SUBSEASYSTEMS

The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

CONTENTS

01 02 03
THE FUTURE OF
SUBSEA IS HERESUBSEA CONNECT is our vision for
the future of subsea. It is focusedon fundamentally improving the
economics of subsea fields to
unlock real value for ourcustomers. We have aligned ourinterests with yours; our uniqueapproach drives early
engagement and integration
across our portfolio to deliver
outcomes that are fully alignedwith our customers' priorities.
Our portfolio influences 80% of
the project cost drivers andSubsea Connect can reduce theeconomical development pointby an average of 30% for theentire project – not just thesubsea scope.
Who we are

PROJECT CONNECT

RESERVOIR TO TOPSIDES TECHNOLOGY SOLUTIONS

At concept stage, we work directlywith our customers to develop
targeted project outcomes, andflexible project assessment. This
independent planning and risk
management, which integrates
subsurface, seabed, surface and
EPCI capabilities, radically
optimizes project execution. It
allows us to help customers push
the technical limits on process,project schedules and delivery
certainty.

Subsea Connect brings our entire
portfolio solutions, products andtechnologies together to deliver
real value in the form of outcomes.
Our Aptara™ TOTEX-lite subsea
system is designed for the life offield and uses standard, modular
and compact components thatcan be configured to suitcustomer requirements. Thisapproach brings shorter leadtimes and better value.

Early Engagement
Case Study: Teamwork Addresses
Harsh Realities West of Shetland

14
16

Case Study: Early Engagement Pays
Dividends Off West Africa
20
04

Our vision for the subsea
industry is built on collaboration& innovation 

06

Subsea Connect 

10Execution Capability

24

Case Study: Center of Excellence

26

Additive Manufacturing
Capabilities

30

Life of Field Services

32

Case Study: Retrievable HIPPS
Provide Life of Field Adaptability

38

Case Study: Upgrading andExpanding a Mature Asset

42

Reservoir to Topsides Technology
Solutions48
Aptara™ TOTEX-lite subsea systems 50
Subsea Wellheads

52

Aptara™ SFX Wellhead Solution

54

MS-80055

MS-70056

Ulti-Max Specialty Connector

57

Subsea Trees

58

Aptara™ Lightweight
Compact Tree60

D-Series for Deepwater62

M-Series for Medium Water

64

S-Series for Shallow Water

66

Subsea Choke Valves

67

SubseaControl Systems

68

SemStar5 Subsea
Electronics Module

70

ModPod Subsea Control Module

71

Master Control Station72

Subsea Communications
and Routing

74

Umbilical Health Monitoring76

Hydraulic Power Generation

77

Subsea Distribution Unit (SDU)

78

Umbilical Termination
Assembly (UTA)80

Multibore Hub Connection(MHC UTA)
Aptara™FLX360 Multi-Quick
Connection System
Subsea Manifolds andPipeline Products

Subsea Connections Systems

98

Vertical Clamp Connection
Systems (VCCS)

100

Horizontal Clamp Connection
Systems (HCCS)

101

Subsea Electric Solutions

102

All-Electric Production Systems

104

Advanced Intelligent
Completions

105

Electric Actuation

106

Rotating Electric Actuators (REA)107

Linear Electric Actuators (LEA)108

Electric Choke

109

81

Subsea Well Access Systems

110

82

Open Water Completion
Workover Riser (CWOR)

112

Installation and Workover
Control Systems (IWOCS)

113

84

Production Enhancement –Light Well Intervention

114

Subsea Test Tree (SSTT)

115
116

Aptara Modular
Compact Manifolds

86

Cluster Manifolds

88

Template Manifolds

90

Simplified Landing String (SLS)

Pipeline Products and Solutions

94

Aptara™ Flexible Pipe Systems,
Jumpers and Rigid Spools

96

Subsea Power andProcessing Systems

118

Subsea Boosting120™

Subsea Compression

122

Subsea Separation

124

Subsea Treatment and Injection

125

Subsea Power126

The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

04 05 06 07 08
FLEXIBLE PARTNERSHIPS &COMMERCIAL MODELSOur flexible partnership model
ensures that we work with thepartner best suited to ourcustomers’ specific needs – basedon geography, capabilities and arange of other factors. This allows
us to further meet customers’
needs and improve project
economics. From assessment andproject design to drilling, SPS-SURF
and Intervention, thesepartnerships reduce complexity
and accelerate speed-to-market
across the sub-surface, wells andsubsea.
Case Studies

SUBSEA CONNECT
SOLUTIONSDIGITAL ENABLEMENT

130

Case Study: Subsea Connect helps
Buzzard fly higher
132
Case Study: New chapter for Baker
Hughes’ Norwegian success story 136
Case Study: High-Temp Expertise
Keeps the LNG Flowing
140

We are layering criticaltechnologies with next-generation
digital solutions to drive greater
uptime and enhance productivity.
engageSubsea

148

Equipment Integrity Management 150
SPS – NAXYS Acoustic &Electromagnetic Monitoring
Solutions152

Well – SureSENS QPT ELITE
Downhole Gauges

153

Well – SureVIEW Distributed
Temperature Sensing (DTS)
and Distributed Acoustic
Sensing (DAS)

153

Riser SPIRE: Real-Time Sheath
Breach Detection System

154

Riser MAPS: Detection of
Unloaded Tensile Wires in Riser

155

Flow Assurance Management(Flow AM)156

SPS - VIRTUAL FLOW METER (VFM)156

SPS – DISTRIBUTED FLOWMETER (DFM)

158

Well – Downhole Flow Metering
Solutions (SureFlo™)

159

Riser DTS – Distributed
Temperature Sensing

160

Subsea Connect Solutions areoutcome-based solutions that wehave created to address specificcustomer needs and problems.
These solutions provide a seamlessapproach that brings together theentire Baker Hughes portfolio fromthe reservoir to the top side. This
minimizes interfaces and theassociated inefficiencies delivering
real value. Our ground-breaking
vision for the future of subsea wasdriven by one of the industry’s key
imperatives: bringing new anddisruptive thinking to the table.
Read about how we’ve brought
value to our customers throughthis innovative approach.
Subsea Connect Solutions

DETAILED SPECIFICATIONSAND DATA SHEETSSUBSEA 101

162

Seamless Tiebacks

164

Intervention Solutions

166

Selecting the optimal products
for your system needs is complex.
We have frameworks to guide yoursubsea design.
Subsea 101

170

Overview

171

Critical Factors

172

Functional assessments

177

Conclusion

181

We have structured our productportfolio with well-defined
specifications that meet customer
demand for vendor-led solutions,which slash capital expenditure,
reduce cycle time and increaseavailability, thereby reducing your
OPEX requirements. Our data
sheets provide clear information
about our product families and theavailable models and options tomeet your needs.

182

01

The Future
Future ofof
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

01

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets02

The Future
Future ofof
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

THE FUTURE
OF SUBSEA
IS HERE

Digital Enablement

Subsea Connect
Solutions

Baker Hughes has unparalleled capability and expertise
across the upstream value chain. Subsea Connect is our new
approach to connect the entire subsea development process
and reduce life-of-field development costs by 30%. ThroughSubsea Connect, we connect the entire subsea development
process from the concept phase and support customers in
optimizing the initial CAPEX spend and the life-of-field, offering
an improvement of up to 80% of project development costs.

Subsea 101

Detailed Specifications
and Data Sheets

03

Who we are04

Our vision for the subsea industry
is built on collaboration& innovation

06

Subsea Connect

10The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Detailed Specifications
and Data Sheets

Subsea 101

04

WHO WE ARE
9,000+400

Our capability at a glance

Employees

Field service
engineers (FSEs)

1,000+
8,000

MexicoHoustonBristol, UK
Montrose, UK
Nailsea, UK
Inverurie,UK

PolandItaly

AngolaXTs Installed
Base

Azerbaijan

Saudi Arabia
Nigeria

Qatar
India

China
VietnamIndonesia
Singapore

Niteroi/Maca
Jandira

Manufacturing
Services
Manufacturing/services
Global engineering

RentalAssetsGlobal:1,434

NorwayCalgaryEng
Capability

PerthThe Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

You can rely on us
As a world-class subsea life-of-fieldequipment and services provider we deliver
optimal solutions for our customers by using
smarter technology, integrated capabilities
and digital innovation. We have been
inventing solutions that have defined the
upstream oil and gas industry for the past 114
years. Our commitment to innovation ensures
we will continue to do so in the future.

Our people
Our project teams have delivered projects
successfully all around the world.
Together, we have pioneered innovative
approaches to solve many of the problems
you face. In fact, we have invented several of
the solutions in use across the industry today.
That’s why we are ideally placed to ensure
you continue to overcome these challenges.
We have more than 1,000 engineers focusedon project execution as well as inventing new
products that will make our industry more
efficient and productive.

We have more than 1,000 engineers
focused on project execution as well as
inventing new products that will make ourindustry more efficient and productive.

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The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

OUR VISION
FOR THE SUBSEAINDUSTRY IS BUILTON COLLABORATION& INNOVATION
At Baker Hughes, our overriding mission is to develop and delivercompetitive and innovative subsea solutions that meet theeconomic and technical requirements of our customers while
simultaneously addressing low-carbon imperatives.

INTRODUCTION
By Neil Saunders
Executive Vice-President
Oilfield Equipment

While using standard “make-to-order” products,
we have designed our outcome-based solutions to
be configured to suit individual customer priorities
across the volatility of the upstream cycle.

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The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Subsea Connect embodies our vision of acollaborative approach with our partners
and customers to deliver outcome-based
solutions that leverage our wide portfolio of
innovative technologies and solutions.
We are committed to delivering projects thatmaximize efficiencies, mitigate risks andreduce uncertainties across all our subsea
operations. Our target is an average 30%
reduction in development costs which we
aim to achieve via innovative solutions thatcombine technological advances, earlyclient engagement, tailored contracting
strategies and a collaborative approach thatmaximizes the value of our wide portfolio
across Baker Hughes.
We believe disruption will continue to change
the energy industry for the foreseeable
future; so, while using standard “make-toorder” products, we have designed ouroutcome-based solutions to be configured
to suit individual customer priorities acrossthe volatility of the upstream cycle. We
believe enhanced productivity can beachieved by reducing non-productive time,
lowering development costs per barrel andimproving recovery rates on an ongoingbasis. We have also developed a suite ofseamless integrated solutions that aredesigned to maximize recovery and extend
the life of existing fields. In addition to
maximising financial returns this approachhas the added benefit of reducing thecarbon intensity of the producedhydrocarbons (as compared to drilling
additional wells).

Detailed Specifications
and Data Sheets

The Baker Hughes subsea toolkit has beenbrought together here in this catalogue andincludes the pioneering Aptara™ TOTEX-lite
subsea system, Subsea Connect Intervention
Solutions, Subsea Connect Seamless
Tiebacks, as well as technological solutions
like subsea power and processing. We also
pride ourselves on embracing new businessmodels that match today’s economic
realities: innovative financing, flexibile
payment models, advanced project
management, dedicated software
applications, and integrated data analytics.

Proof through action
As always, actions speak louder than words.
And one of the many landmark
achievements that has been influenced by
our Subsea Connect vision is the Greater
Tortue Ahmeyim gas field off West Africa –see page 20 – where Baker Hughes
collaborated on the front-end engineeringand execution-readiness phase to define thetechnology and equipment scope for an
initial four-well development.
This BP field some 120km off Mauritania andSenegal is in 2,850 metres of water, holds 15
tcf of gas and is expected to produce 2.5
million tonnes of LNG per year. In addition to
spearheading a large-bore, high-pressure
subsea system, our digital condition
monitoring and asset performance
management technologies will deliver
reliability through the life of the field.
The project is the first in the basin to reach
FID and represents the opening of a new
deepwater gas value chain to monetise LNG
reserves in Africa and beyond. Influenced by
our Subsea Connect vision, all involved
signed an integration agreement to support
collaboration, drive project synergies andreduce time to delivery.

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Project Connect

Reservoir to Topsides
Technology Solutions

Meeting our climate
responsibilities
At Baker Hughes, we believe that leadershipin the ongoing transition to low-carbon
solutions is both the right thing to do forthe planet and will open new opportunities
for business.
We are investing in smarter technologies
and solutions to cut our own operationalemissions by 50% by 2030 and to achieve
net zero carbon emissions by 2050. We arecommitted to rolling annual and three tofive-year targets to ensure we remain on trackwith a range of emission reduction initiatives
across manufacturing, supply chain, logistics,
energy sourcing and generation.
In addition, we continue to invest in a
portfolio of technology solutions that will help
our customers to reduce the carbon footprintof their operations. Technology is a coredifferentiator for us, and our disciplined
approach to product development allows us
to maintain our leadership and drive returns
from our investments in this area. Teams
across Baker Hughes have long adopted anagile approach to develop, test andcommercialize new technologies – such as
our Aptara™ TOTEX-lite subsea system that
has innovative reusable subsea tree caps –so that we can bring new reusable solutions
to the market faster. The results are real. The
Aptara™ tree has about half the CO2 footprintcompared to the previous Baker Hughes
standard vertical subsea tree.

Flexible Partnerships& Commercial Models

Digital Enablement

We continue to invest ina portfolio of technology
solutions that will help ourcustomers to reduce thecarbon footprint of theiroperations.

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

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The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Shaping the future
Under the Subsea Connect vision, Baker
Hughes is focused on fundamentally
improving project economics by aligning
our interests with our customers. The Subsea
Connect concept drives early engagement
to connect all the dots from day one, fromthe reservoir to topsides, and through thelife of the field.
Indeed, everything we do is defined by thiscore philosophy: help customers develop,
transport and refine hydrocarbons more
efficiently, productively and safely with asmaller environmental footprint and at alower cost per barrel. We deploy minds,machines and the cloud to break down
silos, reduce waste and risk, and apply
breakthroughs from other industries
to advance our own.

Detailed Specifications
and Data Sheets

We want to work more effectively alongside
our customers as our industry moves into a
new era in which solutions must not only bemore efficient and cost-effective, but mustalso meet the needs of the low-carbon
imperative that is now fundamental toall our thinking.
We want to be your partner rather than justyour contractor; talk to us about how ourunrivalled mix of technology, people andexperience can help deliver your project via
a shared win-win mindset on risk and rewardthat results in lower risks, an optimizedschedule, and the lowest possible costs.
Neil Saunders
Executive Vice-President
Oilfield Equipment

Our Subsea Connect vision is helping to shape
the future through radically optimized,
outcome-engineered, life-of-field solutions

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The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

SUBSEA
CONNECTThe global E&P market and the subsea
sector are both recovering steadily since thedownturn. FIDs are increasing and approaching
pre-downturn levels, while the industry has
displayed exemplary proficiency and discipline
to bring down breakeven prices of projects byan average of 30%. This has been achieved
through a combination of project design
optimization (including well placement andreservoir drainage), simplification, deeper
collaboration with the supply chain andprice deflation. It is tempting to think thatthe job is done. Baker Hughes believes
there is more to do.

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Our analysis indicates that reducing the
breakeven price of unsanctioned projects
by 30% unlocks an additional 16 billion
barrels of hydrocarbons. We need a new
way of doing business – to add value toplanned developments and to transformmarginal, uneconomic assets into cash
generating opportunities.
Subsea Connect is our approach for
fundamentally improving the economics
of subsea – using a uniquely integrated
and collaborative approach. First, we startas early as the Opportunity and Concept
Evaluation phases to develop a uniquely
comprehensive and integrated approachto configure projects to suit the underlying
economics. We are making better
connections across the development
process with technology solutions
from the reservoir to topsides.
The supply chain is used to thinking only
about its individual siloes, while ourcustomers consider the complete projectand its economics across the entire
development when making investment
decisions. We have listened to our customers,
we understand and appreciate your priorities
and have aligned our interests with yours. We
look beyond CAPEX and consider the Total
Cost of Ownership. We go beyond installationand commissioning and design for the life offield. We look beyond cost and focus on areal and measurable “TOTEX-lite” approach
which is the cornerstone of Subsea Connect.
It’s the manifestation of the deliberate andconscious alignment of our priorities withthose of our customers.
Baker Hughes is the only company in theworld that can connect the entire subsea
development process. From concept
selection through the entire life of field. We
can influence 80% of project development
costs and value drivers across the entire
project – not just the subsea scope. We canlower the breakeven price of the entire
project by 30%, unlocking more reserves andmarginal assets – making subsea projects
competitive with other projects. We deliver
this holistic value through the four key

Detailed Specifications
and Data Sheets

strategic pillars of Subsea Connect – and willcontinue to build capabilities in these areas:• Project Connect• Reservoir to Topsides Technology Solutions• Flexible Partnerships and Commercial
Models• Digital Enablement
This is profoundly different to what’s
been previously available on the market.
Nobody else has the breadth and depthof capabilities that we do. Second, we aretaking the technology further. Lastly, this isa partnership with our customers. We arealigning our interests with yours – flexible
solutions that don’t lock you in. A project thathas been delivered through Subsea Connect
has three characteristics:• Radically optimized – across the entire
project and not just the subsea scope.
• Outcome engineered – we take the timeto understand customer priorities andthen adapt the approach accordingly.
This is not a rigid cookie cutter approach.
As an example, customer priorities could
be lowest cost of development or
maximum recovery or fastest first oil.
Depending on the priorities there may be
trade-offs and the approach may need tobe adapted. Lowest cost of development
may mean a lower recovery factor. We do
not sacrifice standardization for this –instead, we deploy the standard solutions
or systems in a different way.
• Life-of-field solutions – Most suppliers
see their responsibilities ending at
commissioning and installation whereas
for our customers, that’s when life begins
and carries on for the next few decades.
When we design our solutions, systems
and products, we have taken that into
account and the life-of-field factors area big influence on our solutions, systems
and products as demonstrated by our
Aptara™ TOTEX-lite subsea system.

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Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

THIS IS SUBSEACONNECT

Flexible Partnerships& Commercial Models

Digital Enablement

It’s about deploying the very potent arsenalof Baker Hughes wide technologicalsolutions through the central framework of
Project Connect to drive real value. We havealigned our interests with yours and Subsea
Connect is the vehicle that makes it real.

Subsea Connect
Solutions

Subsea 101

While the most value from Subsea Connect
comes from early engagement we also
recognize and appreciate that different
operators have different preferences. Some
may and do indeed prefer to do some ofthese activities inhouse. That does not

Detailed Specifications
and Data Sheets

stop us from applying Subsea Connect or
our technologies to the project. Our flexible
approach allows us to adapt to suit thescope of work and to deliver solutions
that are: radically optimized outcome
engineered life-of-field solutions.

Subsea Connect: The four pillars

PROJECT
CONNECT

The Project Connect
pillar offers an integrated, streamlined
approach to contracting from theearliest stages – see page 12.

RESERVOIRTO TOPSIDESTECHNOLOGYSOLUTIONSThe Reservoir to Topsides Technology
Solutions pillar aims to transform theeconomic development point, productivity
and lifetime yield through reservoir
optimization, field design, lean wellconstruction, topside optimization, andproduction enhancement – see page 46.

FLEXIBLE
PARTNERSHIPS
AND COMMERCIAL
MODELS he Flexible Partnerships pillar representsTa shared risk and reward philosophy startingwith assessment and project design to
SPS-SURF solutions; partnerships provide
a comprehensive solution that reducecomplexity, offer integrated solutions andaccelerate speed to market – acrosssubsurface, wells and subsea and spanningthe fullstream – see page 128.

DIGITALENABLEMENTThe Digital Enablement pillar seeks toprovide better recovery, more uptime andlower risks via advanced analytics that
inform field planning, production
optimization, and asset performance
management – see page 146.

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Project Connect
Connect
Project

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions02

Subsea 101

Detailed Specifications
and Data Sheets

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Project Connect
Connect
Project

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

PROJECT
CONNECT
Project Connect is our
independent assessment
and project delivery
process; it integrates
subsurface, subsea,
surface, and EPCI
capabilities.

Project Connect provides the framework andapproach to connect early engagement,
our wide and deep capabilities and ourability to provide the optimal solutions
from Concept to Commissioning andover the Life of Field.
It drives the focus towards understanding
required project outcomes and thenderiving the optimum associated value
proposition around these. Early engagement
is part of our core capability – we haveinvested even more in building up thiscapability internally. Additionally, through
GCA (Gaffney, Cline & Associates) and io Oil& Gas Consulting – we can draw
on unparalleled expertise in adjacentdisciplines as well.

Project Connect is an integrated approach– starting at concept evaluation involving
design from the reservoir up. It connects
each system element, reduces and removes
interface. It unlocks value and accelerates
schedule by eliminating project recycle(revisiting previous steps) and reducing cost
overruns. This ultimately:• Promotes integrated end-to-end solutions• Manages risk and limits contingency• Provides efficiency and most importantly,
certainty.
Project Connect delivers a new level ofexecution certainty – one that is alignedwith your priorities. Working with the rightpartners, we can fundamentally change therealities of a given project. We believe that
we are the only company that can do this.

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

13

Early Engagement

14

Case Study: Teamwork Addresses
Harsh Realities West of Shetland

16

Case Study: Early Engagement
Pays Dividends Off West Africa

20

Execution Capability

24

Case Study: Center of Excellence

26

Additive Manufacturing
Capabilities

30

Life of Field Services

32

Case Study: Retrievable Hipps
Provide Life of Field Adaptability

38

Case Study: Upgrading andExpanding a Mature Asset

42

The Future of
Subsea is here

Project Connect

Reservoir to Topsides
Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

EARLY
ENGAGEMENT
For operators and the supply
chain alike, the demands on our
sector have intensified over the
past few years. Together with thegrowing need for hydrocarbons is
an unflinching desire to improve
performance and increase
shareholder value.

Early engagement, together withcollaboration and commercial innovation,
are key components of our Subsea Connect
strategy; designed to drive outcomes acrossthe total life of field. Project Connect, one of
the four pillars of our strategy - complemented
by Flexible Partnerships and Commercial
models – is about engaging earlier than everbefore, in an integrated manner, to maximize
value through the project lifecycle. The
earlier we engage, the easier it is for us
to effect change.
Project Connect is founded on bringing thecustomer on the journey from the earliest
point in the project lifecycle by offering ourstandard, fit for purpose solutions that arefocused on delivering the entire project
outcome needs. This pillar is the backboneof Subsea Connect, drawing in partnerships
and technologies as required.
Project Connect changes the project
development process, dramatically shifting
project economics by harnessing thebreadth of the Baker Hughes portfolio alongwith the right partners, the right technology
and the right commercial models. We apply
an independent and flexible assessment,
configuring a project to the economics andleveraging technology solutions from thereservoir to topside. The breadth of ourportfolio means we are the only company
in the world that connects the entire subsea
development process from the concept
phase, supporting our customers in
optimizing not just the initial CAPEX spend
but expenditure across the total life offield (TOTEX).

To further enhance the value in projectdelivery, we have a network of preferredpartners that help us to reduce
process inefficiencies and streamline
communications; supported bycommercial models that have been
designed to reduce uncertainty, remove
layers of cost and align participants to theproject goals. There is no one size fits all. The
key is having the flexibility to work together
to find the right model and solution that best
fits the project. In the end it is all about
driving breakthrough outcomes... the typeof outcomes that can completely reshapeproject economics or turn a non-viable
project into an economic success.
Baker Hughes’ early engagement team iscomprised of industry experts who work in
partnership with you from the initial stagesof your project. The purpose of this team andtheir Project Connect approach is to achieve
an alignment between your strategic targets
and the project execution plans. We support
you through front-end engineering anddesign (FEED) studies, to technology
development and delivery through tolife-of-field support.

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Project Connect

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Technology Solutions

Flexible Partnerships& Commercial Models

Digital Enablement

Subsea Connect
Solutions

Subsea 101

Detailed Specifications
and Data Sheets

Early engagement is all about startingwith the outcome in mind, to reduce risk

ASSESS

Project Connect

ECT
SEL

OPER
ATE

Reservoir &subsurface

PROJECT
CONNECT

TopsidesLean wellconstruction

E
FIN
DE

SPS &
SURF

Key features• Economic outcome assessment• Parallel tracks to compress ‘assess’ phase• ‘All hands’ dedicated project teams• Independent project management ability• Technology system configuration andproject integration• Flexible partners and solutions for the
project’s needs
Benefits• Execution certainty embedded• Collaborative and common purpose• Speed – get FID faster• Improved scheduleBaker Hughes credentials• Early engagement starting atconcept evaluation• Built-in capability: Gaffney Cline &Associates, io oil and gas consulting• Unparalleled expertise in reservoir
modelling, planning, project feasibility,
conceptual design, environmental
advisory, and asset late opportunities• Fullstream technology capability

15

DE
V
E
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Project Connect

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Technology Solutions

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Digital Enablement

Subsea Connect
Solutions

CASE STUDYTEAMWORK ADDRESSESHARSH REALITIES WEST
OF SHETLAND
Baker Hughes’ subsea team pursued an
innovative and groundbreaking approach topartnering and outcome-based contracting
to push down costs and increase certainty
at Siccar Point Energy's harsh-environment
Cambo field, West of Shetland.

Subsea 101

Detailed Specifications
and Data Sheets

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The Challenge
The Cambo field lies in 1,050 metres ofwater, West of Shetland, in what is one of
the harshest environments in the global
oil and gas sector. Operator Siccar Point
Energy is seeking to push the boundaries
of development in this region, which is initially
expected to feature around 10 gas-lifted
production wells, supported by up to four
dedicated water-injection wells tied backto an FPSO.
Key to realisation at Cambo is breaking
with convention through committed early
engagement with an approach in which
Baker Hughes designs and integrates thewells, SPS and SURF scopes in a collaborative
partnership with Siccar Point Energy.
Better harnessing of the skills and experiencein the supply chain is allowing Siccar Point
Energy to remain lean and agile with
reduced interfaces; strong relationships
result in a development that is more efficient,quicker to launch, with lower execution risks
and at the lowest possible cost.
Commercial drivers dictate an approachfeaturing more flexibility and trust overpricing structures as well as an increased
onus on performance which links financial
rewards for all parties to a successfulproject outcome.

1,050m (3,445 ft)
Cambo's water depth, 125km West of Shetland.

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The Solution
Baker Hughes took an innovative approach,analyzing the field development from thereservoir to the FPSO and designing asolution comprising well design, drilling
services, SPS equipment, flexible flowlines
and a collaborative partnership for
installation and commissioning services.

on evolving input data as subsurface
and FPSO solutions continued to progress.
Our willingness to challenge the traditional
operator-supplier norms will result insavings across CAPEX and TOTEX – delivering
a true TOTEX-lite solution designed for thelife of field.

Early engagement with the customer
allowed solutions to be tailored to their needs
while leveraging Baker Hughes' innovative
product catalogue, optimizing the subsea
architecture with standardized solutions,emerging Aptara™ technologies andextending across traditional supply
boundaries. This flexible approach also
facilitated ongoing improvements based

We are working closely with Siccar Point
Energy to explore the potential benefitsof deploying the Baker Hughes Aptara™
TOTEX-lite subsea system, including
lightweight, compact vertical trees,
manifolds and horizontal connections.
Baker Hughes will also provide completions,wellheads, flexible flowlines and risers andindustry-leading control systems.

It is all about being a partof the project’s success as
partners and collaborators
rather than simply suppliers.

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The Benefits
Siccar Point Energy has increased certainty
and reduced costs through its partnershipwith Baker Hughes, which allowed for a muchsmaller and leaner project team that could
access technical guidance and robust
prices, schedules and interfaces at a muchearlier stage of project development.
We were able to offer continuity andcooperation from initial concept throughto execution. We developed a relationshipbased on trust from the earliest stages,
leveraging Baker Hughes' extensive
experience of the field development strategy
and our understanding of the client's need.
All parties committed to a win-win
philosophy based on fairer models andfeaturing the ability to integrate subsurface
and subsea scopes from initial studies
through to final decommissioning, thecreativity to adapt equipment and service
models, and the leadership commitment
to prove a new way of working.

Enabling technology
Deepwater Lightweight Vertical Trees
Aptara™ HCCS-L Connection System
Deepwater Harsh Environment Flexible Risers

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CASE STUDY

Subsea 101

EARLY ENGAGEMENT PAYS
DIVIDENDS OFF WEST AFRICA
Baker Hughes spearheaded a fresh approachto FEED work to reduce costs and optimize
project delivery for BP's Tortue/Ahmeyim fieldon the maritime border of Mauritania andSenegal, where resources are estimatedat 15 tcf of gas.

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The Challenge
The Tortue/Ahmeyim gas field off West
Africa posed a three-pronged challenge todeveloper BP, starting with prolific production
wells that demanded a large-bore offtake
system. Complicating the flows were water
depths of nearly 3,000 meters, among thedeepest anywhere in the world, and a long
offset to control facilities some 80km away.
Collaborative, early engagement was requiredahead of the FEED studies from Baker Hughes
and subsea partner McDermott to meet thedemands for project optimization andintegrated solutions that would reduce costs
and streamline delivery. Baker Hughes

15 tcfEstimated resources at Tortue/Ahmeyim.

focused on the subsea production system
while McDermott defined the scope forsubsea umbilicals, risers and flowlines(SURF) with installation enabled throughits differentiated Amazon pipelay andconstruction vessel.
Tortue/Ahmeyim Phase 1a will initially feature
four wells, some 100km offshore, connected
through production pipelines to an FPSO
closer to shore. The expansion of Phase 1
is expected to require around eight further
wells with future phases 2 and 3 likely totake the well count to 40 to 50 in total.

