offshore201410-dl.pdf

October 2014

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

INSI

DE:

60-y

ear a

nniv

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ry

repo

rt

Australiaupdate

Deepwater technology review

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34

38

International EditionVolume 74, Number 10

October 2014

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 2014 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 (978) 750-8400, Fax (978) 646-8600 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 $112.00 per year, Canada/Mexico $ 145.00 per year, All other countries $184.00 per year (Airmail delivery: $257.00). Worldwide digital subscriptions: $112.00 per year. Single copy sales: US $11.00 per issue, Canada/Mexico $13.00 per issue, All other countries $15.00 per issue (Airmail delivery: $24.00). 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 3264, Northbrook, IL 60065-3264. To receive this magazine in digital format, go to www.offshoresubscribe.com.

Celebrating 60 Years of Trends, Tools, and Technology

AUSTRALIA UPDATE

Prelude turret sets new standards for size, capability .......... 34Shells Prelude FLNG project offshore northwestern Australia contin-

ues to push the technology boundaries with a number of frsts. The

mooring turret system for the vessel is no exception. At almost 100 m

(328 ft) in height, it is the largest in the world. This part of the system

weighs 4,300 metric tons (4,740 tons) alone. The turret construction

contract is held by Drydocks World and consists of fve parts, all to

ship from Dubai to Geoje, South Korea.

Ichthys project reaches peak construction activity ............... 38Australias Ichthys project is now offcially half way to completion. Three

mega-projects in one, the Ichthys project will involve some of the largest

offshore facilities in the industry, signifcant onshore infrastructure, and

an 889-km (552-mi) pipeline connecting the two. When complete, the

pipeline will become the ffth-longest subsea pipeline in the world.

Australian research aims to reduce pipeline, drilling costs............................................. 42Australia has invested heavily in the oil and gas industry but with

increasing capex and ever-increasing demand, the country is focus-

ing heavily on R&D to help mitigate costs while continuing to attract

foreign investment to exploit its oil and gas reserves. Australian re-

searchers have pinpointed three areas in which costs can be decreased

through innovation and new technology.

DEEPWATER UPDATE

ONS 2014 highlights next-phase deepwater drilling, subsea recovery challenges ...................................... 44Deepwater engineering contractors Aker Solutions, Baker Hughes,

GE, and GVA outlined their visions of the way forward at the recent

Offshore Northern Seas exhibition in Stavanger, Norway.

RPSEA continues technology advance with ultra-deepwater R&D projects ........................................ 50The business of advancing technology continues as the Research Part-

nership to Secure Energy for America (RPSEA) moves forward with its

transition into the role of technical coordinator under National Energy

Technology Laboratory/US Department of Energy management in 2015.

RPSEAs Ultra-Deepwater Conference recently held in Houston not only

reviewed the status of programs under way, but also took a look ahead

at how the organization might function in the future.

Collaboration takes industry to new technical highs, greater depths .............................................. 54 Since its inception in 1991, DeepStar has served as an incubator for

collaborative development of technologies that enhance deepwater ex-

ploration, drilling, and production. DeepStars approach to technical col-

laboration has delivered advances across the deepwater E&P spectrum,

from reservoir appraisal, ultra-deepwater drilling and completions, fow

assurance, subsea processing solutions to foating structures and life

extension. Some of the key research initiatives under way in its Phase

XII development are described.

1410OFF_2 2 10/1/14 3:56 PM

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Obtaining downhole data in real time allowed Petrobras to terminate the test earlier than planned

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74

82

70


October 2014

C O N T E N T S

4 Offshore October 2014 www.offshore-mag.com

Celebrating 60 Years of Trends, Tools, and Technology

60 YEARS OF OFFSHORE

Offshore at 60: The Blue Water breakthrough ........................ 58In January 1962, a strange contraption under lease to Shell Oil, called

the Blue Water 1, spudded a record-setting offshore well in 297 ft

(91 m) of water in the Gulf of Mexico. The maiden voyage of the

Blue Water 1 took place a month before NASA astronaut John Glenn

became the frst person to complete an orbit of the earth. Both mis-

sions revealed a newfound human ability to explore frontiers beyond

the comfort of terra frma. On Aug. 14, 1962, Shell Oil dramatically

disclosed the details of its new foating drilling platform.

From the archives: CDI completing frst deepwater decommissioning .......................................... 66Selected from the October 1999 issue of Offshore, this article describes

Cal Dive Inc.s journey to complete the Cooper feld, the frst deepwater

subsea decommissioning project in the Gulf of Mexico.

GEOLOGY & GEOPHYSICS

Reservoir modeling: revising uncertainty quantifcation and workfows ................................................. 70Technology to support a better reservoir understanding is available.

Operators can continuously update models everywhere in the workfow,

from seismic to simulation. A combination of powerful hardware, an

intelligent visualization-driven framework for computation and data-

management, and a model-driven software approach to interpreting and

modeling workfows can properly support reservoir modeling demands.

DRILLING & COMPLETION

Liner drilling enables operators to reach new depths ........... 74The process of liner or casing drilling, in which the wells liner or

casing string is used as part of the drillstring, can be a cost-effective

solution to address many drilling challenges. Liner/casing drilling is

an integrated services solution that can shorten drilling time and costs,

reduce non-productive time, lower the risk of drilling through trouble

zones, and help ensure that the liner reaches total depth.

MPD and closed-loop techniques solve drilling challenges off West Africa .......................................... 78A complex set of challenges offshore West Africa has defed drilling ef-

forts for more than 40 years. Multiple attempts in the areas high-pres-

sure/high-temperature and regressive pressure regimes using conven-

tional methods have been unable to construct a wellbore to total depth.

The solution came with an unusual scope of managed pressure drilling

(MPD) operations and closed loop well construction techniques.

ENGINEERING, CONSTRUCTION

& INSTALLATION

Industry shows renewed interest in foat-over installation .......................................................... 82Float-over installation has become an attractive alternative to heavy-lift

crane installation for offshore construction, as increasing size and weight

of offshore platform topsides continually exceed the lifting capacity of

cranes. Dockwise Ltd. analyzed topsides installation trends from 2005

to 2012, and found that the demand for cost-effective and more fexible

alternatives to crane installations has been the driving force behind foat-

over installation using semisubmersible heavy transport vessels.

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October 2014

SUBSEA

Subsea power grid accelerating transfer of topsides functions to seafoor............ 84Siemens is close to completing an initial test program on the four main components of a pro-

posed subsea power distribution hub. The Subsea Power Grid will be connected on the seafoor

to an array of new equipment emerging for subsea production, processing, and boosting. This

should facilitate expansion of feld development into deeper water, longer step-outs, and more

demanding production environments.

FLOWLINES & PIPELINES

Reservoir conditions, fow regimes challenge measurement accuracy .................. 86Multi-phase meters play an increasingly important role from royalty and fscal allocation to

production control, prevention of water encroachment, and the generation of real-time well data

to help diagnose and optimize well performance. Yet, as multi-phase meters continue to increase

their market penetration, more challenges arise.

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

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

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

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

Offshore Europe .................................. 18

Gulf of Mexico ..................................... 20

Subsea Systems ................................. 22

Vessels, Rigs, & Surface Systems ...... 24

Drilling & Production .......................... 26

Geosciences ........................................ 28

Offshore Automation Solutions .......... 30

Regulatory Perspectives ..................... 32

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

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

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

COVER: With much of the oil and

gas world watching developments

offshore northwest Australia, Shell

continues to pursue its Prelude FLNG

project, the frst of its kind. The hull,

shown on the cover, is in Geoje, South

Korea, at Samsung Heavy Industries

shipyard awaiting arrival of the largest

non-disconnectable internal mooring

turret ever built. The mooring system is

just one of several technologies being

adapted for use on the largest foating

facility ever built. These design hurdles

range from shrinking the footprint of

an equivalent onshore LNG process-

ing plant by 75% to dealing with liquid

natural gas sloshing in partially flled

tanks. Shell expects Prelude to be the

frst of many FLNG installations to

come. (Photo courtesy Shell)

1410OFF_6 6 10/1/14 3:56 PM

1410OFF_7 7 10/1/14 3:56 PM

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CONTRIBUTING EDITORS Dick Ghiselin (Houston)

Doug Gray (Rio de Janeiro) Nick Terdre (London)

Gurdip Singh (Singapore)Wendy Laursen (Australia)

MANAGING EDITORBruce A. Beaubouef

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TECHNOLOGY EDITOR,SUBSEA & SEISMIC

Gene [email protected]

EDITOR-EUROPE Jeremy Beckman

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SENIOR TECHNOLOGY EDITOR/ DOMESTIC CONFERENCES

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[email protected]


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

technology, companies, personnel moves, and products.

