schneider electrica diagrams.pdf

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August 2013

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

World Trends and Technology for Offshore Oil and Gas Operations

For continuous news & analysiswww.offshore-mag.com

INSIDE

:

FPSO

poste

r,

MWD/LW

Dsurv

e

All electric HIPPS

Deepwater pipeline designs

Reservoir imaging

North Sea update
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International EditionVolume 73, Number 8

August 2013

CON T E N T S

Offshore (ISSN 0030-0608) is published 12 times a year, monthly by PennWell, 1421 S. Sheridan Road, Tulsa, OK 74112. Periodicals class postage paid at Tulsa, OK, and additional offices.Copyright 2013 by PennWell. (Registered in U.S. Patent Trademark Office.) All rights reserved. Permission, however, is granted for libraries and others registered with the Copyright ClearanceCenter, 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 othercountries $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 areavailable 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 SEA

BP looking to maximize productionrom Shetland area felds ................... 32Some large-scale projects are under waythroughout the UK North Sea, reminiscento the early days in the 1970s. None, though,are as coordinated and wide-ranging in scopeas BPs programs on its felds in the ar-northShetland area.

Norwegian Sea trunklineto oer new outlet or strandedgas accumulations ............................. 40Norways parliament (Storting) has approved amajor new subsea pipeline to export gas romfelds in the Norwegian Sea. The Polarledsystem calls or investments o NOK 25 billion($4.2 billion).

Apache fnds new opportunitiesat Forties feld ..................................... 44

This year marks the 10th anniversary oApaches entry into the North Sea with theacquisition o the Forties feld rom BP, at acost o roughly $667 million. Original planshad called or the feld to cease production by2013 with decommissioning to ollow. Technol-ogy and considerable capital investment haveextended that date by at least a generation.

GEOLOGY & GEOPHYSICS

Full waveorm inversionimproves subsurace models ............. 48Full waveorm inversion is providing the E&Pindustry with ever-more detailed imagesand models o the subsurace that can makeexploration, development, and production moreefcient and reduce drilling risk.

DRILLING & COMPLETION

MWD/LWD oers aster,more complete real-time

data technology .................................. 55The annual Offshore magazine MWD/LWD ser-vices directory is packed with details about thelatest downhole technology currently availablein the market. MWD/LWD providers highlighttheir latest advances and a broad spectrum oresponses demonstrates the growth o applica-tions or real-time inormation.

2013 MWD/LWDServices Directory ..............................58Get the latest inormation on measurement-

while-drilling (MWD) and logging-while-drill-ing (LWD) tools and services or 2013.

ENGINEERING,

CONSTRUCTION,

& INSTALLATION

Italian abricator responds to HP/HTNorth Sea project demands ................79Most northern European abrication yardsrely on work rom oshore projects at theirown doorsteps. The same used to apply to

yards in Italy, until environmental legislationbrought the countrys oshore activity to a

virtual standstill. However, Rosetti Marino,based in Ravenna on the Adriatic coast, has notdepended on the domestic sector alone.

Water jet cutting an option

throughout structures lie .................82Oil and gas developments have progressedsignifcantly in the last several decades. Thisprogress has been aided by the developmento abrasive water jet technologies, which canbe used or a variety o applications rom thecradle to the grave o a structure.

Saety, easibility highlightplatorm removal plan ........................ 88

Even high oil prices cannot sustain deplet-ing felds orever, so CNR International hasdecided to end production on the Murchisonfeld in the UK northern North Sea. Last oil isscheduled or early 2014. One notable eatureo the decommissioning program is the recom-mendation to seek derogation (exemption)rom the usual requirement to recover the

jacket to shore in its entirety.

ALE sets jacking recordwith Berkut topsides lit ..................... 94

Ater years o technology development andproject planning, heavy-lit specialist ALE has

completed the successul lit o the 42,780-met-ric ton (47,156-ton) topsides or the Berkutplatorm, an operation that the UK-based com-pany claims is by ar the heaviest such jackingoperation in history.

PRODUCTION OPERATIONS

Flexibility in perormance and felddevelopment propel FPSO market ..... 96

The FPSO eet has been steadily growing sincethe frst acility was activated more than 35 yearsago. Today, there are more than 200 global FPSOinstallations. Since the FPSO market is certainlygrowing, eorts are being made by all industryparticipants to cater to this growth.

SUBSEA

Study explores all-electric subseaHIPPS reliability and maturity ............ 97Recently, research was undertaken to assess theSaety Integrity Level (SIL) achievable or an all-electric subsea High Integrity Pressure ProtectionSystems (HIPPS). The work showed that an SIL 3is achievable or an all-electric subsea HIPPS. Thisis in the same range as that o electro-hydraulicsystems or similar architectures.

Subsea stations couldreduce cost, loadso long-distance umbilicals .............102

Total and Doris are proposing that subseastations be located at various points alongthe route o a tieback, or chemical storageand injection. The main goal is to locate theseunctions close to the subsea processing equip-ment in which the chemicals are to be injected.

58
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honouring the past,

shaping the future


9/1374Offshore August 2013 www.offshore-mag.com

International EditionVolume 73, Number 8

August 2013

D E P A R T M E N T S

FLOWLINES & PIPELINES

New installation methods may acilitate ultra-deepwater pipelay ........................106Since the 1970s, oshore oil and gas development has gradually proceeded rom shallow-water

installations up to around 400 m (1,312 t) to the ultra-deepwaters around 3,000 m (9,842 t) that

represent the maximum today. The question is whether the curve will fatten out at 3,000 m, or i

this is just a temporary pause on the way to even greater depths.

Operators planning some 5,600 miles o oshore pipelines through 2017 ...........112The second annual Global Offshore Pipeline Construction Surveyprovides a detailed project-by-

project listing o all the major large-diameter oshore oil and gas pipeline systems being built,

planned, and studied.

Castoroneextends the threshold or deepwater, large-diameter pipelay ..............115The oshore market will increasingly require lay vessels capable o installing large-diameter

trunklines in all water depths, with more advanced dynamic positioning capability and higher

pipe storage capacity or remote locations. Saipem has engineered and constructed its latest fag-

ship vessel Castorone with these industry needs in mind.

Intelligent fexible pipe can improve tieback design ..............................................117With discoveries in more challenging elds, the implementation o intelligent pipelines can be

a qualied solution or both new and existing elds. Key advantages o intelligent options can

include improved thermal perormance, reduced complexity o existing elds/new elds, and

minimized installation time.

