

is applicable in water depths from 50 to 260 m (165 to 853 ft). Thetower motions improve with water depth and the design becomesmore efficient. However, in the upper end of the water depth rangethe costs of the tower increases to the point where floating conceptsare more efficient.

SCF model tests indicate that this foundation type is applicable inareas with milder environmental conditions. This includes the non-cyclonic event belt on both sides of the equator, and other milderenvironmental areas such as offshore Peru, Brazil, and West Africa.Studies for towers in the Mediterranean and Caspian seas show theconcept is also feasible in these areas. Extension of the design toharsher environmental areas is under study. �

“Cells” being fabricated for the Corvinafield buoyant tower production facility.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.GustoMSC.com






S U B S E A

Controlling tomorrow’sdeepwater developments

System functionality and obsolescence management are key to success

To address the future subsea develop-ment challenges of remoteness, envi-ronmental requirement, and reliabil-ity, the oil and gas industry needs toexplore new technological avenues.

For instance, all-electric control systems arebelieved to be one of the major technological steps that will help create new opportunities.

Total addresses these challenges throughstrategic technology development and quali-fication projects. A case in point is the K5Fproject which piloted the first all-electric treeand control system in the Dutch North Sea.All-electric technology paves the way formore complex subsea processing systemsand, coupled with fiber-optic (FO) commu-nications, enables ultra long tiebacks. This isfurther confirmed by the Laggan/Tormoreproject, a 157 km (98 mi) subsea to beach tie-back in the west Shetlands area of the NorthAtlantic. This project incorporates FO com-munications and potential future addition ofwet gas compression.

Total also focuses on development of sub-sea control system infrastructure. AdoptingFO open architecture control system designsas a base case on all current and future proj-ects prepares these developments for futuretechnology integration and field extensions.Proving the core technologies necessaryfor seabed-wide communication and controlinfrastructure that is neither constrained by,nor impacts the performance of the wellheadcontrol system is a significant step.

The ability to communicate to any subseadevice on an industry standard TCP/IP proto-col enables future integration of complex sub-systems such as subsea processing, gas com-pression, reservoir monitoring, etc. It also facesthe growing need to address obsolescence andadvanced system condition monitoring. Theuse of standard interfaces and communicationprotocols also allows upgrades, replacementtechnology, and extended functionality to beintroduced at a sub-system level without impacton the core control system.

The extension of surface network tech-niques to subsea systems brings many triedand tested tools to the operator such asbandwidth allocation, message prioritization,network storm protection, and diagnosticsthrough simple network management proto-col (SNMP).

Short-term benefits of a high bandwidthopen architecture also are significant. Mostimportantly we can remove the burden ofdata acquisition, validation, routing, andtransmission from the subsea productioncontrol system (PCS) processor to an intel-ligent network management device. These devices are well established on surface sys-tems and provide a level of flexibility andfunctionality unavailable subsea.

The following list highlights some of themore pertinent characteristics:

Plug and play. Open architecture reduc-es interface development and testing costs and allows new sensors to be added as they become available with limited integration requirement

Transparent connectivity. The open net-work allows surface acquisition systems tocommunicate directly with the sensor on the

seabed or downhole. This means communi-cation handshakes between the two devicesis direct rather than to the PCS processor onthe surface and subsea, providing autonomywith respect to functionality and future soft-ware upgrades; it also reduces the overallworkload on the PCS

Expandability. The open network per-mits electrical and mechanical interfacesto be pre-installed for future sensor installa-tions. This facilitates the procurement of thesubsea monitoring and control equipment without the need for upfront informationabout the final sensor requirements and in-terfaces. The ability to route serial commu-nications over the network allows sensors tobe interfaced easily after installation of thesurveillance system with the provision ofmechanical interfaces and subsea wet-mateconnectors

High bandwidth. Advanced surveillancesystems link communication with band-widths in the region of GB/sec. This high-speed link allows real-time data, includingdiagnostic data, to be acquired from existingsubsea sensors and also enables the use ofnew sensors and data rate intensive equip-

Rory MacKenzieTotal SA

Total’s future vision for long-distance subsea tiebacks.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________

http://www.omc.it





moody gardens hotel & convention center | galveston, tx | november 6-8, 2012

www.deepwateroperations.com

FOLLOW US ON

GO TO WWW.OFFSHOREOILEVENTS.COM

TO SIGN UP TODAY!

The Deepwater Operations Conference and Exhibition is celebrating its 10th anniversary this year. The event will continue the tradition of excellence in addressing operational challenges involved in developing deepwater resources. We will return to the Moody Gardens Hotel and Convention Center on November 6 – 8, 2012 in Galveston, Texas.

Challenges in deepwater production are complex and command our attention to develop solutions that are economical and long-term. The Deepwater Operations Conference and Exhibition provides a unique experience for attendees and exhibitors to share, learn and connect in a forum dedicated to addressing these challenges. We hope you will join us in Galveston.

room drop, cyber cafe continental breakfast andand golf tournament title sponsor: media sponsor: networking breakfast sponsor:

platinum sponsor: gold sponsor: delegate bag sponsor: bottled water sponsor:

speaker gift sponsor: golf tournament hole sponsors: coffee break sponsor:

owned & produced by: presented by: supported by: hosted by:

S U B S E A

ment such as subsea video, leak detection,downhole seismic, and inspection and main-tenance/repair support.

Based on these concepts, Total has up-dated its general specification for subsea pro-duction control systems. The key aspects are:• Topside control equipment is developed

from industrial PLCs and or DCS controllers• Elements integrated in ICSS network are

developed with ICSS vendor components

• Each subsea loop shall comprise of inde-pendent A and B control from SCU to SCM

• Subsea communication shall be high speedFO using an industry standard TCP/IPprotocol

• Local subsea network from SRMs is electri-cal using industry standard TCP/IP proto-cols

• Subsea power distribution is switchable atSRMs

• Third-party equipment has direct router ac-cess topside and subsea (SCM and SRM)

• Spare Ethernet connections available atSCMs and SRM

• 100% spare FO capacity available at eachmanifold.The flexibility of this architecture prepares

for future complexities when implementingmore advanced subsea systems. One exampleis that of subsea gas compression (SSGC). AnSSGC system will have to incorporate mul-tiple vendor control systems, unique conditionmonitoring sub systems, shutdown and equip-ment integrity, closed-loop control systems,and all the standard subsea systems suchas manifold valving, power distribution, andchemical management.

Another consideration with respect to lifeof field operability is obsolescence issues aswe attempt to upgrade aging infrastructure orrepair failure of aging equipment, materials,and software. In the case of the subsea controlsystem, this is particularly critical as many ofthe internal electronic components can be ob-solete by the supplying manufacturer withinonly a few years. This means a strong empha-sis on modularity, ease of modification, andreparability must be prioritized during design.

Operational experiences with Total’s as-sets highlight this issue. For some years

This graph illustrates one reason that obsolescence management needs to be considered whendesigning subsea control systems.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_______________

http://www.deepwateroperations.com

http://WWW.OFFSHOREOILEVENTS.COM





WWW.BIGLIFTSHIPPING.COM | [email protected]

KEY INHEAVYLIFT

First class technology and engineering |

Modern fleet | Innovative cargo handling

MEET US AT ONS STAVANGER - STAND 996

S U B S E A

this issue has been magnified in West Africa due to the remotenessfrom main manufacturing centers for subsea control systems. This,coupled with a growing concern about our ability to efficiently main-tain subsea equipment throughout the life of field, is the subject ofnumerous studies within Total over the past few years. Componentobsolescence is intrinsic to all commercial products.

Component life cycles are subjects of many factors: market lifecycles, component production costs and volumes, the technologiesused, and the number of competitors. The main causes of obsoles-cence typically are:• Technology advances, this makes innovation cycles shorter: new

technologies replace older ones which in turn become obsolete• The original manufacturer goes out of business or the original

supplier decides to stop manufacture• The product is no longer viable to produce.

Our industry has no influence over any of these factors and must,therefore, accept component obsolescence as a fact of life. Ratherthan looking for a cure we must instead learn to manage it. By learn-ing from other industries such as defense, nuclear and the aeronauti-cal industry, and tapping into already mature processes from theseindustries Total has produced a general specification that requires aproactive obsolescence management system to be in place for all oursubsea suppliers.

The IEC 62402 standard has been used as the baseline for the

Total general specification on obsolescence management. The spec-ification defines minimum requirements in terms of design, com-ponent monitoring, and creating adequate reporting systems backto Total to permit proactive action. A basic aim of the proactive ob-solescence management system is to extend choice in terms of theobsolescence solutions away from costly redesign.

The remaining issue is industry acceptance. Other operators alsoare developing processes to manage this issue. It is important thatsuppliers do not end up with widely different requirements from itscustomers. A number of initiatives are starting to appear on a joint-industry basis and this is strongly encouraged. It is our hope thatover the next few years an industry standard obsolescence manage-ment endorsed by all operators system can be developed.