Offshore commemorates 60 yearsFirst published in 1954 by Texas native Long John Latham in a small town

north of Houston, Offshore magazine has evolved into an industry leading global must-read for world trends and technology. Scroll through featured an-niversary articles and the interactive timeline to experience the changes in the offshore oil and gas industry over the past 60 years.

http://www.offshore-mag.com/offshore60.html

New videos Interviews of offshore

oil and gas industry pioneersOffshore magazine is pleased to provide video interviews of offshore oil and

gas pioneers. These industry pacesetters offer their thoughts on their early days in the industry, and discuss how the relevant technologies and applica-tions have evolved over time. They also speak to the challenges and issues that the industry faces today.

These interviews, completed in 2013, were undertaken as part of Offshores partnership with the Offshore Energy Center and the George Bush Presiden-tial Library and Museum at Texas A&M University, and its exhibit Offshore Drilling: The Promise of Discovery, which runs through January 2015. Video production provided by Frame by Frame, College Station, Texas.

http://www.offshore-mag.com/index/celebrate60/interview-videos.html

New on demand webcast Improving the Design of Subsea Riser Systems

Experts from Intel, Cray, and Altair discuss a high-performance computing solution proven to improve speed and performance in designing subsea drill-ing risers. Attendees will learn performance benchmarks and recommended confgurations for a solution that increases riser design accuracy, extends component life, reduces uncertainty, and improves the overall safety of ultra-deepwater systems.http://www.offshore-mag.com/webcasts/offshore/2014/10/improv-

ing-the-design-of-subsea-riser-systems.html

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

www.offshore-mag.com

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

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

Available at

Offshore-mag.com

1410OFF_8 8 10/1/14 3:57 PM

1410OFF_9 9 10/1/14 3:57 PM

To respond to articles in Offshore, or to offer articles for publication,

contact the editor by email ([email protected]).10 Offshore October 2014 www.offshore-mag.com

COMMENT David Paganie Houston

Historic initiative paved way

for deepwater, industry collaborationRecent reports indicate that deepwater and ultra-deepwater capex will continue their

upward trend. Infeld Systems predicts it will grow 8% from now to 2018. Developments offshore Brazil, myriad FLNG/FPSO projects underway and in planning, and new deep-water regions joining the trend all contribute. They also expand the defnition of deep-water and ultra-deepwater.

But what, exactly, is deepwater? What are the defning water-depth parameters? What are the technological limitations? The answers depend on who you ask, and when. In the early 1960s, Shell launched a technology development program to extend the water-depth limitation of drilling and production to 600 ft. That was considered deepwater back then. The program was top-secret to give Shell a competitive advantage for deepwater leases in an upcoming bid round. To Shells chagrin, it was the only bidder on a handful of deepwater tracts, which, as a result, were defaulted back to the government. The operator concluded that there had to be competition both to enable Shell to acquire the deepwater acreage and to stimulate the commercialization of the technology. It would need to share its knowledge with the industry. Thus, in 1963, Shell held an unprecedented three-week educational pro-gram on offshore technology for representatives from industry and government.

Most importantly, they (Shell) established a new learning curve, redefning what was possible at the time, helping other companies in the industry see the potential of offshore, and fostering a new spirit of technological cooperation, writes Tyler Priest, associate professor and author of The Offshore Imperative: Shell Oils Search for Petroleum in Postwar America. As part of our ongoing coverage of Offshores 60-year anniversary, Priest shares an excerpt of this compelling story beginning on page 58.

Regardless of defnition, a lot of attention is being directed toward deepwater. ONS 2014 stressed the next phase of deepwater drilling and subsea recovery. See Jeremy Beckmans review of the conference starting on page 44.

Australian technologyShell, today, continues to push the boundaries of technology development. A good ex-

ample is the Shell-operated Prelude FLNG project for installation offshore Australia. It boasts a number of industry frsts, including its mooring turret. Upon completion, it will be the largest of its kind in the world. Gene Kliewer, Offshore Technology Editor, Subsea & Seismic, interviewed Shell senior management for a review of the projects key design parameters, and the outlook for similar projects. Kliewers report begins on page 34.

Elsewhere in Australia, the Ichthys project is now offcially half way to completion. Three mega-projects in one, Ichthys will involve some of the largest offshore facilities in the in-dustry, signifcant onshore infrastructure, and an 889-km (552-mi) pipeline connecting the two. When complete, the pipeline will become the ffth-longest subsea pipeline in the world.

Offshore contributing editor Wendy Laursen shares a detailed review of the project scope, challenges, design strategy, and construction progress to-date. Laursens report begins on page 38.

Subsea power gridSiemens is close to completing an initial test program on the four main components (sub-

sea transformer, subsea MV Switchgear, subsea variable speed drive, and subsea power control & communication system) of a proposed subsea power distribution hub. The Subsea Power Grid will be connected on the seafoor to the array of new equipment emerging for subsea production, processing and boosting. This should facilitate expansion of feld devel-opment into deeper water, longer step-outs, and more demanding production environments, suggests Jeremy Beckman, Offshore Editor, Europe. The development, testing and qualifca-tion program is supported by Chevron, ExxonMobil, Petrobras and Statoil. The technolo-gies they and other operators are looking to transfer to the seabed include gas compression, water injection, multiphase booster pumps, and subsea separation.

Beckmans full report on the subsea power grids design, components, and qualifca-tion status begins on page 84.

1410OFF_10 10 10/1/14 3:57 PM

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Worldwide offshore rig count & utilization rate

July 2012 August 2014

1,000

900

800

700

600

500

100

90

80

70

60

50

No

. o

f ri

gs

Fle

et u

tilizatio

n ra

te %

July

12

Oct

12

Jan

13

April

13

July

13

Oct

13

Jan

14

April

14

July

14

Contracted fleet utilization Total fleet Contracted Working

So

urc

e: IH

S

Operator capex share (%) in Australia 2009-2018

100

90

80

70

60

50

40

30

20

10

0

Chevron

Woodside

Inpex

Shell

Apache

ExxonMobil

GDF Suez

PTTEP

ConocoPhillips

BHP Billiton

Others

2009

Source: Infield Systems

2010 2011 2012 2013 2014 2015 2016 2017 2018

Op

era

tor

cap

ex s

hare

(%

)

Worldwide day rates

Year/Month Minimum Average Maximum

Drillship

2013 Sept $151,000 $460,989 $681,000

2013 Oct $151,000 $465,759 $681,000

2013 Nov $151,000 $472,587 $681,000

2013 Dec $151,000 $477,497 $681,000

2014 Jan $151,000 $480,353 $681,000

2014 Feb $151,000 $486,160 $681,000

2014 Mar $151,000 $487,145 $735,000

2014 Apr $151,000 $497,479 $735,000

2014 May $151,000 $500,733 $735,000

2014 June $151,000 $502,751 $735,000

2014 July $151,000 $502,771 $735,000

2014 Aug $151,000 $506,750 $735,000

Jackup

2013 Sept $30,000 $125,384 $365,000

2013 Oct $30,000 $126,303 $365,000

2013 Nov $30,000 $127,986 $365,000

2013 Dec $30,000 $127,469 $365,000

2014 Jan $30,000 $129,462 $365,000

2014 Feb $30,000 $131,160 $365,000

2014 Mar $30,000 $130,610 $365,000

2014 Apr $30,000 $131,247 $365,000

2014 May $30,000 $131,924 $365,000

2014 June $30,000 $133,665 $377,000

2014 July $30,000 $136,846 $377,000

2014 Aug $30,000 $136,624 $377,000

Semi

2013 Sept $145,000 $386,554 $656,662

2013 Oct $145,000 $382,295 $656,662

2013 Nov $145,000 $395,521 $656,662

2013 Dec $145,000 $394,529 $656,662

2014 Jan $145,000 $394,603 $656,662

2014 Feb $145,000 $393,032 $656,662

2014 Mar $145,000 $387,284 $656,662

2014 Apr $145,000 $391,396 $656,662

2014 May $145,000 $393,873 $656,662

2014 June $145,000 $395,812 $656,662

2014 July $145,000 $396,901 $656,662

2014 Aug $145,000 $397,563 $656,662

Source: Rigzone.com


G L O B A L D ATA

This month Infield Systems looks at offshore capex

distribution in Australia up to 2018.

