developing shtokman field – a unique international … europe - shtokman... · 27.10.2010...

27.10.2010

Shtokman Development AG

Developing Shtokman field – a unique international energy project

Didier Bertrane

Subsea Europe Paris

Deputy Offshore Project Director

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Content

• Shtokman field overview • Key technical features• Subsea facility description

– Overall– SPS

• Project status / achievements

27/10/2010 Subsea Europe Paris: Shtokman Development - October 2010

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Shtokman Development AG (SDag)

• Scope– Organize, design, finance, construct

and operate during 25 years the “SHTOKMAN Phase 1 development“

– Production plateau of 23.7GSM3/year, 7,5mtpa LNG - 5% gas for local market, the rest piped to the North Stream pipeline Project

– SDag and its Shareholders support the technical & economical risks of the Phase 1 development.

• A single integrated and dedicated Project team Gazprom + Total + StatoilHydro

• Synergy of Russian and European cutting-edge skills and technologies– Sharing of knowledge and resources optimization


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Shtokman field overview


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SHTOKMAN Field• Gas & condensate field in the Russian

Barents Sea– Discovered in 1988– Super giant field: 3800GSm3

(135Tcf)– Water depth: 320-340m (1100ft),– Good gas quality and low GCF– Offshore at 550km (340mi) from

Kola peninsula– 7 discovery/appraisal wells

• Too large to be developed at once, – full field development in 3 phases

of 23,7GSm3/year (~2.4Bscf/d) each (400,000bepd)

– Phase 1: 7,5mtpa LNG & 11.2GSm3/y pipe gas

– Onshore plant near Teriberka, 120km (75mi) eastward of Murmansk


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SHTOKMAN field development

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1

27o

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64

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1

27o

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27o

A phased but unique development… 2 large projects in 1 (OFF & ON)

Wells InfieldSS layout Floater Trunklines

Receivingfacilities

LNG plant Gas pipeplant

Storage &loading

Exportcompressor

Onshoretrunklineto Vyborg

LNGcarriers

technical scope

GAZPROM scope

PHASE 1

PHASE 2, 3…

General PurposeInfrastructures Cond.

Utilities

Camp

OFF

ON


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Harsh environment: arctic conditions• Harsh metocean conditions

– Extreme conditions equivalent to Northern North-Sea, associated to rapid evolution of phenomena

• Polar Lows

• Icing– From atmospheric and sea-spray

• Low temperatures– Extreme lowest -40°C

• Snow– Twice more than in Sakhalin

• Polar night (3month/year)– From Dec. to Feb.

• Darkness, fog…

• Metocean parameters were validated by extensive measurements

– 8 years of observations on site & 1 year along trunkline

Barents SeaShtokman

20 50

Surface Current 0.9 m/s

Max Temp = 9.0°C

Min Temp = -1.6°C

Waves

Hmax 23.3m

Hs 12.5 m

Seabed Current 0.4 m/s

Wind 31.0m/s

Water depth: 320-350m

Polar low, Barents Sea, 27 Feb. 87

Constant challenges to HSE


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Ice & Iceberg conditions at Shtokman

• Ice occurs once in 2.6 years.– when occurs, stays in average 3.3

weeks but could be up to 3 months

• First-year ice with – thickness average 0.85 m, max 2.0 m – rare inclusions of second year floes

(<50 m)– Ice ridges keel up to 21 m deep

(locally)

• Ice drift reversals occur

• Icebergs – Collision probability with

FPU about 0.2 in 50 years, if not managed

– in open water and embedded in Sea Ice

Ice concentration

Shtokman field is unique by the combination of harsh metocean conditions and presence of ice and icebergs


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Shtokman Phase 1 development: main challenges

• Technical challenges– Size of the project– Remote location: 550km (340mi) from mainland

• Open sea, no other nearby development– Arctic environment

• Ice & icebergs, etc.• Polar lows• Icing

– Environmentally sensitive ecosystem– Operating conditions

• Weather season limitations � autonomy• Complex logistics, EER response time• Winterization (Offshore & Onshore)

• Organizational & human challenges– Local content– Human factor.


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Size of project

• Floater to process 71.2MSm3/d of gas (2.5Bcf/d), incl. FG

– One of the biggest floater worldwide– Ice resistant & disconnectable– Topsides > 40,000t– Flare size– Turret size & number of risers– Emergency Evacuation & Rescue

• Dual dry 2-phase 36” trunklines:– unique compared to all other 2-phase and

MPF pipelines:– Distance + rough seabed topography +

diameter

• 7.5mtpa LNG plant– A mega LNG train in a very remote area– Utilities & support (600MW PGU, service

harbor, camp, etc.)