COVER:New technology has

enabled North Sea operators to unlockresources in a region that has been

declared past its prime more than once.Ten years ago, the Forties feld, oneo the UKs oldest and biggest, wasscheduled to begin decommissioningin 2013. Instead, seismic and drilling

advances have helped Apache Corp.recover 200 MMboe since acquir-ing the feld rom BP in 2003 and to

tally up another 114 MMboe in provedreserves. The jacket or a new platormat Forties Alpha (cover) sailed out o theOGN yard on the River Tyne last year;

topsides were installed in June, parto a $4.3-billion investment that has

extended Forties feld lie by 20 years.(Photo courtesy Apache Corp.)

Online .................................................... 6

Comment ............................................... 8

Data ..................................................... 10

Global E&P .......................................... 12

Oshore Europe .................................. 18

Gul o Mexico ..................................... 20

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

Vessels, Rigs, & Surace Systems ......24

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

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

Oshore Automation Solutions .......... 30

Business Bries ................................. 122

Advertisers Index ............................. 127

Beyond the Horizon .......................... 128

Find us on Stand 4A160
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Formation Evaluation | Well Construction | Completions | Production 2013 Weatherford. All rights reserved.

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COMMENT David Paganie Houston

Positive signs in Northwest EuropeWhile the UK North Sea stil l commands the greatest percentage share o o shore

investment in Northwest Europe, other areas in the region are drawing increasing inter-

est. The Barents Sea, in particular, is attracting new participants on the heels o Statoilsdrilling success on Skrugard. At its 22nd Licensing Round, the Norwegian governmentissued 20 new licenses in the Barents Sea and our in the Norwegian Sea to a total o29 companies. Indeed a strong showing, new operators in the Barents Sea include Cen-trica, ConocoPhillips, Edison, GDF Suez, RWE Dea, Lukoil, Rosnet, and Shell, whileDet norske Oljeselskap, Eni, Lundin, Repsol, and Total expanded their interests in theregion.

Meanwhile, rontier seekers are gathering in the west coast o Ireland to test theemerging oil and gas play in the deepwater Porcupine basin. ExxonMobil has testedit frst with the Dunquin North exploration well in 1,700 m (5,577 t) o water. The wellresults indicate a working petroleum system in the basin and likely will spur greaterinterest in the area, according to partner Providence Resources.

The positive signs in the region are urther illustrated by recent drilling activity. Dur-ing the second quarter o this year, a total o 35 exploration and appraisal wells weredrilled oshore Northwest Europe, up 40% rom the frst quarter, according to a recentsurvey by Deloitte Petroleum Services Group. O those wells, 30 were drilled oshoreUK and Norway. Farm-in deals to assist with drilling and development are increasingas well. Across Northwest Europe, arm-ins accounted or 70% o all reported deals inthe region, according to the survey. Development activity, too, has remained strong inrecent months, with six felds granted development approval and our coming onstreamoshore the UK and Norway.

West of ShetlandSome large-scale projects are underway throughout the UK North Sea, reminiscent

o the early days in the 1970s. None, though, are as coordinated and wide-ranging inscope as BPs programs on its felds in the ar-north Shetland area, writesJeremy Beck-man, OffshoreEditor Europe. These vary rom comprehensive overhauls o acilities

West o Shetland to a lie extension o Magnus in the east, one o Britains longest-producing felds. Beckmans regional analysis begins on page32.

Norwegian SeaNorways parliament (Storting) has approved a major new subsea pipeline to export

gas rom felds in the Norwegian Sea. The Polarled system calls or investments o NOK25 billion ($4.2 billion), according to Nick Terdre, Offshore Contributing Editor. Al-though Norway has an extensive subsea pipeline network o nearly 8,000 km (4,971mi) or delivering gas to northern Europe and the UK, only two lines currently connectNorwegian Sea felds o mid-Norway to the transportation network in the North Sea.

Terdres complete report begins on page40.

UK North SeaApache Corp. has installed and commissioned the Forties Alpha Satellite Platorm

(FASP), the latest inrastructure addition at the venerable Forties feld, says RussellMcCulley,OffshoreSenior Technical Editor. The new structure, linked to the existing

Forties Alpha platorm by a 90-m (295-t) bridge, includes a our-pile jacket and deck,weighing a total 17,000 tons, in water depths o about 110 m (360 t). The FASP adds 18new well slots to accommodate new drilling to begin this year. McCulleys ull reportbegins on page44.
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DISC VER

C NNECT

EXPL RE
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Worldwide offshore rig count & utilization rate

July 2011 June 2013

950

850

750

650

550

450

350

100

90

80

70

60

50

40

No.ofrigs

Fleetutilizationrate%

July

11

Oct1

1

Jan12

April

12

July

12

Oct1

2

Jan13

April

13

Contracted fleet utilization Total fleet Contracted Working

Source:IHS

UK & Norway capital expenditure (%) by operator 2008-2017

100

90

80

70

60

50

40

30

20

10

0

Eni

Premier

Nexen

ConocoPhillips

GdF Suez

Shell

Total

BP

Statoil

Others

2008

Source: Infield Systems OFFPEX

2009 2010 2011 2012 2013 2014 2015 2016 2017

US$m(

%)

Worldwide day rates

Year/Month Minimum Average Maximum

Drillship

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

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

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

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

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

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

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

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

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

2013 Apr $50,000 $451,918 $674,000

2013 May $50,000 $456,868 $674,000

2013 June $50,000 $460,255 $674,000

Jackup

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

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

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

2012 Oct $30,000 $112,290 $368,000

2012 Nov $30,000 $114,691 $368,0002012 Dec $30,000 $115,456 $368,000

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

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

2013 Mar $30,000 $120,287 $368,000

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

2013 May $30,000 $121,823 $368,000

2013 June $30,000 $122,044 $368,000

Semi

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

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

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

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

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

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

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

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

2013 Mar $145,000 $363,062 $648,000

2013 Apr $145,000 $372,930 $648,000

2013 May $145,000 $380,335 $648,000

2013 June $145,000 $379,863 $648,000

Source: Rigzone.com

GLOBAL D ATA


This month, Infield Systems looks at operatorsthat are active offshore the UK and Norway, whichencompasses the North Sea area and the Norwegianand Barents seas. Across the 10-year timeframe, atotal of 86 operators have or are expected to direct