The focus on efficient project management and successful applica-tion of innovative technology has never been greater. With more than80% of its producing subsea wells in deepwater, Total has had to em-brace novel installation techniques, push existing technology to newboundaries, and pioneer advanced development methodology. Thehigh success rate of these developments is not by chance, it is built onexperience, highly developed processes, and vigorous qualificationprograms. It is in this vane that Total strives to optimize its technologyreadiness for future subsea challenges. The open architecture controlsystem infrastructure together with effective obsolescence manage-ment will contribute significantly toward this aim. �

The focus on efficient project management and successfulapplication of innovative technology has never been greater.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________

http://WWW.BIGLIFTSHIPPING.COM






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

New automation concept promisesto enhance deepwater pipeline integrity

DNV engineers have developed the X-Stream concept to improve the viabil-ity of gas transport pipelines in deepand ultra-deep water a long distancefrom shore. Currently, the cost of

pipes strong enough to withstand the pres-sure differential between internal gas pres-sure and external hydrostatic pressure indeepwater, and the logistics associated withtheir installation, can make such pipelinesuneconomical. Using X-Stream to control in-ternal pressure, thinner pipe can be used, al-leviating these challenges without compro-mising safety or the integrity of the pipeline.

In 2009, Petrobras posed the question to Dr.Henrik O. Madsen, DNV’s CEO: three hun-dred kilometers (186 mi) from shore, in water3,000 m (9,842 ft) deep, how can associatedgas be economically piped to shore so it can besold rather than just re-injected? This was notjust a theoretical question. A solution could en-able commercialization of the gas associatedwith Brazil’s presalt oil fields.

“The challenge is to avoid pipeline collapseover hundreds or even thousands of kilome-ters as a result of loss of internal pressurethrough a leak or rupture of the pipe duringoperation,” said DNV Project Manager FlavioDiniz.

Madsen was enthusiastic about the chal-lenge. “As the deepwater gas transportationmarket will experience massive investmentsand considerable growth in the years tocome, new safe and cost efficient solutionsare needed,” he said.

DNV has a history of involvement in deep-water projects, including the proposed Oman-

to-India pipeline; as well as Bluestream, Per-dido, and Ormen Lange.

“We have been instrumental in develop-ing and upgrading the safety and integrityregime and standards for offshore pipelinesfor decades, and today more than 65% of theworld’s offshore pipelines are designed andinstalled to DNV’s offshore pipeline stan-dard,” said Madsen.

In Rio de Janeiro, DNV has a strong techni-cal team that focuses on riser/pipe engineer-ing and risk management. So, Madsen es-tablished a team of mostly young engineers,backed by the global expertise of DNV, andset them to work on the question. The solu-tion was to only involve proven technology.Petrobras engineers were enthusiastic part-ners throughout the project.

The breakthrough came with the realiza-tion that the concept behind existing high in-tegrity pressure protection systems (HIPPS)could be used to protect against not just highpressures but low pressures as well. HIPPSis a type of safety instrumented system (SIS)designed to prevent over-pressurization of aplant, such as a chemical plant, oil refinery,or pipelines. It will shut off the source of thehigh pressure before the design pressure ofthe system is exceeded, thus preventing lossof containment through rupture (explosion)of a line or vessel. Therefore, a HIPPS is con-sidered as a barrier between a high-pressureand a low-pressure section of an installation.

Currently there are about 20 subsea HIPPSaround the world. They are used when theflowlines are designed with a lower pressurethan the full well shut-in pressure, to avoidoverpressure of the flowline. The idea is thatif it is acceptable to use a HIPPS to avoid over-pressure of a pipeline, it should be equally safeand acceptable to use a HIPPS system to avoida low-pressure scenario. The inversion of thistechnology laid the foundation for DNV’s X-Stream deepwater piping solution.

It is the need to prevent the pipe from im-ploding that currently dictates pipe wall thick-ness. In ultra-deepwater, the wall pipe needs tobe extremely thick, and thus can only be manu-factured by a limited number of pipe mills. Thethick pipes are also heavy to transport andhandle; slow to weld and difficult to install;and require extremely thick and costly bucklearrestors. Currently, the number of suitable in-stallation vessels is also limited.

Floating gas facilities are being developed asan alternative. However, floating gas facilitiesare in many cases not yet field-proven, and areunlikely to be viable for the relatively low gasvolumes associated with some oil fields.

X-Stream introduces a new method to dealwith the high external hydrostatic pressures ofdeepwater without relying purely on materialthickness to ensure the integrity of the pipeline.

“Fundamental to the solution is the need toprotect thinner pipe from collapse during in-stallation, in case of accidental damage and inemergency shutdown scenarios,” explainedAsle Venås, DNV Pipeline Segment Director.“The idea of an inverted HIPPS system, i-HIPPS, which isolates the deepwater section

Wendy LaursenSpecial Correspondent

The dividing line between safe and collapse critical depth indicates the boundary below which the external pressure can compromise the pipeline.(green = safe area, red = collapse critical area)

X-Stream’s inverted high integrity pressure protection system (i-HIPPS) isdesigned to isolate the deepwater section of a pipeline if internal pressuredrops to a critical level.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








Off shore Webcasts Help You Reach Your Target Audience.

WEBCASTSC S S

Unmatched as quality lead generators for sponsors, Off shore deliversfull contact information for potential buyers who have signed up tohear your message.

Ongoing sponsor benefits

• Sponsors are highlighted on pre and post promotional materials• Anyone wishing to view the webcast must provide contact

information to register• Webcasts continue to register potential clients for up to one year

after the initial release date• Offshore webcasts position sponsors as leaders in their specific

industry arenas

Visit the Off shore Webcast Archives:

December 16, 2011 — “Top 5” Offshore Projects of the Year

Sponsor: FMC, LLOG and Hempel — Leads: 716

February 24, 2011 — Meeting the Challenges of Arctic Development

Sponsor: ION Geophysical — Leads: 591

February 16, 2011 — Advancements in Synthetic Rope Technology

for Dynamic Bending Applications

Sponsor: DSM Dyneema, Samson — Leads: 286

January 11, 2011 — Emergency Response

Sponsor: ASSI, Boots & Coots, Cudd Well Control — Leads: 591

December 7, 2010 — “Top 5” Offshore Projects of the Year

Sponsor: FMC — Leads: 837

October 28, 2010 — Tesco Casing Drilling Webcast

Sponsor: Tesco Corp — Leads: 916

October 5, 2010 — Drilling With Power: The Importance of Power

Generation in the Offshore Sector

Sponsor: Caterpillar — Leads: 381

September 23, 2010 — Gulf of Mexico Decommissioning Market

Outlook

Sponsor: Boots & Coots, Halliburton — Leads: 755

March 31, 2010 — Selection of Deepwater Floaters for Field

Development

Sponsor: KBR — Leads: 1,019

February 25, 2010 — Recent Innovations in Mooring Technology

Sponsor: Intermoor — Leads: 512

Contact your representative for sponsorship opportunities today:

Mitch Duffy 713.963.6286 [email protected] Davis 713.963.6206 [email protected] Sumner 713.963.6274 [email protected]

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







Use reprints to maximize your marketing initiatives and strengthen your brand’s value.CUSTOM REPRINTS

REPRINTS ARE IDEAL FOR:

■ New Product Announcements ■ Sales Aid For Your Field Force

■ PR Materials & Media Kits ■ Direct Mail Enclosures

■ Customer & Prospect Communications/Presentations

■ Trade Shows/Promotional Events ■ Conferences & Speaking Engagements

■ Recruitment & Training Packages

For additional information, please contact Rhonda Brown at

Foster Printing Service, the official reprint provider for Offshore.

Call Rhonda at 866.879.9144 ext. 194

or [email protected]


of a pipeline when internal pressure drops toa critical level, will fulfil this role, enablingpipe walls to be significantly reduced com-pared with traditional pipelines.”

However, risk analysis showed one un-likely but potentially serious danger remain-ing – that of an internal leak in the i-HIPPSsystem itself. If this happened, it would meanthe pressure drop could not be arrested.

To cover the situation of an i-HIPPS leak,another inversion of existing technology wasbrought to the system. This time, rather thandouble block and bleed (DBB) valves beingused to relieve high pressure situations, theywould be used to prevent pressures droppingto critical levels. An i-DBB provides backup forthe containment of the pressure drop by intro-ducing a gel into the enclosure between thei-HIPPS valves in shallow waters. X-Stream,then, consists of a series of automated valves,pressure transducers and autonomous logiccontrollers to provide an integrated pressurecontrol system for the lifetime of the pipeline.

In a pipeline running to shore from deep-water, the main i-HIPPS system would belocated above the water line to ensure easyaccess for maintenance, inspection, and test-ing. The collapse critical point for a pipelineis the depth at which the external pressurecan compromise the whole pipeline. Below

this point, the impact of a pipeline rupture islimited by the ingress of water which holdsback the gas in the pipeline. This situation isthe same for traditional pipelines.