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The Solution

The Benefits

We adopted a collaborative approach
during the FEED process that combined theexpertise, equipment and installation
services of the contractors as proven inprojects in Asia-Pacific, India and elsewherein Africa. Together with the client BP, a teamapproach was adopted that delivered
throughout the FEED process as a single unit.
This proven approach was subsequently
carried forward into full EPC contracts aheadof first gas in 2021.

Early engagement between Baker Hughes
and BP led to reduced costs and optimized
project delivery at Tortue/Ahmeyim, where
the initial contract has since transitioned
into a full EPC contract.

On this project, we are deploying large-bore
7" Deepwater Horizontal Production Trees andManifolds rated to 10,000psi working pressure– which have previously been qualified aspart of a system on a separate project also
in 3,000 meters water depth.
In addition, we are providing Remote
Operated Pig Launcher (ROPL) technologies
and are leveraging digital tools including
RealTrack for more efficient project
management and execution. The McDermott
vessel Amazon supplied deepwater J'Lay
pipeline capability.

Workscopes were optimized across the
project team, including on the supply
side, with efficiencies adopted on a
project-wide basis rather than confining
those benefits in the more traditional
fashion to individual contractors.
The development is a further proof pointof Baker Hughes' extensive knowledge ofdeep-water, large-bore gas systems.

Enabling technology
Large bore 7" Deepwater Horizontal Production Trees
and Manifolds 10,000psi working pressure; system
qualified to 3,000m water depth on another project
Remote Operated Pig Launcher (ROPL)
Digital tools including RealTrak Equipment Integrity
Management, Flow Assurance Management
10km of 8" production and 10km of 2.5" gas lift
flexible flowline jumpers including terminations
and bend restrictors

This further cements Baker Hughes’ role as a FEED
contractor with capabilities that extend to the entire
subsea scope.

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EXECUTIONCAPABILITY

Project execution is the coreof our Project Connect offering
to our customers.

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No two projects or customers are alike,so at Baker Hughes we listen and adapt.
Every project has a unique set of challenges,
like location, infrastructure, water depth,
reservoir conditions or field economics.
Similarly, every customer has a unique setof requirements formed from their size,
ambitions, resources, finances, culture,
portfolio and past experiences. We use
this product catalog to support rapid
execution and faster mobilization.
The first step for Baker Hughes on any
subsea project is therefore to work inclose collaboration with our customers
and partners to understand the key drivers
for project success and explore how best
to tailor our approach to maximize thevalue we can offer. We co-locate with ourcustomers and partners to enable optimum
communication, Integrated project controls
and active risk management.

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We bring industry-leading, robust andreliable technologies, the best in engineeringand project execution experience, andcombine them with commercial innovation
to unlock the full potential of every subsea
project we undertake. We proactively
engage with customers, partners andsuppliers at every stage and forge long-term
partnerships built on respect, collaborationand trust. We believe in aligning ourselveswith shared vision and commitment tosuccessful project outcomes and continue
to seek opportunities to reduce risk andincrease value to all stakeholders throughthe life-of-field cycle from early engagementand design through to decommissioning.

Working with Baker Hughes on subsea
projects provides more than just a capablesupplier - it provides a committed andtrusted partner. We prioritize the long-term
benefits of the collective project successover any opportunities for short-term
individual gains. Baker Hughes has thebreadth of technical capabilities, portfolio ofindustry-leading technologies and appetite
for commercial innovation to unlock thepotential of the most challenging subsea
stranded assets and harsh environments.

9,000+ 1,000+
employeesengineers

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Subsea 101

Product structuring
We have carried out a structured
transformation of our subsea products
and services to enable project configuration
directly from this catalogue:• Make To Order Products (MTO)• Configure To Order Products (CTO)• Engineer To Order products (ETO)
Our structured products are pre-engineered
with a configurable modular design. All
products have a defined procurement andstocking strategy and come with optimized
manufacturing and testing processes andtools as well as standard test and installation
tooling and procedures.
The structured approach provides certainty
to our customers in project delivery andquality, as well as:• Accuracy of tendered price and delivery• Certainty of delivery time andproduct quality• Minimized project risk
• Optimal operational performance• Standard installation and commissioning
methodology• Lifetime reliability of products and systems

Sourcing

8,000
rental assets

Our sourcing function manages a broad,resilient supply chain that underpins our
project execution. We have establishedlong-term partnerships with vendors acrossthe globe to support our manufacturing
sites and customer requirements. The
transition to structured, repeatable products
enables us to deepen our focus on fewer
parts, and value engineer these with our
supply chain partners to provide further
cost and reliability improvements.

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Each EPC project we perform for ourcustomers is allocated a project sourcing
manager and executed through our supply
chain partners. These high-caliber functional
experts provide a dedicated interface
between the customer requirements and our
supply chain. They are well positioned withboth vendor and internal contacts to ensure
delivery schedules are executed on time with
the quality right first time. Further support isprovided by our dedicated teams of buyers
and experienced sourcing managers in eachproduct line.

Manufacturing
capability
Baker Hughes operates Centers of Excellence(CoE) globally; world-leading, high-tech
manufacturing campuses which deliver
greater efficiency to our customers bydelivering new products that lower
development costs and increase productivity.
Our subsea manufacturing capability
is centred around our Centers of Excellencein Montrose and Nailsea in the UK. They aresupplemented with regional capability in
Asia (Singapore and Batam) , SSA (Luanda
and Angola) and South America (Jandiraand Brazil).
The Centers of Excellence in the UK havededicated capability encompassing
machining, welding, cladding, assembly,
testing and controls, supplemented with R&D,
technology development and dedicatedtraining capability.
The regional execution hubs represents the“extended” factory covering selected
machining and full testing and assembly
capability to serve regional project execution.

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CASE STUDY

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CENTER OF EXCELLENCE
Baker Hughes officially unveiled its new
Center of Excellence (CoE) in Montrose,
Scotland, in June 2019. A world-leading
high-tech manufacturing campus, theCoE will deliver greater efficiency for ourcustomers by delivering new productsthat lower development costs andincrease productivity.

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From innovation
to delivery
We deliver design, engineering,
manufacturing, test and assembly services
to advance deepwater technology for ourcustomers worldwide. We’re committed tobringing the most innovative subsea
solutions to market to help customers
improve productivity through the life of field.
Today, our $43 million Center of Excellenceenables Baker Hughes to offer world-leading
product innovation from design throughto delivery – all from one location tocustomers globally.

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Reliable fulfillment
At Baker Hughes, we work every detail anduse our experience to take the integrated
view we need to make continuous
improvements to the way we bring our
products to market.

One of the most advanced facilities of
its kind, the 35-acre campus brings together
our expertise in the engineering, design,
manufacturing and testing of subsea
equipment with state-of-the-art training
and R&D facilities. The campus underlines
our international reputation for oil and gas
innovation, developing the products andservices that our industry needs for the
future, while continuously meeting andexceeding the expectationsof our customers.

$43m

This $43m investment underlines ourinternational reputation for oil andgas innovation

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Advancedmanufacturing
Baker Hughes' Subsea Connect vision is all about
manufacturing innovative products that deliver
lower costs, increased productivity and a simpler
approach to subsea development for ourcustomers. The CoE represents an important
step forward in this vision.
Underpinning this is our Aptara™ Global Design
Center, which is an integral part of the CoE. Our
Aptara™ Totex-Lite subsea system (see page 50)
is designed to make installation, production andintervention more efficient and is exclusively
manufactured and tested on the campus.
With facilities on site capable of handling
X-tree systems up to 100 tonnes, plus a 16 meterhigh covered controlled environment for trial
assembly, the campus has the resources needed
for manufacturing both, the smallest complex
components and full subsea production systems.

Brilliant Factories
At Baker Hughes we are looking holistically at how
we can improve the way we bring our products tomarket. Manufacturing is at the heart of what wedo, so we are investing in several areas where we
can take advantage of new technologies – fromsensor enablement, additive manufacturing, anddigital design, to factory and supply chain
optimization, including our digital production
scheduling capability. We call this our ‘Brilliant
Factories’ initiative and our objective is to create
a new manufacturing paradigm with the ultimate
aim of ensuring consistently reliable fulfilment.

35acres

The 35-acre Center of Excellence inMontrose is one of the most advanced
facilities of its kind.

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FROM INNOVATION TO DELIVERYINNOVATIONRESEARCH AND
DEVELOPMENT

CLASSROOM
AND TECHNICALTRAININGADVANCED
MANUFACTURING
ENGINEERING

MACHINING

CLADDING
AND COLD METAL
TRANSFER

SUB-ASSEMBLYTEST ANDASSEMBLYSITE,
INTEGRATION
AND TESTCUSTOMER
DELIVERY

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The Center of Excellence is helping our customers toboost offshore and deepwater productivity globally.

Advanced tools
and processes

Emerging
technologies

The CoE benefits from advanced
manufacturing tools and processes that aredesigned to improve efficiency andproductivity. These include:

The CoE is Baker Hughes' center for
innovation. This is where much of our
R&D into new technologies takes place –whether it’s new materials or new products.

• Virtual reality tools and training
opportunities to help technicians assemble
equipment digitally and troubleshootissues before construction begins• Automation to boost efficiency on
activities like welding, testing andmaterial-handling• Sensor-equipped machines that allow
customers to view manufacturing updates
and equipment test results in real-time.
Once deployed, the sensors also enable
Baker Hughes to analyse critical data to
improve operations and increase
productivity• 3D printers to help quickly develop
fully-functional prototypes of components
and highly complex structures, as well as
actual production parts• Advanced digital metrology testing
equipment to improve build accuracy

Our EMT (Engineering, Manufacturing,Technology) teams are focused on
identifying and understanding emerging
technologies long before they have any
commercial application. We’re continuously
looking for the next generation of innovativeand cost-effective technologies that will
make our industry more sustainable –and rigorously testing these in
our dedicated labs.
With our R&D and EMT teams embedded
alongside the engineering and design
teams there are opportunities for informal
collaboration and the sharing of ideasthat help to identify both the challenges
our customers face and the solutions
they require.

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ADDITIVE
MANUFACTURINGCAPABILITIESDigital Enablement

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Additive manufacturing, otherwise known
as 3D printing, is a growing area of Baker
Hughes’ manufacturing portfolio. Our
additive manufacturing initiative began in2014 with the mission to develop previously
inconceivable products, while supplying
parts on demand with no inventory. Baker
Hughes has been recognized as a leader inboth technology and talent in this field.
Several global teams are dedicated to
expanding our capabilities by deploying
cutting edge processes that support awide range of metal and plastic productdevelopment. Baker Hughes leveragesa large direct asset pool and dozens ofindustry and academic partnerships toaccess all seven additive “modalities”,
or unique additive processes.

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Internally, investment has been prioritized on
powder bed fusion, laser-powder directedenergy deposition, and filament extrusion.
Product footprint can range from the micronscale to several feet, and from a diverse
range of materials including stainless steels,
nickel alloys, to a wide variety of polymers.
Baker Hughes' core services include accessto a multidisciplinary, global team. Our
material scientists develop innovative
processes to continually expand thematerials supported. Product engineers andtechnology experts work closely with clientsto customize designs while optimizing
existing asset performance.
Production is vertically integrated, andemploys the latest digital inspection andquality assurance techniques. With the depthof both technology and personnel, Baker
Hughes’ additive manufacturing practiceis firmly dedicated to bringing this newtechnology to the industry.

Our material scientists develop innovative
processes to continually expand thematerials supported.

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LIFE OF FIELDSERVICES
With more than 100 years' experience in theoil and gas industry, we design innovativeand effective solutions that support key
industry drivers; uptime, availability,
production fluid recovery, safety andefficiency around the globe, leading theindustry in installation services, asset
integrity management and digitisation.
Throughout our history we have provencapable of executing technically complex
solutions, pushing the boundaries ofoperation, extending the life of your field andworking pressure-fuelled scenarios. We are areliable partner, capable of supporting you
through any challenge that presents.

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OUR GLOBAL SERVICES FOOTPRINT
We deliver value through our global
scale and local capabilities.

75

Stadiums equivalentof workshops

24 global locations, servicing
more than 350 customers,
with 45 active asset integrity
management contracts acrossthe globe, handling more than
5,000 assets for customers.

400+

Field service
engineers

8,000+

Dusavik
Stord
Kristiansund
Hammerfest

Houston

Aberdeen
Blackness
Bristol
InverurieMontrose
Nailsea

Villahermosa

Baku

Takoradi

LaundeMacaé
JandiraPort
Harcourt

Kakinada
Pemba

Singapore

Batam
BroomeJandakot

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INSTALLATION & COMMISSIONING
Harnessing the experience of an OEM to offer
integrated packages and meet your deadlines.
Our core offering:

FIELD SERVICES

400+ highly trained, certified andexperienced field service engineers (FSEs)
with 24/7 technical support where and when
you need it.

RENTAL TOOLING

Our rental fleet includes in excess of 200 sets
of wellhead and tree installations, work overand commissioning tooling, ROV, shallow,
medium and deep water IWOCS systems
and light well intervention stacks.

TRAINING

We have a long history of manufacturing
and supplying equipment and supporting
operations throughout the project lifecycle.
The OEM experience ensures training
programs are technically accurate,comprehensive and a key driver in thedelivery of EHS, financial and operational
performance to you.
The benefits to you:
• 20% average reduction in crew size
through our use of multiskilled technicians• Reduced deck space through integrated
well access solutions (IWOCS/LS)• 80% reduction in cost v CAPEX over threewell (Wellhead & XT) campaign using ourrental equipment• 33% reduction in NPT by utilising
maintenance and repair teams
experienced in tooling management• Capability to support in excess of 200
wellhead and tree installations every year

INTEGRATED OPERATIONSACHIEVING SUCCESSUNDER SCHEDULE
PRESSURE
Baker Hughes was awardeda large second phaseproject in the Mediterranean
in 2017 with installation
activities commencing in
2019. The customer had anaggressive schedule for firstgas with minimal margin for
unforeseen events.

We successfully installed
the first batch of DHXTs withno non-productive time
incidents achieved using ourcompletions, controls, andIWOCS FSEs and rental
equipment for all operations.
We also carried out onboard
pre-deployment testing on
secondary deployment
equipment ahead of the
deployment date.

Onshore, at the customer
base, our team worked with
their project team to bringforward site receival testingon the second batch ofequipment to achieve
readiness ahead ofsailaway dates.
• Zero NPT• 40% of FSE team local
to region• First gas was achievedon time• Seamless transition forcustomer from competitor
equipment on first phaseto Baker Hughes oncurrent phase• Owned interfaces withthird party equipment
to ensure no delay
to schedule

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ASSET INTEGRITY MANAGEMENT
Many field lives are now projected to continue producing
well beyond their original design life. We create flexible
partnerships that benefit all to increase uptime, minimize
OPEX, cut unnecessary inventory, proactively manage
obsolescence and ultimately improve and extend field
performance across the entire lifespan of your project.

GLOBAL STORAGE
FOOTPRINT

24 global regional hubs providing
capability for• Rapid deployment of equipment• Localized maintenance, refurbishment
and overhaul• Testing, troubleshooting and fault finding• Preservation and storage

INTEGRATED EQUIPMENT
MANAGEMENT

Our real time, flexible equipment
management programs coupled withrepeatable maintenance significantly
reduce contingency and mobilization spend.
We can track usage data to optimize andprioritize inventory globally.

BESPOKE, FAST TRACKREPAIRS, MODIFICATIONS,CONVERSIONS &UPGRADES

We have an unrivalled track record ofdelivering solutions that offer a cost-efficient
alternative to purchasing new. Each year
we carry out around 20 XT refurbishments
and maintain and/or upgrade more than
400 pieces of controls equipment for ourcustomers. We monitor the worldwide installedbase regularly to offer modified equipment tomeet our customers' urgent needs.

LONG-TERMPARTNERSHIPNORTH AMERICAXT REFURBISHMENT

18 Christmas trees that wereno longer producing
optimally have been
recovered and thenrefurbished. A further six
trees are in progress andanother four are planned.

The XT was purchased froman operator and converted
from a direct-hydraulic XT toa subsea control module(SCM) controlled XT withmetering valves and a flowline isolation valve.

We have a majority Nigerian
workforce and they support
the blasting, painting andinsulation of the trees which
are stripped back toindividual components andthen rebuilt and tested in
the country.

The tubing hangers, crownplugs and internal XT cap
were also refurbished.

Our Onne facility, in Nigeria,
has carried out services
since drilling of a customer’s
first well in 2002 including
completion, commissioning,
operation, production,
health care and intervention
and workover on the field.

These refurbished trees arethen rerun on new wells on
the customer’s project,enabling the FPSO to carryon producing in excess of
200,000bbls/ day.

In 2019, we successfully
delivered a 10k deep water
Christmas tree system in the
Gulf of Mexico, refurbishing,delivering and installing
subsea in under eightmonths with no nonproductive time (NPT).

Assembly and testing of
the whole system wascompleted in our local
facility in Houston.

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OBSOLESCENCE

Our obsolescence solutions enablesignificant improvements in production
efficiency and operating costs including
control system enhancements that co-exist
with legacy infrastructure, regardless of theOEM, to both extend functionality and life ofolder assets.
We're committed to keeping our legacy
installed base current with a structured andcost-effective approach to obsolescencemanagement and system sustainability, andhave a strong record for upgrading subsea
controls to our best-in-class, highly reliable,
SemStar5 system — with zero failures
recorded since it was introduced in 2011 — sofields with older equipment can continue
operating efficiently and safely.

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Digital Enablement

The benefits to you:
• 30% reduction in lead time purchasing
refurbished equipment versus new• 60% of work carried out locally• Experience of managing more than
8,000 assets globally• 20% reduction in inventory
through optimization• 10% lower mobilization time versus industry• Typically £1MM production loss being
avoided per incidence of an obsolete
sub-system failure

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PLUG AND ABANDONMENTSERVICES

When a well no longer produces enoughhydrocarbons to remain economically
viable, it becomes a liability instead ofan asset. Our comprehensive integrated
portfolio allows us to tailor our approachto each customer and asset, helping meet
objectives and adhere to all relevant andlocal regulations. From sealing the cap rockto final wellhead removal, we help minimize
costs, improve reliability, and reduce
non-productive time.

PLUG ANDABANDONMENTACROSS OEMS

We were contracted toprovide the well accessequipment and supporting
project management,
engineering, logistics andfield service engineers to
support a decommissioning
project in the UK North Sea.
With limited information
available and having tocontrol multiple vendors andmechanical interfaces wesuccessfully accessed andabandoned 30 subsea wells
consisting of 12 Baker
Hughes XTs and 18 fromother OEMs. The campaign
was delivered within budget,
five months ahead ofschedule and with zero losttime incidents.

TVCM OBSOLESCENCESOLUTIONS

We were challenged toextend the life of two fields in
the Norwegian Continental
Shelf, which had significant
obsolescence issues. To
complicate the issue further,
the fields had subsea control
modules (SCM) frommultiple vendors.

Following the completion ofa FEED we were awarded acontract for the provision of
our brand new SemStar5
based controls system withnew communications routerand single SCM/xadapter
plate solution which allowed
us to install our products
onto the 28 wells frommultiple vendors, supportingthem all until 2030.

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CASE STUDY

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RETRIEVABLE HIPPSPROVIDE LIFE OF
FIELD ADAPTABILITY
Baker Hughes deployed a retrievable
High Integrity Pipeline Protection
System (HIPPS) on the Burullus West
Delta Deep Marine (WDDM) asset, in
the Nile Delta region, offshore Egypt.
The modular set of HIPPS units has
enabled the operator to further
expand the field – and deliver
more gas to the onshore LNG plant.

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1,100 mWater depth up to

The Challenge
The WDDM concession was discovered in
1997 and sits 120km off the coast of Egypt.
Production started in 2003 and the firstseven phases of development delivered
60 subsea wells in water depths between
200m and 1,100m.
More recently, during phases eight and nineof the development, the operator has seen
an increase in the rated pressure for theprocess lines. The rating of the process lines

in earliest phases was 228 bar, but withfurther development, it became necessary
to protect the earlier field infrastructure fromthe relatively high (up to 289 bar) wellhead
shut-in pressure (WHSP) in the new wells. In
particular, a solution was required to protect
the export pipeline to the onshore LNG plant,as there was then a potential risk of overpressurising this critical system.

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The Solution
The deployment of a set of retrievable
HIPPS modules made sense logisticallyand economically. The use of the HIPPS
modules allowed for the new, high-pressure
wells to be tied into existing manifold andpipeline infrastructure so they can be
retrieved and replaced by a passive spool
as the shut-in pressures naturally decline.
The integration of HIPPS components fromseveral sources required skilful project
management of specialist OEM vendors
on our part.
Installation methodology and sequence
was a key design consideration along with
the integration of HIPPS controls with theexisting control system. As part of a pressurecontaining process line, the HIPPS modules
need to provide a high level of risk reduction
and had to be certified by a third party
independent certification body to achieve thedesignated safety integrity level (SIL) rating.

Most importantly, in terms of long-term
flexibility, the Baker Hughes integrated,compact HIPPS module can easily be
retrieved from the seabed when the initiallyhigh WHSP has declined after the initialstages of gas production. The flow-line
connector mechanisms are specificallydesigned to allow for vertical installation
and retrieval of the HIPPS, without disturbing
the flow line or tree hardware. And, once
retrieved, and replaced with a passive
pipeline spool piece, the HIPPS module
can then be reused.

All six of the HIPPS modules have been
installed, tested subsea, and are
currently operational.

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The Benefits
The cost implications of providing new
infrastructure rated at the WHSP of the newwells – described as a ‘fully rated’ system –is such that the operator was able to makeconsiderable CAPEX savings by being able
to continue to operate with their existing
lower pressure rated facilities.
An important part of the design anddeployment of HIPPS technologies is toachieve this goal, while maintaining safety
integrity level (SIL) certification in a costeffective way. The adaptability over life-offield offered by a recoverable HIPPS unitthat can be removed as the reservoirpressure reduces, means this solution offers
reduced capital outlay in the future when
the HIPPS is reused.

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Enabling technology
Standalone HIPPS module
HIPPS module mounting base
Seabed mono suction pile
Retrievable HIPPS module
Passive spool piece (dummy module
installed once WHSIP reduced)
Horizontal connection system(to ease recovery of HIPPS module)
MCS functionality to remove HIPPS
from HMI following decommissioning
Note: Suction Pile & HIPPS Module Mounting Baseare only permanently installed items.

Detailed Specifications
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CASE STUDYUPGRADING AND
EXPANDING A
MATURE ASSET
Baker Hughes was engaged in 2010 tocollaborate on the planned expansionof a major Norwegian North Sea asset –first developed in 1999. We delivered an
integrated portfolio of services from concept
engineering and equipment upgrades tothe supply of new build trees, controls andflexible pipelines.

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The Challenge
Phase I of this field was completed in
1999 with Phase II following in 2001. Subsea
consisted of four field sites with 17 wells tiedback to a FPSO. Phase III proposed adding
five new wells – the first since 2001. A life-offield expansion was granted to 2025 and asubstantial scope of work was developedwith the customer which identified thefollowing key issues:• Tree design with a desire to reuse stock
trees from 2000
• Controls capacity and obsolescence(Baker Hughes SEM3 variant), no newumbilical planned• Topsides master control station upgrade,
HPU capacity, turret space constraints• Intervention equipment (WOR/WOCS/
IWOCS) refurbishment and recertification• Legacy equipment versus current
company specification compliance

The subsea control module adaptor plate
enabled the ModPod SCM to be fitted to the
new trees and also retrofitted to the legacy
trees subsea.

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The Solution
Baker Hughes rose to this challenge andmobilized teams across the UK and Norway,
project managed by a core team in Dusavik,
Norway. We drew upon a wide range ofexpertise and execution skills from across the
Baker Hughes subsea portfolio. In addition,
multiple sub-vendors were screened andselected to support the team in the
refurbishment phases including a major
recertification of the riser joints.

New design emergency disconnect package incorporatinglatest ISO 13628 specification including retainer valves toprevent pollution in the event of an emergency disconnect.

Phase III was initiated following early
engagement with the customer which saw
budgets, financial and commercial terms
maturing over several months through small,but highly collaborative teams culminatingin the award of the full project scope.
Reuse, refurbishment, conversion andrecertification were the customer’s initial
requests – all to keep project costs to aminimum and meet a tight budget andschedule. FEED gap analyses were used
to identify the mandatory specification
changes to legacy equipment. In addition
the customer was required to seek
concessions from their global engineering
specifications to adapt legacy equipment
certified under the original project
development licence.
Hierarchy of applied requirements

To supplement the reuse of equipment,
the project also identified the need for newbuild equipment to replace obsolete partsor to meet the needs of the planned
drilling campaign.
The new build equipment supplied included
two trees, work over riser (WOR); running
tools; and legacy control modules (SEM3),
installation and work over control system(IWOCS); and new ModPod subsea control
modules with a virtualised software package
and adaptor plates to be fully interchangeablewith the installed subsea and new build trees.
New build components were, wherepracticable, designed in accordance with
ISO 13628 and Norsok U-001 standards,(valves to ISO 10423 / API 6A).

Enabling technology
2 x vertical subsea trees including chokes,
tubing hangers, controls mounting bases,
sensors and harnesses

FDS
PSA

Subsea control module adaptor plate provided the ability toretrofit the ModPod SCM to legacy trees still subsea and to the
new trees being built.

ISO 13628
ISO 10423
eTOPPS
Global Practices

5 x flowbases including ROV installed flowline
hub connection systems
6 x MS700 wellhead systems, conductors
and connectors
5 x subsea control modules (SCM) complete with theaward-winning SemStar5 subsea electronics
moduleIWOCS system complete with umbilical, landing
string and associated tools and connections
10km of 8" production and 10km of 2.5" gas lift
flexible flowline jumpers including terminations
and bend restrictors
MCS functionality to remove HIPPS
from HMI following decommissioning

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The Benefits
Delivering a substantial subsea expansion
project like this required the combined
efforts and skills of the entire Baker Hughes
product portfolio. We rose to the challenges
presented by the customer to interface
legacy equipment alongside the latest
technologies – thereby maximizing theirassets while minimizing the need forany significant subsea equipment
recovery and upgrades
The upgraded system was not only fit-forpurpose, but ensured that any legacy
equipment that fails in the future can be
replaced on a simple plug-and-play basis.
The client now has the framework in place
to deliver any future upgrades at a low
engineering cost.

Detailed Specifications
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ENABLINGTECHNOLOGIES

Subsea control module(SCM) adaptor plate
provided the ability to retrofit
the ModPod SCM to legacy
trees still subsea and to the
new trees being built. The
solution in this application
was used to fit our standard
square module onto alegacy round mounting
base.
Active power conditioning
module, designed to takeincoming vessel AC supply
and condition this to provide
a 60Hz low distortion AC
output to the subsea control
units. Each module was sized
to power the total field(30 wells planned) providing
redundancy and securityof power supply.
MCS and human machineinterfaces software wasadapted and modified
to capture the enhanced
housekeeping data
produced by the SemStar5
electronics modules. This
provided additional data for
analysis to build predictive
maintenance routinesand for trouble shooting
subsea issues.

Stack-up sketches of the EDP, LRP, XT, flowbase with flowline
connector, tree mounted UTA. Tree is shown with the Modpod
SCM installed on an adaptor plate to provide fullinterchangeability with legacy equipment subsea.

DHPT instrument cards
supplied to monitor the
downhole gauge pressure
and temperature wereidentified as obsolete. The
new DHPT cards suppliedand fitted into the SEMs
required an alternative
supply voltage.

Baker Hughes' SemStar5
design provided a simple
adjustment to cater for
either variant of card
thereby providing flexibility
to install on legacy or
new wells.
SemStar5 has been
designed to be backwards
compatible with legacy
Baker Hughes SEMs throughvirtulisation of the original
subsea operating systemon the SemStar5 modem's
single board computers.
The ‘SEMulation’ software
allows SemStar5 to operate
alongside the existing
legacy modules with nodisruption to the topsides
hardware or operator
interfaces. This has beensuccessfully installed andoperating on many control
system upgrades globallyand provides a costeffective and fast track
method to maintain or
expand older control
systems without the needfor costly infrastructurechanges. The SemStar5 has
been extensively qualified
and proven in the field,with more than 600 units
deployed across multiple
projects since our first
installation in 2011.