Australia will continue to attract significant offshore

investment, with key operators Woodside, Chevron,

Inpex, and Shell projected to account for a combined

60% of the countrys capex. Woodside-operated develop-

ments are expected to require the highest levels of

offshore expenditure, with the Browse resources which

will require the use of three FLNG FPSOs projected

to account for almost 39% of the companys Australian

offshore investment over the timeframe. Chevron will

continue to invest in the Greater Gorgon Area, while its

Wheatstone project is anticipated to be the most capital

intensive field development that the IOC will develop

over the 2014-2018 period. Inpexs Ichthys field, which

requires an FPSO and semisubmersible platform, is

anticipated to require the largest offshore investment in

Australia over the next five years. While Shells Prelude

FLNG project is likely to account for almost 70% of the operators Australian offshore capex to 2018, with

the FLNG FPSO anticipated to be installed toward the end of the timeframe.

The floating platforms market in Australia is projected to see significant levels of investment to 2018,

supported by the growth of FLNG upon which Australia is anticipated to capitalize in order to exploit

remote offshore gas reserves as well as the development of other various floating developments such

as the Ichthys, Equus, and Laverda projects. Likewise the pipelines market is also projected to require sig-

nificant investment during the timeframe, driven by a number of subsea developments which are required

where deeper waters prevent the use of fixed platforms and thus require the use of subsea production

equipment, and long export pipelines including the Ichthys and Poseidon export lines. With increased

levels of offshore activity in Australia the demand for subsea infrastructure, and thus expenditure demand,

will undoubtedly increase over the next five years.

George Griffiths, Senior Energy Researcher, Infield Systems

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1410OFF_13 13 10/1/14 3:57 PM


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

Analysts forecast steady deepwater growthBrazil will account for 32% of deep and

ultra-deepwater capex worldwide between now and 2018, according to a report from In-feld Systems. Overall, the market is set for 8% capital growth over this period, the au-thors add. Other contributory factors will be an increase in FLNG/FPSO projects across Southeast Asia, Australasia and the Middle East, and deepwater gas pipeline projects in Europe such as Polarled in the Norwegian Sea and South Stream in the Black Sea.Infeld also foresees steep increases in

deepwater activity outside the established Atlantic triangle area, including projects such as the Krishna Godavari UD and Dhi-rubhai developments off eastern India and the giant Rotan offshore Malaysia, where the PFLNG-2 facility is due to be installed in 2018. Infeld expects a total of 81 operators to contribute to deep and ultra-deepwater capex over the period compared with 55 during 2009-2013, with independents such as Anadarko and Noble Energy among the highest spenders.

North/Central AmericaShell has resubmitted a draft plan to the

US Department of the Interior concerning exploration drilling in the Chukchi Sea. Ac-cording to the New York Times, the company plans to use two rigs for a campaign in 2015 or 2016. Shell holds interests in three pros-pects spanning fve offshore blocks.

Statoil and state-owned entity Petronic are looking to collaborate on joint oil and gas ac-tivities offshore Nicaraguas Pacifc coast. They have submitted a request to the coun-trys Ministry of Energy and Mines to ne-gotiate concession contracts in the region, where Petronic has authorized Geoex Inter-national to acquire 32,000 sq km (12,355 sq mi) of 3D seismic.

South America/ Caribbean SeaBP has awarded Technip an EPIC contract

for the Juniper project offshore southeast Trinidad. Technips Houston center will man-age the program which includes construc-tion of a 10,400-ton (9,434-metric ton) plat-form, designed to process 590 MMcf/d (17 MMcm/d) of gas, and engineer and install a 10-km (6.2-mi) 26-in. rigid pipeline and asso-ciated fexible fowlines, umbilicals, and other subsea structures. Offshore work is expected to start during the second half of 2016.

Petrobras has confrmed an extension of a gas and light oil discovery in the Moita basin area of the Sergipe-Alagoas basin off-shore Brazil. Moita Bonita 3, the second well

in the BM-EAL-10 concession, was drilled 82 km (52 mi) from the Sergipe coast in 2,790 m (9,153 ft) of water. It encountered 40-m (131-ft) thick reservoirs with good perme-ability and porosity.In the presalt Santos basin, the company

has submitted a declaration of commercial-ity for three felds Sul de Guar, Nordeste de Tupi, and Florim which it proposes to rename Sul de Sapinho, Sepia, and Itapu. Combined reserves are 1.214 Bboe. Produc-tion from Sepia and Itapu should start in 2018 and 2020, respectively. Concept evalu-ation continues for Sul de Guar.Wood Group Kenny (WGK) is working

on conceptual engineering for Petrobras presalt Lapa (ex-Carioca) feld, 170 m (273 km) off the south coast of Rio de Janeiro. WGK is examining two alternative pipeline heating systems, water or electrically trace heated. Either would be a frst in a presalt

environment. The results will help deter-mine options for a southwest area tieback on the feld.

KCA Deutag subsidiary RDS is performing a drilling front-end engineering and design study for main contractor AMEC for the Sea Lion development in the offshore North Falk-land basin. This covers the drilling rig mod-ules for the proposed TLP, to be installed 200 km (124 mi) north of the Falkland Islands.

West AfricaNigerias Department of Petroleum Re-

sources has sanctioned development of the Afren-operated Aje oil feld. The frst-phase will involve tieback of two subsea production wells to a leased FPSO, with start-up likely in late 2015.

Mediterranean SeaADX Energy has been awarded an explo-

ration permit in the Sicily Channel offshore southwest Italy, on trend with the companys Kerkouane permit in adjoining Tunisian wa-ters. The 363 C.R.AX concession includes the abandoned Nilde oil feld, formerly oper-ated by Eni.

Circle Oil is reporting a promising oil discovery in the Mahdia permit offshore Tunisia, 120 km (74 mi) east of the port of Sousse. The El Mediouni-1 well, drilled in 240 m (787 ft) of water, encountered light oil in the lower Birsa and upper Ketatna car-bonates, with analysis confrming a working petroleum system both for this and other prospects. Discovered resources could be around 100 MMbbl.

The Petrobel joint venture has brought onstream the DEKA gas project in the Tem-sah concession in Egypts offshore East Nile Delta. Initial production is through the Denise South-6 well, 65 km (40 mi) north of Port Said in 100 m (328 ft) of water. JV part-ners BP and Eni plan fve subsea wells on various felds in the concession, linked via sealines to the onshore El Gamil gas plant, with production peaking at 230 MMcf/d (6.5 MMcm/d) early next year.

Noble Energy has a letter of intent (LOI) to supply 1.6 tcf (45 bcm) of gas over a 15-year period from the deepwater Leviathan feld offshore Israel to Jordans National Electric Power Co. Deliveries will occur at a border location between the two countries, with an initial sales volume of 300 MMcf/d (8.5 MMcm/d). Noble says it now has more than 60% of the 22-tcf (620-bcm) felds initial capacity tied up in LOIs with customers in the region.