If, however, leakage or rupture of the pipe-line occurs above the collapse critical point, atthe rig or near the shore, major damage canresult since the water pressure is insufficientto contain the gas and therefore the pressureloss. In this case, a secondary set of i-HIPPSvalves would close on a pre-determined lowpressure signal to isolate the deepwaterpipe and ensure that pressure is maintained.

Should the i-HIPPS system leak and pressurecontinue to fall, the i-DBB system would beactivated. Further pressure drop would thenbe prevented by the gel release.

The secondary i-HIPPS system located belowthe collapse critical point would be activated tocontain the de-pressurization. Should this sec-ondary system develop an internal leak andthe internal pressure reach a critically low level,a small bleed valve in the i-DBB system wouldopen to the surrounding water so seawater couldflood the void between the i-DBB valves and haltpressure loss.

“With i-HIPPS and i-DBB combined, thesystem immediately and effectively isolatesthe deepwater pipe if the pressure starts tofall. In this way, the internal pipeline pressureis maintained above a critical, pre-determinedlevel for any length of time,” said Diniz.

DNV’s innovation, therefore, centers on in-verting the well-established HIPPS and DBBsystems to prevent too large a pressure dif-ferential in the pipeline, and X-Stream meetsthe strict requirements set for the safety andintegrity of existing subsea piping includ-ing ISO and DNV-OS-F101. It becomes costattractive when more than a kilometer ofultra-deepwater pipeline is required. This isbecause even small reductions in wall thick-ness make a huge difference in terms of

In the inverted double block and bleed (i-DBB)concept, a viscous substance with a gel consis-tency is pumped into the closure between thevalves to effectively hinder any leaks from thehigh pressure side, thus ensuring the integrityof the pipeline.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







Registered trade names:

V

Manufacturer and supplier of wire

rope- and chain accessories with

branches in The Netherlands,

Germany, France and USA, and

stock holding distributors in over

80 countries worldwide.

Van Beest B.V.

Tel : +31 184 41 33 00

Fax : +31 184 41 49 59

E-mail : [email protected]

www.vanbeest.com

Member of Van Beest International

Visit us at ONS in Stavanger, Norway! Booth #J996


steel volume, welding effort, and installationcosts. The exact reduction in wall thicknessdepends on the water depth, pipe diameter,and actual pipeline profile. Typically for gaspipeline in water depths of 2,500 m (8,202 ft),the wall thickness reduction can be around25 to 30% compared to traditional designs.

Diniz described a typical scenario for thepresalt region where a pipeline runs to shorefrom water depths of 3,000 m (9,842 ft). Threehundred kilometers (186 mi) of pipe with out-side diameter of 0.457 m (18-in.) lays in deep-water and a further 100 km (62 mi) lays inshallow water. If a minimum internal pressureof 200 bar is maintained by X-Stream, pipe wallthickness can be reduced from 25 mm to 17mm (~1 in. to 0.7 in.) – a 32% reduction. Withconcrete coating, this could be further re-duced to 15.6 mm (0.6 in.).

The result is a system that would be signifi-cantly cheaper than current pipeline technol-ogy. The production costs decrease as less steelis required in the construction of the pipe. Thereduced wall thickness also means that manu-facture using higher grade steel is possible.Installation costs are slashed by the reducedwelding times, and the new system also re-sults in increased lay rates without the need forbuckle arrestors in some cases. Alternatively,the system could mean a larger diameter pipe

can be achieved for the same wall thickness.In either case, X-Stream reduces the con-

sequences of accidents during installation.The pipe is installed fully or partially floodedwith water to prevent collapse. Cleaning andgauging of the pipeline is performed and thenit is dewatered and dried for operation. A mini-mum pressure is maintained in the pipelineduring pre-commissioning using producedgas, separated from the water in the pipe by aset of separation pigs and gel. This technologyis not new and is already standard practice forseveral oil companies, but X-Stream providesan additional safety mechanism during deep-water installation operations.

To date, the X-Stream innovation projecthas been limited to a concept study, and moredetailed design will need to be carried out be-fore it is realized on an actual project. DNV isnot patenting the concept but intends to workwith industry partners to refine the concept,and then act as certification body to approvethe detailed design.

“At DNV, we feel confident that huge fi-nancial savings can be made for long-distancedeepwater gas pipelines without compromis-ing pipeline safety and integrity,” explainedMadsen.

X-Stream is not a one-off concept limited toBrazil’s presalt fields. It is timely to take it to

the next stage of development now, he says.New offshore oil and gas fields are being de-veloped in deeper and deeper waters, and ex-port solutions for the gas are critical.

“The technology could be taken around theworld,” said Madsen. “For instance, it is just asrelevant to the pipeline planned between Alge-ria and Italy for the GALSI project; the SouthStream project in the Black Sea; and the SAGEproject linking India and the Middle East.”

Madsen introduced the X-Stream conceptin London this past January, and it has beenpositively received by offshore companiessuch as Petrobras, British Gas, OdebrechtOil and Gas, Saipem, Technip, Subsea 7, andHeerema, among others. For Celso Raposo,Steering Committee Member of the proj-ect and head of pipeline services for DNVin South America, the project, coming at atime when Brazil is investing $1 billion/yr inresearch and development, is an example ofthe country’s growing capacity for success-ful industry partnerships and technical in-novation. He says: “DNV has been a pioneerin pipeline technology and we already workclosely with Petrobras providing certificationand verification services. The success of thisproject demonstrates DNV’s ability for lateralthinking when it comes to solving practical,real-life problems for the industry.” �

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.vanbeest.com







Global offshore pipeline construction survey

Max. ContractorLength Pipe dia. Type of water Project and/or In-service

Company (miles) (in.) Location of project service depth (ft) status eng. firm target

UNITED STATESAmberjack Pipeline Co. 136 24 Jack/St. Malo hub, Walker Ridge Export, oil 6,890 Planned Wood Group (E) 2014

blk 718 to Shell Boxer “A” platform,Green Canyon blk 19

Enterprise/Genesis Energy 149 18 Lucius-truss spar Gathering, crude 7,000 Planned 2014to South Marsh Island 205, GoM

Williams/DCP Midstream 215 20 Keathley Canyon, Walker Ridge, and Gathering, gas Planned 2014Green Canyon areas, central GoM

Total Miles 500

EUROPEBP (Shah Deniz) 310 Shah Deniz field, Caspian Sea Transmission, gas 1,800 Planned 2017

DONG E&P 15 12 Hejre field, offshore Denmark Export, gas 226 Await start Saipem (C ) 2014

DONG E&P 56 10 Hejre field, offshore Denmark Export, oil 226 Await start Saipem (C ) 2014

Galsi SpA 170 22 to 48 Olbia, Sardinia, to Piombino, Italy Transmission, gas Planned 2014via Mediterranean Sea

IGI Poseidon SA 135 42 Ionian Sea Transmission, gas Under Study

Lukoil 78 22 Vladimir Filanovsky field, Trunkline, oil Await start Saipem (C) 2015Caspian Sea, to shore

Lukoil 83 28 Vladimir Filanovsky field, Transmission, gas Await start Saipem (C) 2015Caspian Sea, to shore

Trans Adriatic Pipeline AG 65 36 Greece to Albania and Italy Transmission, gas 2,657 Planned 2017via Adriatic Sea

Operators planning some 5,800 miof offshore pipelines through 2017

Operators and developers are study-ing, planning, and building morethan 5,800 mi of oil and gas pipelinesto bring these supplies from offshorefields to onshore markets.

Europe is the clear leader in offshore pipe-line projects, with more than 2,500 mi of sys-tems being built and planned. The largestproject being planned offshore Europe is theproposed South Stream pipeline. It would moveRussian gas through the Black Sea to Bulgariathrough a 560-mi, 32-in. pipeline to be installedin waters down to more than 7,300 ft. Gazpromand Eni, the developers of South Stream proj-ect, announced earlier this year that they willmake a final investment decision in Novemberand start construction in December.

The Middle East is the next most activeregion, with nearly 1,100 mi of oil and gaspipelines being built and planned. The mostnotable project in this region – and a big con-tributor to the region’s total – is the proposedSouth Asia Gas Enterprise (SAGE) pipelineproject, which proposes to move natural gasfrom the Oman Middle East Compression Sta-tion (MECS) to Gujarat, India, by building 807mi of 24 to 27-in. pipe through the Arabian Sea,

in waters down to 11,100 ft. The project is cur-rently under study, and project developers arelooking at a 2017 in-service date.

The South Pacific is another active regionfor offshore pipeline activity, with Chevron’sGorgon and Wheatstone projects both havingassociated pipeline systems as part of the de-velopment projects. Work is currently under-way on the 43-mi, 20-in. Gorgon gas trunkline,with installation contractor Clough working tocomplete the line before the end of the year.The biggest offshore pipeline project in thisregion is associated with the Ichthys projectoffshore Western Australia. It calls for 552 miof 42-in. pipe to move gas from an offshore pro-cessing facility to Darwin, Australia. An instal-lation contract has been awarded to Saipem,who will work toward a 2014 completion date.