2x36”x560km


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Content


– Overall– SPS



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• Good quality gas– No significant H2S– No significant CO2– Very low liquid content– Moderate reservoir temperature

• Low condensed water content– Moderate reservoir pressure

• 210 bar WHSIP

• High deliverability wells– Potential in excess of 10 Mm3/d– Top of the range Xmas tree (7")– 16" OD flowlines with 14" ID risers

• 350 m water depth– Deepwater diverless technology– Flexible pipe only choice for risers–– Trawling activity Trawling activity template architecturetemplate architecture

Key technical features for the subsea development (1/2)


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• Arctic environment– Need to accommodate FPU disconnection

• Flexible risers– Seasonal installation– Risk of severe weather conditions

• Large gas flow rate for export– Avoid "singing risers"– Redundancy

• Project size + expected 50 years operational life– Conventional solutions

• Hydrate prevention with permanent MEG injection• Looped flowlines

– Minimum qualification • Wet Gas Flow Meters

Key technical features for the subsea development (2/2)


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Content


– Overall– SPS



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Subsea facilities

6 x 4 Slots Production Templates

6 x 14" ID Infield Flexible Risers

6 x 16" ND Flowlines

4 x 14" ID Export Flexible Risers


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Subsea architecture - schematic

18 I-tubes for Risers and umbilicalsI-tubes

4 x 14" ID Smooth boreExport Risers

6 x 14" ID Rough boreInfield Risers

3 drill centers -> limited rig moves achieved by skiddingDrilling

Flowlines: 16"ND can be laid as well in S-lay, J-Lay or reel layInstallation

Umbilical with derivation to control the IRB + 2nd template in daisy chain

Umbilical architecture

Subsea choking and subsea Wet Gas Flow Meter

Flow Control Module

Topside to topside via riser, flowline & pigging loop on template

Infield pigging

Single valve and connectors on simplified IRB

Risers connection to Flowlines

6 x 16" NDFlowlines

6 x 4-Slots templates(2 templates in series on 3 drill

centers)Template

Description

TRB

FP2 x 14"ID

2 x 16"ND

2 x 16"ND

2 x 16"ND

2 x 14"ID

2 x 14"ID

PA12PA14

PA13

PA11

PA02

PA01

PA03 A12 J0 wells2 J1 wells

1 J0 well1 J1 well +

1 back-up well

A2

PK14PK13

PK12PK11

PK04

PK02

2 J0 wells1 J1 back up well

K1

2 J1 wells + 1 back-up well

K2

PD11

PD13

PD02

PD01

PD04

PD14PD12D1

2 J0 wells1 J1 well

1 J0 well2 J1 wells +

1 back-up well

D2

4 x 14"ID

PLEM

PLEM

2 x 36" ND Trunklines

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Export system general arrangement


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Trunkline riser base and PLEM configuration with built-in redundancy

Foundations

Modules

16" remotely operated valve

16" ROV operated valve

36" ROV operated valve

4 x 16" spools

16" By pass2 Umbilicals


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Design: 2x36” trunklines to shore

• TWO phase flow design – optimized solution with two 36” trunklines– Nominal export rate per trunkline = 35 MSm3/d – full capacity per line = 38 MSm3/d – FPU discharge pressure about 150 bara, arrival pressure 60 bara

(packed up to 110 bara)– Onshore slug catcher capacity 2500 m3 (in two parts)

Осн.райз.

PLEMТрубопр.36”

К пробкоуловителю

PLEM Трубопр.36”

Осн.райз.Райзеры


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Subsea IMR and monitoring philosophy• Design life philosophy

– Category 1: 50 years service life (structural/static)– Category 2: 30 years service life with potential extension through Inspection

• Capability to retrieve (e.g. manifold)– Category 3 <30 years service life

• Modular design replaceable by Shtokman installation means (e.g. choke module/risers)

• Production parameters monitoring at drilling centres– Classical: P, T Hydrate inhibitor flow– Wet gas flow meters (with emphasis on formation water detection)– Sand production detection (acoustic + erosion & momentum sensor)– Acoustic leak detection (1 per template)

• Production line inspection– Looped configuration allowing surface to surface round trip internal pigging by intelligent pigs– External inspection (CP, visual inspection, geophysical survey, FLET)

• Trunkline inspection– Subsea pig launcher and receivers designed to accommodate intelligent pigs– External inspection

• Riser and riser system monitoring– Annuli venting and monitoring + polymer coupons monitoring– Visual inspection (including in the I tubes)– Midwater arch buoyancy


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Subsea Intervention and ROV Services• Typical ROV operations required will be:

– Assistance during ROT operations and subsea construction work – Operation of various ROV skids/tools (i.e. tie-in tools, torque tools)– Replacement of flying leads / cables / hoses. – Cleaning and high pressure water jetting – Replacement of subsea control

modules, choke modules and other replaceable equipment

– Visual inspections of subsea installations and pipelines


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Content• Shtokman field overview and brief history• Key technical features• Subsea facility description

– Overall– SPS



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Status (offshore part)• Main technical options selected for base case

– Offshore concept, sub-sea system, marine infrastructure configuration, onshore process…

– FEED (launched in Dec. 07) completed– Compensated call for tender for FPU completed– Qualification programmes completed for the subsea part

• Decision to de-couple LNG from Offshore scheme

• Moving towards two distinct final investment decision (FID)– One for offshore scheme– One for LNG plant

• Call for Tenders for Subsea, FPU, Trunkline in progress


Thank you!

developing shtokman field – a unique international … europe - shtokman... · 27.10.2010...

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