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Imagination at work

Subsea Production Systems Engineers Ireland – Dublin Tony Pincombe – Regional Sales Leader Ashish Jain – Principal Engineer 7th October 2015

SUBSEA TREES SUBSEA CONTROLS POWER & PROCESSING SUBSEA WELLHEAD SYSTEMS

INTEGRATED INTELLIGENCE FROM FLOOR TO SHORE

Subsea products and services

SPS (Subsea Production Systems) = Trees+ Controls + Manifolds + Power & Processing

Power, boosting, and compression solutions for both mature and new field developments

Complete portfolio to cover diverse field types, water depths, and operating environments

Industry leading technology to enable safe and reliable operation of subsea production systems

SPECIALTY CONNECTORS & PIPE

FLOATING PRODUCTION SYSTEMS

WELLSTREAM FLEXIBLE PIPE SERVICE & SUPPORT

• Field service • Fleet and equipment • Storage and asset management • Triple S • SmartCenter

Dynamic risers, static flowlines, subsea and topside jumpers and fluid transfer lines to meet the demands of subsea and FPSO production.

TECHN

OLO

GY SO

LUTIO

NS

MANIFOLDS & CONNECTION SYSTEMS

Production Manifolds and connections portfolio to handle various field configurations

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Subsea Production Trees Subsea Controls Systems

EPC Field Development

Subsea Drilling Systems

Platform Aftermarket Products &

Services

Capital Drilling

Equipment TLP & SPAR

Systems

Subsea Processing, Boosting, Compression,

Subsea Manifolds Subsea Connections

The GE Oil & Gas World Surface Drilling & Completions

Onshore Surface Drilling &

Completions Offshore

Onshore Aftermarket

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© 2015 General Electric Company - All rights reserved

0 – 100m

“S Series”

SVXT

SHXT

100 – 750m

“M Series” MVXT MHXT

750 – 3000m

“D Series” DVXT

DHXT

Depth Vertical Horizontal

Subsea Tree Structured Product Landscape

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https://youtu.be/x8dXonwMjYw

Deep Water Vertical Tree Installation




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Downhole Pressure & Temp (DHPT) Cards

Transformer Module

Power Supply and Diplexer Cards

Data Acquisition & Control Cardframe

Power Supply Cardframe

Front End Assembly

Electrical Connectors

SemStar5 – the Brain behind subsea

GE’s Subsea Power & Processing Toolbox

Boosting Compression

Prezioso -92

Power Separation

KBS -92 Troll Pilot -99 Tyrihans -07

Increase Oil Recovery and production rate from maturing subsea wells

Remove water from oil stream at the seabed – and re-inject back into reservoir

Drive gas from matured subsea wells to host ..and all these systems

need power, delivered at the seabed


Imagination at work

Subsea Compression Game Changer for the Atlantic Margin

Ashish Jain – Principal Engineer 7th October, 2015



Atlantic Margin - Introduction

Offshore west of Ireland is largely unexplored and least understood region of Europe

The Irish Atlantic Margin Basins share similarities to Atlantic Margin hydrocarbon basins in the UK and Norway

The Corrib Gas Field in the Slyne Basin was successfully appraised and opened up a new play in the region. The field has estimated gas reserve of 1.0 TCF.

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“The Atlantic Margin from Norway to Ireland: geological review of a frontier continental margin province”, Shannon et. al., Petroleum Geology Conference 2005.


Atlantic Margin - Prospect Drilling by Providence in Dunquin North demonstrated presence of working petroleum system Ref: offshoreenergytoday

Recoverable resources at Spanish Point between 100 mmbo and 202 mmbo Ref: www.rigzone.com

Kosmos Energy identified two new prospects, Doyle A and Doyle B, prospective resources of 123 mmbo and 69mmbo

Europa Oil & Gas also identified two prospects, named Beckett, Wilde & Shaw, prospective resources of 760 mmbo and 493 mmbo Ref: offshore-technology

High interest by several operating companies in recently concluded licensing round further indicates the potential in the region

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Water depth range from 400m – 3000m, step out in excess of 100km