expenditure offshore the UK and Norway. While thepercentage share of other operators predominatelysmall independent companies with perhaps only oneor two assets is expected to increase from 32% to38% during the forecast compared with the historicperiod. Looking at the major operators over the 2008-2017 period, Statoil remains dominant throughout,with capex expected to be directed toward a total of 99field developments. The operator is expected to bringonstream key capital intensive global developmentssuch as the giant Aasta Hansteen, accounting for theoperators peak share of capex demand in 2015. Alto-gether, the Norwegian NOC is expected to comprise33% of total capex offshore the UK and Norway dur-

ing the 2013-2017 period. BPs activities within the North Sea are expected to remain strong, despitethe UK supermajors share of overall capex decreasing from a 15% share over 2008-2012 to a 6%share going forward to 2017. One of the key developments for BP is expected to be the SchiehallionQuad 204 project, with an FPSO expected to see installation in 2015. Other operators expected tobe featured offshore the UK and Norway include Total, with key developments including Laggan andTormore offshore west Shetland, while Shell is expected to continue investments across a variety ofprojects, including the expansion of Ormen Lange.

Catarina Podevyn, Analyst, Infield Systems Ltd.
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G L O B A L E & P Jeremy Beckman London


Sustained growth ahead ordeepwater drilling, foating production

Total investments in deepwater drilling could surge rom $43 bil-lion last year to $114 billion in 2022, according to a new study by

Wood Mackenzie. Global drilling activity returned to pre-Macondohighs in 2012, the analysts claim, and the deepwater drilling sector

is set or annual growth o 9% over the next decade. Majors are driv-ing much o the activity, and that trend should continue with a 39%increase last year in deepwater and Arctic acreage licensed by the20 leading deepwater players.

To meet the orecast exploration, appraisal, and development wellnumbers set to rise rom 500 to 1,250 wells per year another 95deepwater rigs will need to be built during 2016-22, WoodMac says.

This will represent the longest period o deepwater rig constructionto date. Tightness in the market has been driven by accelerated de-mand or newbuilds ollowing Macondo, which has heightened theoperators ocus on risk mitigation.

In another new market report, energy analysts Ineld orecasts an 18%hike in expenditure on foating production systems (FPS) in the periodto 2017, with a 95% increase in installations that year compared with 2008.Growth in both cases is being driven mainly by new gas eld develop-ments in remote locations, and the ocus on optimizing production romultra-deepwater projects. Around 59% o total FPS capex over the next ve

years should come rom deep/ultra-deepwater developments o Aricaand Latin America and rom mostly shallow-water gas developments o-shore Australia. Toward the end o the ve-year period, new areas to FPSactivity will emerge o East Arica and the Falkland Islands.

Eastern CanadaStatoil has ound more oil in the Flemish Pass basin oshore New-

oundland and Labrador. The semisub West Aquarius drilled the Harpoondiscovery well in 1,100 m (3,609 t) o water on the EL 112 concession,10 km (6.2 mi) southeast o Statoils 100-200-MMbbl Mizzen nd and 500km (310 mi) northeast o St Johns. The company has since spudded a

well on the Federation prospect in the Jeanne dArc basin, to be ollowed

by another on the Bay du Nord structure, southwest o the two discover-ies.

South AmericaRWE Dea is to arm into 40% o block 52 o shore Suriname, oper-

ated by Petronas. The concession covers 4,743 sq km (1,828 sq mi) inthe Guyana-Suriname basin, 120 km (74 mi) oshore, in water depths

ranging rom 100-1,000 m (328-3,281 t). Strongest potential could bein Upper Cretaceous strata. The work program includes a 3D seismicsurvey and one exploration well during the next three years.

O neighboring Guyana, Tullow has agreed to arm into 30% othe newly dened Kanuku block, operated by Repsol. The originalGeorgetown license expired last year ollowing the partners deci-

sion to terminate the Jaguar 1 exploration well. Terms or the newlicense include acquisition o 3D seismic.

West AricaKosmos Energy has contracted the new deepwater drillship At-

woodAchiever or exploration drilling oshore Morocco. The rigis under construction at the DSME shipyard in South Korea andshould be delivered in June 2014. It will work or Kosmos or a rmthree years at a day rate o around $595,000/day.

CNR International has secured a 60% operating interest in blockCI-12 oshore Cote dIvoire. The concession contains two undevel-oped oil discoveries rom the 1980s, with potential Turonian an chan-nels not drilled previously. It is west o CNRs producing Baobab eld

where a third development phase has started, comprising ve newproduction wells and one injector. First oil is due in 2Q 2015.

Also close to Baobab is block CI-504 where Lukoil Overseas hasbecome operator, in partnership with Nigerian independent TaleverasEnergy and state-owned Petroci. Here water depths run rom 800-2,100m (2,624-6,890 t). Focus o the rst exploration period will be on inter-preting historic seismic and acquiring new 3D data by next January.

Total has started development o the deepwater Egina eld, 200 km(124 mi) oshore Por t Harcourt, Nigeria, and 20 km (12.4 mi) south-

west o the companys producing Akpo eld. Water depth is 1,600 m(5,249 t). Development calls or 44 wells connected to a 330-m (1,082-t) long FPSO with 2.3-MMbbl oil storage capacity and acilities toaccommodate uture tie-ins. Contracts let to date include subsea pro-duction systems to FMC Technologies ($1.2 billion); 76 km (47 mi)

o steel tube umbilicals to DUCO; and a $3-billion EPCI contract toSaipem or installation o fowlines, pipelines, and mooring/ofoadingsystems, with much o the equipment abricated at the companys Ru-moulumeni yard in Port Harcourt. Total expects rst oil at end-2017,building to a peak o 200,000 b/d.

Optimum could have a substantial oil discovery o Nigeria, accordingto partner Aren. The Ogo-1 well conrmed an extension o the sameCretaceous sandstones that delivered other nds arther west along the

West Arican Transorm Margin. It encountered a 524-t (160-m) grosshydrocarbon section. The well was due to be deepened to target urtherhigh-potential zones, ollowed by a side track testing a new play.