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Digital Enablement

RESERVOIRTO TOPSIDESTECHNOLOGYSOLUTIONSThe subsea industry has come a long way since its
beginnings in the 1960s. The industry has changed
extraordinarily since then and today we are designing
subsea power and processing modules that would havepreviously required a platform on the surface.
The one thing that has remained constant is our pioneering innovationthat has created practical and efficient solutions for our customers,
demonstrating our proven ability to deliver everything required for asubsea system even if we have to develop the underlying technology– just as we have done many times.

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RESERVOIR TO TOPSIDESTECHNOLOGY SOLUTIONS

48

Aptara™ TOTEX-lite
subsea systems

50

Subsea Wellheads

52

Subsea Trees

58

SubseaControl Systems

68

Subsea Manifolds andPipeline Products

84

Subsea Connections
Systems

98

Subsea Electric
Solutions102

Subsea Well
Access Systems

110

Subsea Power andProcessing Systems

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RESERVOIR TO TOPSIDES TECHNOLOGY SOLUTIONS
Baker Hughes is the only company with awide and deep portfolio equipped to
optimize subsea developments – from thereservoir to the topsides.
We are uniquely placed to provide both awide and deep set of capabilities that cut
across all E&P segments.
Reservoir optimization and field development– Baker Hughes has over 400 geoscientists
globally who are able to provide detailed
and localized analysis of regional prospects,
fields and developments.
We connect subsurface development
options with the best technology solutions on
the market today.
We engage early in the process to develop
the optimal reservoir and field development
plans that maximize value while addressing
customer priorities.
On existing developments, we have an
established track record of extending field lifeand maximizing economic recovery. As an
example, on a project in Malaysia, our fielddevelopment team led to a doubling ofproduction in two years and extending thefield life by 10 years.

Integrated Well Services

We have developed an integrated lean wellconstruction process that weaves integrated
drilling services, integrated well construction,
automation and remote operations into a
simplified well delivery solution. It redefines
the technical limit through integrated wellengineering resulting in accelerated drilling
campaigns and significant reduction in wellcosts, and its consequent effect on overall
project costs and timelines.
IWS (Integrated Well Services) has several
projects around the world; in an example
offshore in the North Sea, working with alarge E&P operator, we formed a trilateral
partnership between Operator, Drilling
Contractor and Baker Hughes. We enabledaggressive targets for tangible efficiency
gains.
The results from this approach speak forthemselves:• 50% below budgeted costs on the firsteight wells drilled• Wells were delivered eight months aheadof plan• Technical limit or ‘perfect well’ target was
improved by 25%• And most importantly, there were noserious injuries or incidents

AptaraTM TOTEX-lite
Subsea System
This is one example of our wide and deep
portfolio of integrated subsea solutions.
Our Aptara™ TOTEX-lite subsea solutions
use lightweight, modular technology
re-engineered to cut the total cost ofownership in half and designed to be
more responsive to changes over the lifeof the field.
A summary of the benefits it provides:• Delivers up to 50% lower total cost ofownership for each subsea system• Innovative and industry-first tree caps
incorporate Life-of-field design to deliver
unparalleled flexibility• Modular and structured portfolio• Compact and up to 50% lighter• 30% reduction in lead time
• Simpler and easier installation, operation,and maintenanceTopsides Optimization
Production optimization through enhanced
topsides, extending asset life with no change
in platform footprints to handle 25% morevolume at minimal CAPEX. Baker Hughes has
proven results here:• De-bottlenecking, gas handling, andpower solutions to extend asset life
• Over 1,400 units upgraded – from gas
turbines, centrifugal compressors,
reciprocating compressors and more
• Asset life extension• Improvement in uptime• Emissions reduction and control

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APTARA TOTEX-LITE
SUBSEA SYSTEMS™

Our Aptara™ family of TOTEX-lite products
has been born from our life-of-fieldapproach. The Aptara™ name is derived from
Latin for “adapt” or “fit”. It signifies the flexibilityof this family of products to meet the evolving
needs of operators from the time of
installation and over the life of field. We havere-engineered the subsea system to makeinstallation, production, and intervention
simpler and more efficient – dramaticallylowering the total cost of ownership.

Our next-generation technology is smarter,
simpler, and more efficient. It is designed towork for you and ensure your subsea system
is easier and more economic to install, thatit operates smoothly, and is flexible enoughto evolve over the life of your field.

Innovative life-of-fieldapproach
Our Aptara™ family of products combines aninnovative approach with industry-firstpatented technologies to deliver subsea
systems that have shorter lead times andlower initial CAPEX as well as OPEX savings
over the life of your field – making it a
TOTEX-lite family. We have taken a radicallydifferent life-of-field approach to create asuite of products that is lightweight, compact
and optimized to reduce total cost ofownership (TCO).
These individual products are the building
blocks of our Aptara™ subsea system. The
main products in the Aptara™ familyof TOTEX-lite products are:
•
•
•
•
•
•

Aptara™ lightweight compact tree
Aptara™ modular compact manifold
Aptara™ modular compact pump
Aptara™ composite flexibles
Aptara™ SFX wellhead solution
Aptara™ subsea connection systems–– FLX360 multi-quick connection system–– HCCS-L Lightweight Horizontal Clamp
Connection System

Aptara™ lightweight compact tree
The Aptara™ lightweight compact tree uses
unique patented innovative tree caps,
allowing it to be configured to suit changing
requirements, reducing cost, and increasing
value over the life of your field. These treecaps eliminate the need for independent
modules and connections, reducing yourcosts further. At 50% lighter, with aconsiderably smaller footprint, it can also
save you up to 50% in CAPEX and OPEX of
the subsea system over the life of your field.
Aptara™ modular compact manifold
The Aptara™ compact block manifold
addresses the industry’s need for modular,
pre-engineered manifolds that use off-theshelf components, reducing cycle time, costand footprint. We have achieved a level ofstandardization that limits the engineeringto the manifold header, structural steel,and foundation, resulting in faster delivery
with reduced risks and costs. For the mostcommon configuration, the manifold will
be a Make to Order variant with zero productengineering and delivered in 10 months
from the award of a contract.
Aptara™ modular compact pump (MCP)The Aptara™ MCP is the world’s first subsea
multi-phase pump without a barrier fluid
system which reduces topside footprint by
50% and cuts system costs. The standard
pre-qualified 1 MW building blocks enable
the Aptara™ MCP to be configured to different
field requirements quickly and easily. Our
life-of-field approach to design is evident
in unique features that reduce the TCO.

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The stages are controlled individually by
local subsea Variable Speed Drives (VSDs)
that allows the pump to react and adapt
dynamically to changes in wellstream
conditions. This ensures high inherent
reliability, as high-risk items such asmechanical seals are not needed. It also
effectively eliminates the need to re-bundle
the hydraulics during the life of field.
Aptara™ composite flexibles
Baker Hughes’ composite riser flexible pipe isa step-change product. It provides a
cost-effective solution for ultra-deepwater
applications in water depths up to around
10,000 ft (3,048 m). The new product is ahybrid of traditional flexible pipe designs,
introducing 21st century materials technology
for one specific layer – bringing 30% weightsavings without affecting bending radius orcompressive load capability.
For risers, this is achieved by reducing
hang-off weights and platform burdens,
simplifying riser configurations, andminimizing ancillaries and subsea
infrastructure while keeping the exposure to
new technology to a minimum. The producteliminates riser system complexity, reduces
cost and installation time while delivering
predictable and stable hydrodynamic
performance over the full product lifecycle.
For flowlines and jumpers, we retain theflexibility this product brings with regards
to final layouts, accommodating re-spuds
and early deployment/wet storing of pipe
to accommodate installation windows ofopportunity, which may occur off the project
critical path. Particularly, for high-sour or
high-CO2 developments, this hybrid
composite pipe significantly reduces
permeated gas flow rate through the pipeannulus, reducing operational risk andadding cost benefits over the field lifecycle.

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Aptara™ SFX wellhead solution
The Aptara™ SFX wellhead solution is focusedon improved fatigue resistance to maximize
life-of-field options for the operator. The resultof our life-of-field approach to designtranslates into tangible benefits, enablingproduction enhancement through wellintervention activities even in late life andensuring longevity of field operations, all witha lower risk profile than traditional wellheadsystems. The Aptara™ SFX wellhead solution
enables you to plan your well activities reliably
and with higher confidence for years to come.
Aptara™ subsea connection systems –FLX360 multi-quick connection system
The Aptara™ FLX360 multi-quick connection(MQC) system that enables fast and reliable
connections between all elements of thesubsea distribution system. It uses apatented locking mechanism that leaves asingle moving part of the design on theseabed. The complexity of the connection
system is housed within the retrievable andserviceable ROV tooling. Its unique life-offield design also allows maintenance insitu with no need for disconnection of theconnector thereby reducing total cost ofownership. The Aptara™ FLX360 family isextended to also provide reliable andcompact connection for steel tube flying
leads (STFLs) as well as umbilical termination
in a Cobrahead assembly (CHA).
Aptara™ subsea connection systems –Horizontal Clamp Connection System
Light (HCCS-L)
Our Aptara™ HCCS-L is a proven horizontal
connector suitable for rigid, and flexible
jumpers and spools, as well as umbilicaltermination with use of multi-bore hub
technology. The HCCS-L range has been
designed to be lighter, smaller and optimized
to minimize make-up time, allowing for rapid
installation. They come with a pre-mounted
stroking tool and require fewer subsea
operations, reducing the connection timeby more than 30%. Our unique push-type
stroking functionality allows full access forcleaning and cap replacement with the
pre-mounted stroking tool.

Aptara™ lightweight compact tree

Aptara™ composite flexible

Aptara™ modular compact manifold

Aptara™ modular compact pump (MCP)

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SUBSEA WELLHEADSOVERVIEW
With half a century of fieldproven experience andmore than 5,000 wellhead
installations worldwide,
our subsea systems set
the industry standard.
Since its introduction in 1991,
operators still rely on the
MS-700 in some of the mostchallenging conditions.
Our new Aptara™ SFX technology takes
the core metal sealing technology toanother level of reliability and fatigue
resistance. We are extending fatigue
life through the improved and recently
released H-4FX designs. We offer awide range of premium connections
and casing products and continue todevelop new solutions like our Ulti-Max
family of Gas Tight weld-on casing
connectors that will make youroperations safer and more productive
in increasingly demanding conditions.

Our subsea wellhead and premium
weld on connectors are offered as
standalone solutions or as anintegrated system designed for therobust performance you need, withreliability, efficiency, and versatility thathas been proven in the field. Our
complete-system approach enables
fast, simple and economic installation
and running, while our portfolio
supports subsea drilling operations
at all stages of exploration andproduction. Lead times for delivery
of a subsea wellhead system range
between five and 12 months forstandard and fully customized
solutions respectively.
Baker Hughes' excellence inengineering is typified by our
proprietary Metal Sealing (MS)technology, which is one of theindustry’s most reliable wellhead
seals. Our proven technology provides
multiple independent metal to metal
seals making it significantly more
resilient and effective than traditionalelastomeric sealing systems,
providing a wider range of operating
temperatures and improved gas
sealing and applied successfully
across our portfolio including
premium weld on connectors.

Detailed Specifications
and Data Sheets

APTARA™SFX WELLHEAD SOLUTION

Our enhanced Standardized Fatigue
Resistant Wellhead Solution (SFX) delivers
significantly improved fatigue resistancecompared to existing systems.
54
Baker Hughes is introducing the next
evolution of MS Sealing technology,
MS-2. The MS-2 seal incorporates all
the advantages of our Legacy MS seal
solutions and adds an enhanced single
trip integrated lockdown solution toprovide assurance for all wellapplications. This feature provides
immediate lockdown up to two million
pounds force without the need for asecond trip saving rig time. The MS-2
seal is PR2F tested to 20,000 psi perGroup 4 requirements including a
combined load envelope and isfurther tested to 200 load cycles
ensuring life of field reliability.
We continue to invest in and upgrade
market leading solutions. To support
operators working in more challenging
conditions, we have improved theH-4 profile to provide two to four times
more fatigue life. The H-4FX profile
is now available, increasing theoperating life of the interface andis fully compatible with H-4 styleconnectors already in the field, whichmeans no change over management
for the operator to worry about.

MS-800The MS-800 can reach deeper well depths
with a larger production string, whichenables larger completion options.
55

MS-700The MS-700 can be used across a wide
range of applications, including TLP/spar
tieback, subsea completion anddeepwater drilling.
56

ULTI-MAX SPECIALTY CONNECTORThe Ulti-Max Connector provide Gas Tight
performance and meets or exceeds pipe
performance capabilities providing
confidence in even extreme applications.
57

See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA WELLHEADSAPTARA™SFX WELLHEAD SOLUTION
Our enhanced Aptara™ Standardized Fatigue
Resistant Wellhead Solution (Aptara™ SFX)
takes the field-proven architecture of our
MS-700 and MS-800 subsea wellheads
to the next level.
The Aptara™ SFX wellhead solution delivers
up to 20 times the fatigue resistance ofexisting systems. With its stress-reducing
geometries on extended length forgings,
tougher materials (A707 and F22) and areduced number of welds, the Aptara™ SFX
is stronger – providing industry-leading
reliability in extreme fatigue conditions. The
system delivers this improved performance
while maintaining all the familiar systeminterfaces, tools, and operating proceduresthat have been proven in fields across theglobe. This minimizes risk and improvessafety by reducing management of change.

Aptara™ SFX Wellhead Solution
FeatureMake to Order

Variant

3 OptionsBending capacity (mm lb-ft)

5.25 or 7

Casing program (inches)

36 x 28 x 22 x 18 x 16 x 14 / 13 x 10 / 9

Casing load (mm lbs)

8

Fatigue loading

ExtremeMaterials–– F22 and A707–– DNV C/C1 curve tested welds–– DNV B curve tested connector

The Aptara™ SFX wellhead solution is focusedon improved fatigue resistance to maximize
life-of-field options for the operator. The
result of our life-of-field approach to designtranslates into tangible benefits, enablingproduction enhancement through wellintervention activities even in late life andensuring longevity of field operations, all witha lower risk profile than traditional wellheadsystems. The Aptara™ SFX wellhead solution
enables you to plan your well activities
reliably and with higher confidence foryears to come.

Its standardized solution optimizes supply
chains, simplifies operations and allows you
to extend drilling days in harsh environments,
as a result of having lower fatigue damage
rates compared to traditional wellheads. The
Aptara™ SFX also offers reduced cycle times
and we can deliver a Make to Order Aptara™
SFX variant with configured options within
6 months, which eliminates the incremental
6 months of material procurement lead time.
The Aptara™ SFX can be supplied in both,MS-700 and MS-800 configurations andcomes with 5 inches of extra sealing surface
for compatibility with all completion systems.
Available with optimized C1 or automatedorbital C class performance welding withtight pipe tolerance providing industry
leading girth weld fatigue life performance,
the Aptara™ SFX wellhead family can besupplied with fabrication options optimizing
the customer’s fatigue resistance solution
to meet their challenging or extreme
global environments and applications.
The comprehensive system includes
wellhead, pipe, and casing connectors,
all designed to meet or exceed industry
standards for materials, quality and fatigue
performance. The Aptara™ SFX also comeswith improved and standardized inspection
protocols for greater safety and reliability.

Typical lead time:

6 months

Our Make to Order Aptara™ SFX wellhead
solution can be delivered in 6 months.

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SUBSEA WELLHEADS

MS-800The MS-800 subsea wellhead system
was developed in 2007 to allow more
flexibility in designing casing programs,
using larger drill bits and testing pack-offs
to higher pressures.
The MS-800 can reach deeper welldepths with a larger production string,which enables larger completion options.
The wellhead system gives you the option
to run 18-inch and 16-inch casing strings
below the mudline, giving you better zonal
control of your well casing program. We candeliver an MS-800 in 6 months. The systemcomes with 8 million lbs of total load
capacity, allowing the operator substantial
flexibility on casing programs and working
pressures up to 20,000 psi.

The MS-800 benefits from true metal-tometal seals and the system has highpressure capabilities of 20,000 psi,
temperature capabilities up to 350°F (177°C),
and bending capacity up to 7 million ft-lbs
to maintain high standards of reliability
and safe operation.

MS-800FeatureMake to Order

Variant

2 OptionsBending capacity (mm lb-ft)

5.25 or 7

Casing program (inches)

36 x 28 x 22 x 18 x 16 x 14 / 13 x 10 / 9

Casing load (mm lbs)

8

Fatigue loading

NormalMaterials

8630 HP / 4130 LP

Typical lead time:

5 months

Our Make to Order MS-800 subsea
wellhead system can be deliveredin 5 months.

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SUBSEA WELLHEADS

MS-700The MS-700 subsea wellhead system
launched in 1991 and continues to be oneof the most widely used wellheads in theworld. Operators In every global basin haverelied upon the MS-700 for some of theirmost challenging campaigns.
The MS-700 proved its versatility over theyears, across a wide range of applications,
including TLP/spar tie-back, exploration,subsea completion and deepwater drilling.
We can deliver an MS-700 wellhead system,
supporting multiple casing configurations
from 36 inches through to 7 inches, in around
5 months. The system comes with 7 million
lbs of total load capacity, which allows forthree casing strings and up to 3 million lbs
combined string weight.

Baker Hughes provides the benefits of true
metal-to-metal seals with the MS-700 and
we supply a single trip running tool to test
both the casing hanger and the annulus seal.
The system has high-pressure capabilities of
15,000 psi, temperature capabilities up to
350°F (177°C) and bending capacity up to
5.25 million ft-lbs to maintain high standardsof reliability and safe operation.

MS-700FeatureMake to Order

Variant

2 OptionsBending capacity (mm lb-ft)

5.25

Casing program (inches)

36 x 28 x 20 x 16 x 13 x 9

Casing load (mm lbs)

7

Fatigue loading

NormalMaterials

8630 HP / 4130 LP

Typical lead time:

5 months

Our Make to Order MS-700 subsea
wellhead system can be deliveredin 5 months.

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SUBSEA CONNECTORULTI-MAX SPECIALTY CONNECTOR
With lineage of over 1 million joints installed
and counting, our latest weld-on connector,
the Ulti-Max™ Family, launched in 2015, is ourmost rigorously tested solution. It performs
in extreme upset conditions with a seawatersealing, while delivering improved rig
productivity, through fast make up andcasing string installation.

Designed with flexibility in mind and tailoredto specific application needs the Ulti-Max™ GT
meets or exceeds all ISO 13679 requirementsof tension, compression, bending, internaland external pressure. It also has a singlethread start that optimizes fatigue
performance while minimizing the effects ofback-out on seal ability and pre-load loss.

The Ulti-Max GT connector has a gas-tightmetal-to-metal internal seal and is available
in multiple diameters and thicknesses. It
combines all the features of our widely used
RL-3M connector with new materials and amore compact, lightweight, and costeffective design. Baker Hughes also offers a
High Fatigue resistant version of the Ulti-Max
GT, the Ulti-Max SFX, that meets your Gas
Tight and Fatigue requirements.

Advanced threads and stress reliefs ensure
higher fatigue performance. Large selfaligning stab guides provide fast, safe
installation in 3.5 turns, and large stress-relief
grooves prevent hydraulic locking. Our
patented new anti-rotation keys design iseasily and safely installed in less than 30
seconds with no special tools for between
49,500 and 62,500 ft-lbs of torque capacity.

Specialty Connector (Ulti-max GT)
FeatureMake to Order

Configure to Order

Variant

2 Options

Production bore size (inches)

20/22

20/22

Wall Thickness (inches)

0.812/1.000

0.438 to 1.500

Tension (kips)

3426 / 5278

up to 7728

Compression (kips)

3426 / 5278

up to 7728

Bending (kip-ft)

1316 / 2209

up to 3092

Burst (psi)5660 / 7,235

up to 10781

Collapse (psi)-2820 / -3870

up to -9460

Materials

LCM, 4130

LCM, 4130, A707

Yields (ksi)

70, 8070, 80

Typical lead time:

5 months

Our Make to Order Ulti-Max Connector
Tubular joint can be delivered in 5 months.

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SUBSEA TREESOVERVIEW
Baker Hughes completed its first
subsea tree system installation in
1962. Since then, we have installed
more than 1,400 subsea trees
worldwide and are at the forefrontof oil and gas field developments.
Our trees are based on standardized,
modular designs that drive highmanufacturing consistency and delivery
speed. With Make to Order lead times of
10 and 14 months, we can help you minimize
the time to first oil or gas and maximize thereturns on your project. Offering both 5-inch
and 7-inch systems, as well as a range offunctionality including gas lift, electricalsubmersible pumps and facilitating control
of intelligent completions, Baker Hughes has
the tree system to meet your needs in up to
10,000 ft (3,048 m) water depth.

We have a strong legacy in key valve andconnector technology, ensuring we deliver
trees that offer you the highest levels of
reliability and performance. Our latest trees
exceed the American Petroleum Institutestandard API 17D and demonstrate ourcommitment to building systems withindustry-leading products. For example,
our VG300 valve design, which has morethan 15,000 valves in operation, has beensuccessfully tested to 1,200 cycles –double the industry standard requirement– demonstrating the reliability androbustness of the design.

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59

APTARA™ LIGHTWEIGHTCOMPACT TREES-SERIES FOR SHALLOW
WATER~10,000 ft (3,048 m), 10,000 psi,
300°F (149°C)
60~330 ft (100 m), 6,500 psi,
250°F (121°C)
SVXT vertical tree

66

D-SERIES FOR DEEPWATERSHXT horizontal tree

66

Designed to reduce initial CAPEX as wellas OPEX over the entire life of your field,
our Aptara™ lightweight compact tree
uses an industry-first design.

Our light, efficient and reliable shallow
water trees are based on an in-depth
understanding of the environmental
challenges facing operators.

Our D-Series Trees take on the world’s
most challenging subsea conditions, withstructured, modular and cost-effective
designs and installation.

~10,000 ft (3,048 m), 15,000 psi,
300°F (149°C)
DVXT vertical tree

62

DHXT horizontal tree

63

SUBSEA CHOKE VALVES

Our subsea chokes meet the rigorous
demands of your wells and ensure yourreservoir performs reliably and safely.
67

M-SERIES FOR MEDIUM
WATER

Our M-Series Trees are qualified to meetrigorous international standards for subsea
products and use field-proven valvesand connectors.

~2,500 ft (750 m), 10,000 psi,
300°F (149°C)
MVXT vertical tree

64

MHXT horizontal tree

65

See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA TREESAPTARA™ LIGHTWEIGHT COMPACT TREE
Our revolutionary Aptara™ vertical tree
is lightweight and compact and uses ourlife-of-field approach to reduce not justinitial CAPEX but also OPEX over the entire lifeof your field. This TOTEX-lite approach uses aunique industry-first tree cap design thatallows it to be adapted on the seabedto address the changing requirements ofyour field over its life.
These simpler, lower-cost vertical subsea
systems incorporate 4-inch, 5-inch and7-inch production bores, 10,000 / 15,000 psi
pressure ratings and can be run with orwithout a tubing head spool. The Aptara™
lightweight compact tree can be deployed
in up to 10,000 ft (3,048 m) of water.
While our Aptara™ lightweight compact tree
is built on mature field-proven technology,
its design is driven by our life-of-fieldapproach. It uses an innovative flow paththat reduces size and complexity, which
supports faster field development, lower fieldtotal expenditure (TOTEX) and allows you torealize increased value from your reservoir.
The configuration has also been simplified,with a lower valve count requirement that still
provides all the functionality you need andcomplies with all industry standards.

The Aptara™ lightweight compact tree has
been designed with the entire lifecycle inmind and our Make to Order variant can bedelivered in 10 months. By reducing thenumber of components, the footprint andweight of the compact tree is reduced byaround 50% compared to a traditional
deepwater tree. With this reduction in sizeand complexity, comes a reduction in costs
across the entire manufacturing cycle of thetree. Its size and weight offer you flexibility
during installation and enable vessel
optimization. If you want to flow the well, you
can also use a Subsea Test Tree (SSTT)
system, either before or after tree installation,
as well as a traditional Open Water
Completion Workover Riser (CWOR).
The Aptara™ lightweight compact tree
includes integrated flow metering,
comprising Baker Hughes’ Virtual Flow
Meter (VFM), downhole flow meter (SureFLO™)
and water cut measurements at the tree,
providing accurate oil, gas and water flowrate measurements at the wellhead. It also
supports enhanced real-time condition
monitoring and diagnostics enabling
active control and monitoring of subsea
equipment integrity.

Aptara™ Lightweight Compact Tree
FeatureMake to Order

Variant

5 Options

Production bore size (inches)51⁄ 8 / 71⁄ 16

Pressure rating (psi)10,000Temperature rating (operating)

0°F to 300°F(-18°C to 149°C)

Depth capability

10,000 ft (3,048 m)

Tubing head spool

Optional

Gas lift

Optional

Downhole function lines

11

Connection system

Horizontal / Vertical

Configure to Order

15,000

Typical lead time:
10,000 ft (3,048 m)

10 months

Our Make to Order Aptara™ lightweightcompact tree variant can be deliveredin 10 months.

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SUBSEA TREESAPTARA™ LIGHTWEIGHTCOMPACT TREE

Our Aptara™ lightweight compact treesystem adapts as your needs change
through the entire life of your field, witha plug and play capability in the innovative
modular tree cap.

The Aptara™ lightweight compact tree allows
your tree system to evolve to suit changing
reservoir conditions. Its unique patented
industry-first design involves an innovative
flow path and tree caps that integrate
functionality such as High Integrity Pipeline
Protection (HIPPS) or add boosting capability
to reduce your overall development cost or
increase reservoir recovery. The life-of-field
cap also facilitates conversion of subsea
wells from producer to water injection,
adapting your subsea infrastructure to meetyour reservoir management needs. Mounting
this technology on the tree removes theneed for independent modules andconnections, reducing your costs further.
The compact tree has a significantly
reduced footprint compared with traditional
deepwater subsea trees, which means 50%
less weight and the potential to reduce TOTEX(CAPEX + OPEX) of the subsea system bymore than 50%.
The system is configured for up to 11
downhole functions, including well safetyvalves, chemical injection, intelligent
completions and two electric functions,adding further flexibility and functionality to
improve well performance when installed on
Tubing Head Spool. The System is configured
for up to nine downhole functions when
installed directly on Wellhead.

Operations can be optimized withlife-of-field tree caps configured for thechanging demands of a wells lifetime

HIPPS TREE CAP

The HIPPS tree cap can be added when thepressure is high at the beginning of the field
life. This increases your cost efficiency byeffectively downrating the subsea pipeline
and risers to transient flow pressures. The
HIPPS tree cap eliminates the need for the
traditional HIPPS module along with all its
associated equipment and installation costs.
Additionally, as HIPPS is not required beyond
the initial phase, the HIPPS tree cap can beeasily swapped for a production tree cap
and can be used elsewhere.

HIPPS tree cap

PRODUCTION TREE CAP

As reservoir pressure falls, or when a HIPPS
is not needed, a standard production cap
can be installed.

BOOSTING TREE CAP

When boosting is needed in later life of the
field, a boosting system can be configured
and installed as a tree cap without the needfor more equipment on the sea bed. This canincrease field output and improve theeconomics of the field.

Boosting tree cap

Production tree cap

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SUBSEA TREES

D-SERIES FOR DEEPWATER
Our D-Series Trees incorporate more than
55 years of our design heritage and subsea
experience. They take on the world’s
most challenging subsea conditions,with efficient and cost-effective designs
and installation following a structured,
modular approach.
Our deepwater D-Series modular shortdelivery subsea tree systems are engineered
for up to 15,000 psi and 10,000 ft (3,048 m)
water depth, with an operating temperature
range of 0°F to 300°F (-18°C to 149°C).
They feature our DW-HTH4 connector,
which provides high capacity and fatigue
resistance, as well as the field-proven
VG-300 valve product line and Baker Hughes’
unrivalled range of controls and connections
to complement the system, providing a
reliable solution for our customers’ fielddevelopment needs.

DVXT Structured Product Boundaries
FeatureMake to Order

Configure to Order

Variant

3 Options

Prod. Bore Size (inches)

51⁄8 or 71⁄16

Pressure rating

10,000psi

Temperature Rating (Operating)

0°F to 300°F(-18°C to 149°C)

0°F to 335°F(-18°C to 168°C) for 7

Depth Capability

4,921ft to 6,561ft(1,500M to 2,000m)

10,000ft(3,048m)

Flow Control Module

Yes

No

Gas liftNo

Yes

Downhole function lines

2, 4 or 8

Up to 11

Connection system

Horizontal /Vertical

The financial viability of deepwater projects
can be a challenge, so the minimized leadtimes we offer are a significant enabler for
operators in the oil and gas industry. Our
modular approach helps us to increase
quality and reduce lead times considerably.
The systems can be installed from a vessel ora mobile offshore drilling unit (MODU) in linewith a field operator’s installation preference.
The systems have an enhanced bending
capacity of 5.25 million ft-lb, improving
safety and reliability, and can be suppliedwith an optional retrievable Flow Control
Module to improve intervention functionality
and minimize life-of-field costs. The D-Series
includes both standard production-bore
sizing as well as large bore trees for gas
developments to allow faster flowrates
that improve field economics.