Ref: www.energy-pedia.com


Challenges for deep water field development

Deepwater and a harsh environment, is a high-cost environment for designing and development of any discovery

Conventional platforms are not feasible in deeper water

With offshore activities, personnel risk exposure is multifold

Flow assurance is a critical challenge,

o High pressure, high temperature developments

o Low ambient temperature

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Brage platform, North Sea, Norway Ref: offshore-technology

Field development with subsea system can offer techno economic viable solution


Subsea production system

The exploitation of subsea oil and gas fields is a mature industry that relies on qualified components and systems like subsea trees, flowlines, manifolds and electro-hydraulic control systems.

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Why subsea processing?

Subsea Processing Adding Value Green Fields

Long offsets Increased Recovery by Boosting

Deep waters Increased Recovery by Separation

Near shore Development Enabler

Small field Tie-in Alternative

Brown fields Increased recovery

Deck space alternative

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The evolution of more than 50 years of increased oil recovery

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Challenging market dynamics for technology investment

No. of subsea trees installed /yr [Quest]

0

150

300

450

600

1960 1980 2000 2020

20 years to adopt

Subsea boosting is at same stage as subsea trees were in c1981

0

50

100

150

0 10 20 30 40

Subsea boosting just reaching the

20 year mark

? Can we use the past to predict the future?


GE … Subsea, Processing and Power

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Power Conversion

Turbomachinery

Power Conversion

• Gas compression • Pumping

Power & Water • Water treatment

System design and integration: Components: • Controls • MECON connectors • Electrical actuators

• P/T sensors • Leak detection • Acoustic monitoring • Flow metering • RM&D

Measurement & Control

Subsea Systems

Drilling & Surface • Electrical submersible pumps

Processing System • Gas compression • Full Wellstream boosting • Seawater injection • Separation & boosting

• Topside power supply • VSD • UPS • Switchgear • Electrical motors


Title or Job Number | XX Month 201X 16



What is subsea compression?

Compression system on sea bed

Increased recovery by reducing back-pressure on the reservoir

Typically less pressure ratio compared to compressor at host facility, lower power need

Enable transport of wellstream over long distances (flow assurance concerns)

Reduces need for offshore manning

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Technology development based on conventional compression system

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Marinization of topside system Mainly suitable for larger fields

https://youtu.be/Ew1h9aU4odo

Ormen Lange Pilot , Nyhamna

Photo: Svein Roger Ivarsen / Norske Shell

https://www.youtube.com/watch?v=Ew1h9aU4odo

https://youtu.be/Ew1h9aU4odo


Exploring the subsea compression business case

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• Simple reservoir, production and pipeline model

• Rystad Energy … water depth, reservoir depth, step-out, reservoir size, plateau production rates

• CAPEX and OPEX for entire system from topside to subsea

• Time period 2012-2030

• Run on >1100 gas fields around the world

KEY CRITERIAOverall system CAPEX (Station with cables) (MUSD) 251 176 177 177 158 159 159 189Unavailability - A 0,050 0,036 0,036 0,036 0,031 0,031 0,031 0,037Unavailability - B 0,0005 0,0003 0,000 0,000 0,000 0,000 0,000 0,000System availability 0,950 0,963 0,963 0,963 0,969 0,969 0,969 0,963Cost of maintenance per year 1,8 1,6 1,6 1,6 1,2 1,2 1,2 1,6Minimum TRL 0 0 0 0 0 0 0 0Average TRL 6 5 5 5 5 5 5 5Development cost (MUSD) 0 0 0 0 0 0 0 0Time to market (year) 0 0 0 0 0 0 0 0

INTERVENTION VESSEL CALCULATIONNo of days for light vessel per year 7 6 6 6 5 5 5 6No of days for heavy vessel per year 15 12 12 12 12 12 12 12Days of lost production based on availability 18 13 13 13 11 11 11 14