Production has started rom the $10-billion Angola LNG project,

designed to harness associated gas rom producing oilelds in vari-ous blocks oshore Angola. Gas is transerred through a network osubsea pipelines to a liqueaction plant on the coast near the CongoRiver. According to operator Chevron, the acilities will be able to de-liver 5.2 MM metric tons/yr (5.7 MM tons/yr) o LNG, 63,000 b/do NGLs or export, and 125 MMc/d or Angolas domestic needs.Other partners are BP, Eni, Sonangol, and Total.

Technip subsidiary Genesis Oil and Gas Consultants is perorm-ing a ront-end engineering design study or subsea acilities or

Tullow Oils Kudu gas-to-power project. Shell originally discoveredthe Kudu gas eld in 170 m (558 t) o water oshore Namibia, butuntil now, successive studies have ailed to nd a commercial solu-tion or the stranded reserves. Tullow plans three subsea wells tiedback to a foating production system, with processed gas sent to a

Block 52 offshore Suriname.
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G L O B A L E & P

power station onshore at Uubvlei via a 170-km (105-mi) pipeline.

Black SeaOMV Petrom has completed acquisition o

a 3D seismic survey over the Neptun Deep

block oshore Romania. The 6,000-sq km-plus (2,316-sq mi) program was the largestanywhere in the Black Sea, the company said.OMV Petrom and partner ExxonMobil haveadditionally contracted the semisubOceanEn-

deavor to resume exploration drilling on thedeepwater part o the block late this year orearly next, one aim being to assess last yearsDomino gas discovery.

Russia

Around the turn o the year, Gazprom ex-pects to complete an updated developmentplan or the Shtokman gas and condensatefeld in the Barents Sea. Current ocus ison design and survey operations or the

oshore inrastructure and the marine portwith LNG storage acilities. Design workcontinues on related onshore acilities.

Rosnet and ExxonMobil have signed f-nal agreements concerning establishmento an Arctic Research Center in Russia. This

will provide a wide range o R&D to supportthe two companies joint oshore activities,including sea ice management and design odevelopment concepts.

Mediterranean SeaOLTs oating storage re-gasifcation unit

Toscana has sailed rom Drydocks World inDubai to western Italy. As a oating LNG re-ception terminal it will be moored permanent-ly 19.3 km (12 mi) o Livorno and connectedto shore via a gas export pipeline. The steelmonohull vessel, a conversion o the ormerLNG carrierGolarFrost, has storage capacityo 137,100 cu m (4.84 MMc) o gas, and is de-signed to remain at the location or 20 years.Saipem is the main contractor or the project.

First asttrack datasets are available romPGS newly acquired 2D multi-client seismicsurveys oshore western and southern Greece.

The company compiled 12,500 km (7,767 mi)o new data using its GeoStreamer technologyto remove receiver and resource ghosts. Theull results, and reprocessed vintage 2D data,

will be available to bidders or Greeces nextplanned licensing round in mid-2014.

Caspian Sea

The BP-led Shah Deniz consortium haschosen the Trans Adriatic Pipeline to trans-port gas rom the Shah Deniz II oshoredevelopment in the Azeri sector. This latestphase, still to be sanctioned, will produce up to16 bcm/yr, in addition to the 9 bcm/y alreadydelivered by Shah Deniz felds frst phase.

The gas will head west across Turkey throughthe new TANAP onshore pipeline, transer-ring to the start o the 20 bcm/yr TAP line atKipoi on the Greek border. TAP will continuenorthwest through the Balkan countries osoutheast Europe, and rom Croatia a 115-km(71-mi) section will traverse the Adriatic Sea,

making fnal landall on the Italian east coast.

North Caspian Operating Co. (NCOC) hascompleted the acilities or initial oil produc-tion rom the Kashagan feld in the Kazakhsector, 80 km (49.7 mi) southeast o Atyrau.Because o the ultra-shallow and ice-prone

waters, and the high reservoir pressure o 770bar (11,168 psi), start-up will involve a care-ully staged sequence o steps leading to frstproduction. First oil and gas will ow romeight wells drilled on the man-made A islandto a subsurace depth o 4,200 m (13,779 t)below the North Caspian Sea. Production willramp up, with 20 wells eventually delivering
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G L O B A L E & P

180,000 b/d under the frst-phase pro-gram. Second-phase gas re-injection

will more than double production to

370,000 b/d.

Asia/PacifcTwo semisubs built at the Vyborg

Shipbuilding Plant in northern Russiawere due to drill wells this summeror Gazprom on the Kirinsky blockon the Sakhalin shel.PolyarnayaZvezda is resuming production drill-ing on the Kirinskoye gas/condensate feld 17 mi (27 km) oshoreSakhalin Island in 90 m (295 t) o water. This will be Russias frstsubsea development and is due to enter production later this year.SevernoyeSiyaniye will drill a urther exploratory well on the larger

Yuzhno-Kirinskoye feld, discovered in the same block in 2010. Therewill be urther exploration drilling on the Vostochno-Odoptinksyblock as part o the Sakhalin II project, Gazprom said.

CNOOC has started oil production rom the Wenchang 8-3E feldin the western Pearl River Mouth basin in the South China Sea.Four producer wells have been drilled in water depths o 110-120m (361-393 t). In slightly shallower waters in the same region, thecompany has signed a production-sharing contract or block 28/03

with PetroBroad Copower; the latter will acquire 3D seismic dataand drill wells during the exploration period.

The Malaysian partnership o con-tractor MISC and abricator MMHEhave delivered the semisubmersibleplatorm or Sabah Shells Gumusut-Kakap project oshore Sabah. Thisis Malaysias second deepwater de-

velopment ater the Murphy-operat-ed Kikeh. Partner Petronas Carigalisays the semi is the largest such a-cility ever ully built and integratedon land, and will be the largest o-shore operating system anywhere in

Asia. It arrived at its oshore loca-tion in June. SSPC will install the platorm in around 1,200 m (3,937t) o water.

AustralasiaINPEX Browse has been awarded a new exploration concession

oshore Western Australia. The WA-494-P permit, around 400 km(248 mi) northeast o Broome, extends over 305 sq km (118 sq mi)in water depths ranging rom 190-250 m (623-820 t). Discoveriescould be tied into the companys nearby Ichthys gas/condensatefeld development, and Shells emerging Prelude/Concerto FLNGinrastructure is also close.

OMV expects to drill the Matuku exploration well next monthoshore Taranaki, New Zealand. The semisubKan Tan IVwill drillthe well in license PEP 51906, with an estimated duration to TD o40 days. Matuku has estimated recoverable resources o 65 MMbbl,according to partner New Zealand Oil and Gas.