The FPSO Cidade de Ilhabela left the Brasa

shipyard last month for sea trials ahead of

starting service on the Sapinho field in the

presalt Santos basin offshore Brazil. Owners

SBM Offshore, Quiroz Galvo Oleo e Gas, and

Mitsubishi will operate the vessel on behalf of

Petrobras and its block BM-S-9 partners BG and

Repsol. (Photo courtesy SBM Offshore)

1410OFF_14 14 10/1/14 3:57 PM

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Energean Oil & Gas has purchased the tender-assist rig Glen Esk from KCA Deutag for use in a $225-million development program offshore northwest Greece. The rig, to be renamed Energean Force, is expected to start operations in early December. Energean plans to drill 15 wells and install two new unmanned platforms on the Prinos North and Epsilon felds.

Caspian SeaOffshore delivery started last month of the topsides for the riser

block platform for Lukoils Vladimir Filanovsky feld in the Russian sector. It will connect interfeld and export pipelines carrying oil and gas. This month, transport was due to start on the ice-resistant

stationary platform that will be used for drilling. All four platform topsides and bridges are expected to be in place by year-end.

Middle EastMore development phases are nearing completion at the South

Pars gas-condensate feld in the Persian Gulf. The export pipeline has been laid between the Phase 22 facilities and the Iranian main-land, while a new platform at Phase 17 should enter service in Janu-ary, adding 14.5 MMcm/d (500 MMcf/d) to the countrys output.

East AfricaA second drillstem test on the deepwater Mzia gas discovery off-

shore Tanzania has reduced reservoir risk ahead of a planned devel-opment, according to operator BG Group. The DST was performed on the Mzia-3 appraisal well in block 1 in 1,800 m (5,905 ft) of water, 6 km (3.7 mi) north of the discovery well, fowing up to 101 MMcf/d (2.8 MMcm/d) of gas. BG now estimates recoverable resources from blocks 1, 3, and 4 at 15 tcf (425 bcm). The drillship Deepsea Metro-1 was due to transfer north to drill the Kamba-1 well in block 4.Aminex has applied to Tanzanias Petroleum Development Co. to

convert an obligation for shallow-water seismic over its Nyuni Area PSA to deepwater 3D seismic in the outboard sector. Aminex has identifed a large prospect that appears analogous with other large deepwater gas discoveries in neighboring blocks.

ION Geoventures has acquired an additional 2,330 km (1,448 mi) of 2D seismic over three blocks offshore the Union of the Comoros. Bahari Resources and partner Discover Exploration commissioned the survey which total around 18,000 sq km (6,950 sq mi) in the western part of the Comoros. Interpretation to date indicates an extension of the same gas-

Energeans tender-assist rig will drill

development wells offshore Greece.

(Photo courtesy Energean)

1410OFF_16 16 10/1/14 3:57 PM

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rich reservoir play fairway offshore neighbor-ing Mozambique.

Asia/PacifcRosneft has started production from the

northern section of the Chayvo oil and gas feld offshore Sakhalin Island. In the process, the land rig Yastreb established a new record for a long-reach well drilled from shore, the company reports, with a drilled depth of 10,825 m (35,515 ft) and a horizontal displacement of 9,517 m (31,223 ft). The second well will be around 11,000 m (36,989 ft) long. Rosneft was also due to start drilling from the newly in-stalled Berkut platform in the Sea of Okhotsk.

CNOOC has brought onstream the Wen-chang 13-6 oil feld in the Pearl River Mouth basin offshore China. Water depth is 120 m (393 ft). Facilities include a wellhead platform with 12 producing wells, fve of which were in service last month.

Shell has discovered gas in the deepwater Marjoram structure offshore Sarawak, Malay-sia. Marjoram-1 was drilled in 800 m (2,624 ft) of water in block SK318, 180 km (112 mi) from shore. It follows a gas fnd earlier this year on the Rosmari prospect in the same concession.In the shallow-water SK408 permit, Sapura-

Kencana Energy notched its ffth gas discovery of the year with Bakong-1, which intersected a gross gas column of more than 600 m (1,968 ft) within late Miocene carbonates. Total resources found to date are more than 3 tcf (84 bcm). Petronas has achieved start-up three months ahead of schedule at the Banang oil feld development off peninsu-lar Malaysia. This was the second feld onstream in the KBM cluster (Kapal produced frst oil last December). Facilities include a mobile offshore production unit, a 600,000-bbl storage tanker, a wellbay module, and a fexible fowline.

Idemitsu Oil & Gas has proven more gas and condensate in blocks 05-1b and O5-c, 300 km (186 mi) offshore Ho Chin Minh City, southern Vietnam. The well was spudded in February, and drillstem tested in May and August. The company and partners JX Nip-pon Oil & Gas and Teikoku Oil plan to assess other prospects on the block.Also off southern Vietnam, the consortium

developing the TGT feld is aiming for frst oil in September/October 2015 from the nearby H5 accumulation. According to partner SOCO International, the jackup Naga 2 was due to start drilling the frst of fve planned wells from the newly installed wellhead platform that will be linked by pipeline to the FPSO serving the TGT complex.

Husky-CNOOC Madura has awarded a LOI to Bumi Armada Offshore for a leased FPSO for the Madura feld development offshore In-

donesia. The location is 65 km (40 mi) east of Surabaya and 16 km (10 mi) south of Madura Island. Contract value is $1.18 billion over 10 years, with optional extensions.

AustraliaApache has discovered a potentially large

oil feld in the Canning basin offshore Western Australia. According to partner Carnarvon Pe-troleum, the Phoenix South-1 well in the WA-435 permit encountered at least four discrete

oil columns in the Triassic lower Kerauden formation. In-place reserves could be 300 MMbbl. The location is 110 mi (180 km) north of Port Hedland in 435 ft (133 m) of water.Santos is also claiming a signifcant fnd in

the Browse basin. The Lasseter-1 well, 480 km (298 mi) northeast of Broome and 35 km (22 mi) southeast of the companys Crown discovery, intersected a 405-m (1,329-ft) gross gas/conden-sate bearing interval. Lasseter is near the sites of proposed LNG projects in the area.

1410OFF_17 17 10/1/14 3:57 PM


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

Statoil is considering a new type of unmanned

platform on Oseberg. (Photo courtesy Kvaerner

Oil and Gas)

Drilling technique brings productivity gains

Statoil plans to step up use of Baker Hughes SureTrak steerable drilling liner (SDL) ser-vice on its wells offshore Norway.

According to a presentation at ONS Stavan-ger, the company will employ the technique on up to three wells this year after favorable results on the Grane oil feld in the North Sea. Next in line will be Oseberg in the same sec-tor and Midgard in the Norwegian Sea, and further applications could follow on greenfeld developments including Johan Sverdrup and Gina Krog.

According to Lars Hoier, Statoils senior vice president research, development, and innova-tion: The normal approach is to drill through a formation, pull [the drillstring] out, and then bring in the liner. However, there is a lot of risk with hole stability in certain formations, and the process takes time. With SDL, you bring in the liner while drilling, which leads to increased well robustness. The technique also enables drilling of sections considered undrill-able, and allows more optimal well placement in some reservoirs, with a higher IOR factor. In time, we think this could replace conven-tional drilling on a regular basis.

Statoil frst challenged its vendors to de-vise a solution in 2004. Baker Hughes re-sponded and worked with Statoil during the subsequent four-year development phase. The technique was frst trialed on a Norwe-gian feld in 2009-2010, followed by the frst commercial applications in 2012-2013.

SureTrak employs proven rotary steer-able/liner drilling technologies, including the AutoTrak range. Aside from eliminating the need to re-enter the borehole to run cas-ing or liner, the rotary steerable system al-lows continuous drilling without the need to slow down to change direction.