DEEPWATER VERTICALTREE (DVXT)Our Deepwater Vertical Tree (DVXT) offers
simple installation with functional flexibility.
The DVXT system is a truly flexible structured
system that conforms with all operators’
installation methodologies. The system canbe installed using a simple support vessel
and has the flexibility to accommodate
either a blowout preventer (BOP) or Open
Water Completion Workover Riser (CWOR)
system on the tree. Our flexible design also
allows for installation on a tubing head spool,or directly onto the wellhead delivering
additional CAPEX and OPEX benefits.
The system is configured for up to 11
downhole functions, including well safetyvalves, chemical injection, intelligent
completions and two electric functions,adding further flexibility and functionality to
improve well performance when on Tubing
Head Spool. The system is configured for up
to nine downhole functions when installed
direct on Wellhead. By making the Production
and Annulus Wing valves integral to the
Master Valve Block and removing bolton arrangements, not only have we removed
potential leak paths but we have also
reduced the weight of the tree.

Typical lead time:

14 months

Our Make to Order DVXT variants
can be delivered in 14 months.

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SUBSEA TREESDEEPWATER HORIZONTALTREE (DHXT)

Our Deepwater Horizontal Tree (DHXT)
can be configured for production or water,
gas or alternating injection.
This DHXT tree system’s highly flexible designand capability improves both reservoir
management and hydrocarbon recovery.
It is compact and lightweight, with a flush
top plate and extended mandrel for efficient
blowout preventer (BOP) operation. And withup to nine hydraulic downhole functions,
you can rely on the highest standard ofintelligent well control.

Feature5" DHXT Structured Product Boundaries

7" DHXT Structured Product Boundaries

Make to Order

Make to Order

Configure to Order

Variant

Multiple

Prod. Bore Size (inches)

51⁄8

Pressure rating

10,000psi

15,000psi

10,000psi

Temperature Rating(Operating)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

0°F to 300°F(-18°C to 149°C)

Depth Capability

6,561ft (2,000m)

10,000ft (3,048m)

10,000 ft (3,048 m)

The DHXT comes with either 5-inch or
7-inch production bores and the system isconfigured for up to ten downhole functions,
including well safety valves, chemical
injection, intelligent completions and twoelectric functions, adding further flexibility andfunctionality to improve well performance.
In addition, the system benefits from multiple
pressure, temperature and sand detection
sensors, as well as a variety of features thatminimize intervention and maximize the field
performance data available.

Configure to Order

2 Options71⁄16

Flow Control Module

Optional

Yes

Gas lift

Optional

No

Downhole function lines

10

Connection system

Horizontal / Vertical

Up to 10

5
Horizontal

0°F to 300°F(-18°C to 149°C)
No

Typical lead time:

12 months

Our Make to Order DHXT variants
can be delivered in 12 months.

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SUBSEA TREES

M-SERIES FOR MEDIUM WATER
Our M-Series trees have served the industry
for more than 30 years and are designed forwater depths of up to 2,500 ft (750 m), withinstallation possible from semi-submersibleor jack-up drilling rigs. They are qualified
to meet the most rigorous international
standards for subsea products – API,ISO and NORSOK – and they use standard,field-proven VG300 valves and H4 connectors.
Designed to accommodate guideline drillingand completion techniques, our M-Series
subsea tree systems can also be run
guideline-less using vessels of convenience,
offering the potential to reduce installation
costs. They are engineered for 10,000 psi, andan operating temperature range of 0°F to
300°F (-18°C to 149°C).

MVXT Structured Product Boundaries
FeatureMake to Order

Configure to Order

Variant

2 Options

Production bore size (inches)

51⁄8

Pressure rating (psi)10,000Temperature rating (operating)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)
2,460 ft (750 m)

71⁄16

Depth capability

820 ft (250 m)

Electrical submersible pumpsNo

Gas lift

Optional

Downhole function lines

6Connection system

Diver

Horizontal / Vertical

Guidance fishing protection

Flowbase

Guide base NORSOKTo date, Baker Hughes has installed morethan 700 M-Series Trees in offshore basinsaround the world. With our proven installation
tools, diverless installation and connection
to flowlines and umbilicals using our HCCS
connection systems, the M-Series
accelerates your time to first oil. All our
M-Series trees have options for oil, gas, water
injection and Electrical submersible pumps
applications to enhance reservoir
management and hydrocarbon recovery.
They are also suitable for template, fisherfriendly and NORSOK protection structuresin heavy fishing areas.
The M-Series tree rental tools suite offers
an option to minimize CAPEX for small fielddevelopments and allow greater flexibility
with your planning developments andbudgets. The tools can be deployed to any
location to meet specific operational needs
and provide everything you require for wellintervention and maintenance.

MEDIUM WATER VERTICALTREE (MVXT)

Our Medium Water Vertical Tree (MVXT)
is highly compatible with a range of drilling
fleets and rigs.
Our guideline MVXT has been used
extensively in offshore basins around theworld. It provides wide flexibility in fielddevelopment planning and is designed forboth cluster and template applications.
The system is configured for up to six
downhole functions, including well safetyvalves, chemical injection, intelligent
completions and two electric functions,adding further flexibility and functionality
to improve well performance.
The MVXT can be installed directly onto yourcompleted wellhead to enable batch setting
and early completion of the field, minimizing
your time to first oil.

Typical lead time:

12 months

Our Make to Order MVXT variants
can be delivered in 12 months.

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SUBSEA TREESMEDIUM WATER
HORIZONTAL TREE (MHXT)
Our Medium Water Horizontal Tree (MHXT)
is compatible with industry-recognized18¾-inch drilling systems.

The system is configured for up to six
downhole functions, including well safetyvalves, chemical injection, intelligent
completions and two electric functions,adding further flexibility and functionality
to improve well performance.

Our MHXT is well established in offshoredevelopments around the world. The tree
design allows for installation of the tubing
hanger directly into the tree master valve
block – eliminating the need for an openwater completion riser and reducing yourproject CAPEX. The tree also provides
flexibility for drilling from jack-up rigs, as well
as from semi submersibles and drillships.

MHXT Structured Product Boundaries
FeatureMake to Order

Variant

2 Options

Configure to Order

Production bore size (inches)

51⁄8

Pressure rating (psi)10,000Temperature rating (operating)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

Depth capability

820 ft (250 m)

2,460 ft (750 m)

Electrical submersible pumps

Optional

Gas lift

Optional

Downhole function lines

6Connection system

Diver

Horizontal / Vertical

Fishing protection

Fisher friendly

Multi-flowbase

Installation

Guidelineless

Guidelineless /Flowbase

The MHXT provides flexibility covering bothcluster or template configurations, allowing
your field architecture to be optimized andhelping to minimize costs during initialdevelopment. It also simplifies intervention
operations through ease of access to thecompletion when increased downhole
activity is required. The tree system is readily
suited to the needs of Gas Lift and electricalsubmersible pumps to address small poolhydrocarbon recovery and improve yourdevelopment’s economics.

71⁄16

Typical lead time:

11 months

Our Make to Order MHXT variants
can be delivered in 11 months.

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SUBSEA TREESS-SERIES FOR SHALLOW WATER
Monetizing stranded reserves in shallow
waters requires an appropriate solution.
Baker Hughes is the industry leader inshallow water trees with more than 35%
of installations worldwide since 2000.
Our light, efficient and reliable designs
are based on an in-depth understanding ofenvironmental challenges facing operators– including weather, sub-surface currents,
poor visibility, and fishing interaction.
Our S-Series Trees allow you to maximize
safety and efficiency for jack-up drilling
operations in water depths up to 328 ft (100m), operating pressures up to 6,500 psi andtemperatures between 0°F to 250°F (-18°C to
121°C). Our designs enable deployment using
standard offshore jack-up drilling rigs andno need for major modifications.
The S-Series features an innovative barrier
design that blends Horizontal and Vertical Treetechnology, removing the need for a swab
valve through use of Crown Plugs and reducing
your CAPEX, while simultaneously helping to
reduce the overall height of the system.

SVXT Structured
Product Boundaries

SHXT Structured
Product Boundaries

FeatureMake to Order

Make to Order

Variant

2 Options

2 Options

Production bore size (inches)

5

51⁄8

Pressure rating (psi)

6,500

5,000

Temperature rating(operating)

0°F to 250°F(-18°C to 121°C)

0°F to 250°F(-18°C to 121°C)

Depth capability

328 ft (100 m)

262 ft (80 m)

Wellhead size (inches)

135⁄8

135⁄8

Gas lift

Optional

Optional

Control system

Direct Hydraulic/Electrohydraulic

Direct Hydraulic

3

6

Downhole function lines

Configure to
Order

Baker Hughes' Smart Tools can further
improve installation by performing multiple
functions with reduced trips. They can also
eliminate the need for diver or remotevehicle (ROV) assistance by deploying
camera technology to the tree and tools. This
reduces your dependency on weather
conditions, giving greater flexibility for launchscheduling and logistics

SHALLOW WATERVERTICAL TREE (SVXT)Electrohydraulic

Our Shallow Water Vertical Tree (SVXT)
is 20% lighter and 30% shorter than
traditional tree-on-mudline systems.
Using the field-proven 135/8" Wellheadsystem, our SVXT vertical tree offers a lightarchitecture arrangement with options ofmudline conversion. Its optimized modular
core block components are fully integrated
with Baker Hughes control systems.
It offers fisher-friendly wellhead protection
structures and an innovative barrier
philosophy that removes the need fora separate tree cap. With a simplified
installation process, reduced diver and ROV
operational intervention and the option of agas lift, the SVXT offers you significant costand operational advantages over a fixed
platform or semi-submersible drilled well.
The system is configured for up to threedownhole functions, adding further flexibility
and functionality to improve well performance.

SHALLOW WATER
HORIZONTAL TREE (SHXT)Our Shallow Water Horizontal Tree (SHXT)
is designed to increase tubing size anddelivers high performance.

The SHXT integrates the latest technologies
and offers lower installation and operating
costs. Building on the heritage of our
traditional horizontal systems, the SHXT canbe run with a high-pressure riser for fast andmore efficient installation of the completion.
The system is configured for up to five
downhole functions, including well safetyvalves, chemical injection, intelligent
completions and two electric functions,adding further flexibility and functionality.
Typical lead time:

11 months

Our Make to Order SVXT / SHXT variants
can be delivered in 11 months.

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SUBSEA TREESSUBSEA CHOKE VALVESWith our wealth of experience in the design
and manufacture of the equipment required
to meet the rigorous demands of wells,
including the recent trend towards large
bore gas developments, we have thesubsea chokes you need to ensure yourreservoir performs reliably and safely.
Our latest Hydraulic Stepping Choke has
been qualified to API, ISO and NACE
standards with endurance testing to twicethat required, with more than two million
steps performed. Our design allows forboth fast actuation timing and superior
controllability and stepping resolution,
which gives you greater control of the
production and injection rates.
To date, we have supplied more than
2,000 subsea choke valves, offering modular
configuration options for production,
injection, MEG (monoethylene glycol)
injection, and gas lift applications, for insert
retrievable or non-retrievable operations,and for shallow to deepwater use. Our
chokes are available integrated with oneof our subsea tree systems, or as a single
supply with a lead time of around 7 months.

Comprising a high integrity forged one-piecechoke body and using a single-stage HighFriction HF-LCV design, our ‘plug and cage’trim design has been used successfully on
debris/sandy service applications – withmultiple trim options that provide the specificrange-ability for the application. This proventrim technology controls the flow and thetrim design minimizes erosion, vibration andnoise within the system. For water injection
applications we can offer multi-stage trims
to mitigate the onset of cavitation.
The valve actuator consists of a core
gearbox with a proven high-integrity‘ratchet and pawl’ design and pulsed/
stepped hydraulic cylinders that provide themotive power. The actuator is of the “fail asis” position type, though we provide you with
options for either side or top over-ride aspart of our modular configuration design.
Our chokes are nominal 2", 5" or 7" sizes
and are engineered to operate in water
depths up to 10,000 ft (3,048 m), operatingpressures of 6,500 psi to 10,000 psi andoperating temperatures between -51°F to
300°F (-46°C to 149°C). We use provenmaterials with premium grade Tungsten
Carbides and Corrosion Resistant Alloys
for longevity in field life.

Typical lead time:

7 months

Our Make to Order Subsea Choke
Valves can be delivered in 7 months.

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SUBSEA
CONTROL SYSTEMSOVERVIEW
All production availability isunderpinned by the reliabilityof your Subsea Control System.
Baker Hughes' control systemequipment is designed forreliability, from the unrivaled
and industry-leading SemStar5
electronics module, to our
Smart distributed flow
meter and uniquely andhighly-maintainable FLX360.

Our Subsea Control Systems comewith dual redundancy throughout,highly effective heat-management andobsolescence-managed components.
Our subsea electronics are all subjected toHighly Accelerated Life Testing (HALT) as partof the design process and during production
they are exposed to stringent Environmental
Stress Screening (ESS) in the factory. We
use purpose-designed Automated Test
Equipment to monitor a Subsea Electronics
Module throughout ESS, testing it to both thespirit and letter of API 17F. This is how weachieve a result of Mean Time Between
Failures (MTBF) that is 10 times better thanthe Offshore and Onshore Reliability Data
Project (OREDA) average – weeding out thecauses of possible failure on every unit
manufactured.

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SEMSTAR5 SUBSEAELECTRONICS MODULE

HYDRAULIC POWER GENERATION

SemStar5 is our ultra-reliable fifthgeneration subsea electronics module forcontrol systems and draws on 40 yearsof Baker Hughes’ subsea experience.
70

MODPOD SUBSEA CONTROLMODULEWith its configurable and compact design,
our ModPod is one of the most advanced,
versatile and reliable control systemcomponents available.
71

MASTER CONTROL STATION

While our Hydraulic Power Units aredesigned to meet your specificrequirements, they are engineered andbuilt around standard building blocks.
77

SUBSEA DISTRIBUTION UNIT (SDU)

Our distribution product portfolio enables
you to extend the boundaries of subsea
production by focusing on simpler,
lower cost and optimized solutions.
78

UMBILICAL TERMINATIONASSEMBLY (UTA)

Our Master Control Station is the unit thatbrings together the control and monitoringof your Subsea Control System.
72

Our UTA products offer a wide range ofconfiguration to meet the most demanding
field requirements whilst simplifying
installation and operability.
80

SUBSEA COMMUNICATIONSAND ROUTING

MULTIBORE HUB CONNECTION(MHC UTA)

Our approach to subsea network
reliability that has made Baker Hughes amarket leader in the provision ofcomplex subsea control networks.
Subsea Communications and Routing

74

Redundant Bus75

Redundant Star

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UMBILICAL HEALTH MONITORING

Our Umbilical Monitoring Device (UMD) is
specifically designed to monitor the healthof an umbilical’s electrical conductors
continuously.
76

Our MHC-UTA provides Totex savings andsimplified seabed infrastructures withdirect tie-in of umbilicals to the manifold
or SDU.
81

APTARA™ FLX360 MULTI-QUICKCONNECTION SYSTEM

Our FLX360 is an innovative Multi-Quick
Connect (MQC) system that enables fastand reliable connections between allelements of the subsea distribution system.
82
See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA CONTROL SYSTEMSSEMSTAR5 SUBSEA ELECTRONICS MODULE
SemStar5 is our ultra-reliable fifthgeneration subsea electronics module
for control systems. It has industry-leading
reliability, with a mean time between failures(MTBF) of more than 150 years, 10 times the
Offshore and Onshore Reliability Data
project (OREDA) average.
SemStar5 draws on the design heritageand learning from over 40 years of subsea
controls experience. It is modular inconstruction and highly configurable tomeet wide-ranging customer needs fromthe control and monitoring of trees andmanifolds, to SIL2 and SIL3 safety systems,
such as Process Shut Down (PSD) andHigh-Integrity Pipeline Protection System(HIPPS) systems.
The SemStar5 has been extensively qualified
and proven in the field, with orders for morethan 600 with 225 units already deployedsince 2011. It is Technology Readiness Level(TRL) 7 and can be delivered with a typicallead time of seven months.

Subsea Electronics Module – SemStar5
FeatureMake to Order

Make to Order

Make to Order

Variant

1 Option
Low Power

1 Option
Medium Power

1 OptionHigh PowerPower consumption< 150 W

< 200 W

< 300 W

Operatingenvironment

23°F to 104°F (-5°C
to 40°C) at 9,842 ft(3,000 m) water
depth

23°F to 104°F (-5°C
to 40°C) at 9,842 ft(3,000 m) water
depth

23°F to 104°F (-5°C
to 40°C) at 9,842 ft(3,000 m) water
depth

DHPTG interface

Baker Hughes,
Schlumberger, Well
Dynamics

Baker Hughes,
Schlumberger, Well
Dynamics

Baker Hughes,
Schlumberger, Well
Dynamics

Communications
type

Point-to-point:
Point-to-point:
Point-to-point:
CAPS DSLCAPS DSLCAPS DSLCAPS Ethernet
CAPS Ethernet
CAPS Ethernet
Multidrop:
Multidrop:
Multidrop:
CAPS Cooper Modem CAPS Cooper Modem CAPS Cooper Modem
COPS Copper Modem COPS Copper Modem COPS Copper Modem

Dimensions –Dia x L (mm)275 x 912

275 x 912

275 x 1,155

Weight, max< 286 lbs (130 kg)<309 lbs (140 kg)<341 lbs (155 kg)

Reliability extends to our product design,where we specify the use of industrial grade
components and all electronic components
are de-rated accordingly. Because weknow that heat is the greatest threat to thereliability of electronics, SemStar5 has been
designed for effective heat-dissipation,
through careful choice of materials andthermal modeling. The robustness of thedesign has also been demonstrated byboth accelerated life testing (ALT) andhighly-accelerated life testing (HALT), testing
the unit in extreme temperatures andvibration conditions to truly understand its
performance boundaries and modifying thedesign and component selection accordingly.

The SemStar5 employs Baker Hughes’
high-end networking capability to connect
using dynamic, Layer 3 networks. Its software
comprises a set of layered components
deployed as a single package that executeson each PCB within the unit. This common
firmware and hardware used on eachfunctional card facilitates obsolescencemanagement, as the brain on each
SemStar5 card can be separated andupgraded without redesign of the cards
themselves. We use a cross-industry realtime operating system, QNX, for the unit’s
TCP/IP Ethernet backplane, and external
connection to Ethernet enabled devices.
SemStar5 has been designed to be
backwards compatible with legacy Baker
Hughes SEMs. Our ‘SEMulation’ software
allows SemStar5 to emulate legacy SEMs
without disruption to existing topside
hardware or operator interfaces, as
demonstrated on many successfully
upgraded projects. This provides an
upgrade path to maintain or expand
older systems without the need forcostly infrastructure changes.
System redundancy continues into the
SemStar5 itself, using a redundant 100 Mbit/s
ethernet Backplane and Interbay-comms
and a redundant DC power bus to eachplug-in module – reducing wiring by 50%
and further improving availability of thecontrol system. In situ downloading ofsoftware is also permitted to ensure theunit is future proof.
Typical lead time:

7 months

The SemStar5’s Make to Ordervariants can be delivered in 7 months.

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SUBSEA CONTROL SYSTEMSMODPOD SUBSEA CONTROL MODULE
We know that the safe and efficient
control of subsea production systems
is at the top of our customers’ priorities.
That’s why we have ensured the Baker
Hughes Subsea Control Module, ‘ModPod’, is
one of the most technologically advanced,
versatile and reliable control systemcomponents available.
ModPod is a multiplexed electro-hydraulic
Subsea Control Module (SCM), typically used
for subsea tree and manifold-mounted
applications. It is also used for wider
applications such as subsea interventions,workovers, safety-systems and subsea
isolation valve (SSIV) control. It ensures thestable and reliable control of subsea valves,
while providing the communications andsensor data read-back required to maintain
optimal operational efficiency.

Subsea Control Module (SCM)
FeatureMake to Order

Variant

1 Option

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

Depth capability

6,561 ft (2,000 m)

Size – W x D x H (mm)770 x 770 x 1,550

Weight in air

6,172 lbs (2,000 kg)

Weight in water

3,527 lbs (1,600 kg)

LP working pressure (psi)

5,000

3,000

Number of hydraulic functions

Up to 24

Up to 42

HP working pressure (psi)10,000

SCM base connector manufacturer Siemens Tronic

Configure to Order

9,842 ft (3,000 m)

Teledyne ODI

SCM base connector quantity

Up to 6

Open/Close Loop

Open

Close

Control Fluids

MTO: –
 Transaqua HT2– Oceanic HW443– Oceanic HW540 (and P)– Oceanic 740R

CTO: Any Water Glycol fluid
subject to qualification andcompatibility testing

The ModPod’s modular, configurable design,in conjunction with Baker Hughes’ structured
engineering and quality processes, enables
short cycle times and certainty of schedule.
This allows us to deliver Make to Ordervariants as fast as nine months.
Common ModPod components across all
applications also means repeatable build
processes, improving reliability at the coreof your subsea system. Every manufactured
unit is subjected to hyperbaric testing to9,842 ft (3000 m). Using standard
components allows us to volume source
them, extending reliability into the supply
chain and bringing down the capital costof this unit in our customers’ production
systems – a principle that extends to the
SemStar5 units within the ModPod.
To date, we have delivered more than 1,000
ModPods to our customers and the SCM
has a proven track record across a rangeof high-functionality applications, hitting
production availability targets of over 99%.

The ModPod is API17F, SIIS and IWIS compliant.
The standard Make to Order ModPod
configuration supports 24 control functions,sufficient for most subsea production
applications; however, ModPod variants canbe configured to control up to 42 hydraulicfunctions, enough even for subsea workover
control applications. It also offers integral
hydraulic filtration and accumulation andhydraulic filtration, which means that
separate subsea accumulation modules
are not required, reducing the total cost ofownership over the asset life and improving
the control system reliability.
Baker Hughes has been designing andmanufacturing directional controls valves(DCV) for use in the Mod-Pod Subsea
Controls Module (SCM) for over 25 years.
The product has undergone continual
development and design validation to meetthe ever increasing demands of controls
systems from a reliability, availability andsafety perspective.
Baker Hughes DCVs are qualified to
10,000psi with a variety of control fluids.
Validation work is continuous, and the
product line is continuing to evolve to meetthe requirements of HPHT (15,000psi and
350F) and 20,000psi field requirements.

Typical lead time:

9 months

While we can offer a fully configured
solution, our Make to Order ModPod
can be delivered in 9 months.

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SUBSEA CONTROL SYSTEMSMASTER CONTROL STATION
Our Master Control Station (MCS) is
the unit that brings together the control
and monitoring of your Subsea Control
System (SCS). It is designed to operate
in conjunction with other topside safety,
utility, and management systems.
The MCS enables you to control and monitor
your subsea facilities from either the host
ICSS/DCS, via TCP/IP, OPC UA/DS or MDIS,or from the unit’s local Human MachineInterface (HMI). We can also offer an option
where you can use a Remote Operator Work
Station, providing full MCS capability from astandalone workstation remote from the MCS
itself. This Remote Operator Workstation canbe located anywhere with a network link to
the MCS, be it in the Central Control Room,or in a remote location away from thehost facility.

Typical lead time:

10 months

We can deliver a Master Control
System in 10 months, configured
to our standard two-cabinet
base build to handle up to 16 wells(or more with additional cabinets).

A Make to Order MCS can be delivered in
10 months, configured for any field or projectsize. The unit is modular in construction andbased around two cabinets for the controlof 16 wells, packaged for efficient use of
space and minimizing the topside footprint
required. The first cabinet houses thehost servers and local HMI/Engineering
Workstation and routers. The second cabinet
contains programmable logic controllers(PLCs) for the handing of and processing ofdata from the subsea equipment. Fields ofgreater than 16 wells are accommodated
simply by adding more PLC cabinets.
The MCS’s HMI allows you to view the statusof all the field’s subsea devices in one place,monitoring everything from your drill centers
and wells, to your manifolds and sensors.
It has a layered graphical interface that
presents an overview, plus detailed screensthat enable you to run diagnostics, as well as
capture and record required data. Local area
networks also allow the MCS to provide
control and data acquisition from otherassociated equipment, such as the HydraulicPower Unit (HPU), Electrical Power Unit (EPU)or Uninterruptible Power Supply (UPS).

As an integral element of control system
reliability, and therefore a driver for overallsystem availability, the MCS employs
technology you can rely on. This includes
robust components proven in Baker Hughes
systems over decades, including the
Rockwell Allan Bradley Control Logix PLC.
The PLC runs software written in ladderlogic, using predefined Add-On Instructions(discrete function blocks) that come from
Baker Hughes’ standard software library,obsolescence-managed offline from project
execution, pre-tested and configured toeach project application. The MCS’s
architecture is designed to provide seamless
operation, allowing for in-built redundancy,with a hot standby and bump-less transfer
between the active and standby system.
Security is also a paramount requirement for
any control unit and the MCS is compliant
with the cyber security requirement of
IEC62443-2-4. The unit’s HMI has several
operational modes with password protected
access privileges. Only the highest privilege
enables full device configuration and valve
and choke control, the setting of alarm limits
and shutdown sequences.

IC-MCS (Industrial Controller – Master
Control Station).
Where Programmable Logic Controllers are
not a requirement, and when topside spaceis at a premium, Baker Hughes can offer an
IC-MCS.
This technology utilises Beckhoff’s TwinCAT
3 eXtended Automated Technology (XAT)
operating under Ring 0 (i.e. on a Kernel) of
redundant servers. Running ‘above’ any
Operating System (such as Linux or Windows)
the Beckhoff system is immune to any
operating system error or failure, ensuring
there is no impact on the monitoring orcontrol of the Subsea Control System.
The Beckhoff system supports bumplesstransfer for duty/standby, and Baker Hughes
have successfully tested the control of 30
wells from a single 19" cabinet.
Subsea Gateway
For integrated ICSS/DCS & MCS solutions,
Baker Hughes can deliver a subsea
gateway. This unit contains SCI (Subsea
Communication Interface) servers which
provide a communications interface between
the Topside system communication and the
Baker Hughes subsea equipment for thesubsea control system. In this configuration,
the subsea facilities can only be controlled
and monitored from the host ICSS/DCS on
which all logic, shutdowns, sequences andinterlocks reside will reside. Communicating to
the ICSS/DCS over Modbus TCP/IP or OPC UA/
DS, the unit can be delivered MDIS-compliant.

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SUBSEA CONTROL SYSTEMSSUBSEA COMMUNICATIONS AND ROUTINGThe availability of modern subsea
production systems is largely dependent
on the reliability of the control system
software and the local area network ofmodems and devices. We use a threepronged approach to subsea network
reliability that has made Baker Hughes
an industry leader in the provision ofcomplex subsea control networks andthe development of proven modems thatare effective over the longest of Industry
offset distances.
Our network specialists start by ensuring
fault-tolerance by design. Their standard
approach to managing complex subsea
communication networks is to use Layer 3,
dynamic routing, often equivalent to thenumber of communication nodes in alarge office building.

Power Communications Distribution Module (PCDM)
FeatureMake to Order

Make to Order

Make to Order

Variant

2 Options
6 Slot Manifold

2 Options
8 Slot Manifold

2 Options
10 Slot Manifold< 250 W

< 500 W
300 – 600V

Power consumption < 250 W
including SIIS 2 Power
Input supply
Number of output
channels

300V – 600V

300V – 600V

500V – 1000V

500V – 1000V

Up to 6 SHDSL or
Ethernet + 1 Ethernet

Up to 6 SHDSL or
Ethernet + 2 Ethernet

Up to 11 SHDSL or
Ethernet

Power switching

Optional

Optional

Optional

Weight, max< 2,866 lbs (1,300 kg)<3,086 lbs (1,400 kg)<3,417 lbs (1,550 kg)

SIIS2 + power1 x 30W

1 x 20W

2 x 30W

Communications
range

Optical to 120 km

SHDSL Steel Tube
15 km

SHDSL Thermoplastic
30 km

Dimensions –W x D x H (mm)770 x 770 x 1,841

770 x 770 x 1,841

770 x 770 x 1,841

Secondly, the communication networks
are built and tested well before the projectextended factory acceptance test (eFAT),
ensuring you can ‘plug and play’ (not ‘plug
and pray’) at what is a crucial stage inyour project execution. And of course, our
SemStar5 is based on open architecture,
which makes adding, upgrading, orswapping of subsea components seamlessfor life-of-field management and ad-hoc
field expansion.

Finally, our modems are extensively tested
at the unit and system level, using our on-site
vibration beds, thermal chambers andumbilicals of copper quads and twisted
pairs. We have even run optical transceivers
through six months of Accelerated-Life-Tests
to verify vendor selection for subsea use.