Polyarnaya Sveda mobilizing

for development drilling on Kirinsky.


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


Statoil seeking recoveryboost on sgard, Snorre

The crane barge Saipem 7000 has in-stalled the frst components or the subseacompression station serving Statoils s-gard complex in the Norwegian Sea. These

comprised the 1,800-metric ton (1,984-ton)subsea template that will contain the com-pressors and the module providing poweror the new subsea system, to be installed onthe sgard A production ship 43 km (27 mi)away. Water depth at the site is 300 m (984t). The 22 modules orming the compressortrains will be installed next year.

Assuming Statoil achieves its goal o veri-ying the compressor technology, the acilityshould be ready to start operating on sgardin 2015. Over time, the company expects the$2.9-billion project, which will compress upto 21 MMcm/d o gas, to increase recoveryrom the Midgard and Mikkel reservoirs

within the sgard area by 280 MMboe.

In the North Sea, the company has com-missioned what it claims is the worlds frst

well stimulation tanker, designed to boostoil extraction rom the producing Snorrefeld. Siri Knutsen, a ormer shuttle tanker,

was converted or the role and now eaturesa new mezzanine deck housing three resh

water modules, fve pumps, a control sys-tem, and a larger accommodation area.

Fresh water and sodium silicate will be in-

jected into Snorres E-4H water injector wellas a test case to increase oil output rom theP-15 production well. Previously on Snorre,Statoil has pumped water into the poroussandstone rock to press out oil; however,sandstone quality varies in dierent partso the reservoir, leaving large volumes un-swept. Sodium silicate is aected by thereservoir temperature, taking on a gel-likeconsistency that blocks the pores in the res-ervoir where water ows most easily, orc-ing the water to fnd new routes.

With the new injector well, hydrochloricacid will be added to the water mix to ad-

just the PH level. The company, which has

been working on the new technique since2008, says the planned pilot wells are in arelatively isolated segment o the reservoir.Halliburton and Knutsen are supplying theequipment and the vessel, at a total estimat-ed cost o $62.5 million.

Developments off IcelandThe Faroese government has awarded

Danish company DONG Energy two li-censes covering six oshore blocks in theFaroe-Shetland basin, under the islandsOpen Door license round. DONGs blocksextend over 900 sq km (347 sq mi), and are

west o the developed Foinaven and Schie-hallion felds, and the undeveloped Tor-nado. They also include Marjun, the solepublicized Faroese oshore oil discovery todate. DONG plans to apply new 3D seismicdata and in-house processing techniques toprogress prospects.

To the north, Icelands National EnergyAuthority Orkustonun is reviewing localcompany Eykon Energys application or thecountrys second licensing round in the o-shore Dreki area. The company submittedits original bid last year, on the understand-ing that it would need to bring in a biggerpartner to manage its planned explorationprogram. In June Chinas CNOOC steppedinto the breach Orksustonun is now re-

viewing the partnerships fnancial and tech-nical capacity to carry out the work, and willmake its decision on awarding the licensethis all. Norway has the right to back into

25% o any concession Iceland awards in thisoshore region, which is between the twocountries.

Breagh re-thinkFirst gas was due to ow this month rom

Breagh, one o the larger feld develop-ments in the UK southern North Sea in re-cent years. Operator RWE Dea and partnerSterling Resources are now turning their at-tention to Breagh Phase 2, ocused on theeastern side o the feld.

The project has been running behindschedule due to a combination o weather

delays and commissioning issues at the ter-minal in Teesside, northeast England, thatwill receive the felds gas. As a result, ac-cording to feld analysts BritBoss, capex isar beyond the $649 million budgeted. Onthe plus side, the perormance o the frstthree production wells drilled suggestsreserves may be higher than previouslythought, causing the partners to revise theirPhase 2 plan.

Sterling said well A03 appeared to pen-etrate a Carbonierous section with betterporosity and higher permeability. The sameapplied to the subsequent A05 well oncedrilling here is completed, the geological

model or the north/northeastern parts othe 80-sq km (31-sq mi) feld will be refnedand the new well data will be used or Phase2 adjustments.

Phase 1 is based around an unmanned 5,400-ton platorm on the western part o the feld

built by Heerema Vlissingen in the Nether-lands. The gas will be exported to Teesside viaa 100-km (62-mi), 20-in. subsea pipeline with a9-km (5.6-mi) onshore section.

In the UK central North Sea, Antrim Energyis making a resh attempt to develop the smallheavy-oil Fyne feld, discovered by Mobil in1986. Antrim had planned to use Teekays cir-cular Sevan FPSOHummingbird Spiritas thecentral production system, with three subseadrill centers. But a poor result rom the EastFyne appraisal well last year caused partnersPremier and First Oil to exit the license.

Now Enegi Oil and partner Advanced BuoyTechnology (ABT) have agreed to perormresh engineering studies based around ABTsmarginal feld production buoy concept withoil ooaded to a tanker. I they can make theeconomics work and Britains governmentapproves their entry into the license on a 50-50 basis with Antrim this could be the NorthSeas frst unmanned buoy development, al-though Energi/ABT have other applicationoptions elsewhere in the UK sector.

UK attractionsremain strong

Wood Mackenzie orecasts 44 billion($66.5 billion) o development capex across

the UK continental shel over the next fveyears. The analysts, marking 40 years o re-porting on the sector, add that currently 126companies hold interests licenses oshorethe UK. Although this is way below the 292present in the sector in 1973, it is still thehighest total in any European country.

Another big change since those early dayso UK North Sea production is that today,more than 60% o the sectors commercial

value and three-quarters o operatorshipsare held by companies that are not majors.

And ollowing CNOOC and Sinopecs dealswith Nexen and Talisman last year, Chinese

companies will produce around 10% o UKliquids during 2013-2017, the analysts claim.Since the frst UK oshore felds were de-

veloped, nearly 300 billion ($453.5 billion)in 2013 terms has been invested in upstreamdevelopment, they add. During 2012 UKCSdevelopment spending reached 11 billion($17 billion), similar to levels in real termslast seen in the mid-1970s. Although this canpartly be attributed to cost ination and thehigher costs needed to develop more chal-lenging reserves, it suggests that the sectorremains vibrant. And despite its maturity,the country still ranks as a Top 10 destina-tion or investment globally.