In the Gulf of Mexico, Williams and DCPMidstream Partners are pushing forward withplans to extend the Discovery natural gas gath-ering pipeline system. The Keathley Canyon

Connector involves the construction of a 215-mi,20-in. pipeline. It will gather production fromthe Keathley Canyon, Walker Ridge, and GreenCanyon areas in the central deepwater Gulf.Construction is expected to begin next year, andwork toward a mid-2014 in-service date.

Also in the Gulf, Enterprise Products Part-ners and Genesis Energy are developing plansfor a new crude oil gathering pipeline servingthe Lucius development area. The 149-mi,18-in. SEKCO oil pipeline is would connectthe Lucius truss spar floating production plat-form to an existing junction platform at SouthMarsh Island 205. There, it would connectto the Enterprise-operated Poseidon pipelinesystem. The SEKCO oil pipeline is expected tobegin service by mid-2014.

Offshore South America, Petrobras is alsomoving forward with plans to move gas fromthe Guara and Lula Northeast FPSOs in itsLula field to other systems that will take thegas to onshore markets.

The inaugural Global Offshore Pipeline Con-struction Survey – a detailed project-by-projectlisting of all the major, large-diameter off-shore oil and gas pipeline systems being built,planned and studied – makes its debut below.�

Bruce BeaubouefManaging Editor

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








With a combination of the most experienced and capable people in the industry, a modern fleet

of DP offshore installation and subsea construction vessels and a long track record of successfully

executing complex projects around the world, EMAS AMC is well positioned to efficiently meet

your offshore construction needs at every stage of your project.

Right People. Right Solutions. Right Now.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









Global offshore pipeline construction survey

Max. ContractorLength Pipe dia. Type of water Project and/or In-service

Company (miles) (in.) Location of project service depth (ft) status eng. firm target

South Stream AG 560 32 Russia to Europe via Black Sea Transmission, gas 7,381 Planned 2015

Statoil 298 36 Aasta Hansten field, Norwegian Sea, Transmission, gas 4,265 Under Study 2016

White Stream 780 20, 24, 42 Georgia to Ukraine and Romania Transmission, gas Under Study 2016Pipeline Co. Ltd. via Black Sea

Xcite Energy 1.3 Rowan Norway production jackup Export, oil Await start Ocean Installer (C) 2012to shuttle tanker, Bentley field, North Sea

Xcite Energy 1.3 Rowan Norway production jackup Export, oil Await start Ocean Installer (C) 2012to shuttle tanker, Bentley field, North Sea

Total Miles 2,553

MIDDLE EAST KGOC 29 12 Al Khafji Joint Operations complex Export, gas Technip (C) 2014

to Kuwait Oil Co. tie-in, offshore Kuwait

POGC 180 32 Salman offshore field, Persian Gulf, Sour gas Working IOEC (E&C) 2012to onshore plant at Assaluyeh, Iran

POGC 68 South Pars field, Persian Gulf Sour gas Working Sadra Co. (C) 2012

South Asia Gas 807 24 to 27 Oman MECS to Gujarat, India, Transmission, gas 11,100 Under study 2017Enterprise Pvt. Ltd. (SAGE) via Arabian Sea

Total Miles 1,084

AFRICAGalsi SpA 354 22 to 48 Two lines from Koudiet Draouche, Transmission, gas Planned 2014

Algeria, to Porto Botte, Sardinia

Total Miles 354

SOUTH PACIFICChevron 140 44 Wheatstone processing platform to Transmission, gas 229 INTECSEA (E) 2016

LNG plant, Ashburton North,Western Australia

Chevron 43 20 Barrow Island, offshore Australia, Transmission, gas Working Clough (C) 2014to Dampier

INPEX 552 42 Offshore processing facility to Darwin Transmission, gas 902 Planned Saipem (C) 2014

Total Miles 735

FAR EASTCNOOC 162 30 Liwan gas platform to Gaolan Export oil/gas 230 Await start Offshore Oil 2012

gas plant, South China Sea two-phase Engineering Co.Ltd. (E), Technip (C)

Husky Oil China 100 Dual 22 Infield pipelines, Liwan 3-1 field, Export oil/gas 4,921 Await start Saipem (EPCI) 2013South China Sea two-phase

Total Miles 262

MEXICOPemex 48 36 Coastal Connecting Platform Working Dragados Offshore/ 2012

to onshore terminal, Dos Bocas Swiber (C)

Pemex 11 16 GoM Working Technip (C) 2012

Pemex 11 24 GoM Export, gas Working Technip (C) 2012

Total Miles 70

SOUTH AMERICA Petrobras 236 24 Gathering manifold, Lula field, to Export, gas 7,218 Await start Saipem (EPCI) 2014

onshore processing plant, Macae district

Petrobras 33.6 18 Guara FPSO to subsea gathering Export, gas 7,218 Await start Saipem (EPCI) 2014manifold, Lula field

Petrobras 13.7 18 Lula Northeast FPSO to subsea Export, gas 6,890 Await start Saipem (EPCI) 2014gathering manifold, Lula field

Total Miles 283.3

GRAND TOTAL 5,840.40

Project status term definitions:

• Under study – project is currently undergoing feasibility, economic, technical or other preliminary studies

• Planned – project developers are currently in the process of obtaining required permits and regulatory approvals

• Await start – project has needed permits and approvals and is waiting on construction season or contractor availability

• Working – project is currently in the construction and installation phase

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








moody gardens hotel & convention center | galveston, tx | november 6-8, 2012

www.deepwateroperations.com

The Deepwater Operations Conference and Exhibition is celebrating its 10th anniversary this year. The event will continue the tradition of excellence in addressing operational challenges involved in developing deepwater resources. We will return to the Moody Gardens Hotel and Convention Center on November 6 – 8, 2012 in Galveston, Texas.

Challenges in deepwater production are complex and command our attention to develop solutions that are economical and long-term. The Deepwater Operations Conference and Exhibition provides a unique experience for attendees and exhibitors to share, learn and connect in a forum dedicated to addressing these challenges. We hope you will join us in Galveston.

FOLLOW US ON

GO TO WWW.OFFSHOREOILEVENTS.COM

TO SIGN UP TODAY!

email registration room drop, cyber cafe continental breakfast supportingconfi rmation sponsor: and golf tournament title sponsor: sponsor: media sponsor: organization:

platinum sponsor: gold sponsor: silver sponsor: delegate bag sponsor:

bottled water sponsor: speaker gift sponsor: golf tournament hole sponsors: coffee break sponsor:

owned & produced by: presented by: supported by: hosted by:

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_______________________

http://www.deepwateroperations.com

http://WWW.OFFSHOREOILEVENTS.COM





Owned & Produced By: Presented By: Supported By: Hosted By:

27 –29 November 2012

Perth Convention Exhibition Centre | Perth, Australia

For more than 30 years Deep Offshore Technology (DOT) International has been showcasing pioneeringtechnology that has been shaping the future of the deep and ultra-deepwater industry. DOT puts you at theheart of the leading industry forum which attracts key industry experts and decision makers from the major

exploration and production companies. Don’t miss your opportunity to be a part of this once-a-year event.

Quick Stats from Deep Offshore Technology International 201125 Operating Companies in Attendance including Shell, Chevron, BP, ExxonMobil, TOTAL, Anadarko,Hess, Woodside, Petrobras, and more 95% of attendees said DOT met or exceeded their expectations 73% of conference attendees rated the quality of the conference content as good or excellent67% of attendees said that attending DOT is important or very important in meeting their

business objectives

*Source: Deep Offshore Technology International 2011 independent survey

Visit www.deepoffshoretechnology.com to Register Today!

developingTechnologies

for frontier regionss

www.deepoffshoretechnology.com

Reg

ister

Befo

re26 O

ctober

2012

and

SAVE $

100!

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM









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

www.offshorewestafrica.com

EMERGINGOPPORTUNITIES

Presented by:Owned & Produced by: Supporting Publication: Follow Offshore Events on:

DEEPWATER DISCOVERIES

EXHIBITOR PROSPECTUS

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.offshorewestafrica.com





ABOUT OFFSHORE WEST AFRICA

Offshore West Africa, the region’s premier technical forum focused exclusively on West Africa’s offshore oil

and gas industry will return to Accra, Ghana in 2013.

Providing an exclusive source of information for over 16 years, Offshore West Africa 2013 will showcase

the most innovative technologies and ground-breaking solutions within the deepwater exploration

and production industry. Combining both a high-quality conference and rich exhibition of services and

equipment, Offshore West Africa offers a unique insight into this exciting and progressive marketplace.