Geir Tungesvik, Statoils drilling & well senior vice president, said that although the heavy-oil Grane reservoir is generally productive, there are sections with reactive shales that were causing the liner to collapse when retracting the drillstring. So we were having to drill above these shales, leaving oil we couldnt recover. Use of SDL has allowed the company to access 350,000 bbl from the feld that would otherwise have stayed in the ground. Another potential application, Tung-esvik said, could be on Statfjord in the North Sea. Although the reservoir is depleted, there may be further volumes underneath which until now we havent been able to ac-cess due to pressure issues.

Huldra on the way outIn the North Sea, Statoil is looking to put

a new platform in and take an existing one out. The company has commissioned a con-cept study from Kvaerner Engineering for a

standardized, unmanned dry tree wellhead platform for the Oseberg Future Develop-ment project. The focus will be on minimiz-ing facilities, equipment, and costs in water depths down to 150 m (492 ft), and the result could be the frst of a series of unmanned wellhead platforms replacing traditional, higher-cost subsea tiebacks.

The Huldra feld platform, which came on-stream in 2001, ceased gas/condensate pro-duction last month. Statoil will continue regular maintenance on the facility until 2016, when the jackup West Epsilon is due to arrive to begin plugging the six production wells. The platform comprises conventional topsides and a 154.5-m (507-ft) tall jacket, each weighing 5,000 tons. According to feld analysts ScanBoss, the com-pany considered re-using the topsides for the current Valemon development and also offered the entire platform for sale on the Norwegian version of e-Bay. Whether or not the facility ends up being re-used or scrapped, it will have to be removed from its current location.

Statoil says it will decommission the plat-form no later than 2021. The company is re-taining Huldras 160-km (99-mi), 22-in. pipe-line to export Valemons gas to the Heimdal complex, while the existing condensate line to Veslefrikk will be left in situ.

Veolia Environmental Services UK has won a contract to decommission Talisman Ener-gys 14,000-metric ton (15,432-ton) oil produc-tion MOPUstor platform, which never entered service on the redeveloped Yme feld. Contin-ued construction delays at Adyard in the UAE led to the structure fnally being installed on the feld in mid-2011. However, a year later

hookup and commissioning had to be halted when cracks were discovered in grouting se-curing one of the legs to the seabed storage tank. Talisman then decided not to use the platform and terminated the redevelopment. Veolia says the structure will be removed in a single lift operation and towed to Lutelandet, southwest Norway, in mid-2015 for disman-tling and subsequent recycling.

Norways growing undeveloped resources

Wood Mackenzie claims Norway holds 10 Bboe of discovered resources that have yet to be developed, of which more than 60% could be commercialized. These are spread across 206 discoveries ranging in size from 1 MMboe to the 2.4-Bboe Johan Sverdrup feld. Half are in the North Sea with the remainder split be-tween the Norwegian and Barents seas.

Another Wood Mac report details how al-most half of Norways $200-billion development spend over the next decade will be directed at incremental projects, led by sgard and Ormen Lange (subsea compression), Heidrun Nord Flank, Valhall Vest Flank, and the Hod feld re-development. These fve projects alone should add estimated reserves of 1 Bboe, increasing the felds recovery factor by an average of 9%. Com-pared with the new Norwegian greenfeld devel-opments, the average investment capex/bbl of these projects is 30% lower, the analysts claim, although some have incurred large increases in costs that could erode their long-term value.

Denmark set for further decline

Analysts Douglas-Westwood believe that Den-mark could be a net importer of oil by 2021, with the countrys North Sea production by that point down to around 130,000 b/d, the lowest level for 30 years. They point to continuing declines in Denmarks North Sea felds, with production halving this year to 192,000 b/d compared with the peak of 389,000 b/d in 2004. A lack of large discoveries has also held back the countrys up-stream sector, they claim, while a paucity of fresh developments has led to a decline in develop-ment drilling, with just eight development wells drilled over the last three years.

In the mid-term well completions should rise during development of the high-pressure/high-temperature Hejre feld, although ac-cording to operator DONG Energy, work on the topsides is behind schedule and this may push back the start of production until 2017.

Douglas-Westwoods forecast does not take into account the impact of two probable new development projects. Maersk Oil & Gas has submitted an $868-million plan to link the Adda gas/condensate feld to its Tyra East complex via a new 16-slot, unmanned platform and two new subsea pipelines. Phase 1 calls for drilling of eight wells, with start-up slated for late 2016.

1410OFF_18 18 10/1/14 3:57 PM

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1410OFF_19 19 10/1/14 3:57 PM


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

Operators advancing deepwater projects with new and existing technologies Work is proceeding on a number of deepwater production efforts

in the Gulf of Mexico, and recent announcements regarding the Big Bend, Dantzler, and Jack/St. Malo projects are providing fresh evi-dence of the Gulfs vitality as an E&P region. Some projects are making use of existing infrastructure by tying

back to foating production facilities already in place, and some are deploying huge new deepwater production facilities. In mid-September, SBM Offshore reported that it had signed a

production-handling agreement with Noble Energy to produce the Big Bend and Dantzler felds to the Thunder Hawk DeepDraft Semi located in 6,060 ft (1,847 m) of water in the Gulf of Mexico.First oil from the Big Bend and Dantzler felds is expected in late

2015 and 1Q 2016, respectively. At these levels, both felds will use a maximum of 85% of total daily asset capacity. Brownfeld construc-tion to upgrade the facility will be handled by Noble Energy.The Big Bend feld is 18 mi (29 km) from the Thunder Hawk

platform in 7,200 ft (2,195 m) of water in Mississippi Canyon block 698. Noble Energy operates a 54% working interest in Big Bend, alongside W&T Energy VI LLC (a wholly owned subsidiary of W&T Offshore Inc.) with 20%, Red Willow Offshore LLC with 15.4%, and Houston Energy Deepwater Ventures V LLC with 10.6%.The Dantzler feld is 7 mi (11 km) from the Thunder Hawk platform

in 6,580 ft (2,006 m) of water in Mississippi Canyon block 782. Noble Energy operates Dantzler with a 45% working interest. Additional interest owners are entities managed by Ridgewood Energy Corp. (including ILX Holdings II LLC, a portfolio company of Riverstone Holdings LLC) with 35%, and W&T Energy VI with 20%. Big Bend and Dantzler will be developed via a dual pipe-in-pipe loop system.The Thunder Hawk DeepDraft Semi, installed in July 2009, was

developed as a steel catenary riser-friendly foater solution. The deck and hull can be integrated quayside, avoiding costly offshore lifting and system commissioning operations.The Thunder Hawk platform allowed for a cost-effective develop-

ment solution for Noble Energy and its partners, said SBM CEO Bruno Chabas. The deepwater semi solution offers numerous advan-tages for subsea developments including reduced development capi-tal, lower operating costs, and an accelerated development schedule.Also in mid-September, McDermott International Inc. said it had

completed its work on the Jack and St. Malo project for Chevron USA Inc. The project involved the installation of jumpers, fying leads, sub-sea pump stations, umbilicals, and subsea landing of some of the indus-

trys largest and complex umbilical end terminations to a host foating production platform in 7,200 ft (2,195 m) of water 279 mi (449 km) off-shore Louisiana. The project is part of the frst stage of development of the Jack South, St. Malo South, and St. Malo North drill centers.McDermott says it executed in-house fabrication of 21 high-spec-

ifcation rigid fowline, manifold and pump jumpers, and installed the structures using the Derrick Barge 50 (DB50) with its specialized deepwater lowering system. In addition, the DB50 installed more than 80 fying leads, fve ad-

ditional rigid production well jumpers, and other subsea control and production boost components. DB50 was assisted by a feet of up to 12 support vessels delivering material from various Gulf Coast fabri-cation and staging facilities to the offshore installation site.Additionally, three control and two power umbilicals totaling 65 mi

(105 km) were transported and installed by the subsea construction vessel North Ocean 102, along with other related subsea structures.