Saipem 7000 has installed the first sgard subseatemplate. (Photo courtesy yvind Hagen, Statoil)


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


New study analyzes deepwaterGulf production, operating cost

Zi Energy recently completed the 9th edition o its Gul o MexicoDeepwater Improving Field Perormance (IFP) study, which evaluatesthree years (2010 to 2012) o operations perormance or 24 deepwaterproducing assets in the GoM.

Participation included six deepwater operators, with majors such asShell and Chevron and leading independents Anadarko and Murphy tak-ing part. The study participants collectively account or 736,000 boe/d totalproduced in the deepwater region and $887 million in operating expense.

The study says that the GoM deepwater region represents the mostimportant domestic oil supply area or the US, with the Permian basin,Bakken, and Eagle Ford onshore plays accounting or the other notabledomestic supply areas.

In recent years, operators have developed many new world classdiscoveries in the GoM deepwater areas, the study notes. But it alsopoints out that in 2011, production ell in the wake o the Macondoincident. Deepwater oil production in 2012 was stable, the study says,but has not recovered to the pre-Macondo level. By way o contrast,the gas production decline was more signifcant, and the current levelo 2 bc/d is only hal o the peak reached in 2003-4.

The average unit operating cost ($/boe) in the deepwater Gulduring the past two years has increased signifcantly (about 45%higher) relative to 2010 as a result both operating cost spending in-creases (the primary actor; up over 40% between 2011 and 2010)and production declines (down about 10%). However, at less than$5/boe opex, the oil netbacks are highly attractive.

This years study updated the Operating Cost Efciency and UptimeReliability Metrics last measured in 2011 with the 8th Edition. This year,Zi Energy collected data or 2011 and 2012 and conducted extensive

trend analysis over the three-year period 2010 to 2012 at both feld andcompany levels. Zi Energy says that its database o historical costs in thedeepwater, which goes back to 1998, allows it to examine cost trends overmore than a decade, covering the lie cycle o a number o felds.

The study analyzes the eectiveness o each participants oper-ating philosophies on production loss control, surace repair and

maintenance programs, stafng levels, logistics, and chemical andwell servicing programs, said Shuqiang Feng, Zi Energys projectmanager or the study. The study identifes key opportunities tolower operating cost in these areas by benchmarking new key per-ormance indicators (KPIs) or operations, such as asset complexityactor, stafng index, and energy index. The study also identifeskey opportunities to improve production efciency and reliabilityby benchmarking production uptime perormance metrics. The up-time metrics are based on analysis o daily production and includedeerred production, mean time between downtime incidents(MTBI), and mean time to recover production (MTTR). Zi Energyalso collects inormation on the reasons or downtime incidents tounderstand why production is being lost.

Zi Energy says its deepwater study ound a surprisingly wide rangeo uptime perormance, which indicates an improvement opportunityor industry wor th hundreds o millions o dollars o annual revenue.

The study examined deerred production or 2012 associated withplanned and unplanned downtime by type o cause: acility ailures (on theplatorm), well ailures (subsurace), midstream and market (e.g. pipeline),reservoir, weather, and other external causes. Weather was a signifcantactor in 2012. Zi Energy notes that the value o the unplanned deerment($1.7 billion) was 1.9 times the total opex ($0.9 billion) o the assets.

Olympus TLP leaves for Shells Mars BThe OlympusTLP has departed the Kiewit Oshore Services yard

in Ingleside, Texas, bound or Shells Mars feld in the MississippiCanyon area o the Gul o Mexico.

The 120,000-ton TLP, believed to be the largest ever deployed inthe Gul o Mexico, will be moored in 3,000-t (914-m) water depths

about 1 mi rom the existing Mars platorm, which started produc-tion in 1996. The new TLP hosts a 24-slot drilling unit and includescapacity or six subsea wells to gather production rom the nearby

West Boreas and South Diemos felds.The platorm, centerpiece o what Shell has dubbed the Mars B

development, has a production capacity o about 100,000 boe/d. Theproject is expected to extend the feld lie o Mars to at least 2050.

Apache to sell GoM shelf assetsApache Corp. has agreed to sell its GoM shel operations and

properties to Fieldwood Energy or $3.75 billion. Fieldwood is anafliate o Riverstone Holdings.

Apache will retain 50% ownership interest in all exploration blocksand in horizon below production in existing blocks.

The e ective date is July 1, 2013, and the project closing date isSept. 30, 2013, subject to regulatory and closing conditions being met.Apaches shel to 1,000 t (305 m) water depth comprises more

than 500 blocks with 1.9 million net acres and year-end 2012 esti-mated proved reserves o 133 MMbbl o oil and natural gas liquids,and 636 bc o natural gas. In 1Q 2013, the felds averaged net pro-duction o approximately 50,000 b/d o l iquid hydrocarbons and 254MMc/d o natural gas.

The shallower horizons in the Shel have matured to the point thatdependable production growth is more difcult to achieve than romour onshore liquids plays, said Steven Farris, chairman and CEO o

Apache. We remain excited about the potential associated with theemerging plays under existing salt domes, which is why we retained50% o the deep rights on 406 blocks held by production and 50% o allrights in 146 primary term blocks.

Deepwater production in the GoM, 1995-2012. (Courtesy Ziff Energy Group)

Deepwater average unit operating cost, 2006-2012. (Courtesy Ziff Energy Group)


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


Deep, ultra-deepwater capexto continue growing to 2017

Infeld Systems ninth Global Perspectives Deep and Ultra-deep-water Market Report to 2017 sees capex in those depths to growover the next fve years.

The orecast is or water depths o 500 m (1,640 t) and more.

Demand is pushing exploration urther oshore into harsherand deeper waters, says Infeld. Deepwater reserve additions areexpected to remain a marginal proportion o overall global produc-tion; rising rom a 7% cumulative share o global reserves in 2012 to10% by 2017. In capex terms, the deepwater market, which requireshigher capital expenditure than its shallow water counterparts, isexpected to rise rom a 38% share in 2012 to a 53% share o globaloshore capex by 2017.

Even with attention centered on the Deepwater Triangle o Bra-zil, West Arica, and the Gul o Mexico, Infeld sees support com-ing rom less traditional deepwater arenas such as Southeast Asia,

Australasia, and Europe. Substantial growth is also predicted or theMiddle East and Caspian.