Including Offshore West Africa as a key component of your company’s marketing strategy ensures one-

on-one access to key industry professionals from around the world. Ghana is one of the most promising

exploration regions within West Africa. The recent discoveries and emerging strength of oil and gas

�G��X��!��Z��$��*/;+��J�

Deepwater Discoveries, Emerging Opportunities - and demonstrates the reasons why we will be returning

to Accra in 2013.

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.

WHO SHOULD EXHIBIT?

[�� "��=��'��

[�� #��\K��]�"��

[�� "��^��3��\K��

[�� :��]�_��

[�� &��]�Z��_��

[�� =��]�'��

[�� &��]�_��

[�� ]�`��"��

[�� #��]�:��

[�� &��$K��

[�� "��]�=��

[�� `��'��"��

[�� _��"��

[�� `��_��

[�� >��]��

[�� '��\K��]�"��

86% OF OFFSHORE WEST AFRICA 2012 EXHIBITORS IMPROVED PROSPECTSWITHIN THE REGION

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







EXHIBITING PACKAGE

Cost to Exhibit:Exhibition space is $650 per s/m raw.

Exhibition space is $755 per s/m with shell scheme.

For the latest Offshore West Africa 2013 Floor Plan please visit www.offshorewestafrica.com

DirectEventConnect

In addition to the exhibit space above, a compulsory basic enhanced listing on the Exhibition website’s

��&��\��_�� }*97�//��=��

searchable community will give your buyers access to your information and provide an opportunity for you

to communicate with potential customers before the Exhibition.

:��\��\G��>��&��\��_��

SPONSORSHIP OPPORTUNITIES

#��!��Z��$��*/;+��"��

��

Whether your company is well established in the region or seeking new business opportunities, we can

tailor a unique sponsorship package that meets with your event objectives. Contact us to discuss your

sponsorship requirements.

Examples of sponsorship available:

[� !��"��"�� [� &��^��"��

[� !��"�� [� 3��^��"��

[� ��"�� [� =��"��

[� _��^��"�� [� _��'��!��

[� &��"�� [� !��"��

[� ��]�^��"�� [� "��$��X��"��

'��!��Z��$��"��=!=$��#!&\_��$^"��

\GG��#��`#_�=��!��"��'��^��_��^��?��#&��

and ConocoPhillips.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








CONTACTS

Exhibit and Sponsorship Sales4\��$��]�#��\��8

Tony B. Moyo'��4/8�;55*�<7<�<76

`�G��4/8�;55*�<7<�9//


Exhibit and Sponsorship Sales4$��'��8

Michael Yee'��<7�5<;<�6/6/


Exhibit and Sponsorship Sales4��8

Dele Olaoye'��*+��6/*�**+�*6<�


Exhibit and Sponsorship Sales4=��$��8

Desiree Reyes'��;�9;+�5<+�<*6+

`�G��;�9;+�5<+�<*;*


WHY EXHIBIT AT OFFSHORE WEST AFRICA?

Offshore West Africa is a unique annual forum for the industry, with both a world class conference combined

with the exhibition showcasing the latest technological developments. This unique event attracts senior

decision makers, enabling you to make crucial contacts within the industry.

[� :��

[�� :��

[��

[�� =��

[�� #��

[�� "��

[�� X��

of high level decision makers

Please send me information about:

� Exhibiting at Offshore West Africa 2013

� Sponsorship Opportunities at Offshore West Africa 2014

��Making a presentation at Offshore West Africa 2013

� Advertise in Flagship Media Sponsor: Offshore / Oil & Gas Journal

� Attending Offshore West Africa 2013

� Booking a Corporate Plan for Attending Offshore West Africa 2013 conference (if sending more than 5 people)

Please Indicate

I would prefer to be contacted by:

��Email �� Fax �� Telephone �� Mail

��

Title:

Company:

Address:

City:

Post Code:

Country:

Tel:

Fax:

Email:

FAXBACK ON: +44 (0) 1992 656 700

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_____________________






ANYWHERE

SIGN UP FOR YOUR FREEDIGITAL SUBSCRIPTION TODAY!

Since 1954, Offshore Magazine has lead the industrywith exceptional editorial, reporting on offshore opera-tions, technology, trends and events worldwide.

If you are actively involved in the offshore industry you may qualify to receive a free subscription and join tens of thousands of other offshore professionals around the world that rely on Offshore magazine every month.

With a free digital magazine subscription, and freetopic focused eNewsletters, you will have ready accessto authoritative reporting and expert analysis of eventsand developments affecting the offshore oil and gas industry . . . anywhere . . . anytime.

ANYTIME

Subsea

Production

Drilling & Completion

Construction & Installation

Transportation & Logistics

Geology & Geophysics

Go to: www.offshore-mag.com

for information on print, digital,

and eNewsletter subscriptions.

Free Offshore eNewletters

Offshore Weekly Report

Offshore Asia

Offshore West Africa

Offshore Geosciences

Offshore Drilling Technology

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








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


PeopleSTATS Group has appoint-

ed Angus Bowie as regional director for the Middle East North Africa.

Ensco plc has promoted James W. Swent III to executive vice president.

IHS has appointed Dr. Daniel Yergin as vice chair-man.

Ron Huff has joined Buccaneer Resources as CFO.

Jiang Li Jun has resigned as vice chairman and non-executive director of COSCO Corp.

Anadarko Petroleum Corp. has promoted Doug Lawler to senior vice president, interna-tional and deepwater operations, and will join the executive committee.

Broad Cairn Group has appointed Tony Robertson as general manager of CairnToul Tubular Services, Bill Walking-shaw as general manager of QTEC International, and Allan Pritt as general manager of CairnToul Well Equipment Services.

The reorganized National Ocean Industries Association staff includes Randall Luthi,president; Faith Burns, executive assistant to the president; Franki Stuntz, senior vice president for administration and membership; Ann Chapman, vice president for confer-ences and special events; Luke Johnson, vice president for policy and government affairs; Jeff Vorberger, vice president for intergov-ernmental and political affairs; Nicolette Nye,vice president for communications and exter-nal relations; and Robert Myers, director of public affairs.

Independent Oil and Gas Ltd. has named Mehdi Varzi as non-executive chairman.

Subsea 7 has appointed Ricardo Rosa as CFO.

Knowledge Reservoir has appointed Dr. Sheldon Gorell as vice president of technol-ogy.

Quickfl ange has appointed Pål Falch as sales manager for the North Sea, Thomas Karlsen as sales engineer for Norway, Roy Nedrebo as fi eld technician, and Kristin Benjaminsen as administration and opera-tions coordinator.

Reservoir Group has appointed Simon Howes to lead Interica, the company’s data management business.

Gazprom has elected Viktor Zubkov as chairman of the board of directors, and Alexey Miller as deputy chairman.

Edward A. Beaumont has assumed the

presidency of the American Association of Petroleum Geologists.

MAN Diesel & Turbo has appointed ArndLöttgen as chief manufacturing offi cer.

OGX has appointed Luiz Eduardo Gui-marães Carneiro as CEO.

Tideland Signal Ltd. has appointed James West as sales manager for Europe, North Africa, and East Asia.

Mermaid Maritime has appointed Chal-ermchai Mahagitsiri as executive vice chairman.

Michel Moreno has resigned as chair-man and CEO of Dynamic Energy Services International. Emile Dumesnil will become president and CEO.

William S. Chadwick, Jr. has retired as executive vice president and COO of Ensco plc. He is succeeded by Mark Burns.

Murphy Oil Corp. has appointed Steve Cossé as president and CEO. He suc-ceeds David Wood, who has retired after a 17-year career at the company. Murphy’s board of directors also named RogerJenkins to the newly-created position of COO.

Deloitte has appointed Moray Barber,Shaun Reynolds, and Chris Hunter as directors.

AGR has appointed Bill Fletcher as vice president of well management for UK and West Africa.

U.S. Steel has named Eric K. Schomer as general manager- procurement.

Forest Oil has appointed Patrick R. Mc-Donald as interim CEO.

Nina Udnes Tronstad has stepped down as executive vice president for Kvaerner’s Jackets business and president of Kvaerner Verdal A/S. Senior VP Sverre Myklebust will serve in both positions until a successor is recruited.

Prospectiuni SA has ap-pointed Eric Williams as vice president West Africa, and Rahul Gupta as vice president Asia.

Andy Jones has returned to Xodus Group as operations director of the new offi ce in Perth, Australia.

USON has appointed Dave Foran as president, and Gene Grilli as global sales director.

Rocksource ASA has ap-pointed Christopher Spen-cer as permanent CEO.

Ashtead Technology has appointed Graham Philip as group deputy chairman. He will be primarily responsible for the instruments division. In

the offshore division, the company has ap-pointed Allan Pirie as CEO, and Mark Derryas COO.

Altor Risk Group has named Matthew Wardner as director of services, Paul Swinnas team leader for Australia and Southeast Asia, Dominic Webb as business unit leader for the Middle East Africa and Central Asia region, Rona Young as European business unit leader, and Brian Davis will provide line management to the teams across the Middle East, Africa and Central Asia region.