PRESENT COST AFTER TAXESPresent cost of power MUSD 5 6 6 6 6 6 6 6Present cost of CO2 tax MUSD 1 2 1 1 2 1 1 1Present cost of NOX tax MUSD 0 0 0 0 0 0 0 0Present cost intervention MUSD 8 7 7 7 7 7 7 7Present cost of maintenance 2 2 2 2 1 1 1 2Present cost lost production MUSD 29 21 21 21 18 18 18 22Present cost insurance MUSD 8 6 6 6 5 5 5 6Present cost facility and personell MUSD 3 3 3 3 2 2 2 3CAPEX after tax 251 176 177 177 158 159 159 189Company cost on CAPEX after tax 25 18 18 18 16 16 16 19Total present cost 333 240 240 240 216 216 216 254

SAVINGS ESTIMATE TOWARDS BENCHMARKSavings only on compression station CAPEX (%) 31 % 31 % 31 % 42 % 41 % 41 % 24 %Savings on total CAPEX (%) 30 % 30 % 30 % 37 % 37 % 37 % 25 %Savings on total present cost (%) 28 % 28 % 28 % 35 % 35 % 35 % 24 %Savings on total CAPEX (MUSD) 75 74 74 93 92 92 62Savings on total present cost (MUSD) 93 93 93 117 117 117 79

Subsea compression concept evaluation tool

Market Need Technology choice

• Holistic view required while evaluating different system options

• Avoid simply moving cost around the system or shifting CAPEX to OPEX

Key findings from business case analyses

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Simplified, robust, low cost centrifugal wet gas compression system best option

• 245 target candidates between 2012-2030

• 217 fields profitable with compression

• 82 profitable with subsea compression

• 11 subsea compression best option

• 3 early subsea compression best option

• Almost 100% of profitable subsea cases

• <1500m, <2% LVF

• The largest savings are obtained with a system having only a wet gas compressor

• Lower savings on longer step-outs since the cable cost becomes dominant .


Next generation subsea compression

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• Dry gas compressor • Separate pump • Scrubber • AMB, AMBCS, UPS • Subsea VSD ~50km

• Wet gas compressor • No pump • Simple slug catcher/distributer • Topside VSD for longer stepouts


BlueC™ Subsea Motor-compressor

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• Vertical configuration

• Configurable from 4-20 MW

• Closed loop cooling system

• Single shaft line (rigid coupling)

• Canned Active Magnetic Bearings

Compressor designed for subsea


Wet gas compression challenges

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Technical Challenges

• Performance prediction

• Rotor dynamics

• Mechanics

• Droplets erosion

• Fouling

Considerable amount of experience from compression in wet conditions Strong foundation to develop centrifugal wet gas compression

Droplet erosion


3rd generation system design

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System and technology development by one integrated team

• Base design case … two train station for long step-out with two inlets

• Subsea power distribution

• All electric

• Integrated manifold providing full flexibility

• Active cooling

• Standard module sizes ... Simple intervention and sparing

• 6m x 6m x 12m (LxWxH): 60 tons

• 12m x 6m x 12m (LxWxH): 250 tons


Main wet gas compression system modules

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Three standard modules that can be used to build field specific systems

6 x 6 x 12 m 60 tons

Cooler Module HV Power Module

12 x 6 x 12 m 250 tons

Compressor Module

12 x 6 x 12 m 168 tons


Title or Job Number | XX Month 201X 26


GE Oil & Gas Subsea Power & Processing

https://youtu.be/yCYxmjwikJs

https://youtu.be/yCYxmjwikJs

Hypothetical Case study Corrib gas field Using web based information


Corrib gas field facts

Pipeline 20” (510 mm)

Design pressure 345 bara, Operating pressure of pipeline 90-110 bara

Composition: 97% methane and ethane

Onshore processing capacity 9.0MSCMD, About 10 years field life

Estimated GIIP, 1.0 TCF

Estimated recoverable reserves, 0.6 TCF

Onshore arrival pressure 85 bara

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Ref: offshoreenergytoday


Subsea compressor for Corrib gas field Prediction using GE in-house tool

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Additional 18% recovery achievable with subsea compressor One subsea compressor of about 8MW

Normalized production curves Normalized cumulative production


Possible solution for Corrib

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