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SUBSEA CONTROL SYSTEMSREDUNDANT BUS

Redundant Bus communications
are commonly known as multidrop
communications, where a master modem
is deployed topside and communicatesin turn with each subsea unit’s modem,
which are slaves to the master and anode on the bus.
The number of nodes on the bus is astandard of six; this being an optimum
compromise between offset, nodes andtopside data refresh rates.
Baker Hughes has supplied Redundant
Bus communications since 1993 on
numerous projects and it provides a
cost-effective communications solution for
low offset distances (less than 19 miles/30km). Throughout that period, Baker Hughes
has maintained a communications andpower analysis capability, understandingthat good system design is at the heartof a reliable control system.

REDUNDANT STAR

Commonly known as point to point
networks, Redundant Star communications
provide high bandwidth and fast system
update rates. They are typically used with
optical communications that travel long
offset distances (greater than 19 miles/
30 km) and where complex instruments
such as a multi-phase meter or acoustic
leak detection form part of the subsea
instrument suite.
The Make to Order solution comprises a
Master Control Station topside containing
routers that permit the use of opticaltransceivers and Ethernet. This transmits toa subsea receiving unit known as a Power
Communications Distribution Module (PCDM).
The PCDM provides up to 10 star outputs
and contains a Layer 3 switch that converts
optical signals to copper signals for onward
transmission to each of the subsea modules
in the star. Layer 3 switches allow finer
control in the management of the routingof messages through a system. The Layer 3
subsea network topology is hierarchicaland aids in the separation and prioritizationof subsea messages with full traceability.

Providing multiple active routes, the PCDM
can direct packets to their destination via amore deterministic route in link failure modes,
making communications systems morerobust. It can also increase communications
redundancy and availability by ‘crossstrapping’ (routing) between A and B units.
This mitigates a distribution failure(umbilical or UTA to PCDM failure) byenabling communications from the failed
channel PCDM to be routed to the goodchannel PCDM, which maintains A and B
communications to the units downstreamof the PCDMs.
The PCDM provides Optical Communications
Input of 100/1000Mbps, depending on
offset (Ethernet 10/100Mbps, SHDSL
5.7Mbps – 192kbps) and distribute asan output either Ethernet 10/100Mbps
or SHDSL 5.7Mbps – 192kbps.

Typical lead time (PCDM):

10 months

The PCDM can provide up to 10 star outputs
and can be delivered in 10 months.

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SUBSEA CONTROL SYSTEMSUMBILICAL HEALTH MONITORING
A subsea production umbilical is a large
component of your overall system capitalcosts and is expected to last the lifetimeof your asset. Continuous monitoring of
the health of your umbilicals is criticalto the smooth functioning of your wholesubsea control system. It can provide
advance warning if any degradation in thesystem is expected and allow preventative
measures to be put in place in a timely
and OPEX-efficient manner.
The Baker Hughes Umbilical Monitoring
Device (UMD) is specifically designed tomonitor the health of an umbilical’s electricalconductors continuously. It measures theinsulation resistance between the umbilicalelectrical conductors and the system groundwith high sensitivity, to which the umbilical isconnected by applying a DC signal (lessthan 50 V) in analogue mode, and a pulsed
DC signal in digital mode. The Baker Hughes
UMD can measure with 1,000 times thesensitivity of a legacy traditional Line
Insulation Monitor. The device’s highsensitivity is achieved through intelligent
signal amplification, a precise online
calibration service and DC-offset
detection and elimination.

With its sophisticated hardware andadvanced software algorithms, the UMD candetect a wide range of leakage conditions
in your electrical umbilical cores.
Unlike generic Insulation Resistance (IR)monitoring devices for cross-industry use,
the Baker Hughes UMD has a range andaccuracy designed specifically for subsea
umbilicals: less than 5% error for umbilicalsof 10 KΩ to 5 GΩ and less than 20% error
for umbilicals of 5 GΩ to 10 GΩ. Leakage
capacitance measurements are in the
100 nF to 1 μFT range. This range andaccuracy provide more extensive andgranular data for the Baker Hughes Digital
IR-Monitoring application, which in turnprovides continuous and predictive
analysis of subsea insulation resistance.
This enables timely intervention during
planned interventions, rather than adhoc resolution of IR-related failures.

The UMD has two alarm settings, Low (L)and Low-Low (LL). These are triggered whenthe electrical conductor IR falls below thedesired thresholds; the parameters ofwhich are easily configured. The signal for
the L or LL alarm can be seen through thecommunications interface and it will also
activate a visible LED indicator on the front
panel of the unit. Configuration for audible
alarms and isolation of power to the primaryof the subsea isolation transformer canbe enabled.
The UMD can actively function whileconnected to umbilicals powered up to
1,000 VAC at 50–60 Hz. It has an online
earth test circuit that warns if the unit is notadequately grounded. An earth fault allows
an earth leakage current to flow through themeasuring circuit to calculate IR in analoguemode, or IR and leakage capacitance (CL)in digital mode. Using these parameters,
the UMD calculates the exact conditionof the umbilical system without affecting
your subsea power.

Typical lead time:

10 months

A UMD is provided as part of an ElectricalPower Unit (EPU), or Subsea Power andComms Unit (SPCU), with a lead timeof 10 months.

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SUBSEA CONTROL SYSTEMSHYDRAULIC POWER GENERATION
An effective control system requires astable, redundant supply of clean hydraulicpower from the topside Hydraulic Power
Units (HPUs). At Baker Hughes, we analyze
the requirements of the whole field before
specifying, designing and manufacturing
a solution that is suitable for all existing
requirements and any future
expansion cases.
Our Configure to Order HPU is specified with
supply and return reservoirs, a transfer pump
to fill and recirculate fluid within the unit,
electric/pneumatic powered pumps, filters,
accumulator banks and other appropriate
instrumentation and equipment, such as
electric/pneumatic ESD valves, pressure
sensors, tank limit switches, pressure safety
and relief valves.

While the HPUs we build are designed tomeet the specific requirements of your field,
they are configured and built around thesestandard building blocks, enabling us toprovide cycle times of 11 months. Equally, we
review all client specifications to ensure thatthe configuration meets their requirements
and that any sub components are suitably
rated for quality. The standard materials
used in our HPUs can also be tailored tomeet your unique project requirements
for demanding fluids or environments.
We also offer a wide range of field support
to our HPUs during the life of a field frominitial development through to theworkover of a well. This includes ongoingproduction support, the flushing ofequipment to clean the fluid, and pressure
testing equipment and components,
often at very high pressures.
Manufactured on DNV2.7-3 rated skids,
our HPUs meet all local and regional TRS
requirements, including ATEX, ASME and PED.
Any specific regional legislation is considered
carefully during the initial design phase.

Hydraulic power generation – HPU
FeatureMake to Order

Make to Order

Make to Order

Configure to Order

Variant

1 Option

1 Option

1 Option

Region

North Sea

Asia Pacific

Africa / N.America

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

Size W x D x H (mm)Up to 9,000 x 3,000 x 3,300

Up to 9,000 x 3,000 x 3,300

Up to 9,000 x 3,000 x 3,300

Weight in air

Up to 55,115 lbs (25,000 kg)
Dry weight

Up to 55,115 lbs (25,000 kg)
Dry weight

Up to 55,115 lbs (25,000 kg)
Dry weight

Testing

Std testing

Std testing

Std testing

Std + 3rd party witness

Quality requirements

Std ITPStd ITPStd ITP

Customer ITP + 3rd part
inspection

Field Driven

Typical lead time:

10 months

Our Make to Order HPU can be deliveredin 10 months, while a fully configured unit
would take 11 months.

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SUBSEA CONTROL SYSTEMSSUBSEA DISTRIBUTION UNIT (SDU)
Operating a successful oil and gas
production system in a demanding
subsea environment requires a complex,
yet robust distribution system that will
deliver the hydraulic and electrical power,
communications and chemicals precisely
where and when you need them.
Developing such a system demands a broad
understanding of your field performancerequirements and well conditions.
Our distribution product portfolio enables
our customers to extend the boundaries
of subsea production by focusing on
simpler, lower cost and optimized solutions
that put the system at the core. Taking
a Total Expenditure (TOTEX) approach, webuild fully integrated and highly reliable
distribution system equipment to ensurehigh availability throughout your subsea
facilities – from trees and manifolds, tosubsea isolation valves (SSIVs), andprocessing or boosting installations.
The Subsea Distribution Unit (SDU) provide
Hydraulic, Chemical, Optical and Electrical
distribution to XT, manifolds and UTA througha direct tie-in of the main or infield umbilicalusing our Aptara™ Horizontal Clamp
Connection System Light (HCCS-L) multibore
UTA and Aptara™ FLX360 hydraulic flying leadconnections which reduces the overall size
and weight and saves installation andmake up time offshore.
The SDU Module is a retrievable structure
independent from the foundation structure
and accommodates all the pipe/tube workwith related valves and can be configured
with hydraulic stab plates (STFL), HCCS-L
connections, electrical flying leadconnections as well host power andcommunication distribution modules(PCDM) or electrical distribution unit (EDU)
as per your needs in order to optimize yourfield controls distribution philosophy.

With our fullstream capability, we offer afull range of installation support, including
field service engineers, test equipment andtooling where required. Access to our global
services means you can also rely on thebest possible lead times, typically around
10 months for our Make to Order productofferings. These services are not only
available to you during the build andinstallation process, but also for ongoingsupport throughout the entire productand field life.
Our industry-leading design teams havethe expertise and resources to ensure thatyour complete subsea distribution system
not only benefits from the highest levelof engineering optimization and leanmanufacturing best practices but isalso focused on reducing TOTEX.
Our people bring extensive experienceof designing subsea distribution equipment,along with a wealth of knowledge ofdifferent installation methods to suitdiffering water depths and field locations.
Their capabilities include in-housedevelopment and performance ofcomprehensive testing programs – suchas essential extended factory acceptancetesting (EFAT) and site integration tests (SITs)
prior to system deployment.

Typical lead time:

10 months

A fully integrated subsea distribution
system can be delivered in 10 months.

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SUBSEA CONTROL SYSTEMSUMBILICAL TERMINATION ASSEMBLY (UTA)The Umbilical Termination Assembly breaks
out the SPS services housed within the
Umbilical distributing them to the networkof subsea structures. Taking as reference
the steel tube umbilical (static and dynamicboth), the UTA enable break out of the fluid
conduits (hydraulic and chemical) as wellas the electrical cables and the fibre opticalcables. These are then terminated to wetmate, which allows wider distribution ofthese services to the subsea structures tocomplete the Subsea Production System(SPS) network by the means of infield flying
leads. In this way, the control links of the
field are established.

UTA Type D1
Umbilical Termination Assembly (UTA)UTA Type C1

UTA Type C2

Variant

Make to Order

Make to OrderUTA Type D1Make to Order# Hydraulic MQC
connections

Up to 2 outlets

Up to 3 outlets

Up to 6 outlets# Electrical/Fiber optic
connections

Up to 4 outlets(w/ 2 MQC plates)

Up to 18 outlets(w/ 3 MQC plates)

Up to 12 outlets(w/ 6 MQC plates)

Isolation valvesNone

Can be provided

Can be provided

Dimension(L X H X W) (mm)2,945 x 1,087 x 1,383

3,874 x 1,165 x 1,343

3,000 x 1,087 x 1,400

WeightApprox. 2,000 kg

Approx. 4,500 kg

Approx. 2,000 kg

Umbilical connection(inches)Typ. 16 flange,class 600

Typ. 20 flange,class 300

Typ. 20 flange,class 300

PayloadUp to 35,000 kg

Up to 65,500 kg

Up to 70,600 kg

Installation

Category C IAW
API-17-TR10

Category C IAW
API-17-TR10

Category D IAW
API-17-TR10

Stab plate

Aptara™ FLX360

MQC Bore configuration(inches)

Coupler size Up to: 12 x 1⁄2 Up to 4 x 1

Pressure rating

Up to 10,000 psi in all lines

Depth rating

Up to 3,000m

Certification

DNV 2.7-3 on request

Our structured Umbilical Termination
Assemblies are designed to meet thedemands of your SPS distribution networkand ensure reliable delivery of the field’sutilities. We have three Make to Order (MTO)
configurations to effectively meet thedemands of even the most complex
system architecture and layouts.
Our UTA product portfolio enables ourcustomers to extend but also simplify
the boundaries of the subsea distribution
network with MTO options that work in unisonwith our wider system offerings to ensure
lower cost, simpler execution and leaner
cycle times.
With 3 MTO options are designed incompliance to' API-17-TR10 and all have
independent DNV 2.7-3 certification for the
structures against anticipated load cases
for installed as well as installation scenarios.
We are able to offer industry leading design
against reduced cycle times to ensure
umbilical procurement is not impacted
by ensuring the primary, secondary andumbilical interface remain unchanged.

All our designs are TRL-7 having beensuccessfully deployed on a range of products
from diver accessed fields to deep water
developments.
Our Make to Order UTA configurations include
the following:
Type C1 is the most compact UTA offeringand can accommodate 2-off MQC plates aswell as up to 4-off electrical/fiber optic wet
mate connectors.
Classified as a UTA Category C in line with
API17-TR10, these units typically weighapproximately 3,500 kg.
Type C2 is our medium UTA offering and canaccommodate a combination of up to 3-off
MQC plates as well as up to 18-off electrical/
fiber optic wet mate connectors. Project
specific configurations can also be designedwith a number of MQC plates and electrical/
fiber optic connectors and inclusion of ROV
operable isolation valves as required.
Classified as a UTA Category C in line with
API17-TR10, these units typically weighapproximately 4,500 kg.
Type D1 is our largest UTA offering and canaccommodate a combination of Up to 6-off
MQC plates and Up to 12-off electrical/optical
wet mate connectors. Project specificconfigurations can also be designed witha number of MQC plates and electrical/fiber
optic connectors and inclusion of ROV
operable isolation valves as required.
Classified as a UTA Category D in linewith API17-TR10, these units typicallyweigh 9,000 kg.

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MULTIBORE HUB CONNECTION (MHC UTA)UTA Type D1Multibore Hub Connection UTA (MHC-UTA)
FeatureMake to Order

Variant

3 Options - Type B1, B2 & C1

# Multibore Connection Size

Type B1: 450 MB Type B2: 450-MB Type C1: 450-MB# Electrical/Fiber optic connections Type B1: Max. 10 electrical or 8 optical
Type B2: Max. 14 electrical or 10 optical
Type C1: Max 18 electrical or 8 optical+8 electrical
Dimension (L X H X W) (mm)

MHC UTA Cat. B1: 1,502 x 1,610 x 3,285
MHC UTA Cat. B2: 1,502 x 1,610 x 3,610
MHC UTA Cat. C1: 1,592 x 1,694 x 3,505

Weight (kg)

MHC UTA Cat. B1: 4,700, MHC UTA Cat. B2 5,100,
MHC UTA Cat C1: 5,500

Installation

Type B1 & B2 : Category B IAW API-17-TR10
Type C1 : Category C IAW API-17-TR10

Connection System

AptaraTM HCCS-L

Multibore Hub
Configuration utilizing
SX22 - 1" coupler w/ poppet &SX44- 2" coupler w/ poppet

Multibore 450-V1A | V1B | V1C | V1D : 19x SX22 | 15x SX22 |11x SX22 | 5x SX22
Multibore 450-V2 : 14x SX22 + 2x SX44
Multibore 450-V3 : 8x SX22 + 6x SX44

Pressure rating (psi)Up to 10,000 in all lines

Depth rating (m)Up to 3,000

Depth rating (m)Up to 3,000

Certification

DNV 2.7-3 on request

The Multibore Hub Connection Umbilical
Termination Assembly (MHC UTA) belongs
to our Aptara™ HCCS-L connection systemfamily for direct connection of umbilicalto the subsea structures such as SDU or
Manifold. This provides a totex lite solution
compared to a stand alone UTA which
typically requires further break out ofservices, additional mudmat and flying
leads and associated installation.

The MHC UTA is composed by the “Electrical
Compartment” (MHC UTA frame) bolted tothe standard Aptara™ HCCS-L Termination. It
utilizes multi bore hub technology with metal
to metal sealing to connect the hydraulicand chemical lines from the Umbilical to the
Manifold/SDU Tubing. The Aptara™ HCCS-L
comes with standard landing interfaces for
the MHC UTA subsea installation andwet-parking enhancing installation flexibility.

Our Aptara™ HCCS-L enabled MHC UTA
provides the following benefits overconventional UTA:The Electrical Compartment provides theconnection for umbilical subsea terminationinterface (STI), integration and welding
access for the hydraulic tubing, houses thecable and termination junction box as wellas their associated wet made connectors
for the electrical/optical flying leads.

• Compact and light weight productproviding reduced installation costswith smaller vessel and ease of load out• Ease of assembly, handling andinstallation• Optimized field layout and fewer
subsea structures• Optimized tooling by commonality withflowline connections to reduce your CAPEX• Enhanced reliability by possibility of insitue
seal inspection or replacement by ROV• Robust capacity for umbilical installationand tie-in enhancing reliability• Stroke back and wet parking capability
enhancing installation flexibility• Use of field proven proprietary metal tometal SX sealing coupler with poppets(1" and 2")

Our Make to Order MHC- UTA configurations
includes the following:
Type B1 is the most compact MHC-UTA
offering and can accommodate size
450-mulitbore clamp connection as well as
up to 10-off electrical or 8-off fiber optic wet
mate connectors. Classified as a UTA
Category B in line with API17-TR10, these units
typically weigh approximately 5,000 kg.
Type B2 is our medium MHC-UTA offeringand can accommodate size 450-mulitbore
clamp connection as well as Up to 14-off
electrical or 10-off fiber optic wet mateconnectors. Classified as a UTA Category
B in line with API17-TR10, these units typicallyweigh approximately 5,000 kg.
Type C1 is our largest MHC-UTA offeringand can accommodate size 450-mulitbore
clamp connection as well as up to 18-off
electrical or 8 optic + 8 electrical wet
mate connectors.
Classified as a UTA Category C in line with
API17-TR10, these units typically weighapproximately 5,500 kg.

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SUBSEA CONTROL SYSTEMSAPTARA™ FLX360 MULTI-QUICK CONNECTION SYSTEMThe FLX360 is an innovative Multi-Quick
Connect (MQC) system that enables fastand reliable connections between allelements of the subsea distribution system.
Hydraulic and chemical flying leads are
critical components within the subsea
system, ensuring reliable delivery of utilities
around your subsea field. MQC plates enable
the connection of these flying leads to the
fixed structures (trees, distribution units,
manifolds) through the connection of‘fixed’ and ‘flying’ plates.
The FLX360 is an MQC plate that will meeteven the most demanding field applicationsin terms of depth (qualified to 9,842 ft/
3,000 m), load capacity (suitable for larger
Steel Tube Flying Leads (STFLs) and someumbilicals. It incorporates a unique life-offield design that allows maintenancein situ with no need for disconnectionof the connector, reducing the total costof ownership.

Aptara™ FLX360 Multi-Quick Connection System
FeatureMake to Order

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

Depth capability

9,842 ft (3,000 m)

Coupler size (inches)

Up to: 12 x 1⁄2 Up to 4 x 1

Number of lines

Up to 16

Pressure rating

Up to 10,000 psi in all lines

Tubing size (inches)

Up to 1 OD

Originally conceived in 2010, and withover 1,000 MQC plates installed, the API 17F
qualified FLX360 system continues to use apatented locking mechanism that leaves
only one moving part of the design subsea.
The complexity of the connection system(with their associated disadvantages)
is housed within the retrievable andserviceable ROV tooling, eliminating screw
threads from the system and enabling
reliable make up/break out times ofapproximately 90 seconds.

Typical lead time:

3 months

Our FLX360 MQC System can be deliveredin 3 months.

Our suite of FLX360 products will ensure
your subsea distribution system performs
reliably over the life of the field. The FLX360
product range has undergone continual
development and validation to ensure it
meets the ever-increasing demands ofthe subsea system. It has been designed
to further reduce CAPEX without any
detriment to reliability.
The latest FLX360 MQC plate offers
improved calcareous and marine growth
management. It uses molybdenum coatedcomponents and eliminates excessive
close‑fitting components as part of thedesign. The FLX360 also provides 80% more
load capacity vs the original design, ensuring
its suitability for deepwater STFL applications
and some infield umbilicals.
We offer a complementary suite of FLX360
products that includes thermoplastic andsteel tube flying lead carrier frames, fixed/
flying plates, parking plates, protective
covers and logic plates. Our new simplified
tooling package is also qualified to API 17F.
The Aptara™ FLX360 family is extended toinclude Cobrahead Assembly (CHA) suitable
for termination of topside or infield Umbilicals
and provides the connection links between
the topside services and the subsea installed
such as Manifold/SDU/UTA/XT. It enables
subsea infrastructure to be reduced relative
to a typical UTA connection, as it eliminates
the requirement of any additional mudmats
or UTA mounting bases and their installations
saving cost.
The CHA design extends the FLX360 STFL
flying plate with the addition of electricaland/or optical connections.

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SUBSEA MANIFOLDSAND PIPELINE PRODUCTSOVERVIEWOur product portfolio covers
everything you need to integrate
your subsea production systemand ensure safe and efficient
fluid transfer from yourtrees to your risers.
We have the largest installed baseof subsea gas projects in the industry.
And, with more than 170 manifolds
installed, our comprehensive range ofcluster and template manifold
systems has the proven functional
flexibility, scalability, and versatility
to adapt to all your field requirements.
All our manifold and pipeline products arebuilt to a modular design that uses standard
tried and tested components that will workin a wide variety of configurations. This helps
us to compress your schedule and offer
reliable, shorter lead times, while minimizing
the overall costs and risks.

Our range of products includes cluster andtemplate manifolds, pipeline end manifolds(PLEM), riser bases, pipeline end termination(PLET), manual or remotely operated pig
launcher and receivers (PLR), in-line tees (ILT),
High-Integrity Pipeline Protection Systems(HIPPS) and subsea isolation valve modules(SSIV). We can also provide flexible or rigid
jumpers – both with our industry-leading
connection system.
Flexible pipe is highly versatile in meetingthe demands of subsea and FPSO-based
production. In some environments, it’s the
only suitable technology for a production
system. Flexible pipe systems (FPS)
products can be found in every major
offshore production basin worldwide
and are engineered to withstand theharshest operating conditions. Our
systems are currently operating in
depths well beyond 2,300m andare being qualified up to 3,000m.

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APTARA™ MODULARCOMPACT MANIFOLDSOur Aptara™ Modular Compact Manifold
system addresses the need for modular,
pre-engineered manifolds that use
off-the-shelf components. Its lower-weightand compact size allows installation fromsmaller vessels – reducing cost andadding flexibility.
86

CLUSTER MANIFOLDSOur Cluster Manifolds cover deep,
medium and shallow water applications,using a modular approach to meet yourfield-specific requirements.
Deepwater Vertical Cluster
Manifold (DVCM)

88

Deepwater Horizontal Cluster
Manifold (DHCM)

89

Injection Manifold (water and gas)

89

Shallow-water Cluster Manifold

89

Gas Export/Gathering Manifold

89

PIPELINE PRODUCTS
AND SOLUTIONS

Our pipeline products and solutions
offer long-term reliability and safety witha modular approach that adapts to yourfield’s specific requirements.
Open-PLET94
High Integrity Pipeline Protection
System (HIPPS)

94

Subsea Pig Launcher
and Receiver (PLR)

95

Remote Operated Pig Launcher (ROPL)

95

FLEXIBLE PIPE SYSTEMS, JUMPERS
AND RIGID SPOOLS
Our flexible pipe products, rigid well
jumpers, spools and pigging loops
optimize your field layout and offer
long-term reliability and safety.
Flexible Pipe Systems

96

Rigid Jumpers and Spools

97

TEMPLATE MANIFOLDSOur Template Manifolds are designed toensure the highest reliability and safety
across well systems, drilling, controls,
installation and workovers.
Integrated Template Structure (ITS)

90

Template Manifold

91

Flow Control Module (FCM) 

91

Shallow-water Multi Flowbase (MFB)

92

85

See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTSAPTARA™ MODULAR COMPACT MANIFOLDS
Baker Hughes is rethinking the future ofsubsea fields. We are simplifying thecomplex by launching the new Aptara™
family of TOTEX-lite products. The Aptara™
modular compact manifold is part of thisfamily of light and smart subsea equipment
designed to reduce the total cost ofownership over the life of your field.
Our Aptara™ modular compact manifold
system has been developed to address theneed for modular, pre-engineered manifolds
that use off-the-shelf components, reducing
cycle time cost and footprint. The newcompact block manifold from Baker Hughes
has been designed to challenge complexity
with simplicity.

Subsea Compact Block Manifold (SCBM)
FeatureMake to Order

Variant

2 Options

Configure to Order

Number of slots

6

4

Number of headers

Option 1: 6-slot
Dual production
Option 2: 6-slot
Dual production w/ Gas lift

Option 1: 4-slot
Dual production
Option 2: 4-slot
Dual production w/ Gas lift

Distribution

Standalone SDU

Co-located on Foundation

Connector orientation

Horizontal

VerticalPressure rating (psi)10,000 branch valve block
5,000 Manifold

10,000psi branch valve
block 10,000psi Manifold

Temperature rating (°C)-20°F to 250°F (-29°C to 121°C)

Water depth rating

9,842ft (3,000m)

Design life (years)

25

Prod. header size, NPS (inches)

10

Prod. branch size, NPS (inches)6

Gas lift header, NPS (inches)6

Gas lift branch, NPS (inches)

2

Delivery time

10 months

The Aptara™ modular compact manifold’score design uses a 4-slot or 6-slot dual
header configuration to suit your pipeline
requirements and 5-inch or 7-inch branchvalve blocks for its branch valve connections,with separate header piping. The manifold
branch valves are identical to our Aptara™
lightweight compact tree system valves(e.g. 5-inch trees require 5-inch manifold
branch valves), pushing the boundaries ofstandardization to the next level. This enables
large volume purchase of components
like valves and forgings, allowing us to holdthe stock you need – reducing cost andlead time.
We have achieved a level of standardizationthat limits the engineering to the manifold
header, structural steel, and foundation,
resulting in faster delivery with reduced
risks and costs. For the most common
configuration, the manifold will be Make toOrder with zero product engineering anddelivered in 10 months from the award ofa contract.

Typical lead time:
124
12 months

10-12 months
Our Make to Order Aptara™ modular
compact manifold system can bedelivered in 10-12 months.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTS

The Aptara™ manifold features a compact
design enabled by Aptara™valve block, with
reduced pipe work, pipe end preparation,
fitting, welding and NDE along with simplified
interfaces, and is our response to theindustry’s need for reduced lead times andtotal cost. We will have pre-engineered stockof Aptara™valve blocks and gate valves fromour ‘family range’ of 51/8" 10,000 psi and 71/16"
10,000 psi XT valves, all using existing designand qualified components. The manifold
design enables different configurations tobe selected to optimize your production.
Further, chemical injection valves can be
included as required.
The blocks can be readily insulated toprovide the necessary thermal properties
required to enhance operability, andproject specific features such as gas lift
can be accommodated in the manifold
structure. The manifold and mudmat canbe installed in a single lift using smaller
and lower-cost vessels.
Where appropriate, pre-assembled andtested blocks (termed ’flat packs’) can be
shipped to remote fabrication locations
for incorporation into the manifold build,assembly and test activity sequence, where
facilities may not be as well suited as our
XT facility for assembly and testing of thevalve blocks.

The Aptara™ modular manifold iscomplemented by our Aptara™ connection
systems, including our latest lightweight andfast horizontal tie-in system, HCCS-L, which is
50% lighter, 30% more compact, has a highcapture range and can reduce theconnection make-up time by 50%, comparedto other conventional connection systems.
Another member of the Aptara™ connection
system family is the FLX360 stab plateconnector. It has a simple latch that allows
the ROV to connect flying leads quickly to thesurrounding architecture, thus reducing theoverall sub-sea hook up time.
Our Make to Order Aptara™ Manifold can bedelivered in 10 months and our Configure toOrder Variant in 12 months
Aptara™ 4 slot modular compact manifold

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CLUSTER MANIFOLDS
Offering long-term reliability and safety,
our Cluster Manifolds cover deep, medium
and shallow water applications. We use amodular approach to ensure we can adapt
them to widely varying field-specificrequirements, with products ranging fromstandardized deepwater, shallow-waterand injection manifolds, to very large
export/gathering manifolds with headers
up to 42 inches.
Our Cluster Manifolds are all based on alibrary of pre-engineered and qualified
standard components used as modular
building blocks. This gives our portfolio
a comprehensive range of functional
flexibility and versatility for any subsea
field development. It also ensures we canmaintain the highest quality and consistency,with lower overall costs and a faster delivery
to first oil or gas.