Rocksource ASA has appointed Christo-pher Spencer as CEO.

The corporate assembly of Statoil has re-elected Olaug Svarva as chair and Idar Kreutzer as deputy chair of the corporate assembly. Svein Rennemo, Grace Reksten Skaugen, Roy Franklin, Bjørn Tore Godal,Lady Barbara Judge, and Jakob Stausholmwere re-elected as members of the board of directors. Rennemo was re-elected as chair of the board of directors. Marit Arnstad has resigned as deputy chair and member of the board.

Willbros Group Inc. has appointed Michael Lee as senior vice president of com-mercial services in its oil and gas segment.

Coretrax Technology Ltd. has appointed Scott Laingas business development manager.

GDF Suez E&P UK has appointed Oonagh Wer-ngren as business manager (external affairs and supply chain) within its leadership team.

Emerson Process Man-agement has named Bret Shanahan president of its Roxar business unit.

Devin International has named Harold Touchet as operations manager.

Reservoir Group has named Doug Kinsella as managing director of the new Corpro brand.

Company newsHB Rentals has completed the construc-

tion of a new 22,000-sq ft (2,044-sq m) facility in Aberdeen, Scotland.

CNR International has contracted Cosalt Offshore for lifting and mechanical handling support services on fi ve platforms in the UK northern North Sea.

Crowley Maritime Corp.’s vessels have received 67 Jones F. Devlin Awards for out-standing safety records from the Chamber of Shipping of America.

Bowie

Howes

Jones

Werngren

Foran

Shanahan

Touchet

Robertson, Pritt, Walkingshaw

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








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


Hempel USA has acquired Blome International as part of its strategic goal to quadruple the protective coatings business.

Wintershall has opened a new global drill core warehouse in Barnstorf, Germany.

Hyde Marine has named Scanunit Ab as the exclusive sales agent in Sweden for Hyde GUARDIAN ballast water treatment systems.

Raytheon Anschütz has established Raytheon Anschuetz do Brasil Sistemas Marítimos Ltda. to expand its sales and service activities in South America.

Fairfi eld Energy has agreed terms for new injection of equity from funds sponsored by Riverstone Holdings LLC. Initially, Riverstone will make a $150-million equity commitment with the option of subscribing a further $200 million.

Hallin Marine has signed a long-term strategic alliance agreement with Romona Inc. for projects throughout the Russian Federation.

Stork Technical Services has secured a three-year contract from CNR Internationalfor integrated caisson integrity management services across the company’s UK continental shelf assets. Stork also has opened an in-house fabric maintenance training center at its facil-ity in Aberdeen, UK.

Oil States Industries Inc. has entered into a defi nitive asset purchase agreement to acquire Piper Valve Systems Ltd.

MacDermid Offshore Solutions has started construction of the MacDermid Off-shore Fluidos do Brasil manufacturing plant in Cambe, Parana, Brazil.

Allied Training Services has partnered with Maersk Training Aberdeen to provide working at height and rigging and lifting train-ing courses to Maersk’s customers.

EnerMech plans to open its fi rst offi ce in Mumbai, India, and a workshop and storage facility in Kakindada, Andrah Pradesh region.

J. Lauritzen A/S and HitecVision have formed a 50/50 joint venture to focus on ordering high-end semisubmersible ASVs ca-pable of serving customers in the North Sea.

Clarus Technologies has named Ameri-can Pollution Control Corp. the offi cial Gulf Coast distributor of the Oil-CAT and Oil-CAT II fuel blending systems. AMPOL also has added the Tornado Tank Cleaning System to its service range.

Wood Group PSN has introduced a project delivery arm to its business. The move is de-signed to enhance WGPSN’s ability to secure and deliver large-scale North Sea projects.

InterMoor has launched MoorVision, a software system that provides clear, up-to-date photos of the infrastructure in any defi ned area in the Gulf of Mexico using Google Earth.

Siemens has acquired the connectors and measurement division of Expro Group.

Glacier Energy Services has acquired Site Machining Services Ltd.

Aker Solutions is making a $100-million in-vestment to expand its production, assembly, and testing capacity in Brazil to support the country’s rig-building plans.

Bureau Veritas has acquired TH Hill,which provides oil and gas drilling failure prevention and analysis.

Tendeka plans to move its headquarters to Abercrombie Court, Arnhall Business Park, Westhill. The company will retain its current premises in Peterseat Drive, Altens, Aberdeen, and convert them into high-end research and development, testing, and as-sembly facilities.

Weatherford has acquired Petrowell Ltd.Thrane & Thrane has expanded its work-

boat and fi shing vessel VHF radio portfolio with the launch of the new SAILOR 6217 VHF DSC Class D AIS Receiver.

Coretrax Technology Ltd. has expanded its range of services and products with the launch of its wellbore chemical division.

Penspen has announced plans to open a new offi ce in Mexico City.

Liquid Robotics Inc. and Schlumbergerhave jointly created Liquid Robotics Oil & Gas to supply wave-powered AUVs to the oil and gas market. The venture aims to supply Wave Glider technology combined with Sch-lumberger’s upstream technology services.

H2O Inc. has added the Monsoon self-cleaning fi ltration system to its product line.

Expro has opened an operations base in Paradise, Newfoundland.

Polar Star Consultants has been ap-pointed oilfi eld marketing services provider for VeruTEK Technologies.

Apax Partners and JMI Equity have agreed to acquire Paradigm Ltd. for $1 bil-lion in cash.

Rosneft and ExxonMobil have agreed to establish a joint Arctic Research Center for Offshore Developments.

Cairn Energy subsidiary Capricorn has

made an agreed offer for London-based inde-pendent Nautical Petroleum. The proposed share transaction values Nautical at around £414 million ($644 million).

Subsea 7 has won the Tremendous Train-ing and Development Award at this year’s Cherries ceremony in recognition of its inno-vative Engineering Conversion Program and Graduate Engineering Development Scheme.

Aker Solutions has opened a lifecycle services workshop in Songkhla, in the Gulf of Thailand.

Lukoil Engineering and Schlumbergerhave jointly opened the Center of Geologic Ex-ploration Technologies in Moscow. The center was established to prepare and integrate studies of promising assets in Lukoil’s license areas using advanced geological exploration technologies and equipment supplied by Schlumberger.

Kongsberg Oil & Gas Technologies has established a new offi ce in Perth, Australia.

TGS has acquired Arcis Seismic Solu-tions.

Variable Bore Rams has added a distribu-tion center in Yoakum, Texas.

CGGVeritas has opened a new processing and imaging center in Melbourne, Australia.

Dron & Dickson has expanded into the Middle East market with the opening of a new base in Dubai.

Falmouth Scientifi c Inc. has added Geomatrix Earth Science to its family of manufacturers representatives.

ABCO Subsea has acquired MPV Corp.ABB has won an order from Rickmers

Group to supply advisory systems for dy-namic trim optimization and fl eet management solutions for fi ve multi-purpose vessels.

Specialist Services Group has offi cially launched its hire fl eet in Aberdeen, UK.

Swire Oilfi eld Services has opened two new facilities in the Macaé region of Rio de Janeiro state, Brazil.

Reservoir Group has consolidated all its coring activities under one brand, Corpro.

JSW Steel opens mill to PennWell media

JSW Steel recently provided the editors of Offshore and Oil & Gas Journal with an informational tour of its pipe and plate mills in Baytown, Texas. Located 30 mi east of Hous-ton, the mill first opened in 1971 to manufacture line pipe for the Alaskan pipeline project. Today, the facility is one of only three plate mills in North America capable of rolling widths of 160 in. and thicknesses up to 6 in. The mill provides line pipe to both the onshore and offshore oil and gas market.

JSW Steel’s 650-acre complex is located in Baytown, Texas.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM








• Display Ads: $235.00 per column inch. Same discount as above. 15% agency commission. $235.00 minimum charge for inser-

tions. Page size is 3 columns wide by 10 inches deep. One Column = 2.25” wide, Two Columns = 4.75” wide, Three Columns = 7”

wide. Minimum Size: 1 Column X 1 Inch.

• Deadline for classified advertising is the 15th of the month preceding publication. Contact Glenda Harp, (918) 832-9301, orfax your ad for a quote (918) 832-9201. E-mail: [email protected]• No special position available in classified.