Brazil is expected to lead the deepwater market with spending onthe Lula and Franco developments.

The GoM deepwater action will be led by Shell, with a 24% marketshare o capex including the ultra-deepwater development at Stonesand Appomattox.

While West Arica will continue to lead the continent, deepwateractivity is expected to increase oshore East Arica, particularly theProsperidade complex oshore Mozambique.

The key felds expected to go on produc-tion through 2017 oshore Asia, include Li-

wan o China, Shells Gumusut-Kakap oMalaysia, and Chevrons Gendalo-Genhemoshore Indonesia. New developmentso Brunei, Myanmar, and Sri Lanka areexpected to emerge toward the end o theorecast period.

The Aasta Hensteen deepwater feld o-shore Europe is expected to be the thirdmost capital intensive project developedglobally during the orecast period. That

will give Statoil the largest market share,with other capex coming rom Chevronat Rosebank and Gazprom on the SouthStream project.

Deepwater oshore northwest Aus-tralia has seen capex rom Chevron andExxonMobil at Greater Gorgon, andExxon is expected to continue spendingon Jansz and Scarborough.

The Middle East is the smallest mar-

ket or deepwater capex. Even so, NobleEnergy gas developments oshore Israeland BP at Shah Deniz o Azerbaijan willsee considerable capex.

Exxon awards EPC forJulia in deepwater GoM

Exxon Mobil has awarded engineering,procurement, and construction (EPC) atits deepwater Gul o Mexico Julia feld toMcDermott.

Julia Phase I project is a subsea tiebackto a semisubmersible oating productionunit and the scope includes six subsea

wells, one six-slot maniold, two umbili-

cals, six jumpers, two owlines with two steel catenary risers, twosubsea pump modules, and topsides support equipment. Production

will ow through two 10-in. production owlines with subsea single-phase boost pumps.

Julia is 265 mi (426 km) southwest o New Orleans in the WalkerRidge area in water depths o approximately 7,000 t (2,134 m).

McDermott will undertake engineering, procurement, and con-struction o the jumpers, our suction piles associated with the mani-old, subsea pump, pump transormer, and subsea distribution unit/umbilical termination assembly (SDU/UTA), as well as transporta-tion and installation o the maniold, suction piles, ying leads, subseapump system, the power and control umbilicals, and SDU/UTAs.

McDermott will also carry out testing o the tieback system andmechanical completion beore hand over to the customer.

McDermott deepwater installation vessel Derrick Barge 50is ex-pected to install the suction piles and subsea equipment, includingthe maniold, pump station, and transormer. The vessels new deep-

water lowering system has the capability to lower loads o up to 480tons to depths o up to 11,500 t (3,505 m).

In addition,North Ocean 102is scheduled to transport and installumbilicals, ying leads, and jumpers.NO102is a ast-transit vessel

with horizontal carousel. Recent improvements include installationo a high-capacity exible-lay system to enable ultra-deepwater in-stallation work comprising a 330-ton top-tension ex-lay tower,

with 275-ton active heave compensation crane and 330-ton hang-oclamp capable o lowering loads to a depth o 10,000 t (3,048 m).

The o shore installation is expected to begin in 2Q 2015 and ex-tend through 2015.

Aker Solutions winsits largest-ever UKsubsea contract

Aker Solutions has won a contract worthup to $440 million to deliver subsea produc-tion system or an oil feld in the UK North

Sea.The delivery includes 25 subsea trees,

six template maniolds, and associatedcontrols, wellheads and tie-in equipment.

This is the single-largest subsea contractthat weve won in the UK, said Alan Brun-nen, head o Aker Solutions subsea business.

The order includes technologies new tothe UK, including maniolds and trees thatcan enable the use o hydraulically sub-mersible pumps to improve oil recoveryand ow assurance. Aker will also providediverless horizontal tie-in systems andslim line rigid lockdown wellheads.

Aker, at Fornebu in Norway, will handlecentral management, engineering, and pro-curement or the project. The companys

Tranby acility outside o Oslo will manuac-ture the subsea trees, while production othe maniolds and system integration test-ing will be at the companys oshore yardin Egersund on the west coast o Norway.

Aker Solutions subsea operations in Aber-deen will manuacture the control systemsand wellheads. It will also provide liecycle-support services.

The frst deliveries are scheduled or thefrst hal o 2014. Aker Solutions has withheldthe name o the feld and the operator.

Oil Spill Response has opened a new base at Loyang

in Singapore. The facility also has taken delivery of

a fourth subsea capping stack that can be mobilized

throughout the Asia/Pacific region. The location is ex-

pended to 9,500 sq m (102,257 sq ft) and has a storage

area for response equipment and dispersant systems,

dedicated warehouse for subsea well intervention

equipment, an emergency operations center, and train-

ing/office space for 100 staff.


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


Hercules spins oUS litboat feet to All Coast

Newly ormed Houston marine services company All Coast hascompleted the acquisition o Hercules Oshores domestic litboatfeet. The $57.5-million deal includes 29 active litboats, ranging romclass 105 to class 229, as well as 10 cold stacked units. All Coast Vice

President and COO Byron Allemand said the company is retainingsome 300 Hercules Oshore employees as well as the companysoperations center in Laayette, Louisiana.

Edison Chouest feet set to growEdison Chouest Oshore announced plans to increase its feet

o oshore service vessels by more than 40, most o which will bebuilt at the companys aliated shipyards on the US Gul Coast andBrazil. The newbuilds will include 17 diesel-electric platorm supply

vessels 312 t (95 m) in length, two high ice class AHTS vessels oruse in the Arctic, our subsea construction vessels or the Gul oMexico market, and 22 other vessels covering a range o oshoreservices. The company also said its C-Port 3 terminal in Port Four-chon, Louisiana, would be in operation by March 2014, and that a

urther expansion, C-Port 4, is in the design phase.Seadrill, SapuraKencanaink contract with Petrobras

A joint venture o Seadrill and Malaysias SapuraKencana Petro-leum Berhad has been awarded a contract worth $2.7 billion withPetrobras or three pipe laying support vessels. The JV Sapura Naveg-ao Martima will operate the three newbuild vessels or Petrobrasor a period o eight years, with an option to extend or another eight.

Work is scheduled to begin oshore Brazil in 2Q 2016. The vesselswill be built in the Netherlands at a cost o about $800 million.