Deepwater Vertical Cluster Manifold (DVCM)
FeatureMake to Order

Variant

2 Options

Configure to Order

Number of slots

4

6

Number of headers

Option 1: Dual production
Option 2: Dual production
with gas-lift

Single prod. + MEG /gas lift + service

Distribution

Standalone SDU

Integrated SDU

Pressure rating (psi)

5,000

7,500 to 10,000

Temperature rating-20°F to 250°F (-29°C to 121°C) 291°F (144°C)

Water depth rating

6,561 ft (2,000 m)

9,842 ft (3,000 m)

Design life (years)

25

Up to 50

Prod. header size, NPS (inches)10

8, 12 or 14

Prod. branch size, NPS (inches)68

Gas lift or MEG header, NPS (inches)46

Gas lift or MEG branch, NPS (inches)

2

Delivery time

12 months

16 months

Baker Hughes has an installed base of morethan 120 Cluster Manifolds, demonstrating asolid track record in fulfilling the needs of any
deepwater oil and gas production system.
Lead times typically range between 12 and16 months, and we offer guideline-less anddiverless installation in deepwater, while
divers can be used in shallow water.
A skirted mudmat or single/multi-can suction
anchor foundation is provided, with the skirt
customized to suit soil conditions at yourfield. We can also supply a gas lift, MEG
header and service header, as required,to improve production rates andenhance operability.
Pigging loops facilitate round trip pigging
to improve operability for dual flowlines,
while a ROV pig launcher or remotely
operated pig launcher can be used
for single flowline applications.

As standard, all our manifolds come witha design pressure rating of 5,000 psi, 7,500
psi and 10,000 psi to cope with required
shut-in pressures. They have a standard
temperature rating of 0°F to 250°F (-18°C
to 121°C), while higher temperatures can beaccommodated depending on your fieldrequirements. Thermal insulation with highthermal cool down performance can beprovided, improving availability and flexibility
during an unplanned shut down.

DEEPWATER VERTICAL
CLUSTER MANIFOLD (DVCM)
Our Make to Order Deepwater Vertical
Cluster Manifold (DVCM) has 4 or 6 well slots.
It uses dual production headers, with theoption of a gas lift. The DVCM has a standard
vertical clamp connection system (VCCS) for
flowline and well jumpers with standard seal
sizes. It has a production branch size (NPS) of
6 inches and a header of 10 inches, althoughother size options are available. The DVCM
also uses a standalone subsea distribution
unit, but an integral distribution solution canbe provided.
Our Make to Order DVCM can be deliveredin 12 months.

Typical lead time:

12-16 months
Our Make to Order DVCM can bedelivered in 12-16 months.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTS

DEEPWATER HORIZONTALINJECTION MANIFOLD
CLUSTER MANIFOLD (DHCM) (WATER AND GAS)
Our Make to Order Deepwater Horizontal
Cluster Manifold (DHCM) has 4 or 6 well slots.

Our Make to Order Injection Manifold (waterand gas) has 2, 4 or 6 well slots.

SHALLOW-WATER
CLUSTER MANIFOLD

It uses dual production headers, with theoption of a gas lift or MEG header. The DHCM
has a standard horizontal clamp connection
system (HCCS-L) for flowline and well
jumpers with standard seal sizes. It has a
production branch size (NPS) of 6 or 8 inches
and a header of 12, 14 or 16 inches, althoughother size options are available. The DHCM
also offers integrated subsea distribution
with a multi-bore HCCS-L umbilicaltermination head (MHC UTA). Where needed
we can supply thermal insulation provided
by our proprietary Heatbank system, whichallows for an extended cool down period.

It uses a single header, with the option ofdual headers for a water alternating gas(WAG) injection process. Our Injection
Manifold has an injection branch size (NPS) of
6 inches and a header of 8 inches, 10 inches
or 12 inches, although other size options areavailable. It offers ROV-operated valves withno Subsea Control Module (SCM), with ahydraulic option for a WAG injection process.
It uses single isolation philosophy, but there
is a dual isolation option for WAG, and it has
a standard vertical or horizontal clamp
connection system for flowline and well
jumpers with standard seal sizes.

It uses a single production header, with theoption of dual headers, and employs diver
operated flange connections for tie-ins. Our
Shallow-water Manifold has integrated
subsea distribution with a, multi-bore HCCS-L
umbilical termination assembly (MHC-UTA)
with the option of a diver connected
Umbilical Termination Assembly (UTA). It also
has an integrated protection structure, toensure it is fishing-friendly or ‘over-trawlable’,as per the industry standards ISO 13628-15
and NORSOK U001.

Our Make to Order DHCM can be deliveredin 15 months.

Our typical Injection Manifolds can bedelivered in 12-16 months.

Deepwater Horizontal Cluster Manifold (DHCM)
FeatureMake to Order

Variant

2 Options

Configure to Order

Number of slots

4&6

8

Number of headers

Option 1: Dual production
with gas-lift (oil)
Option 2: Dual production
with MEG (gas)Single prod. + MEG /gas lift + service

Distribution

Integrated

Standalone SDU

Pressure rating (psi)

5,000

7,500 to 10,000

Temperature rating-20°F to 250°F (-29°C to 121°C)

291°F (144°C)

Water depth rating

6,561 ft (2,000 m)

9,842 ft (3,000 m)

Design life (years)

25

Up to 50

Prod. header size, NPS (inches)

10 (oil) or 16 (gas)12, 14 or 18

Prod. branch size, NPS (inches)

6 (oil) or 8 (gas)Multibore

Gas lift or MEG header, NPS (inches)4

6 or 8Gas lift or MEG branch, NPS (inches)

2

Delivery time

15 months

16 months

Our standard Shallow-water Cluster
Manifold has 4 or 6 well slots.

Our typical Shallow-water Manifolds canbe delivered in 12-16 months.

GAS EXPORT/GATHERINGMANIFOLD
Our Gas Export/Gathering Manifold
has multiple headers to suit yourfield requirements.

Baker Hughes has the largest installed base ofcustomized large-size Gas Export/Gathering
Manifolds in the industry. As with our othermanifolds, we use of pre-engineered andqualified standard components as modular
building blocks. This allows us to deliver highly
customized large-size manifolds with lower
costs and reduced execution risks to a fasterdelivery schedule.
Our optimized large-size manifold systems
come with as many connection slots as
required to suit various field requirements.
Their size range (typically from 18 to 42
inches), design pressure and temperature
can all be specified to meet your exact
project needs. They use a standard horizontal
clamp connection system (HCCS), but also
our vertical clamp connection system(VCCS)for flowline and well jumpers withstandard seal sizes. Integrated subsea
distribution can also be provided to suit
your field requirements.
Our typical Gas Export/Gathering Manifolds
can be delivered in 16-20 months.

Typical lead time:

12–16 months

for all of our DHCM.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTSTEMPLATE MANIFOLDS
We take a total-system approach todesigning Template Manifolds that will
ensure the highest reliability and safety
across well systems, drilling, controls,
installation and workovers. They are built
around the Baker Hughes standard
Template Manifold solution, which includes
an Integrated Template Structure (ITS),a Template Manifold and a Flow Control
Module (FCM).
Like our Cluster Manifolds, our Template
Manifolds are based on a library of preengineered and qualified standard
components used as modular building
blocks. They provide functional flexibility andversatility for any subsea field development,
while maintaining the highest quality andconsistency, with lower overall costs anda faster delivery to first oil or gas.
Baker Hughes has an installed base of morethan 45 Template Manifolds, most of whichhave been delivered in the North Sea where
it is required to be fully over-trawlable. Leadtimes typically range between 12 and 15
months, and our solutions offer you longterm reliability and safety with a modular
approach that means we can adapt toyour field specific requirements.

INTEGRATED TEMPLATESTRUCTURE (ITS)

Our standard Integrated Template Structure(ITS) is a guideline-less system with 4 or
6 well slots.
With a solid track record in the North Sea,
our standard ITS is a reliable choice for any
typical oil or gas field service application.
It is NORSOK compliant with its fully validated
over-trawlable design and integrated
protection structure, which has foldable
protection hatches to simplify installation.
The ITS’s optimized size and weight – around15-20% lighter than previous designs – also
makes installation much easier, and thesystem comes with a suction control panel
for active levelling and include a system forgrouting. It has a multi-pile suction anchor
foundation that can be tailored to suit soil
conditions.
The ITS provides foundation support for yourconductor, wellhead, XTs, distribution andmanifold, and facilitates access to a blowout
preventer (BOP) during drilling, completion
and workover interventions. The system
also includes ROV access for intervention
and operation.
Our Make to Order ITS can be deliveredin 12 months

Template Manifold
FeatureMake to Order

Configure to Order

Variant

2 Options

Number of slots

4

6

Number of headers

Option 1: Dual production
Option 2: Dual production
with gas-lift

Single prod. + injection+ service

Protection structure

NORSOK compliant,
integrated

NORSOK compliant,
integrated

Foundation

4 can suction pile

Made to project

Delivery time

12 months

15 months

Typical lead time:

12–16 months

for all our Template Manifolds.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTSTEMPLATE MANIFOLD

Our standard Template Manifold is a
guideline-less manifold system with 4 or
6 well slots.
It uses dual production headers, with theoption of a single header. A gas lift, MEG
header and service header can also be
provided to enhance operability. The
Template Manifold is independently
installable and retrievable from the ITS andhas a standard horizontal clamp connection
system (HCCS-L) for flowline and well
jumpers with standard seal sizes, which
reduces installation time.
It has a production branch size (NPS) of
6 inches (with an 8-inch option) withcombination of controls and hydraulic lines
in a multi-bore wing-hub configuration forbranches and a header of 10 inches (withoptions in the range of 12-16 inches). The
Template Manifold also uses an integrated
subsea distribution unit with a multi-bore
HCCS-L Umbilical termination assembly(MHC-UTA) – this reduces the structuresneeded and therefore CAPEX and INSTALLEX.

The system is designed to cope with higher
well growth. Further options include an ROV
pig launcher or remotely operated pig
launcher for single headers, or a pigging
loop (internal or external) for dual headers
to enhance operability.
Like our Cluster Manifolds, our Template
Manifolds come with design pressure ratingsof 5,000 psi, 7,500 psi and 10,000 psi to copewith required shut-in pressures. They have astandard temperature rating of 0°F to 250°F(-18°C to 121°C), while higher temperatures
can be accommodated depending on yourfield requirements. Thermal insulation using
our proprietary Heatbank system can beprovided with an extended cool down period.
Our typical Template Manifold can bedelivered in 12-16 months

FLOW CONTROLMODULE (FCM)

Our Flow Control Module (FCM) channels
and controls the flow between tree
and manifold.
We have extensive experience in delivering
the Flow Control Modules that work at theheart of your subsea system to maintain areliable and accurate rate of flow. Our FCM
comes with a dedicated running tool andstroking tool, and houses a choke module,
flowmeter and other instrumentation vitalto the Template Manifold system.
We offer guideline-less installation of
the FCM and the unit is independently
retrievable to give you increased reliability
and convenience. ROV access is also
improved by having a horizontal
connection to the manifold and verticalconnection to the tree (with the option ofboth vertical connections). By using multibore hubs that handle production, controls
and distribution lines, means we can reduce
the number of connections and offer a lower
installation cost.
We can also provide insulation with ourproprietary Heatbank system that gives you
an extended cool down period, which canenhance both operability and availability.
Our typical FCM can be delivered in
10-12 months.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTS

SHALLOW-WATER MULTIFLOWBASE (MFB)

Our standard Shallow-water Multi FlowBase(SW MFB) System is a guideline-less systemwith 2, 4 or 6 well slots.
Baker Hughes have developed a cost
optimized solution for shallow water, basedon ITS and shallow water Xmas trees andmanifolds in the North Sea.

The MFB provides conductor, wellhead, XTs,
distribution and manifold, and facilitatesaccess to a blowout preventer (BOP)
during drilling, completion and workover
interventions. The system also includes ROV
access for intervention and operation.
Our Make to Order FW MFB can be deliveredin 10 months

The SW MFB facilitate use a of standard
satellite XT into a “template” system, and alsoeasily allows the connection of a step-out
well from a well slot in case if this is required.
Valves are diver replaceable, and hence
there is no need for a retrievable manifold
piping module. This represent a hugesimplification to the template as tolerance
loop is significantly reduced, and fabrication
jigs or precision welding will be required.
The overall simplification have driven asignificant reduction in fabrication
complexity total weight reduction by 50%
and installation complexity, resulting in lower
cost, execution time and installation time.

Shallow Water Multi-flowbase (MFB)
FeatureMake to Order

Configure to Order

Variant

2 Option

Number of slots

4

6

Number of headers

Option 1: Single production
with gas lift
Option 2: Single production
with gas lift and water
injection

Dual production

Installation

Diverless or Diver assist

Protection structure

NORSOK compliant,
integrated

NORSOK compliant,
integrated

Foundation

MudmatSuction anchor

Delivery time

12 months

15 months

Typical lead time:

12–16 months

for all our Template Manifolds.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTSPIPELINE PRODUCTS AND SOLUTIONSOPEN-PLET

Our Open-PLET solution offers simplicity
and robustness to enhance reliability.
Our patented Open-PLET solution allows
you to install a separate and independent
subsea pipeline and pipeline end
termination (PLET) structure. It uses thestandard Baker Hughes connection system– HCCS– and simplifies your pipe laying
operation due to the elimination of PLET
structure work and the associated risks. YourPLET Skid/Structure can therefore be installedon the seabed close to your pipeline.
This all reduces the risk and maximizes
safety and reliability during the installation
process, reducing your overall cost andinstallation time.
Our pipeline products and solutions offer long-term reliability and safetywith a modular approach that allows us to adapt them to your field’s
specific requirements.

Our High Integrity Pipeline Protection System(HIPPS) is a guideline-less module.
It improves your cost efficiency by effectively
downrating the subsea pipeline and risers totransient flow pressures. As well as reducing
your necessary CAPEX, this enhances
reliability and safety, particularly in thecase of a pressure surge through the unit.
HIPPS is easy to install and maintain as it isindependently installable and retrievablefrom foundation. The use of a standard
vertical clamp connection system (VCCS) or
horizontal clamp connection system (HCCS-L)
and intervention tooling allows common
tooling with the XT and manifold system.
HIPPS has a standard temperature ratingof 0°F to 250°F (-18°C to 121°C), while higher
temperatures can be accommodated
depending on your field requirements.
With a logic solver that is fully compatible
with our SemStar5 control system, the unit
can be slotted into your field easily. It is also
SIL3-rated for safety and comes with adesign pressure of 10,000 psi.

We have a longstanding track record for delivering high quality, welldesigned pipeline products and solutions such as Pipeline End Termination(PLET), Pipeline End Manifold (PLEM), In-line Tees (ILT), riser bases and Subsea
Isolation Valves (SSIV). Our differentiated pipeline products and solutions
include an Open-PLET solution, a High Integrity Pipeline Protection System(HIPPS) and remote operated Subsea Pig Launcher and Receiver (PLR).
Our total system approach ensures that we design pipeline products thatwill achieve the highest standards of reliability and safety, while being mucheasier to install. This helps us achieve lead times that typically range
between 10 and 12 months.
Like our manifolds, our pipeline products are based on a library of preengineered and qualified standard components used as modular building
blocks. This gives us a portfolio that covers a comprehensive range of
products that provide functional flexibility and versatility for any subsea
field development. This ensures we can deliver the highest quality andconsistency, with lower overall costs and a faster delivery to first oil or gas.

HIGH INTEGRITY PIPELINEPROTECTION SYSTEM(HIPPS)

Typical lead time:

Typical lead time:

Our Make to Order Open-PLET canbe delivered in 10 months.

Our Make to Order HIPPS module
can be delivered in 12 months.

10 months

12 months

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTS

SUBSEA PIG LAUNCHER
AND RECEIVER (PLR)

Our Subsea Pig Launcher and Receiver (PLR)
has a size range of 4 inches up to 42 inches.
Baker Hughes has a solid track record indelivering Subsea Pig Launcher and Receiversystems offering guideline-less installation,
vertical or horizontal configuration and astandard design with 6-off pigs.
Our PLR has a kicker line (either 2 inches
or 4 inches) with ROV isolation valves
and injection stab. There is also the option
to integrate the kicker line as a tandem
connection to reduce the number ofconnections and associated hardware
and installation costs. Baker Hughes’ newremotely operated PLR is based on ourwell proven design, which enables pig
launching without the need for ROV orvessel intervention, saving significant
operational cost.
It is also an enabling technology for longtie-back single flowline field layouts thatcan result in a significant reduction of your
TOTEX. The PLR comes with an acoustic pig
detector (APD), which allows you to remotely
monitor pig launches. There is also an
option for soft-landing a larger size PLR
for safer installation.

Typical lead time:

12 months

Our Make to Order PLR can bedelivered in 12 months.

REMOTE OPERATED PIG
LAUNCHER (ROPL)High Integrity Pipeline Protection System (HIPPS)
FeatureMake to Order

Our Remote Operated Pig Launchers havea size range of 4 inches up to 42 inches.

Variant

2 Options

Prod. header size, NPS (inches)

8 or 6

To reduce your CAPEX cost, Baker Hughes hasdeveloped a Remote Operated PIG launcher.
ROPL facilitate frequent pigging without
need for offshore operations, influencing
the production or having a large top sidecompressor station to drive the pig in aloop configuration.

Pressure rating (psi)10,000 or 5,000

Temperature range

0°F to 250°F (-18°C to 121°C)

Valve close time, sec<10

SIL rating

SIL3

Delivery time

12 months

ROPL is designed to hang off the subsea
manifold future end allowing the launcher
to be implemented at any time of the field
life without disturbing the production. The
pigs are launched into the flow throughthe already existing header valves on a
production system. Fluid to drive the pig
into the production flow is taken from thedrill-center service lines via a dual bore
configurated connection.
The “heart” in the pig launcher system isthe electrical actuated pig selector – a flow
diverter that divert the flow to the different
kicker lines for pigs preloaded inside the pig
launcher barrel. Using low power electricalactuator removes the need for hydrauliclines to the launcher or hydraulic functions
on the control system, while the low electrical
power required for the flow diverter actuator
ensures no impact on the umbilical orsubsea control unit.

Typical lead time:

10 months

Our Make to Order ROPL can be deliveredin 10 months.

Subsea Pig Launcher and Receiver (PLR)
FeatureMake to Order

Variant

Multiple Options

Pipe size range (inches)4 – 42

Configuration

Horizontal or vertical

Operation mode

ROV operated or remotely operated (ROPL)

Installation

Pre-installed with the Manifold/PLEM/PLET, re-installable

Pig capacity

Up to 6 pigs

Kicker line

2-inch or 4-inch with ROV isolation valves and injection stab

Configuration

Integrated or separate tandem kicker line connection

Delivery time

12 months

Remote Operated Pig Launcher (ROPL)
FeatureMake to Order

Variant

Multiple Options

Pipe size range (inches)

10 - 42

Configuration

Horizontal or vertical

Launching mode

Remotely operated via. Topside MCS, Production launch or Service (MEG or gaslift) launch

Operation

Electric actuation (Service launch) or Hydraulic (Production launch)

Installation

Pre-installed with the Manifold/PLEM/PLET, re-installable

Pig capacity

Up to 6 pigs

Kicker line (inches)

2 (Service launch) or 3 (Production launch)

Connector configuration

Dual concentric connection (Service launch) or separate tandem multibore
connection (Production launch)

Delivery time

10 months

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTSFLEXIBLE PIPE SYSTEMS,JUMPERS AND RIGID SPOOLSThe design and supply of well jumpers
interfacing with XT, manifolds and pipelines
are critical to maintaining the safety andreliability of your operations.
We have extensive experience and aproven track record of delivering flexible pipe
products through our flexible flowline, riser
and jumper portfolio. In addition, we supply
rigid well jumpers, spools and pigging loops
to optimize your field layout. Our solutions
offer long-term reliability and safety, while
our modular approach enables us toconfigure them to your specific fieldrequirements.
Our total system approach ensures that wedesign pipeline products that will achieve thehighest standards of reliability and safety,
while being much easier to install. This helps
us achieve lead times of around 10 months.

Rigid Jumpers and Spools
FeatureMake to Order

Variant

Multiple Options

Pipe size range (inches)

3-42

Orientation

Horizontal or vertical configuration

Bore configuration

Single, dual, multi-bore options

Pipe shapes

Range of 2D and 3D shapes as per field requirements

Thermal insulation

Optional

Installation method

Guideline less

Delivery time

10 months (as kits)

As with all our pipeline products, we use
a library of pre-engineered and qualified
standard components as modular building
blocks, resulting in a versatile portfolio thatcovers a comprehensive range of subsea
field developments. This ensures we candeliver the highest quality and consistency,with lower overall costs and a faster delivery
to first oil or gas.

FLEXIBLE PIPE SYSTEMS

Highly adaptable, reliable, and costeffective pipeline solutions for offshoreand subsea projects
Dynamic risers, flowlines, static and dynamic
fluid transfer lines, and jumpers are criticalto offshore oil and gas production, injection,and export systems. They are subject toextreme temperatures, pressures, physicalstresses, and movement while carrying hot,highly pressurized corrosive materials –yet must still ensure reliable connections
and optimal product flow. As offshoredevelopments move into deeper waters andeven more challenging environments, flexible
pipe is a highly versatile fluid transportation
solution, often it is the only suitable
technology to enable floating production.
Our portfolio of flexible pipe solutions draws
on more than 25 years of research anddevelopment, material science, andinstallation experience in some of theharshest conditions the industry offers –particularly in environments where water
depth and seabed conditions impose
unusual restrictions. Our products are robust,
highly flexible, and adaptable to uniqueproject requirements, and offer cost-effective
and proven reliability for corrosive reservoirs.

Flexible Pipe Systems
FeatureMake to Order

Variant

Multiple Options

Pipe Size Range (inches)

2-16

Applications

Risers, Flowlines, Jumpers, Transfer Lines

Thermal Insulation

Optional

Delivery Time

10 months

Typical lead time:

10 months

Our Flexible Pipe Systems can bedelivered in 10 months.

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SUBSEA MANIFOLDS AND PIPELINE PRODUCTS

Baker Hughes unbonded flexible pipes areconstructed from multiple layers of helicallywound metallic wires and extruded
thermoplastic barriers. Each layer isdesigned to address specific duty
requirements, including, for example:• High temperature• High pressure• Corrosivity including CO2 and H2S inconveyed fluids• Dynamic marine environments such as
floating production in shallow tidal zones• Water depths to 3,000m• Pipe inner diameter from 2 in. to 16 in.
• Required service life
• Flow assurance challenges such as
thermal no-touch time
• Robust structure to cater for routing issues
such as subsea canyons, or unstablegeo-hazards such as mudslides or slopes
In dynamic applications, such as risersand export systems, we optimize designs
to accommodate the motion of the
production facility. In static environments,
our flexible flowlines are ideal for connecting
remote wellheads to riser bases andaccommodating situations where there is
uneven seabed topography or congested
seabed architecture.

RIGID JUMPERS
AND SPOOLSOur Rigid Jumpers and Spools can be
configured horizontally or vertically,
with a piggable design where required.
With decades of experience in deliveringwell jumpers, we offer a wide size range of
3 inches up to 42 inches to meet yourspecific field requirements. All our well
jumpers come with ancillaries to aid
fabrication, testing, load-out and installation.
You can choose from single, dual andmulti-bore configurations to optimize thefield layout and your installation to reduce
the total cost. Thermal insulation can also be
provided to enhance your operability andimprove your hydrate management.
Our Rigid Jumpers and Spools also enhancestability and reliability, as they are designed
to withstand vortex-induced vibration (VIV),
flow-induced vibration (FIV), settlements andthermal expansions, along with operationalloads and accidental seismic conditions.

Typical lead time:

10 months

Our Well Jumpers can be deliveredin 10 months.

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SUBSEA CONNECTION SYSTEMSOVERVIEW
You can count on the reliability
and safety of Baker Hughes’
subsea connection systems,
even in the most demanding
environments.
With more than 2,400 connectors in our
installed base worldwide, you can be sure
we have the proven connection technology
to meet your needs.
More than 20 years’ experience has gone
into the design of our innovative diverlessclamp connection technology. Using
standard core components, our clamp
technology, hubs and seals all work acrossmultiple alignment structures and bore
configurations – improving their reliability
and safety, while reducing your overall costand minimizing downtime.

We supply both horizontal and verticalconnections for use in shallow to ultradeepwaters and offer you our wide system
and installation experience, with delivery
typically available in 5 months for standard
connection sizes. Our industry-leading
metal-to-metal GX and SX sealing
technology also ensures reliable sealing,even in extreme conditions.

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VERTICAL CLAMP CONNECTIONSYSTEMS (VCCS)

Our Vertical Clamp Connection System
is a proven vertical connector witha robust design and high load capacity
to enhance reliability.
100

HORIZONTAL CLAMP CONNECTIONSYSTEMS (HCCS)

Our Horizontal Clamp Connection System
has a robust design with high load
capacity to enhance reliability andis available in various sizes.
101

Whatever the configuration of your pipelines,
flexibles and umbilicals, we have the subsea
connection system you need, fully validated
through rigorous qualification testing(industry standards API 6A/17D and 17R
and ISO 10423 & 13628-4) to perform in theharshest of environments. We have thewidest range of fully-qualified clamp
connectors, ranging from 4 inches (300)
to 42 inches (M5) pipe size, all designedwith robust capacity and with simple ROV
tools to minimize installation time.

See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA CONNECTION SYSTEMSVERTICAL CLAMP CONNECTION SYSTEMS (VCCS)
Our Vertical Clamp Connection System isa proven vertical connector suitable forrigid pipes, flexible pipes with a gooseneck,
subsea Pig Launchers and Receivers (PLR),
piping loops and control/valve modules. It
has a robust design with high load capacity
to enhance reliability.
The VCCS uses either standard single boreor dual bore configurations, although there isan option for multi-bores. It accommodatesa size range of 3 inches up to 22 inches withstandard pre-qualified seal sizes that mean
we can offer the lowest cost and a short leadtime of five months for MTO sizes. Projectspecific seal sizes can also be accommodated,though this will add to the lead time.

VCCS
FeatureMake to Order

Configure to Order

Variant

4 Sizes: VCCS 300, 450, 520,
580

1 Size: VCCS 720

Pipe size (inches)

4 - 1618 - 22

Qualification

API 6A / 17D & API 17R and ISO
10423 & 13628-4

Design Pressure rating(psi)

MTO 10,000

Temperature rating-46°C to 180°C

Water depth rating

MTO 3,000m

Design life

Up to 50 years

Pipe type

Rigid, flexible, pigging loop
& PLR

Bore configuration

Single, dual-concentric

In developing the VCCS, our focus has beenon optimizing the connector size and weight,
as well as the connection make-up-timeand efficiency of ROV operations to allow
for rapid installation. Its high capture range
and installation misalignment tolerances
help to reduce installation time and, simply
by using gravity through its inbuilt passive
soft-landing feature, our VCCS requires
no running or stroking tool for connection
make-up, reducing vessel time and youroffshore installations cost. All VCCS
configurations include a back-seal test port.

The VCCS can also integrate a gooseneck
for flexibles. In addition a flowmeter canbe included if required. VCCS can also be
used for PLR applications. Same toolingcan be used for all applications providing
interchangeability and saving cost.
You can improve reliability by cleaning hubs
without retrieving the jumper and seals canbe replaced in-situ with the ROV flyable tools,
reducing connection time during installationand maintenance.
With a pressure rating up to 15,000 psi and atemperature rating of 350°F (180°C), our VCCS
can withstand the harshest environments.
A range of caps for pressure barrier, flooding,protection and testing activities helps you
during different stages of operations
such as onshore testing, installation,commissioning and future expansion,
while we can provide insulation if required
to enhance operability of the system VCCS
can be provided with insulation.
VCCS tooling can be offered on purchaseor rental basis for standard sizes.

CTO 15,000

CTO 3,500m

Typical lead time:

5 months

Our Make to Order VCCS can bedelivered in 5 months.

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SUBSEA CONNECTION SYSTEMSHORIZONTAL CLAMP CONNECTION SYSTEMS (HCCS)
Our Horizontal Clamp Connection System
is a proven horizontal connector suitable
for rigid pipes, flexible pipes, subsea Pig
Launchers and Receivers (PLR), piping
loops and control/valve modules, as well
as umbilical termination with use ofmulti-bore hub technology. It has a robust
design with high load capacity to enhancereliability and is available in various sizes –Aptara™ HCCS-L covers size range of 4" up to
18" while large bore HCCS covers size range
from 18" up to 42".
The horizontal clamp connection system
uses standard single bore, dual bore, andmulti-bore configurations. It accommodatesa size range of 3 inches up to 42 inches withstandard pre-qualified seal sizes that mean
we can offer the lowest cost and a short leadtime of five months. Project-specific seal
sizes can also be accommodated, though
this may add to the lead time.