C L A S S I F I E D A D V E R T I S I N G

EMPLOYMENT WANTEDEMPLOYMENT

Representative for the offshore/marinebusiness of Korean shipyards

(HHI, DSME & SHI)Very long experience in Korean shipyards as a

technical sales manager.Mr. Simon Kim

E-MAIL: [email protected] phone: +82 (0)10 6560 3619

MECH DESIGN/OCEAN ENGINEER

Sound & Sea Technology has an opening inVentura CA. Position requires 3-4 years ocean

engrg or related exp, BS degree, Solid Works,

and be a quick study. Nearshore/offshore

projects. Visit www.soundandsea.com

Email [email protected]

Indepth reports on activity and spending –

• The World Offshore Drilling Spend Forecast

• The World Floating Production Market

• The World Offshore Oil & Gas Production &

Spend Forecast

•The AUV Gamechanger Report

•The World Deepwater Market Report

•The World Offshore Wind Report

•The World FLNG Market Report

• Subsea Processing Gamechanger

Offshore Oil and Gas Industry of Russia and CIS:

Outlook to 2020

Provides a detailed analysis of all current and projected

offshore projects and develops an outlook for their

development to 2020.

Surveys in Excel Spreadsheets for easy analysis –

• US Gulf of Mexico Deepwater Discoveries & Status

• Worldwide Seismic Vessel Survey

• Global Field Development Survey

• Rotary Steerable Tool Directory

• Production Projects Worldwide

• Construction Projects Worldwide

Directories that download to your desktop –

• Offshore E&P Industry Worldwide

• Pipeline Industry Worldwide

StatisticalTables in Excel (Historical)

• Offshore Crude Oil Production - Monthly

• Offshore Gross Withdrawals of Natural Gas - Annual

• GOM Federal Offshore Production - Annual

• North Sea Crude Oil Production – Monthly

• US Active Seismic Crew Counts - Monthly

918-831-9421 or [email protected]

www.ogjresearch.com

Strategic Data from PennEnergy

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.ogjresearch.com

http://www.soundandsea.com





Offshore Middle East is a conference and exhibition that not only

delivers information on offshore operations, but also provides the

opportunity meet, network, and exchange ideas and experiences

with your industry peers. This unique event offers unrivalled access

to key decision makers, management and offshore engineering

and operations professionals from within the offshore oil and

gas industries.

Register now for the Middle East’s premier offshore oil & gas

event and gain access to:

��The latest technological advances

��Innovation and inspiration

��Unrivalled networking opportunities

��The future of the offshore industry

��Business and Industry leading opinions and viewpoints

Jane Bailey

Middle East and Europe

T: +44 (0) 1992 656 651

F: +44 (0) 1992 656 700

E: [email protected]

Michael Yee

South East Asia

T: +65 9616 8080

F: +65 6734 0655


Peter Cantu

USA

T: +1 713 963 6213

F: +1 713 963 6212


For further information on exhibiting and sponsorship opportunities please contact:

OWNED AND PRODUCED BY: PRESENTED BY: SUPPORTED BY: SUPPORTING PUBLICATIONS:

ORGANIZED BY:

HOSTED BY:

INVESTING IN

OFFSHOREMATTERS

UNDER THE PATRONAGE OF

H.E. Dr. Mohammed Bin Saleh Al-Sada

Minister of Energy & Industry

State of Qatar

CONFERENCE & EXHIBITION

21 - 23 JANUARY 2013

QATAR NATIONAL CONVENTION CENTRE

DOHA, QATAR

WWW.OFFSHOREMIDDLEEAST.COM

FOR MORE INFORMATION PLEASE VISIT WWW.OFFSHOREMIDDLEEAST.COM

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



_________________________________

________________________________________

http://WWW.OFFSHOREMIDDLEEAST.COM

http://WWW.OFFSHOREMIDDLEEAST.COM





2 0 1 3 S U B S E A T I E B A C K F O R U M & E X H I B I T I O N

MARCH 5 – 7, 2013Henry B. Gonzalez Convention Center • San Antonio, Texas USA

www.SubseaTiebackForum.com

In recent years, the subsea industry has seen many technological challenges, engineering demands, resource availability issues, Quality

Assurance requirements, manufacturing constraints, and most recently, changes in the governmental regulatory agencies affecting existing

standards and/or processes. The Subsea Tieback Forum & Exhibition will provide information and the opportunity for you to exchange ideas

to address many of these concerns and challenges.

The Subsea Tieback Forum & Exhibition has become the premier event for one of the fastest growing sectors of the oil and gas industry.

Next year’s Subsea Tieback Forum & Exhibition is scheduled for March 5-7, 2013 in San Antonio, TX at the Henry B. Gonzalez Convention

Center. Visit www.subseatiebackforum.com for up-to-date information about the event. You can’t afford to miss it!

Supporting Organization Online Registration SponsorHog Heaven Title Sponsor & Show Guide Bellyband Sponsor

Thursday Luncheon Sponsor

Owned & Produced by

Presented by

Silver Sponsor Gold Sponsor Platinum Sponsor

Bottled Water Coffee Break

Supported by Hosted by

Wednesday Networking Reception

Opening Night Networking Reception

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.subseatiebackforum.com

http://www.SubseaTiebackForum.com





PENNWELL PETROLEUM GROUP1455 West Loop South, Suite 400, Houston, TX 77027

PHONE +1 713 621 9720 • FAX +1 713 963 6228David Davis (Worldwide Sales Manager)

[email protected] Duffy (Regional Sales Manager)

[email protected] Harp (Classified Sales) [email protected]

GREATER HOUSTON AREA, TXDavid Davis [email protected]

USA • CANADAMitch Duffy [email protected]

WASHINGTON • OREGON • CALIFORNIAMary Sumner [email protected]

UNITED KINGDOM • SCANDINAVIA •THE NETHERLANDS

9 Tarragon Rd.Maidstone, Kent, United Kingdom ME16 OUR

PHONE +44 1622 721222 • FAX +44 1622 721333 Roger Kingswell [email protected]

FRANCE • BELGIUM • PORTUGAL • SPAIN • SOUTH SWITZERLAND • MONACO

• NORTH AFRICAProminter

8 allée des Hérons, 78400 Chatou, France PHONE +33 (0) 1 3071 1119 • FAX +33 (0) 1 3071 1119

Daniel Bernard [email protected]

GERMANY • NORTH SWITZERLAND •AUSTRIA • EASTERN EUROPE •

RUSSIA • FORMER SOVIET UNION • BALTIC• EURASIA

Sicking Industrial Marketing, Kurt-Schumacher-Str. 16 59872 Freienohl, Germany

PHONE +49 (0) 2903 3385 70 • FAX +49 (0) 2903 3385 82 Andreas Sicking [email protected]

ITALYSILVERA MEDIAREP

Viale Monza, 24 - 20127 Milano, ItalyPHONE +39 (02) 28 46716 • FAX +39 (02) 28 93849

Ferruccio Silvera [email protected]

BRAZIL / SOUTH AMERICASmartpublishing Ltd/ OGJLA Pennwell Brazil

HEADQUARTERS: Rua Raimundo Chaves 2182, L5Natal RN 59064-390, BRAZIL

RIO OFFICE: Ave. Erasmo Braga 227, 11th fl oorRio de Janeiro RJ 20024-900, BRAZIL

PHONE +55 (21) 2533 5703 or +55 (21) 3084 5384FAX +55 (21) 2533 4593

Jean-Paul Prates [email protected]

JAPANICS Convention Design, Inc.

6F Chiyoda Bldg., 1-5-18 Sarugakucho Chiyoda-Ku, Tokyo 101-8449, Japan

PHONE +81 3 3219 3641 • FAX +81 3 3219 3628Manami Konishi [email protected]

SINGAPORE19 Tanglin Road #05-20 Tanglin Shopping Center

Singapore 247909 PHONE +65 9616 8080 • FAX +65 6734 0655

Michael Yee [email protected]

INDIAInterads Ltd., A-113, Shivalik, New Delhi 110 017 PHONE +91 11 628 3018 • FAX +91 11 622 8928

Rajan Sharma [email protected]

NIGERIA/WEST AFRICAFlat 8, 3rd fl oor (Oluwatobi House) 71 Allen Ave, Ikeja, Lagos, Nigeria

PHONE +234 805 687 2630 or +234 802 223 2864 Dele Olaoye [email protected]