TDW performs subsea pressure isolation jobT.D. Williamson (TDW) says it was recently retained to isolate

pressure in a GoM riser so that a wye could be safely installed and so that divers, who would be working 228 m (748 ft) subsea near the open end of the line, would be safe.For this job, TDW developed a custom solution that provided the dive spe-

cialist with a safe, reliable method of isolating the riser and platform from the section that was to be prepared for the wye installation.Before the line was isolated, it was imperative to determine whether the

line was piggable, and that the specially sized (or engineered) SmartPlug tool would be able to negotiate the tight bends in the riser to reach the set location. TDW conducted a pig-gability and pipeline stress simulation study by bi-directionally running a modifed gauge pig to simulate the exact path of the isolation tool during the forthcoming operation. The study confrmed that the plugging tool would successfully traverse the pip-ing and reach its target destination.Working from the platform, the

TDW crew launched the tool into the riser. As it traveled through the riser, the team onboard the support vessel used its remote-controlled SmartTrack tracking and monitor-ing system which uses two-way, through-wall electromagnetic com-munication between a transponder and a receiver to track the tools progress, control its speed, and monitor conditions in real time. When it reached its subsea set location of 228 m (748 ft), the tool was set into position, where it remained for 3.5 days, isolating the riser against a pressure of 63 bar (914 psi).With the line safely isolated, divers cut the line in preparation for

the tie-in. Throughout the operation, divers worked near the open-ended line while the plugging tool prevented the gas from escaping. The wye spool was installed, and the tool was retrieved through a valve ftted with a temporary receiver. The procedure was complet-ed on schedule and without incident.Keeping the divers safe while installing the piggable wye on time

was a major achievement, signaling that the next step of the plan to tie in the line to the new deepwater oil and gas project could pro-ceed. The task was carried out using technologies offering continu-ous pressure and subsea condition reports, giving the dive specialist confdence to proceed with the installation.

T.D. Williamson recently used its Smart-

Plug tool to isolate pressure in a GoM ris-

er so that a wye could be safely installed

in advance of a tie-in to a new deepwater

oil and gas system in the Gulf of Mexico.

(Photo courtesy T.D. Williamson)

Noble Energy says it will produce the Big Bend and Dantzler fields via

tiebacks to the Thunder Hawk DeepDraft Semi located in 6,060 ft (1,847 m)

of water in the Gulf of Mexico. (Photo courtesy SBM Offshore)

1410OFF_20 20 10/1/14 3:57 PM

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1410OFF_21 21 10/1/14 3:57 PM


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

Subsea equipment standardization new DNV GL target

DNV GL has launched a new certifcation scheme covering subsea equipment and components. The target is to increase qual-ity control and effciency through standard-ization.

Some of the benefts enumerated by DNV GL of the new standard and certifcation are as follows:

Provide a predictable set of documents for integrators, equipment owners, or operators; there will be a consistent set of quality activities required of all sup-pliers in a project.

Reduce risk for the integrators and owners by having much of the verifca-tion and review work completed on site at sub-suppliers prior to being shipped to integrators sites for assembly. Risks will also be identifed at earlier stages of a project.

Improve quality and, therefore, safety by increasing the suppliers familiarity with the requirements and specifca-tions via the unifed and effcient de-ployment of quality control plans for the individual projects.

Reduce pressure on the global supply chains by facilitating the use of subcon-tractors for inspection and surveillance services.

Enable suppliers to stock long-lead items. Short lead time is important in the development of marginal felds and tiebacks.

The DNV GL standard aims to help in-terpret existing API and ISO standards, and the certifcate will provide operators with confdence that fabrication quality is being controlled and assured.

For operators, it will reduce costs with-out sacrifcing quality, innovation, or safety and subsequently shorten lead times. For suppliers, it will increase predictability and enable the strategic stocking of long-lead items, said Bjrn Sgrd, segment director for subsea at DNV GL Oil & Gas.

In a related step, Statoil has asked DNV to organize a joint industry project to develop subsea processing equipment interface standards.

Think of the modules as LEGO bricks. By having standardized module dimensions which may be assembled using standard tie-ins, we may combine technology from differ-ent suppliers and also cover several needs through subsea solutions. This will reduce costs and increase volume, says executive vice president of Technology, Projects & Drilling in Statoil, Margareth vrum.

Statoil believes that this standardization initiative will help increase the number of

business cases for subsea processing and reduce the cost of new projects. Standard-ization will be important to secure a strong and coordinated approach to the supplier in-dustry in order to achieve the goal of more proftable subsea developments.

A frst step for the JIP will be to collect ideas, comments, and suggestions from suppliers regarding the areas they believe will beneft from standardization.

New vertical subsea tree revealed

GE Oil & Gas has unveiled its Deepwater Vertical Xmas Tree. It is rated for depths to 3,000 m (9,840 ft). It can be deployed with GEs next-generation remote electronics canister, the SemStar5-R. The company also says its ModPod subsea control module with a 220 km (137 mi) range is designed to complement the DVXTs modular layout, with a fexible network that can beneft fu-ture feld expansion and enhance access to remote wells.

GE says the new tree expands its prod-ucts portfolio of pre-engineered, pre-qual-ifed modular systems, designed to enable products to be brought to market faster.

Petrobras has awarded GE Oil & Gas a $300-million-plus contract to supply subsea manifold systems for presalt felds offshore Brazil, in water depths up to 6,500 ft (2,000 m).

The scope includes eight manifolds that will feature retrievable injection modules to allow water-alternated-gas injection for up to four wells, and system integration with sub-sea controls.

All equipment will be manufactured in Brazil.

In Brazil during Rio Oil & Gas, GE Oil & Gas presented its work on the Naxys A10 integrated acoustic monitoring equipment. The sensor uses acoustic sensing to identify potential problems related to subsea opera-tions and to fnd any leaks that may be harm-ful to the environment.

Baker Hughes, Aker Solutions get OK on subsea production alliance

Baker Hughes Inc. and Aker Solutions have received regulatory approvals to form a Subsea Production Alliance. The intent was announced earlier this year when the companies agreed to form an alliance to de-velop technology for production solutions designed to boost output, increase recovery rates, and reduce costs for subsea felds.

The alliance is expected to combine Aker Solutions subsea production and processing systems with Bakers well completions and artifcial lift technology to deliver reliable, integrated in-well, and subsea production solutions that help mitigate risk, accelerate output, and extend the life of subsea felds.

In addition, the team aims to advance in-dustrys well-intervention capabilities to op-timize effciency and reduce risks in subsea developments.

Cameron shows new subsea controls system

Cameron has introduced the Mark IV con-trol system with three-points of distribution (PoD) design as an option for its subsea BOPs.

Cameron introduced the frst multiplex BOP control system for subsea drilling and has developed the patent-pending three-PoD stack design to provide additional redundan-cy. Adding a third PoD can improve the sub-sea control systems availability to as much as 98%, and reduce the likelihood of a PoD-relat-ed stack pull by up to 73%, the company said.

The new PoD design also offers increased functionality in a smaller, lighter package. The simpler design can reduce leak paths by using 50% less tubing compared to the companys previous two-PoD design. Addi-tionally, the number of available functions has increased 33% to accommodate newer, eight-cavity stacks. PoD size was reduced 26%, and weight is one-third less than other control PoDs.

Siemens to acquire Dresser-Rand Siemens has agreed to acquire Dresser-Rand for $7.6 billion. The friendly takeover

bid is supported by Dresser-Rands board of directors, according to Siemens. The transaction is expected to close by next summer.

Given the vision Siemens has for Dresser-Rand as its oil and gas company, and its expressed wishes to build Dresser-Rands product and service portfolio with some of the existing Siemens offerings that have previously been marketed sepa-rately into the oil and gas space, it is clear that this is a transaction that should create value for clients, as well as for both sets of shareholders, that would not have otherwise been achieved had Dresser-Rand not become part of the Siemens group, said Vincent R. Volpe Jr. CEO and president of Dresser-Rand.