Aptara™ HCCS-L/HCCS
FeatureMake to Order

Configure to Order

Variant

3 Sizes: HCCS-L Small,
Medium, Large

4 Sizes: HCCS 22, 30, 36, 42

Pipe size (inches)

4 – 1818 – 42

Qualification

API 6A / 17D & API 17R and ISO 10423 &
13628-4

Design Pressure rating(psi)

MTO 10,000

Temperature rating-46°C to 180°C

Water depth rating

MTO 3,000m

Design life

Up to 50 years

Pipe type

Rigid, flexible, umbilical, pigging
loop & PLR

Bore configuration

Single, dual-concentric & multibore

CTO 15,000

CTO 3,500m

Our lightweight HCCS-L is part of our Aptara™
family of TOTEX-lite products and the HCCS-L
Small (3-6 inches), Medium (8-12 inches) andLarge (14-18 inches) have all been developedwith a focus on optimizing the connector
size and weight, as well as the connection
make-uptime and efficiency of ROV
operations to allow for rapid installation.
They come with a back-seal test port, apre-mounted stroking tool and require fewer
subsea operations, reducing the connection
time by over 30%. Our unique push-type
stroking functionality allows full access forcleaning and cap replacement with the
pre-mounted stroking tool.

Our HCCS-L benefits from the integrationof flexible end-fittings into the connector,
reducing CAPEX and making the system
more compact and reliable.
The HCCS-L also offers umbilical termination
with a multi-bore hub configuration,
further enhancing reliability and theinterchangeability of tooling with otherflowline connections. A Pig Launcher Receiverapplication in manual or remotely operated
mode also comes as standard.
The HCCS range consists of HCCS 22 (20-22
inches), HCCS 30 (24-30 inches), HCCS 36(32-36 inches) and HCCS 42 (38-42 inches)– the largest size in the industry. The whole
range enables you to use our proprietary
Open-PLET technology, which significantly
simplifies your pipeline and PLET installation,
reducing installation time, risk and cost
while enhancing safety and reliability.
With HCCS clamp transfer feature we areable to recover the clamp with termination.
With a pressure rating up to 15,000 psi
and a temperature rating of 356°F (180°C),
our HCCS-L/HCCS can withstand theharshest environments. A range of caps forpressure barrier, flooding, protection andtesting activities helps you keep the systemat peak efficiency, while our proprietary
Heatbank insulation provides a highcool-down time, enhancing operability
and availability.

Typical lead time:

5 months

Our Make to Order HCCS can bedelivered in 5 months.

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SUBSEA ELECTRIC SOLUTIONSOVERVIEW
In line with the industry’s
ongoing transition from electrohydraulic to All-Electric systems,
Baker Hughes is leading theway with the launch of its first
All-Electric subsea production
system in 2021.
Subsea electrification offers ourcustomers substantial benefits – theability to deploy new subsea production
systems that have lower CAPEX andOPEX costs, improved reliability andavailability, reduced topside footprint,
access to assets in deeper water andlonger step-outs and elimination of the
HSE risk of accidental spillage or releaseof hydraulic fluid to the environment.
Subsea electrification is also an
important step towards lowering thecarbon footprint of subsea operations.
Our All-Electric technology will becompatible with all our subsea
production system variants, including
our Aptara™ range of lightweightcompact trees and manifolds.

Our capabilities extend to subsurface
and include electrical downhole safetyvalves and electrical ICVs (Inflow Control
Valves) from our Intelligent Subsea
electrification is also an important step
towards lowering the carbon footprint ofsubsea operations.
Completions group. Our All-Electric
system will have the ability to interface
with other elements including subsea
chemical injection and storage systems(SSCS&I) and to subsea HPUs as analternative method for controlling thedownhole safety valve. Digitalization willplay a key role in delivering enhanced
reliability and availability and system
performance through continuous
condition monitoring based on anabundance of data from sensors,
control boards and battery
management systems embedded inour subsea electric actuators.
Longer term, the next generation of
All-Electric subsea production systems
will be controlled through autonomous
power and communication systems. We
are engaging with partners to evaluate
the feasibility of using novel wave andtidal power systems together with
inherent communication capabilities
that will enable the complete
elimination of hydraulic and power
connections to topside facilities.

But All-Electric is not all in the future.
Today we provide electric actuatorsfor brownfield applications to replace
faulty hydraulic actuators on manifold
structures, high-speed anti‑surge
actuators for subsea gas compression
systems and electric chokes areavailable as standard on our subsea
tree and manifolds. You can learn more
about our range of electric actuatorslater in this section.

ELECTRIC ACTUATION

Our electric actuators can use local energy
storage or central energy storage with arange of AC and DC power input options.
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ROTATING ELECTRIC ACTUATORS(REA)
ALL-ELECTRIC
PRODUCTION SYSTEMSOur All-Electric Production Systems
reduces overall complexity and cost,and allows us to optimize yourremaining electric system.
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ADVANCED INTELLIGENTCOMPLETIONS

Our advanced intelligent completions
solutions include electric downhole safetyvalves and electric inflow control valves.
These can be used separately or in
combination with our subsea solutions tomaximize the value of subsea
electrification.
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Our portfolio of high power and low
power rotating electric actuators covera wide range of operating andinterface requirements.
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LINEAR ELECTRIC
ACTUATORS (LEA)

A premium solution for subsea processing
systems, our Linear Electric Actuator
offers accuracy better than ±0.15 mm.
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ELECTRIC CHOKEOur electric chokes offer our customers
superior motion and positioning control,
higher reliability and enhanced condition
monitoring capability.
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SUBSEA ELECTRIC SOLUTIONS

ALL-ELECTRIC PRODUCTION SYSTEMS
Our subsea All-Electric system is basedon our state-of-the art technologies anddesigned to operate at 3,000m water depth.
All new components and electrical actuators
will be qualified according to API 6A, API 17D
and 17F and specifically to the Joint Operators
Specification addendum to API17F for
All-Electric systems.
Power distribution
From the outset, a decision was made toensure that our system is compatible withall potential power distribution systems,
to provide our customers with maximum
flexibility in field architecture design. Power isdistributed from a topside or onshore facility
as either High-Voltage AC, High-Voltage DC,
Low-Voltage AC or DCFO and is converted
subsea to 400VDC for infield distribution.
Power & Communications
The power and communications distribution
system has been specifically designed for
subsea All-Electric and consists of three
key modules: an electrical Power andCommunication Distribution Module (ePCDM),
an electrical Subsea Control Module (eSCM),
and an Energy Storage Module (ESM).
Electric Power & Communications
Distribution Module (ePCDM) – The ePCDM
receives power and communications fromthe transmission system and distributes
it infield to the eSCM and ESM modules.
Power is received as either High-Voltage AC,
High-Voltage DC, Low-Voltage AC or DCFO
and is converted subsea to 400VDC for
infield distribution using a step-downtransformer and AC/DC convertors to theeSCMs via the ESMs. For DCFO there is norequirement for power conversion since
DCFO is distributed at 400VDC.
Optical communications from topside are
distributed via an ethernet router to theindividual eSCMs as either ethernet or DSL.

Power switching is available in the ePCDM
to ensure that individual trees can beseparately isolated for intervention.
Energy Storage Module (ESM) – Single ordual redundant ESMs can be mounted on
the subsea tree and store energy locally toensure that we minimize power draw on theoverall system and ensure we have sufficient
power to operate at long offsets, and/or tooperate several trees in parallel. The ESMs
are ROV retrievable and include a battery
management system (BMS) that is used tocontrol the charging and discharge of theunit and to provide healthcare monitoring.
Electrical Subsea Communications Module(eSCM) – The eSCM modules receive
ethernet or DSL communications directlyfrom the ePCDM and 400VDC power
distribution from the ESMs. Power andcommunications are then distributed tothe individual electric actuators and to the
instrumentation via electrical harnesses.
Electrical Actuators
The main safety critical valves in the system
will use spring fail safe close actuators. The
400VDC linear actuators for the gate valvesconsist of two parts: a rotary electric actuator(REA) and a rotary to linear motion (RLM)
where the REA part is ROV retrievable and the
RLM remains fixed to the tree body. A 400VDC
rotary actuator will be used to function theball valves on the trees and manifolds.

Typical lead time:

12-24 months
Project dependent.

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SUBSEA ELECTRIC SOLUTIONSADVANCED INTELLIGENT COMPLETIONS
Maximising the value of subsea
electrification requires going beyond thewater column and into the subsurface worldof Completions.
Completions provide the technology that
forms the production (or injection) conduit
from reservoir to the tree. This includes awide variety of technologies including wellconstruction to monitoring to flow control
to flow assurance to safety valves todata management and analytics. The
requirement for monitoring and controlof reservoirs/wellbores is ever increasing
with the need to have finer and granular
control of the asset.
Implementing the right technology
subsurface enables value for the whole
production system:• Removing hydraulics–– Enables full reduction of umbilical cost–– Reduce chemical consumption /waste / disposal and theenvironmental impact–– Simplify operations–– Less control lines to handle during
installation, reducing the risk, and saving
rig time–– Less feed throughs required through thetubing hanger and tree–– Faster tool response times for optimizing
well performance during production

Electrical Downhole Safety Valve
Safety valves are a critical component of awell’s safety and barrier elements and canhelp save lives and protect property and theenvironment. Subsurface safety valves havesignificantly evolved over the last 50 years
with applications now requiring pressures
up to 25,000psi, setting depths up to 15,000ft,
temperatures over 400F and the ability
to safely close and shut in well pressure inhigh rate wells flowing at velocities of over
400 feet per second.
One of our basic philosophies at Baker
Hughes is to ensure we provide simple,
highly reliable safety valves that always
deliver fail-safe closed performance.
This will continue with our electric safetyvalve solutions.
The electric safety valve will provide fail-safe
closure operating on field proven power
springs for closure in worst-case conditions.
Essentially, we will be using existing closure
mechanisms provided in over 30,000 safetyvalves provided in our history. The actuator
powering the electric safety valve will
deliver reliable low power actuation to
open the valve.
We have been operating in harsh deep-water
environments for nearly 20 years and theelectric safety valve will include the features
most critical to reliable performance inthese conditions.

Electrical Inflow Control Valves (ICV)
Remotely controlled ICVs are a criticalcomponent of an Intelligent Completion
providing selective control of various zones/
compartments in the reservoir or wellbore.
Electric ICVs are not new to Baker Hughes.
In the early 2000’s Baker Hughes designed,
manufactured, and installed Electric ICVs
in a subsea well offshore Brazil that is still
operational today. More recently, Baker
Hughes developed our MultiNode electric
ICV technology aimed at horizontal, dry tree
applications that require many ICVs (Up to27) to control water breakthrough and have
had several installations to date.
Today, we are developing our next
generation of Electric ICVs suitable for theharsh conditions of subsea applications. Thissolution will enable the control of multiple
ICVs using a single electric control line whilst
using as low power as feasible. The electric
ICV is a near-infinitely variable choke thatis remotely adjusted with a command fromthe surface to control the flow in or out of a
production zone. This electric completions
technology enables applications previously
not possible or practical due to limitations of
traditional hydraulic intelligent completions.

Digital/Condition monitoring
Our All-Electric system continuously gathers
data through sensors used to control andoperate the electric actuators and can be
designed to capture additional data on
demand. Downtime is reduced throughpredictive maintenance and reduced timefor fault finding. The data will be used
to better understand the equipment
performance and learnings will be takenback into the product development process
to ensure even more reliable products
over time.
Typical parameters that will be measured
include temperature, current, voltage andoil/water content. This enables monitoringof barrier integrity, mechanical wear andbattery health. Information is read fromdirect measurements, and trending ofdata over time is used to give important
information about the system. In addition,
partial stroke testing of electric actuators will
enable monitoring of valves and actuators
which are idle for a period.

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SUBSEA ELECTRIC SOLUTIONSELECTRIC ACTUATION
Building on more than 15 years ofexperience, Baker Hughes’ market leading
portfolio of electric actuators include
qualified rotary, quarter turn and linear
solutions, with 100 Nm, 600 Nm and 2,700 Nm
torque capabilities in single or redundantsolutions, making them very adaptable toa range of applications.

The actuators can be used for a brownfield
retrofit of manual valves or faulty hydraulicvalves in Manifolds, Chokes, In-Line Tees,
Pipeline End Terminations and Flowline
End Terminations, and across All-Electric
production systems and Subsea
Compression systems.

Electric actuators combined with a matching
power and communications network, are thecore element to realizing All-Electric
Production Systems. Our actuators benefit
from direct drive or from a central energy
storage and a range of AC and DC power
input options, ranging from 24V (low power)
to 400V (high power) solutions.

Typical lead time:

9 months

Our electric actuators can be deliveredin 9 months.

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SUBSEA ELECTRIC SOLUTIONSROTATING ELECTRIC ACTUATORS (REA)
Our existing portfolio of rotating electric
actuators has a solid track record andcovers a wide range of operating andinterface requirements. These include
electric chokes, ball valves on manifolds,
SURF modules like in-line tees, pipeline end
terminations and flowline end terminations,quarter turn valves, retrofitting manualvalves, skids, and subsea processing
systems – pumps, compressors
and water treatment.
Our low power (LP) solutions are adapted tointerfacing existing subsea systems through
24 VDC or 48 VDC. The Low Power Rotating
Electric Actuators (LP REA) can provide torqueof 600 Nm or 2700 Nm depending on loadrequirements and is directly powered fromthe subsea control system.

Typical lead time:

9 months

Our electric actuators can be deliveredin 9 months.

All our rotating electric actuators can beinstalled through a standard ISO 13628-8
class 4 ROV interface. Our LP REA solutions areat technology readiness levels (TRL) 4-7 andhave been installed at many sites, including
Dalia and Troll C, while our HP REA solutions
are at TRL 4, following extensive qualification
activities and submerged system testing for
the Ormen Lange Pilot.

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SUBSEA ELECTRIC SOLUTIONSLINEAR ELECTRIC ACTUATORS (LEA)
In addition to Baker Hughes’ standard
electric actuator solutions, our portfolio
also includes premium solutions for subsea
processing systems, including subsea
compressor protection, with a Linear Electric
Actuator that offers accuracy better than
±0.15 mm.
Our electric actuator for subsea processing
systems is designed for continuous andprecise operation of the anti-surge valvestypically found on subsea gas compressor
systems. It has a built-in fail-safe spring
package that does not require any internal
parts to be operated, other than the output
shaft of the actuator. It brings the valve to an
open position in case of any failure in thesystem, ensuring accurate operation andpositioning of subsea linear control valves.
The full end-to-end travel of actuator andvalve is performed in under two seconds andit is designed with dual-redundancy for all
critical systems, including motor, power,
communication, and springs. The valve stem
area is also protected, flushed and oil-filled
by a hot-stab system.

Its specially designed ROV-operated linear
stem connection makes subsea retrieval with
ROV much easier and enables simple tooling.
The actuator also has a built-in, patented
electromechanical clutch system thatconnects and disconnects the valve stem,
actuator and spring package enabling valve
operation without cycling the fail safe spring
package. Reducing risk of mechanical failure
for high cycle applications.
Our linear electric actuators are used ina wide range of applications, including
tree gate valves (critical and non-critical),manifold gate valves and anti-surge
actuation for subsea compressors. We
are also currently developing a complete
range of linear fail-safe solutions forcritical tree valves.
The Linear Anti-Surge Actuator was qualified
to 1 million cycles and system tested at theOrmen Lange Pilot, and is currently installed
and in operation in the Åsgard Subsea
Compression system with a technology
readiness level (TRL) 7 rating.

Typical lead time:

9 months

Our linear electric actuators canbe delivered in 9 months.

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SUBSEA ELECTRIC SOLUTIONSELECTRIC CHOKE
An integral part of our All-Electric systemevolution, electrically operated chokes areavailable as an option to conventional
hydraulically operated chokes on our tree
and manifold systems. Electric Chokes
offer our customers superior motion andpositioning control, higher reliability andenhanced condition monitoring capability.

The main choke assemblies on our electricchokes are identical to the hydraulic versions
and are available in 2", 5" and 7" sizes andengineered to operate in water depths up
to 10,000 ft (3,048 m), operating pressuresof 6,500 psi to 10,000 psi and operating
temperatures between -51°F to 300°F(-46°C to 149°C).

The main difference between our hydraulicand Electric Chokes is the control
mechanism. Rather than controlling thechoke through a conventional electrohydraulic umbilical, the Electric Choke iscontrolled by a field-proven and qualified
24V/48V DC REA (Rotating Electric Actuator)
which is attached to the choke assembly
through an ISO 13628-8 class 4 ROV interface.
Our Electric Choke actuators avoid the needfor dedicated local energy storage modules
by drawing low power directly from theSubsea Electric Module (SEM) located in ourstandard SemStar5 or Aptara™ controls
systems. This also means that they can beeasily retrofitted on brownfield electrohydraulic chokes.

Our Electric Chokes are available
integrated with one of our subsea treesystems,or as a single supply with a leadtime of around 7 months.

Typical lead time:

7 months

Our Electric Chokes are available
integrated with one of our subsea treesystems, or as a single supply witha lead time of around 7 months.

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SUBSEA WELL ACCESSSYSTEMS OVERVIEW
Baker Hughes has a long historyof providing safe, efficient, andreliable Well Access services.
In addition to equipment you canpurchase outright, we have an extensive
portfolio of rental tools and equipment
to support operations from installationand commissioning right through todecommissioning. This comprehensive fleet
can meet the needs of long and short-term
rental contracts, providing well-maintained
equipment for subsea contracts.

Our Well Access product portfolio isfully in tune with the challenges you facethroughout the lifecycle of a well frominstallation and commissioning, toproduction enhancement and ultimately
decommissioning, with a focus on reducing
your CAPEX and OPEX. And, by making fulluse of Baker Hughes’ full-stream capability,
you can be certain of the smooth running of
all activities throughout your overall Well
Access campaign. We can also provide thedownhole tooling and diagnostics you need,while ensuring seamless integration with any
drilling activity being undertaken.
We can offer the full solution, through asingle contract and execute with the Subsea
Connect Interventions Solutions group.

Subsea Connect
Solutions

Subsea 101

OPEN WATER COMPLETIONWORKOVER RISER (CWOR)

Depending upon your field and system
requirements, we can offer an Open
Water Completion Workover Riser (CWOR) to
rent or purchase.
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INSTALLATION AND WORKOVER
CONTROL SYSTEM (IWOCS)

The technology we use is industry-leading
and innovative – offering safe, simple,
efficient and reliable turnkey-ready
IWOCS and intervention products.
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Detailed Specifications
and Data Sheets

SUBSEA TEST TREE (SSTT)

Our long history in supplying SSTT
systems enables us to select the mostefficient, safe and reliable system to suit
your needs.
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SIMPLIFIED LANDING
STRING (SLS)Our Simplified Landing String is similar toa Subsea Test Tree (SSTT) landing string
but without the complexity of wellbarriers.
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PRODUCTION ENHANCEMENT LIGHT WELL INTERVENTION

Our Light Well Intervention systems have theability to work on any OEM XTs and control the
XT functions with our global agnostic IWOCS
fleet. We can perform mechanicalinterventions or fluid stimulation campaigns
from a single vessel, with an over-the-side
deployment or through a moonpool – allowing
more flexibility on vessel selection.
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See Section 8 on page 182 for detailed
specifications and data sheets.

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SUBSEA WELL ACCESS SYSTEMSOPEN WATER COMPLETION WORKOVER RISER (CWOR)Open Water CWOR System
Configure to
Order

Configure to
Order

73⁄8

51⁄8

61⁄8

2 nom

2 nom

2 nom

Pressure rating (psi)10,00010,00010,000Design life

25 years

25 years

25 yearsTemperature range

0°F to 250°F(-18°C to 121°C)

0°F to 250°F(-18°C to 121°C)

0°F to 250°F(-18°C to 121°C)

Max water depth

10,000ft(3,048m)

10,000ft(3,048m)

10,000ft(3,048m)

LRP production bore size (inches)

73⁄8

73⁄8

73⁄8

LRP annulus bore size (inches)

21⁄16

21⁄16

21⁄16

EDP production bore size (inches)

73⁄8

73⁄8

73⁄8

EDP annulus bore size (inches)

21⁄16

21⁄16

21⁄16

FeatureMake to Order

Variant

1 Option

System production size (inches)
System annulus size (inches)

Our Open Water Completion Workover
Riser (CWOR) provides a conduit fromyour subsea tree on the seabed to the rig,
enabling topside access to the well for all
your life-of-field activities. Above the tree,a Well Control Package (WCP) is connected
to an Emergency Disconnect Package(EDP), allowing you to isolate the welland disconnect at any time, leaving
the well fully contained.

The WCP features redundant emergency
barriers that isolate the well during all
operating conditions, including the ability toshear and seal wireline or coiled tubing for
maximum safety during high flow operations.
The barriers are qualified as Safety Heads
according to NORSOK D-002. The WCP also
features a gate valve as an operational
barrier that ensures the emergency barriers
are always primed and ready for use.

Before we supply an Open Water CWOR,
our in-house analysis team will carry out
a Global Riser Analysis to select the system
most suited to the unique challenges at yourlocation. Lead time for a standard system
is around 6 to 24 months and a typical
deployment will include a WCP, EDP, stressjoint, riser system, swivel, cased wear joint,
and tension joint.

The EDP features a connector to the WCP
that, once the well is isolated, allows theriser system to release from the well,regardless of the angle/location of the riser.
This typically complies with API RP 17G (2005).
The EDP also features a valve that retains
the riser inventory during this disconnect
sequence, preventing hydrocarbon escapeto the environment.

To complete your Open Water CWOR system,a surface test tree and lubricator valve will be
provided, enabling you to isolate the well at
the surface, to facilitate fluids entering andleaving the production bore and to allow
access for wireline and coiled tubing toolingto go into the well.

Depending upon the specifics of the field
and your system requirements, you may
want to rent rather than purchase a system.
We also have regional rental CWOR systems
available that could reduce your overall
project CAPEX.

Typical lead time:

24 months

We can deliver an Open water CWOR
in 6 to 24 months, depending on thespecification of your system. For rental
options, our regional offices can advise
on availability.

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SUBSEA WELL ACCESS SYSTEMSINSTALLATION AND WORKOVER CONTROL SYSTEM(IWOCS)
Our IWOCS is based on field-provenproducts and services developed by
Advantec, a business we acquired in 2015.
The technology we use is industry-leading
and innovative – offering safe, simple,
efficient, and reliable turnkey-ready IWOCS
and intervention products.

IWOCS is set up to be a compact unit for thefull integration of all required functionality
in the installation and workover phases.
It is a multifield system that can interface
with different OEM systems through one
human-machine interface (HMI), providing
a fully integrated overview of your operation.
Both, direct hydraulic and multiplexedhydraulic control systems are available.
A single container incorporates both, the
HPU and operator cabin. Alternative solutions
are available on request.
Our IWOCS is based on a standardized
design and is highly adaptable throughsoftware and configuration variants to meetwhatever functionality your project requires.
Installation and Workover Control System – IWOCS
FeatureConfigure to Order

Separate HPU & MCS Control room in asingle 30 feet container

Designed according to ISO 13628-7 & ISO
13628-1

PLC Electronic Control System

Prepared for SIL2 Shutdown (PSD / ESD / EQD)
w/Local Shutdown Panels

MCP and RCP with VDU Screen, keyboard
and Mouse/TrackballDnV 2.7-2 Compliant

UPS A/B (220-240VAC, 50 / 60Hz, 16A)
Located in non-Ex room

EN50381 “Portable Ventilated Room”
Compliant

Up to 44 controlled outputs, LP: 5,000 psi, MP: IECEx (Zone 1 IIB T3) Compliant System
10,000 psi, HP: 12,000 psi
Separate Dirty Return Tank for contaminatedfluid with hydrocarbon detection

DNV 2.7-1 Certified Container / AS 1666 sling

Several layers of redundancy withmechanical or manual back-up

Incorporation of XT supplier SPCU for
SCM control

Built-in F&G system, PA and telephone
for rig interface

With the full integration of landing string
functionality, there are fewer interfaces
between companies and vendors, leading
to increased efficiency. The functionality
and layout of any in-riser SSTT/LS, fromany vendor, can be quickly configured
insoftware. There is no need for separate
HPU/Controls Container from the vendor
and the system ensures simplified andsafer operations of your LS/SSTT fromthe HMI Screen.

Our range of rental IWOCS Containers isavailable in a variety of sizes, functionality
and technologies to fit project needs.

• Direct, manual valve operated systems• Electro-hydraulic (EH) systems for directcontrol of hydraulic umbilical line pressures
to subsea valves and connectors.
• Multiplexed (MUX) EOCS systems forultra-deep-water applications, including
subsea Workover Control Modules (WOCM).
• RWOCS solutions for ultra-deep water(3,000m) application, control skid is placedon the sea bed, controlled by either ROV
or EDL downline connection.
Our IWOCS meets the most demanding
requirements. The shutdown functions of thesystems designed in compliance with SIL2 for
9PSD/ESD/EQD, are initiated from push buttons
located on the drilling rig/vessel. The IWOCS
containers and skids are all DNV 2.7-1 certified
and are supplied with certified lifting slings.

Typical lead time:

12 months

We can deliver a complete system
in 9 to 18 months depending upon
specification and project timing.
For rental options, our regional offices
can advise on availability.

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SUBSEA WELL ACCESS SYSTEMSPRODUCTION ENHANCEMENT – LIGHT WELL INTERVENTION
2 inch Fluid Intervention System
Our 2 inch 10Kpsi Fluid Intervention System
can be operated in depths up to 2,000m(6,500 feet) and can be deployed directly
on to the subsea tree or with a mud-mat
to the sea bed. Live well interventions, wellstimulation, scale squeeze, well kill, hydrate
remediation and pipeline cleaning can all
be supported by this system.

4 inch RLWIS Package
Our 41/16 inch 10Kpsi Light Well Intervention
Package supports slickline and e-line
operations, plug and abandonment, coiled
tubing up to 13/4 inch OD, through tubing
cementing operations, well testing, tree
installation and change-out in water depths
up to 1,070m (3,500 feet).

Our Light Well Intervention systems havethe ability to work on any OEM XTs andcontrol the XT functions with our global
agnostic IWOCS fleet. We can performmechanical interventions or fluid
stimulation campaigns from a single
vessel, with an over-the-side deployment
or through a moonpool – allowing more
flexibility on vessel selection.
We can offer the full solution, througha single contract and execute with ourdedicated Production Enhancement
Center of Excellence team.
7 inch RLWIS Packages
We have three 7 inch Light Well Intervention
packages in our portfolio, primarily for use inriserless applications but can also be used inriser based operations and can beconverted with the Well Control Package
remaining subsea. In Riserless mode thesystems are suitable for a range of slickline,
e-line and braided wire applications.

3 inch RLWISOur 31/16 inch 10Kpsi Light Well Intervention
Package supports slickline & e-line
operations, cutting tubing & casings,
zone isolations, shifting sleeves andsetting/pulling plugs, well diagnostics &logging, perforating tubing & formationand tree installation & change-out up
to water depths of 150m (500 feet).

3 inch Fluid Intervention Systems
Our 3 inch 15Kpsi Fluid Intervention System
can be operated in water depths up to
3,048m (10,000 feet). This system can be
deployed directly on to a subsea tree orto the seabed on a mudmat. Live wellinterventions, well stimulation, scale squeeze,well kill, hydrate remediation and pipeline
cleaning can all be supported by this system.

Light Well Intervention
Feature7.0 inch RLWI

7.1 LWI

7.2 LWI

4.1 inch RLWISize (inches)

71⁄16

73⁄8

73⁄8

41⁄16

31⁄16

Pressure

10Kpsi

10Kpsi

10Kpsi

10Kpsi

10Kpsi150m

Temperature

Class – U

Class – U

-9°C to +121°C

Water Depth

1,600m3,000m3,000m

1,070mPSL

PSL 3

PSL 3GPSL 3G

PSL 3

3.1 inch RLWI

Trim

EE

EE, Sour service

EE, Sour service

EE

EE

Controls

Piloted Hydraulic

Piloted Hydraulic

Piloted Hydraulic

Piloted hydraulic

Piloted Hydraulic

Op ModesRiserless E-Line& Slickline
Riser Based CoilTubingRiserless E-Line& Slickline
Riser Based CoilTubingRiserless E-Line& Slickline
Riser Based CoilTubingRiserless E-Line& Slickline

Riserless E-Line& Slickline

Design CodeAPI Spec 16D, 17D, 6A

Service

NACE MR-0175/ISO15156

Light Well Intervention
Feature2 inch Fluid Intervention
System3 inch Fluid Intervention
SystemSize (inches)

21⁄16

31⁄16

Pressure

10Kpsi

15Kpsi

Water Depth

2,000m3,000mControls

ROV operated

ROV operated

Circulation

Dual 2 inch

Dual 2 inch

Deployment

Directly onto asset or on
seabed with a mud-mat

Directly onto asset or on
seabed with a mud-mat

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SUBSEA WELL ACCESS SYSTEMSSUBSEA TEST TREE (SSTT)
When accessing your well through theblowout preventer (BOP), a Subsea Test Tree
(SSTT) landing string is required, providing
well isolation and the functionality to
disconnect the well.
Our typical SSTT landing string includes anupper string with a surface test tree, swivel,
cased wear joint and lubricator valve; a riser
system; and a lower string with an annular
slick joint, shear sub, SSTT latch, SSTT barrier
package, ported slick joint and tubing
hanger running tool. As with an Open
Water CWOR, our in-house world-classanalysis team will carry out a Global Riser
Analysis to select the riser pipe system thatis most suited to the unique challenges
at your location.