SALES OFFICES

AAker Solutions ........................................23

www.akersolutions.com/subseaAlimak Hek AB ........................................93

www.alimakhek.comAllseas Group SA .....................................3

www.alleas.comASTICAN ..................................................61

www.astican.es

BBaker Hughes .........................................63

www.bakerhughes.comBigLift Shipping ....................................103

www.bigliftshipping.com

CCameron ....................................................9

www.c-a-m.comCanusa CPS ............................................81

canusa.comCORTEC Fluid Control ...........................87

www.uscortec.comCOSCO Shipyard Group ........................35

www.cosco-shipyard.com

DDelmar Systems, Inc. ..............................56

www.delmarus.comDelta Rigging & Tools ............................. 11

www.deltarigging.comDraeger ....................................................17

www.draeger.comDril-Quip ....................................................1

www.dril-quip.com

EEMAS Subsea Services, LLC ...............109

www.emas.comEmerson Process Management SRL ....51

EmersonProcess.com

FFMC Technologies ................................. C4

www.fmctechnologies.comForum Energy Technologies ..................29

www.f-e-t.comFrank Mohn Flatoy AS ............................15

www.framo.comFrontics America, Inc. .............................44

www.fronticsamerica.com

GGusto MSC ..............................................99

www.GustoMSC.comGVA Consultants AB ..............................48

www.gvac.se

HHalliburton ...............................................65

www.halliburton.comHardbanding Solutions ..........................37

www.hardbandingsolutions.comHeerema Marine Contractors .................19

www.heerema.comHornbeck Offshore Services, Inc. .........43

www.hornbeckoffshore.comHSM Steel Structures .............................16

www.hsm.nlHydratight ................................................61

www.hydratight.com

IIHC Merwede Offshore & Marine ...........60

www.ihcmerwede.comIPLOCA ....................................................66

www.iploca.comJ

JD Neuhaus .............................................13www.jdngroup.com

Jumbo Offshore VOF ..............................45www.jumbo-offshore.nl

KKarmsund Maritime Offshore Supply ...53

www.kamos.no

LLloyd’s Register North America, Inc. ....47

www.lr.org/energy

MManaged Pressure Operations .........38-39

www.managed-pressure.com

MECO. ......................................................49www.meco.com

Mokveld Valves. .......................................33www.mokveld.com

NNational Oilwell Varco. ............................25

www.nov.com/xlsystemsNational Oilwell Varco. ............................96

www.nov.com/fpsNewpark Drilling Fluids. .........................27

www.newparkdf.comNylacast. ....................................................8

www.nylacast.com

OOffshore Mediterranean Conference ...101

www.omc.itOMC Ship Management, LLC. ................95

www.oceanicmc.comORR Safety. .............................................41

www.orrsafety.com/KONG

PPennWell

Deep Offshore Technology Conference & Exhibition ........... 48, 112

www.deepoffshoretechnology.comDeepwater Operations

Conference & Exhibition ..........102, 111www.deepwateroperations.com

Offshore Group ....................... 105, 117www.offshore-mag.com

Offshore Middle East Conference & Exhibition .................121

www.offshoremiddleeast.comOffshore West Africa

Conference & Exhibition .......... 113-116www.offshorewestafrica.com

Subsea Tieback Forum & Exhibition .........................................122

www.subseatiebackforum.comTopsides, Platforms & Hulls

Conference & Exhibition .............83, 88www.TopsidesEvent.com

POLARCUS .............................................91www.polarcus.com

PWP Global .............................................31www.pwpglobal.com

RRolls-Royce Marine.................................92

www.rolls-royce.com

SSchlumberger ........................................ C2

www.slb.comShawCor ..................................................67

www.shawcor.comSiemens AG ...............................................7

www.siemens.comSound & Sea Technology, Inc. .............120

www.soundandsea.comSTX Norway Offshore AS .......................57

www.stxosv.comSubsea 7 ..................................................59

www.subsea7.com

TTD Williamson ........................................ C3

www.tdwilliamson.comTetra Technologies .................................14

www.tetratec.comTrade House TMK ....................................55

www.tmk-group.com

VVan Beest BV.........................................107

www.vanbeest.comVICINAY CADENAS .................................89

www.vicinaycadenas.com

W

Walter Stauffenberg GmbH& Co. KG ..................................................82

www.stauff.comWASCO ENERGY GROUP OFCOMPANIES ............................................52

www.wascoenergy.comWeatherford ...........................................4, 5

weatherford.comWild Well Control ....................................21

www.wildwell.comWood Group Mustang ............................85

www.mustangeng.com

The index of page numbers is provided as a service.The publisher does not assume any liability for erroror omission.

ADVERTISERS INDEX

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM







This page reflects viewpoints on the political, economic, cultural, technological, and environmental issues that shape the future of the petroleum industry. OffshoreMagazine invites you to share your thoughts. Email your Beyond the Horizon manuscript to David Paganie at [email protected].


B E Y O N D T H E H O R I Z O N

When the European Commission published its proposals to cen-tralize offshore safety and environmental regulation, its stated aimwas to create common standards across Europe. It acknowledgedthe existing “world-class” regimes of the North Sea countries andsought to use these as a template which other, less established coun-tries should raise their standards to meet.

Oil & Gas UK, the trade association for the UK offshore oil andgas industry, welcomes the European Commission’s broad intent toimprove safety by “leveling up” the rest with the best, but is stronglyopposed to the form of legislation proposed – a regulation. Why? Oil& Gas UK believes it will result in the opposite of its intended aimand actually weaken safety.

As a major hazard industry, safety comes before everything else.The UK has well established and competent regulators, with de-cades of valuable knowledge and experience. The pivotal momentfor the UK was the Piper Alpha disaster 24 years ago, which led to afundamental change in the way safety was managed offshore.

So to shift the overall regulatory control away from member statesover to Brussels, where there is no relevant experience or technicalcompetence in these matters, represents a serious and unnecessaryrisk to the safety of offshore workers. Furthermore, the proposedEU legislation would require the UK government to revoke all itsown world-class safety legislation and regulation to the extent it cov-ers the same or similar ground to the EU regulation. That would bea highly retrograde process involving significant cost and time, allto no added value. Indeed it would prejudice UK offshore safety bydiverting a significant amount of regulatory resources away fromfront-line issues and toward this wholly unconstructive labor.

An additional safety risk comes from the huge administrative bur-den that operators would face when having to replace their safetycases with new “major hazard reports,” which would then have tobe assessed and processed by regulators at a national level. Thebacklog of work for regulators would be considerable, and thereis again the risk that regulators’ attentions could be diverted awayfrom front-line work to dealing with this backlog.

Both the UK and Scottish governments and all the leading politi-cal parties in the UK are aligned in opposition to the EU Commis-sion’s proposed regulation, which is seen as confusing and counter-

productive. They agree that it would require a significant upheavalto change what is already a strong safety regime, and that therewould be no perceivable gain to safety from doing so.

The leading UK trade unions, RMT and Unite, have also come tothe same conclusion and have issued a joint statement with Oil &Gas UK that the EU Commission’s proposals would seriously erodeworkforce safety. This joint statement mirrors similar alignmentsbetween industry and unions opposed to the proposals in both Nor-way and the Netherlands – where strong opposition to the Commis-sion’s plans have also been voiced.

A crucial point around the irrelevancy of the regulation is that90% of all the oil and gas produced in Europe comes from just threemember states – the UK, the Netherlands, and Denmark. Thesecountries are, of course, the North Sea neighboring nations whichthe European Commission already regards as having world-classsafety regimes.

Norway, not an EU member but part of the European EconomicArea (EEA), has decided the proposed regulation is not within thescope of the EEA and therefore not applicable to Norwegian wa-ters. Given that offshore oil and gas activity in Norwegian waters ac-counts for approximately half of all such activity in Europe, it there-fore seems clear that the proposed regulation cannot now achieve itsstated objectives and needs to be rethought.

Oil & Gas UK has been somewhat encouraged to hear that at arecent Energy Council meeting, Commissioner Günther Oettingerindicated the potential for flexibility in the Commission’s approachto this matter. The association is ready to work with all interestedparties to construct a well-worded directive that would encouragemember states that do not currently achieve the recognized highstandards present in the North Sea, to do so in a way which blendswith established legislation. This would protect the existing strongsafety regime in the UK and other North Sea countries, minimizeinappropriate disruption to operators and regulators, and eliminatethe additional risk that the proposed regulation presents.

Malcolm WebbCEO, Oil & Gas UK

European Commission’s proposedregulation hinders safety

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



___________






Stay ahead of the Curve

with SmartPlug ® Technology from TDW.

Easy, safe launching

with bi-directional functionality.

Real-time

pressure monitoring.

State-of-the-art pressure

isolation technology for

onshore and offshore pipeline

maintenance and repair

applications.

Piggable, tetherless

and remotely controlled

with reliable accuracy.

NORTH & SOUTH AMERICA: 918-447-5500

EUROPE/AFRICA/MIDDLE EAST: 32-67-28-36-11

ASIA/PACIFIC: 65-6364-8520

OFFSHORE SERVICES: 832-448-7200

®Registered trademarks of T.D. Williamson, Inc. in the United States and other countries. / TM Trademarks of T.D. Williamson, Inc. in the United States and other countries.

To learn more about SmartPlug ®

isolation technology contact your

nearest TDW sales representative

or visit www.tdwilliamson.com.

with SmartPlug ® Technology from TDW

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



http://www.tdwilliamson.com





FMC Technologies’ subsea solutions and experience are leading the way in all-subsea arctic development. And that makes

life easier when you’re working offshore in a sea that’s ice-covered up to seven months of the year. Our total solutions

include proven subsea processing and pumping, long distance tie-backs and clean, all-electric control systems with robust

condition monitoring and flow manager systems. Don’t let the ice freeze you out of the arctic. Talk to us instead.

qqM

Mq

qM

MqM



qqM

Mq

qM

MqM



______________________

http://www.fmctechnologies.com





Documents

OS_20120801_Aug_2012.PDF