Our intention is to leverage these strengths by maintaining the existing company and brand name and selectively moving complementary products and services from the existing Siemens portfolio into Dresser-Rand enabling us to offer a much broader range of products, services and solutions to meet our customers needs, said Lisa Davis, member of the Managing Board of Siemens AG.

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V E S S E L S , R I G S , & S U R FA C E S Y S T E M S Robin Dupre Houston

Ceona Amazon (Photo courtesy Ceona)

Ceona Amazon foats in Bremerhaven and progresses to fnal outftting

Ceona has successfully foated the Ceona Amazon, the companys new fully owned feld development vessel, in Bremerhaven, Germany. The vessel was towed-out from the Crist yard in Poland, last April.

A major construction milestone was reached at the Lloyd Werft yard in Bremerhaven, and is set for completion at the end of No-vember 2014. All machinery, equipment, and the helideck have been installed, with accommodation, piping, and electrical outftting in progress. System commissioning is due to commence in the next few weeks. Once work in Germany is completed, the vessel will move to the Huisman yard in Schiedam for installation of a 570-ton (517-metric ton) pipelay tower and the two 400-ton (363-metric ton) cranes before entering into service in early 2015.

Ceona Amazon is a 653-ft (199-m) deepwater feld development vessel. With a carrying capacity of 5,000 tons (4,536 metric tons) of fexible or 8,500 tons (7,711 metric tons) of rigid pipe stored on and below the 4,600-sq m (49,514-sq ft) deck, the vessel is equipped with twin 400-ton AHC cranes capable of working in tandem lifting mode, innovative on-vessel pipeline fabrication capabilities (welding, NDT, and FJC), and a drillship-design hull operability.

Rowan Viking rig upgrade completedDamen Shiprepair Vlissingen has completed an upgrade of a Kep-

pel Fels N-Class drilling rig, the Rowan Viking, one of the largest in the North Sea, in 30 days less than was initially projected by the client.

The scope of the project involved extending three legs by 33 ft to 591 ft (10 m to 180 m), a fve-yearly special periodic survey, and bringing the rig up to standard for the acknowledgment of compli-ance (AoC) certifcation required by the Norwegian authorities.

To achieve this goal, Damen Shiprepair Vlissingen adopted a new approach: a project execution plan that allowed the three aspects of the contract to be undertaken simultaneously. To enable this to hap-pen, changes had to be made both to working practices and to the organization of the yard itself, Damen stated.

The use of a Mammoet crane and Palfngers JUMP system were also critical elements. The PTC crane was delivered on more than 100 trucks and was erected to a height of 656 ft (200 m) on special per-manent foundations installed to bear the loads. This allowed the rig to remain at sea level and the leg extension pieces to be lifted directly from the shore on to the legs for installation. Palfnger supplied the platforms that allowed the engineers to move up and down the legs at heights of up to 525 ft (160 m) for ftting and welding.

Oceanteam Shipping partners with Pacifc Radiance

Oceanteam Shipping ASA has secured, through its joint venture DOT Holdings AS, an interest in a newbuild offshore support vessel, resulting in a partnership with Pacifc Radiance Ltd. Closure of re-

maining conditions are expected to be fnalized in the coming month. Once full closure is reached, the initial interest of DOT Holdings

AS is 50%, but the investment comes with an option to buy the re-maining 50% after a period of seven years against agreed terms.

Ulstein Group introduces design for harsh conditions

Ulstein Group has introduced the X-STERN, a vessel design fea-ture that increases operability through positive effects on station keeping, wave response, comfort, and safety in harsh conditions.

An X-STERN vessel can stay on position in harsh weather with the stern toward waves, wind, and current. For vessels where the best pos-sible motion characteristics are vital, positioning the X-STERN toward the weather instead of the bow will be the captains natural choice.

The X-STERN leads to reduced pitch and wave drift forces, and also eliminates slamming. Positive effects are reduced power and fuel consumption while on DP, or the possibility of operating in a wider sector with the same power consumption.

The X-STERN has several of the same characteristics as the X-BOW, and additional ice operation capabilities. Its gentle displace-ment reduces acceleration, pitch, and heave, improves comfort and safety, and increases the operational window. There will be no sea on deck, and reduced ice buildup in cold climates, due to the stern shape and enclosed nature of the aft deck.

Strategic Marine unveils Generation 3 vesselStrategic Marine has unveiled its Generation 3 crew transfer ves-

sel for international offshore markets. The new 40-m (131-ft) design has been in development since 2013. In assessing areas to upgrade the model, Strategic Marine focused on a more effcient hull; in-creased passenger, fuel, and water capacities; higher payload; and increased comfort.

The key beneft we can pass on is the major saving in fuel achiev-able at speeds from 20-30-plus knots, said Reece Newbold, head of Group Business Development. An actual saving in horsepower of 10% at all speeds below 25 knots and even greater reductions in horsepower over 25 knots have been realized. What this means in real terms is a reduction in horsepower and fuel consumption to achieve the 25 knots currently specifed by a large number of charters.

The hull has been designed with adaptability in mind, and the propulsion packages can vary with a clients engine preference. The seating cabin has been increased in size and can cater for 100 pas-sengers. Improvements to the cargo deck area have also been made, featuring a clear deck area of 120 sq m (1,292 sq ft).

The Gen 3 can also serve security/patrol boat duties, emergency response, oil spill recovery, frefghting, general workboat duties, or as a shadow vessel.

Generation 3 (Image courtesy Strategic Marine)

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

Gazprom Neft Shelf LLC says that the Prirazlomnoye facility is the worlds first project involving

oil extraction on the Arctic shelf by means of a stationary platform. (Photo courtesy Gazprom Neft

Shelf LLC)

Conservation takes a different tack

There are many defnitions of the word conservation. According to Websters New Collegiate Dictionary, conservation is de-fned as conserving, preserving, guarding, or protecting. When applied specifcally to natural resources, it relates to maintenance and supervision.

This editor suggests an additional defni-tion as applied to equipment or assets is ex-tending useful life. The industry recently experienced an excellent example of this lat-ter defnition when Shell announced comple-tion of its plan to use the Auger TLP to pro-cess production from its Cardamom feld.

Discovered in 1995, the Cardamom feld is located in Garden Banks block 427, about 225 mi (362 km) southwest of New Orleans. Verti-cal depth to the reservoir is more than 25,000 ft (7,620 m). Water depth is greater than 2,720 ft (800 m), and the reservoir is subsalt, making its discovery technically challenging. The ultimate solution involved advanced ex-ploration technology with its ability to image beneath thick salt layers.

For its part, Shell exercised many of the core principles of conservation in devel-oping Cardamom production by making maximum use of the existing Auger asset. The decision was even more appropriate considering that the Cardamom discovery well was actually drilled from the Auger plat-form. Although the decision to use Auger required additional expenditures, the net effect saved considerable cost. The expen-ditures were needed to upgrade the existing process train; install additional subsea re-ceiving equipment; and increase the liquid handling, cooling, and storage capacities.

Taking a global view, the decision was a victory for conservation in many ways. First, using the existing facility allowed Shell to tie-back Cardamom wells to the mother ship as they were completed. In fact, the frst production from Cardamom began in 2010. All the receiving and processing equipment was already vetted, and had performed safely and effciently for over two decades. This is another way of saying that if there were any bugs, they had certainly been remediated by now. The tension-leg concept is a proven one and several TLPs are currently produc-ing oil around the world. Engineers deemed that Auger had many years of useful life left.