Petrobras pads Subsea 7 order bookSubsea 7 won three contracts with Petrobras worth a combined

$1.6 billion to construct and operate three newbuild fexible pipe-

lay support vessels. The new vessels, to be delivered rom the IHCMerwede shipyard in Holland in 3Q 2016, 4Q 2016, and 2Q 2017, aredesigned to operate in 3,000-m (9,843-t) water depths. Constructionand commissioning costs will run about $950 million; the contractscover a service period o ve years.

Petrobras also extended a contract with Subsea 7 or theNormanSeven pipelay support vessel. The ve-year extension, beginning in4Q 2013, is worth approximately $400 million.

Cat-B semi or NCS cancelledCiting technological hurdles, Aker Solutions and Statoil have

cancelled a $1.9-billion agreement announced in April, 2012, or aCategory B semisub capable o perorming year-round well inter-

vention and drilling services oshore Norway. The technologydevelopment required to build the rig proved considerably moredemanding than initially anticipated, Aker Solutions said, leadingto the mutual agreement to scuttle the project. Unortunately, thetechnological issues werent solved in the initial system denitionphase o the project, said Per Harald Kongel, regional president orNorway at Aker Solutions. We still believe in the concept o Cat B,but the technology needs more time to be developed. The proposedrig would have operated in shallower waters up to 500 m (1,640 t), arequirement that proved to be particularly challenging, Aker said.

Atwood orders ourth UDW drillshipAtwood Oceanics has exercised an option with Daewoo Shipbuild-

ing and Marine Engineering or a ourth ultra-deepwater drillship,

to be named theAtwood Archer. The new drillship, scheduled to bedelivered by the end o 2015 at a cost o approximately $635 million,is a DP-3 dual-derrick rig capable o operating in 12,000-t (3,658-m)

water depths. The Houston-based driller has until March 31, 2014,to exercise an option with DSME or a th ultra-deepwater drillship.

PPL jackup backlog growswith Oro Negro order

Sembcorp Marines PPL Shipyard has secured contracts worth acombined $417 million to build two jackup rigs or Mexicos Integra-dora de Servicios Petroleros Oro Negro. The rigs are scheduled ordelivery in 2015 and will bring to six the number o Pacic Class 400

jackups under construction at or Oro Negro at PPL. The rst twounits are slated or delivery next year.

Dockwise transported the 23,000-ton Lucius truss spar from Technips

Pori, Finland, yard to the Kiewit Offshore Services facility in Ingleside,Texas. Dockwise, acquired by Boskalis this year, used the Mighty

Servant 1 vessel for the journey of 7,700 nautical miles. The spar will

be installed at the Anadarko-operated Lucius development in Keathley

Canyon block 875, and will be capable of producing 80,000 b/d of oil

and 450 MMcf/d of gas. First oil is scheduled for 2014.

Dolphin Drilling held a naming ceremony for a new drillship under

construction at Hyundai Heavy Industries in Korea. The ultra-deepwater

drillship, christened Bolette Dolphin, is scheduled to begin service this

year under a four-year contract with Anadarko. The 751-ft (229-m) long

vessel is equipped to drill in water depths up to 12,000 ft (3,658 m).

(Photo courtesy Dolphin Drilling)


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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


Almost 150 years ago, the world was treat-

ed to a novel by French author Jules Vernethat set the stage or todays reality. 20,000Leagues Under the Sea told the story o thesubmarine Nautilus and its intrepid CaptainNemo whose underwater adventures capti-

vated readers who could not conceive o suchpossibilities.

I Verne had been able to attend the 2013Oshore Technology Conerence (OTC) inHouston, he would have been thrilled to seethe maniestation o his vivid imagination orperhaps he would have simply nodded andsaid, Its about time.

With its massive size and complexity, sub-sea equipment has wowed OTC attendees orseveral years. To their credit, the manuactur-ers o such equipment have treated audienc-es to spectacular exhibits o the real thing,rather than scale models or photographs.Like the parable o the blind men and the el-ephant, one could see people walking up andlaying their hands on the huge exhibits as ito convince themselves that they were real.

Huge subsea wellheads have been joinedby equally huge subsea processing modulesrom booster pumps and compressors toseparators, all linked by fowlines and jump-ers, that terminate at complex manioldseeding risers that lead to surace produc-

tion acilities.The entire network o subsea modules is

part o a system intended to enable and sus-tain production rom wells drilled in deep-and ultra-deepwaters, but until now, there hasbeen a missing elementasset management.

A fexible asset management systemmust be in place to enable production to beoptimized over time as reservoir conditionschange. Massive seabed systems must beable to adapt to deal with pressure decline,hydrocarbon depletion, fow assurance is-sues, and the changes in reservoir dynamicsbrought about by in-ll drilling. But without

measurements, they are like the blind mentrying to describe the elephant.

An integrated solutionOneSubsea, a Cameron & Schlumberger

company, made its debut at the 2013 OTC tooer a solution to subsea lietime reservoirmanagement. Cameron veteran Ed Will,

vice president Marketing & Strategy, said:By engineering subsea modules to includeand be compatible with downhole and sea-bed measurements, OneSubsea aims to pro-

vide a single comprehensive resource orintegrated subsea solutions. With accurate,

real-time measurements o critical reservoir

and production parameters, coupled with e-cient two-way data transmission to produc-tion management acilities, operators takingadvantage o the OneSubsea solution haveeverything they need to anticipate changesin reservoir dynamics in time to react withcost-eective remedies that keep productionfowing. The entire production spectrum,rom pore to pipeline, can be placed undercontinuous surveillance to optimize fowand maximize ultimate recovery. All data arecaptured in an historical database that repre-sents the entire lie o the reservoir.

The result o this broad integration ben-ets petro-technical services, allowing con-tinuous collaboration between geoscientistsand engineers rom both operator sta andtechnical services consultants who developreservoir characterization and productionsolutions over the lie o the eld. The resultis expected to deliver signicant improve-ments in the perormance o subsea devel-opment assets.

Will went on to explain that data fowrom drilling and early completions benetsengineering teams whose responsibilities in-clude maintaining ocus on strategic targetsand project execution plans.

Using powerul simulators that eed on

the latest data, engineers can test plans onpaper beore committing to actions and in-

vestments. Because proposals can be testedand evaluated beorehand, optimum elddevelopment solutions can be launched withcondence. This can reduce capital costsas well as operating expenditures, cut cy

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