Total gross ultimate recovery from Auger was estimated at about 300 MMboe with a 2:1 gas/oil ratio. Cardamom ultimate recovery is estimated at 35 MMboe. Augers produc-tion capacity at the outset was expected to be about 42,000 b/d of oil and 125 MMcf/d of gas, but two separate upgrade projects raised capacity initially to 72,000 b/d of oil and 165 MMcf/d, and later to 100,000 b/d of oil and

300 MMcf/d of gas. Adding more than 10% ultimate recovery to an already proftable as-set is conservation at its best.

Deepwater tiebacks have increased in popu-larity as a way to conserve infrastructure. Why build a new production facility if you can tie sub-sea wells back to a facility already in place? This is particularly benefcial if the existing facility is under-utilized. The Independence Hub was de-signed to accept gas production from 16 felds, process it and commingle it, ultimately ship-ping it to shore in a 20-in. pipeline. The Inde-pendence Hub is operating under its maximum capacity today, so it too could offer an economic solution to a neighboring producer.

Recently, Statoil also employed this strat-egy with two tiebacks offshore Norway. In mid-September, the company reported that it had started production from the Fram H-North and Svalin C satellites in the Norwe-gian North Sea. These are the eighth and ninth of the companys fasttrack develop-ment projects offshore Norway.

Fram H-North, thought to hold around 10 MMboe recoverable, is in the Troll area. It has been developed using a standardized subsea template that can accommodate four wells, and is connected by 5 km (3.1 mi) of pipeline and umbilicals to the existing sub-sea template on Fram West A2.

Svalin C in the Grane area contains just over 30 MMboe. Development called for a subsea facility with two wells, 6 km (3.7 mi) southwest of the Grane platform.

The plan for development and operation (PDO) for Svalin C was submitted in June 2012 and approved by the Ministry of Petroleum and Energy in November 2012. The Fram H-North partners took their investment decision in summer 2012. In this case, the project was exempt from having to submit a PDO.

Statoil says drilling and well activities on

Fram H-North turned out to be more diff-cult than expected, while Svalin C encoun-tered issues connected to deliveries of the control system for the subsea template, re-sulting in a delayed production start.

Millionth barrel produced at Prirazlomnoye

Meanwhile, in the Russian arctic, Gaz-prom Neft Shelf LLC is employing a dif-ferent strategy. The company recently an-nounced that the Prirazlomnoye feld has produced its millionth barrel of oil. A tanker is currently being loaded, and a further two tankers will transport around 1 MMbbl of oil from the Prirazlomnoye feld before the end of the year. In total, 2.2 MMbbl are expected to be produced at Prirazlomnoye in its frst year.

Prirazlomnoye is the worlds frst project involving oil extraction on the Arctic shelf by means of a stationary platform. Extraction as part of pilot production began in December 2013. The new Prirazlomnaya offshore, ice-re-sistant, stationary oil production platform was developed for this feld to facilitate all techni-cal operations, including drilling, extraction, oil storage, preparation, and shipping.

One production well has been drilled and an injection well should be completed soon. There are plans to complete the main drilling work for an absorption well by the end of 2014. Four more wells are to be drilled in 2015. In total, the project will involve the commission of 36 wells, comprising 19 production wells, 16 injection wells, and one absorption well.

The Prirazlomnoye is 60 km (37 mi) off-shore in the Pechora Sea. Recoverable re-serves of oil at the deposit are in excess of 70 MM metric tons (77 MM tons). Gazprom Neft Shelf LLC is the project operator and subsurface license holder.

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

Seismic survey list starts offshore Africa

TGS announces acquisition of a 3D multi-client survey offshore Sierra Leone. The sur-vey, Sierra Leone Block 4A Extension, will add 1,000 sq km (386 sq mi) of new 3D data to the existing 6,268 sq km (2,420 sq mi) of 3D data library in Sierra Leone.TGS is chartering the 12-streamer Polar-

cus Alima for this survey. Data processing will be performed by TGS and will be avail-able to clients in 1Q 2015.The survey is supported by industry

funding.Dolphin Geophysical will acquire and

process a 7,000-sq km (2,703-sq mi) SHarp Broadband 3D survey offshore Senegal for Kosmos Energy.The Dolphin high-capacity 3D vessel Po-

lar Duchess has started to work and it will take an estimated four months to complete. Dolphins OpenCPS software will be used

both onboard the vessel to produce a Post-STM Fast-Track dataset and then for the fnal PSTM volume at the companys UK Processing Centre. Aminex and its partners plan to focus on

the deepwater portion of the Nyuni Area PSA offshore Tanzania following a detailed technical review.The company has applied to Tanzanias Pe-

troleum Development Co. to vary the Nyuni Area work program for the shallow-water seismic obligation, originally planned for this year, to be converted to deepwater 3D seis-mic in the outboard sector of the PSA area.Here Aminex has identifed a large poten-

tial prospect that appears to be analogous to some of the recent major deepwater gas discoveries in neighboring blocks. It plans a tender process for a contractor to acquire 3D data over the Pande West lead and to identify other potential drill-ready prospects.However, a larger farm-in partner will

be needed to help share the costs of any deepwater drilling. Current participants in the Nyuni Area PSA are Aminex subsidiary Ndovu Resources (70%, operator), RAK Gas (25%), and Bounty Oil & Gas (5%).Dolphin also will perform an industry

frst ever 16-streamer 3D seismic contract for an undisclosed client in the Kara Sea.The contract has a duration of approximate-

ly three months starting in 2Q 2015. Dolphin will use one of the high-capacity ice classed 3D seismic vessels for the survey and take ad-vantage of its wide-tow capabilities by towing a large 16-streamer confguration with 100 m (328 ft) separation to acquire the seismic data in as short a time as possible.

Electromagnetic Geoservices has received a supplement agreement from Statoil Petro-leum AS worth $1 million for multi-client 3D EM data acquisition in the Norwegian Sea.EMGS expects to commence the survey

soon, after completing the survey for Statoil announced in June in the same area, using the vessel Atlantic Guardian.

Dolphin enters realmof software processing Following the award of several processing

projects, Dolphin Geophysical wholly owned subsidiary Open Geophysical Inc., has won

its frst contract valued at more than $1 mil-lion to supply software to a national oil com-pany. This contract marks Dolphins entry into supplying advanced and user friendly processing software. Dr. Gareth Williams, chief geophysicist, said

Our processing and imaging business is set for rapid growth on the back of a larger feet, entry to new market segments such as depth imag-ing and re-processing, and increased software sales. To facilitate this growth, our Singapore P&I team have recently moved into a larger offce, our UK hub will relocate and expand in 3Q and we also expect our Houston processing center to be operational in 4Q 2014.

Blueback Reservoir has released Blue-back Toolbox plug-in for Petrel version 15.The Blueback Toolbox suite contains Pe-

trel function features not available in standard Petrel. It has been developed by Blueback Reservoir using Petrels Ocean development framework. All functionality has been devel-oped based on requests from Petrel users around the world and the development is co-ordinated with the Petrel software teams at Schlumberger. Split into four domain modules, the Blue-

back Toolbox is a collection of more than 100 plug-in features complementing current Petrel workfows and has proven to save time for Petrel users, Blueback says. Version 15 supports Petrel 2014 and the

new Ribbons user interface. In addition the new version contains several new and ad-vanced tools, like the wavelet editor which allows the user to perform operations; like av-erage, shift, and fip on one or more wavelets, in addition to the waveform classifcation that searches seismic data for matching wave-forms to aid classifcation of seismic data and identifcation of facies types.

Schlumberger has launched its Quanta Geo photorealistic reservoir geology service. The new service includes the industrys frst microresistivity imager that produces ori-ented, photorealistic, core-like images of the formation in wells drilled with oil-base mud (OBM).The physics of the Quanta Geo services

high-resolution array of 192 microelec-trodes overcomes the electrically resistive barrier imposed by OBM. Using the companys Techlog wellbore

software, Quanta Geo data are rendered, creating an image of 0.24-in. resolution that resembles a whole core. Geologists inter-pret these images in the same manner that they would perform continuous core de-scription, with the added beneft that these images cover a longer continuous interval and are precisely oriented. This enables ex-traction of key reservoir parameters such as the structural dip, or the identifcation of sand body type, extent, and orientation.

GAC Group has signed a frame agreement for ship agency services wi

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