Baker Hughes has a long history of supplying
SSTT systems, which enables us to select themost efficient, safe and reliable SSTT system
to suit your needs. Delivery of an SSTT systemtakes around six to 12 months and it will
typically be supplied in accordance with
API RP 17G.

As a contingency measure, the SSTT landing
string is also supplied with a shear sub,built to a specific geometry and material
grade that can withstand the internalpressure and tension loading, while also
being weak enough to be shearable by
the BOP shear rams.

The SSTT’s ported slick joint provides asurface on which the pipe rams of the BOP
can close to facilitate pressure testing of
the hanger seal. Above that, the dual valve
package is used during unplanned events, toprovide shear and sealing capability ofwireline or coiled tubing when there is toolingin the well. Once the well is isolated, thelanding string has a disconnect feature to
separate the well from the rig. Above this
disconnect feature, a valve closes to retain
the riser inventory and prevent potentiallyhigh-pressure hydrocarbon escape to theenvironmental riser.

Depending upon the specification ofyour project and exact requirements,
these systems can be available to rentor to purchase.

Subsea Test Tree
FeatureConfigure to Order

Water depth (ft)10,000ft (3,048m)

Production bore size (inches)

73⁄8

Design standards

API RP 17G (2005)

Isolate and disconnect time (sec)10

Conforming standards

SIL-2

Shear systems

Wireline and coiled tubing available

Typical lead time:

6–12 months

We can deliver an SSTT system in
12 months – or as few as 6 months
depending upon the specification andproject timing. For rental options, ourregional offices can advise on availability.

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SUBSEA WELL ACCESS SYSTEMSSIMPLIFIED LANDING STRING (SLS)
Where well testing is not required but
full-bore access is required, a Simplified
Landing String (SLS) can be provided. It issimilar to a Subsea Test Tree (SSTT) landing
string but without the complexity of wellbarriers. Not only does this lower thecost of the SLS but, it also reduces thecomplexity of the surface control systems
and umbilicals – therefore reducing runningand retrieval time and lowering your OPEX.
Our typical Simplified Landing String includes
an upper string with a circulation head,
swivel, cased wear joint and lubricator valve,a riser system, and a lower string with acrossover joint, shear sub, ported slick joint
and tubing hanger running tool. As with an
Open Water CWOR, our in-house world-classanalysis team will carry out a Global Riser
Analysis to select the riser system that ismost suited to the unique challenges atyour location.

Baker Hughes has extensive experience insupplying efficient, safe, and reliable SLS
systems. Delivery takes around 6 to 12 months
and the system will typically be supplied inaccordance with API RP 17G. We will configure
the lower string in the SLS to interface withyour project-specific blowout preventer (BOP)
and, like the SSTT, the SLS comes with aported slick joint that provides a surface on
which the pipe rams of the BOP can close tofacilitate pressure testing of the hanger seal.
As a contingency measure, the SLS is also
supplied with a shear sub, built to a specificgeometry and material grade that canwithstand the internal pressure and tension
loading, while also being weak enough tobe shearable by the BOP shear rams.
Depending upon the specification ofyour project and exact requirements,
these systems can be available to rentor to purchase.

Simplified Landing String
FeatureConfigure to Order

Operating pressure (psi)10,000

Water depth (ft)10,000

Production bore size (inches)

73⁄8

Sealing system

Ported and annular slick joints

XT tooling

THRT, THROT, THOJ,
hydraulic latch connector

Shear coupling

Shear subDesign standards

API RP 17G (2005)

Typical lead time:

6–12 months

We can deliver an SLS system in around
6 to 12 months.

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SUBSEA POWER AND
PROCESSING SYSTEMSOVERVIEW
With our broad expertise andcapabilities in subsea boosting,compression, separation,
seawater treatment and injection,and high-voltage subsea powersystems, we can help you
increase recovery rates, accessstranded assets and reduce
your overall production costs.
From barrier-fluidless boosting to subsea
sulphate removal, our processing systems
are designed to increase the efficiency of
your subsea operations, while reducing theimpact on your topside footprint and weight.
Our designs bring processing closer to thewell in an efficient manner and also reduce
your carbon footprint compared toconventional subsea and topside solutions.

Baker Hughes is a global leader in subsea
processing, with the technologies andexpertise that means we can simplify yoursystem design, minimize its environmental
impact, and reduce your life-of-field costs.
We can reduce your system costs, timeand risk, all while allowing even the mostcomplex subsea projects to be tackled
in the safest and most reliable way.

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SUBSEA BOOSTING

Our Aptara™ Modular Compact Pump is acompletely integrated, All-Electric boosting
system that can accelerate and improve
oil recovery in both, new and mature wells.
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SUBSEA COMPRESSION

Our subsea gas compression is now
qualified technology and widely acceptedby the industry to significantly improve theeconomics of mature gas fields.
Subsea Compression
122
Blue-C™ Compressor

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Dry-gas Systems

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Wet-gas Systems

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SUBSEA SEPARATION

Our subsea separation solution can debottleneck your topside production facilities,
allowing you the potential to increase
production and reduce your related CAPEX.
Gravity Separators

124Compact Separators

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SEAWATER TREATMENT
AND INJECTION

Our seawater treatment system allows
seawater to be treated and injected
subsea, eliminating the need for heavy,
high-pressure risers and flowlines.
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SUBSEA POWER

We can supply fully integrated AC power
solutions for all types of applications – fromthe simplest single-load scenario to long
step-out systems with high-power loads.
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SUBSEA BOOSTING
THE APTARA™ MCP RANGEOF SUBSEA BOOSTINGSYSTEMSThe Aptara™ Modular Compact Pump (MCP)
is a completely new and leading-edge
technology platform for subsea pumps
that represents a world first for rotating
equipment. It has been designed to provide
the flexibility to handle an unrivalled rangeof fluids and applications – from multiphase boosting to water injection to CO2
injection – simply by changing the internal
hydraulics of the pump from helico-axial for
multiphase boosting, to centrifugal for waterand CO2 injection. The motor stage sizes
and Variable Speed Drive (VSD) units are
identical across all variants of the pump,emphasizing the flexibility and structured
nature of the MCP design.
The innovative architecture of the Aptara™
MCP makes it compact and its modular
construction means that we can offer
pre-qualified designs for a wide rangeof pump sizes.
Our life-of-field approach to design isevident in the Aptara™ MCP’s unique featuresthat reduce total cost of ownership. The
stages are controlled individually by local
Variable Speed Drives (VSDs) that allow thepump to react and adapt dynamically tochanges in fluid conditions. It also provides
inherent redundancy, as the pump canoperate with one or more non-operational
stages if required.
The MCP breaks convention by using nobarrier fluid – significantly reducing topside
footprint by 50%+ and lowering overallsystem cost. Unlike a conventional subsea
pump, which uses one high-voltage motor
to drive a long shaft connected to a seriesof impellers, the MCP has a uniquearchitecture with integrated motor impellers
that rotate around a static shaft. Thiseliminates potential rotodynamic issues
whereas in a conventional pump, the motor
is connected to the same shaft that drives
the impellers, which limits the numbers ofstages that can be stacked.
Each integrated motor, or “stage” is clad withpermanent magnets and generates 250kW
of drive power. The stages are stacked toprovide a range of power densities – from
1MW with 4-stages to 6MW with 24-stages,
and more if that’s what you require. Because
each stage experiences a relatively low load,
the pump can operate without a barrier fluid,
and instead uses specialized synthetic
diamond bearings that are cooled by theprocess fluid. The hermetically sealed motor
also ensures high inherent reliability, as
high-risk items such as mechanical seals
are not needed. The standard pre-qualified
building blocks enable the Aptara™ MCP tobe configured to a range of different fieldrequirements.
With Subsea VSDs and no need for a barrier
fluid system, all that is required to link theelectric pump system to topside is a simple
and light power umbilical. This can reduce
your topside footprint by more than 50% and
CAPEX by more than 25%, making Aptara™
MCP an ideal solution for brownfield
modifications and long step-outs withtopside space and weight constraints.
The Aptara™ MCP also helps you manage
your EHS priorities and lower your carbon
footprint. The absence of a barrier-fluid
system eliminates the risk of accidental
release of fluid into the environment and our
fluid-less design removes the need totransport barrier fluid to your platform or
FPSO.

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APTARA™ MULTIPHASE MCP

The Aptara™ Multiphase MCP can accelerate
and improve your oil recovery in both, newand mature wells by adding energy tomultiphase wellstreams and by lowering
wellhead pressure. It can unlock and enable
access to your assets, even in the mostchallenging subsea conditions, such as longtie-backs, lower-pressure reservoirs or wellswith difficult flow assurance. The Aptara™
Multiphase MCP will be fully tested andqualified by 2021.

APTARA™ CO2 INJECTIONMCPThe Aptara™ CO2 Injection MCP is specificallydesigned for the pre-salt fields in Brazil
which have a very high CO2 content. A key
advantage in this application over moreconventional subsea pumps is the significant
reduction in space and weight on the FPSO.

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APTARA™ SINGLE-PHASE
MCP

The Multiphase MCP can be used also forwater injection applications, but will have alower efficiency compared to a dedicatedsingle-phase pump. The goal is therefore todevelop a single-phase version of the MCP,
changing the impellers from helicoaxial tocentrifugal impellers, while keeping all otherelements of the boosting system identicalto the Multiphase MCP. The Single-phase
MCP can be used for water injection as astandalone system or in combination with
our Seawater treatment system and for low
GVF (Gas Volume Fraction) wellstream
boosting or upstream from a subsea
separation system.

4 stage configuration

The MCP will be used to inject CO2 in its
supercritical phase (where the CO2 gas
essentially performs like a fluid) into thereservoir following subsea separation fromthe wellstream. The pump will use Baker
Hughes proprietary single-phase centrifugal
impellers that have been field proven in
topside CO2 injection pumps. All otherelements of the boosting system are
identical to the Multiphase MCP.

12 stage configuration

Note: Other configurations also available

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SUBSEA COMPRESSION
Baker Hughes’ subsea gas compression isdesigned and developed with industry
partners to significantly improve theeconomics of mature gas fields. We haveextensive experience in designing subsea
compression systems for both, dry-gas
and wet-gas applications, with powerfrom topside or from subsea power
distribution systems.
Reservoir pressures decrease as gas is
produced, until the pressure may beinsufficient to maintain the flow. Traditionally,
production has been optimized by either
reducing arrival pressure onshore orcompressing the gas on a platform. Now
we can place compression systems on theseafloor, eliminating the need for costly
topside facilities and reducing your overall
HSE concerns.
Baker Hughes in able to provide a fullyintegrated subsea compression system,complete with a subsea power distribution.
Our subsea compression systems use
Blue-C™ centrifugal compressors from Baker
Hughes and the system is placed as close to
the wellhead as possible to provide the mostefficient compression.

While all subsea compression systems
require a reliable high-voltage power supply,
the choice of power supply topology
depends on the step-out distance and thenumber and power requirements of theloads. The step-out distance also determines
where you need to place the variable speed
drives (VSDs) that control the subsea
compressors – either topside, on a floating
structure, or subsea – and we canaccommodate any of these design
configurations.
We have considerable in-house expertise in
the design of high-voltage subsea powersystems. We worked with the Ormen Langelicense to qualify the world’s first subsea
power distribution system with subsea
variable speed drives (VSDs), subsea
switchgear (SWG) and subsea
uninterruptable power supplies (UPSs). Thiswas done in an integrated system string test
together with Baker Hughes’s Blue-C™
Compressor, using an MGV1 electrical motor,
at Shell’s Nyhamna facility in Norway in 2015.

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BLUE-C™ COMPRESSOROur Blue-C™ Compressor is a high-speed
centrifugal compressor designed for
subsea applications.
Our Blue-C™ Compressor is at the heartof both our subsea dry-gas and wet-gas
compression systems. It comes with a choiceof an MGV0, MGV1 or MGV2 high-speed
induction motor that means the compressor
can operate at a broad range of power
levels from 4 MW to 20 MW to best meetyour reservoir conditions. As the world’s firstcentrifugal compressor qualified to handle
up to 5% Liquid Volume Fraction (LVF), theBlue-C™ Compressor can support true
wet-gas performance for both, subsea andtopside compression. Compression systems
based on the Blue-C™ Compressor can be
tailored to cover almost any operating
conditions, providing you with the optimal
combination of differential Pressure (delta P)
and flow.

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DRY-GAS SYSTEMSWET-GAS SYSTEMS

Due to the inherent design of dry-gas
systems, they tend to be larger, heavier andmore costly than wet-gas systems as theyrequire additional equipment including ascrubber or separation unit where the liquid
phase is separated from the gas. The dry gas
is then channeled to the compressor, while
the liquid is boosted with a pump. The gas
and liquid are then transported throughseparate or combined pipelines to afloating facility or back to shore.

Our wet-gas compression systems use
a simpler compression system than otherindustry solutions; it eliminates the needfor the scrubber, condensate pump andpump control system. The result is areduction in size and weight of up to
40% and the potential for a 30% reduction
in your total CAPEX compared to aconventional dry-gas system.

Our Dry-gas Systems can use active
coolers to help reduce the size and weight.

Baker Hughes has extensive experience ofdesigning systems with active coolers
instead of passive coolers, which results in an
overall reduction in system size and weight.

Our Wet-gas Systems can handle
up to 5% LVF for both subsea andtopside applications.

The fundamental requirement of a wet-gas
system is that the compressor must be
capable of handling gas with up to 5% LVF.
Unique to Baker Hughes, we have wettolerant impellers that help do this, withspecial materials and coatings, andmodifications made to the impeller
geometry and compressor flowpath. These
innovative impellers have been qualified at
Equinor’s K-Lab facility in Norway for use
in the Blue-C™ Compressor.

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SUBSEA SEPARATION
When compared to topside separation,subsea separation offers better conditions
to avoid flow assurance issues like theformation of emulsions and hydrates.
Handling of production fluids can be done
closer to the production wells and more
efficiently at higher pressures. Baker Hughes’
solution can de-bottleneck your topside
production facilities by freeing up storage
and transport capacity, allowing you thepotential to increase production and reduce
your related CAPEX.
Production systems typically have complex
multi-phase flow streams where oil, gas,
water or particles like sand may be
combined. Our subsea separation systems
combine technologies that can handle
gas-liquid, liquid-liquid or solids separation(or a combination of them) for flow
management. They also condition the flow
for further boosting, transportation or
reinjection while reducing the risk of flow
assurance issues during production.
Baker Hughes has the required expertise andexperience to design and supply the optimal
subsea separation system for you. Our
field-proven technology and experience
includes Equinor’s Troll C, the world’s
longest-running subsea separation andreinjection system – operating since 2001
and enabling significant increases in thefield’s oil production.
Our building-block approach includes anopen-interface that allows us to partner with
suppliers of complementary technology
to ensure we design a robust and simple
solution that meets your field requirements.
We can also provide a reliable full systemdesign where separation is integrated with
our subsea boosting and compression
solutions for transportation and/or reinjection.

GRAVITY SEPARATORSOur Gravity Separators are robust
and simple.

They can achieve three-phase separation(gas, water and oil) and are designed withsand handling capabilities. Our semicompact gravity separators are an
improvement on traditional gravity
separators and can offer robust systemsolutions for deepwater applications,where they can be combined with internal
separation enhancing devices and bulk
separation equipment for gas, water and/or
sand handling.

COMPACT SEPARATORSOur Compact Separators are designed
to handle high-pressure environments.
In ultra-deepwater applications,conventional gravity separators have
limitations, due to the high-pressure
environment. In these conditions,
smaller‑diameter vessels used in compact
separation become more attractive. Whilegravity settling and coalescence are thedominant mechanisms in conventional
gravity separators, compact separation
solutions enhance coalescence of thedifferent phases by other means, typically
centrifugal forces or turbulence. In-line,
pipe-type and cyclonic separation
devices all form part of our compact
separation solutions.

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SEAWATER TREATMENT AND INJECTION
Water injection is a widely used techniqueto support pressure to the reservoir andenhance oil recovery. With abundantseawater available offshore, it is ideal for
injection applications, but needs to betreated first. Traditionally, seawater has
been treated in large-scale, heavy topside
processing plants. Baker Hughes’ seawater
treatment system allows seawater to betreated and injected subsea, eliminating
the need for heavy, high-pressure risers
and flowlines, and offer more than a 90%
reduction in the weight of topside equipment.
Seawater treatment involves the removal ofsolids that can cause blockages or fracture
the formation, as well as sulphates and otherdivalent ions, which can cause scaling
and souring when interacting with either
formation water or sulphate-reducing
bacteria in the reservoir.
Our subsea seawater treatment systems are
based on a modular concept that can be
tailored to provide exactly the level of water
quality and injection capacity you need,including standard raw seawater treatment,
sulphate removal and desalination. The
systems are also All-Electric, so only require a
power cable to run them, and use
strategically positioned subsea water
injection pumps to inject the treated wateraround the reservoir – optimizing water
flooding and improving oil recovery.
All our seawater treatment systems aredesigned to be highly reliable and thesystem uses many of the technologies
present in typical topside facilities, including
Ultra-filtration (UF) and Nano-filtration (NF)
membranes. The UF and NF membranes
are run at low flux to extend their life, andwe avoid the regular use of the aggressive
chemicals that are normally needed to clean
them and recover their performance.

The UF membranes are back-washedregularly with Sodium Hypochlorite, which is
produced subsea in an electro-chlorinator
unit, ensuring that the membrane modules
only need to be retrieved once every five
years for maintenance.
In standard raw seawater treatment, thewater is filtered to remove any solids or
microorganisms using a coarse filter thatremoves particles down to 30 microns. The
water can then be treated using UV radiation,an alternative to chemical disinfection, to killbacteria, prevent biofouling and reduce therisk of microbiologically-induced corrosionin the injection system.
Baker Hughes’ approach to subsea sulphateremoval is a refinement of raw seawater
treatment that involves a three-step process
before the water reaches the required quality
for pumping into the injection well. The firststep is essentially the standard raw seawater
treatment, but this treated water then passes
through a series of UF membranes whereparticles and even bacteria down to anominal size of 0.02 microns are removed.
In the third and final step, the water passes
through a series of NF membranes thatremove sulphates and other divalent ions,with a small boosting pump compensating
for the pressure drop between the NF andUF membranes.
An additional module with reverse-osmosis
membranes can be added to the sulphateremoval system to remove salt from theseawater and enable tuneable salinity for
injection, providing the potential to slightly
increase recovery by removing more residual
oil from the reservoir. This module is placedin parallel with the NF module and the restof the process is virtually the same used forsulphate removal.

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SUBSEA POWER
A reliable power supply is critical for all typesof subsea processing activities – even more
so if your project faces challenges such as
long tie-backs, multiple loads, deepwater,
harsh conditions or operation in sensitive
areas. Baker Hughes can supply fully
integrated AC power solutions for all types ofapplications – from the simplest single-load
scenario to long step-out systems indeepwater with multiple, high-power loads.

MECON DM 145/700

As a pioneer of subsea power, we designed
and qualified the world’s first subsea powertransmission, supply and distribution system
for Shell’s Ormen Lange Pilot in Norway.
Today, the systems we design are integratedusing our unique portfolio of high voltage
connection systems. Baker Hughes’ MECON
electric connectors are available up to
145kV and 1800A, covering the full rangeof power requirements used in subsea
processing systems.
Our power systems include everything fromtopside drive systems and integrated HV
subsea connection systems, to multi-port
switchgears and standalone circuit breakers.
We provide subsea variable speed drive
solutions, 5-20 MVA subsea transformer
modules and the controls and monitoring
you need. Our field-proven systems aredesigned for maximum installation efficiency
and long-term operating reliability – andthey can be tailored to meet your specificproject needs.

MECOM WM 36/500

145kV dry-mate connection systems
To transfer electrical power from onshore
or offshore hosts down to the subsea
equipment, our 145kV dry-mate connection
system can provide multi-megawatt transfer
over more than 100 kilometers. It is currently
the only high-power connection system inthe market fully qualified for operation above
100kV, and is qualified for 700A and down to3,609 ft (1,100 m). The solution is currently inoperation and classified as TRL 7.
36kV dry and wet-mate connection
systems
Our 36kV connection systems are the mostefficient transmission solution for medium
tie-back distances in the multi-megawatt
range that are required for subsea
processing. The 36kV systems are also used
together with subsea switchgears andvariable speed drives (VSD) to provide full
distribution systems where multiple loads are
fed through a single cable to reduce cost.
These systems come in both, dry-matedand wet-mated configurations and are fully
qualified up to 700A and down to 10,000ft(3,048 m). The dry-mate system is currently
in operation and classified as TRL 7 and thewet-mate system is TRL 4.
12kV supply systems
Baker Hughes has market leading
technology for supplying power into subsea
compressors, pumps and auxiliary systems,
including qualified wet-mate connections at
12kV and 1800A, which is sufficient to feed thebiggest compressors in the market.

Typical lead time:

9 months

Typical lead time for high-voltage
power connectors is 9 months.

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Flexible Partnerships
Partnerships& Commercial
Commercial Models
ModelsDigital Enablement

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Solutions

FLEXIBLE
PARTNERSHIPS& COMMERCIAL
MODELSIn recognition of thevaried requirements
of individual projects
and regions, we havedeveloped suitablepartnerships as well as
innovative commercial
models that help
unlock the value insubsea projects.

We recognize that the demands of eachproject are different and often partnering
to deliver a broader and more integrated
solution can unlock value. We do not havea single prescriptive response, rather we
use our established frameworks with arange of global partners to select the best
option, based on the unique demands ofthe project, according to technical strengths,
regional coverage and capabilities. We canalso take an adaptive approach looking
to find new partnerships where these
are the best fit for the project scope or
local environment.
Baker Hughes continues to lead the way ininnovative commercial models. We havevarious models that balance risk andreward to ensure that our priorities arealigned with yours. These are designed on

Subsea 101

the basis of our TOTEX-lite philosophy and toensure an accelerated schedule to projectcompletion, often extending through the lifeof the field. We’re changing our approach,moving away from traditional contracts todeliver in alliances, consortia and underintegrated contracts. These commercial
models enable us to remove ambiguities
and additional layers of cost anduncertainty, and align the participants
to the same objectives. We have also
introduced performance-based contracts
where our compensation is linked to schedule,
performance, uptime or production rates.
An example is the contract we have with
Diamond Offshore where the BOP stack on
the rig is paid for based on availability. If it’s
not available, we don’t get paid.

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Case Studies

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Case Study: Subsea Connect
Helps Buzzard Fly Higher

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Case Study: New chapter for
Baker Hughes’ Norwegian
success story

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High-Temp Expertise
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CASE
STUDIESNo other company brings
together capabilities acrossthe full value chain of oil
and gas activities – fromupstream to midstream
to downstream.

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Our wide and deep portfolio of
products and services enables us
to create new sources of value,
improving productivity and project
economics through integrated
equipment and service offerings.
We are also leaders instate-of-the-art software,advanced analytics, controls andsensing, and asset performance
management – helping us to sharerisk, reduce costs and increase
productivity at a wide range of
projects around the globe.

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CASE STUDYSUBSEA CONNECT
HELPS BUZZARDFLY HIGHER

For the Buzzard Phase II project in the UK North Sea,
Baker Hughes is working with CNOOC International
in a new outcome-focused framework where webring drilling, completions, subsea production
systems and SURF together, delivering as anintegrated alliance team to develop new reserves
and bring additional production on stream.

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The Challenge
The Buzzard Phase II project in the North
Sea was conceived against a backgroundof tight economics and a historical trackrecord of delay and project overspend thatencouraged new thinking between theoperator CNOOC International and its
major suppliers.
Taking a different approach, the project isdelivered by an integrated project team inwhich Baker Hughes comes together with theoperator, drilling contractor, SURF contractor
and others to provide oil field equipment
and services under a performance-based
commercial model, fostering an environmentof trust and collaboration, where all parties
are aligned to achieve project success.
Buzzard Phase II features an additional six
subsea wells which are tied back to existing
assets where platform topsides and subsea
infrastructure are modified and expanded toaccommodate the new production.
Working in an alliance lets Baker Hughes do acomplex programme spanning well design,
drilling, completions and subsea equipment
supply in conjunction with subsea
construction and brownfield expansion
activities, doing so in a way which manages
interfaces, mitigates risks and aligns
programme deliverables with the aim of
installing and commissioning phase II withminimal impact to ongoing operations.

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The Solution
In line with our Subsea Connect vision, we
supply structured and modular solutions
based on existing, proven technologies andstandardization: a strategy designed to saveboth, time and money while decreasing risk
and increasing certainty.
Baker Hughes provides an extensive scope,from well design, drilling, completions,
wireline and tubular running through tosubsea system design and supply allowing
unique opportunities to standardize, optimize
and deliver in an integrated manner from thereservoir to the topside.
The Subsea tree system selected for Buzzard
is our Make to Order MHXT, which is alreadyfamiliar to CNOOC International and many
global customers, while MS700 well-heads
were supplied from an existing off-the-shelf
system and subsea controls feature ourstandardized SemStar5 technology. The use of
pre-configured, structured products brings
certainty in the engineering, procurement,
manufacturing and installation phases.

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The Benefits
The alliance approach, with Baker Hughes
providing field services and equipment,
overcomes the typical cost, delay and risk
associated with the traditional contracting
model. Our participation alongside partners
recognizes the need for lowering development
costs in a sustainable manner, ultimately
aiming to yield lower costs per barrel.

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Enabling technology
5 x Hybrid MS700 (Low Pressure Housing)/SG-1 (HighPressure Housing) + Conductors
1 x Hybrid MS700 (Low Pressure Housing)/SG-5 (HighPressure Housing) + Conductors
6 x MHXT
6 x Control System – SCM Sem Star 5

We are committed to supporting ourcustomer in improving the economics of the
field, achieving efficiencies across the supply
chain and establishing a new way of working
in the North Sea. Alongside our partners, weapplied our Subsea Connect vision – primarily
the pillars of Project Connect and Reservoir to
Topside Technology Solutions – to provide
certainty to the operator through a combinedcommitment to one common objective.
Buzzard Phase II is aligned with the Oil & Gas
UK Vision 2035 objectives, which outline
next-generation outcomes for the industry:
provide direction, instill confidence, inspiretransformation, drive collaboration, createcompetitive advantage, secure investment
and drive value.

The real win is to overcome the challenges ofcost and schedule to produce first oil on timeand on budget.

6x

Hybrid MS700 wellheads

6x
MHXT

6x

SCM SemStar5

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CASE STUDY

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Solutions

NEW CHAPTER FOR
BAKER HUGHES'NORWEGIAN
SUCCESS STORY
A consortium execution model between
Baker Hughes, installation partner andour client will help to meet a timely
first oil commitment for the landmark
expansion of a vintage Norwegianfield, while simultaneously boosting
efficiencies and minimizing risks.

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The Challenge
Our client is growing an established fieldon the Norwegian Continental Shelf witha system of 17 new wells and five Multi Flow
Base template manifolds feeding backto an upgraded FPSO.
The operator, a newly formed partnership,
is targeting first oil from the project in late
2021 as part of an ongoing expansion
plan at the vintage harsh environment
development in 130m water depths.
The integrated SPS-SURF project is due
to be completed in mid-2022.

17

New wells to feed into the upgraded Jotun FPSO

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The Solution

The Benefits

Baker Hughes teamed up with a SURF partner
to provide a collaborative SPS and a SURF
solution on an EPCI basis. Key to success
was a flexible execution model that was
tailored to the needs of our customer.

Our alliance approach to contracting for
the SPS-SURF package provided certainty
over reporting and lines of accountability
based on management of interfaces andassociated risks. Delays will be reduced
and gaps avoided through the integrated
contract structure.

We will supply proven equipment including
trees and manifolds that will minimize
required engineering. Our project solution
enables the re-use of existing installation
tools owned by the operator which has
minimized the project's TOTEX.
A Norway-based build solution and an
execution team co-located in Stavanger
will cement existing relationships between
the Baker Hughes consortium alliance andthe client team with whom we are alreadyvery familiar and have a well-establishedand successful working relationship.
Our joint project management team willfurther facilitate close collaboration andprovide ready access for ad-hoc meetings,
project follow-up, witnessing and discussions.

Furthermore, early engagement withthe client ensures that continuity andthe valuable lessons of risk identification,
management and mitigation are not lost
between the FEED, tender and execution
stages of the expansion.
Finally, our “One Team” approach is part ofmaking the client our number one priorityand putting the project first, building on theexisting relationships between all parties andcommitting to an expansion that is deliveredon time, within budget and incident free.
Enabling technology
MVXT to Medium Water Vertical Tree
Multi-Flowbase Template Manifold

We offered the right mix of standardization
and bespoke engineering solutions, thatmaximized value while delivering against
our client’s priorities.

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CASE STUDY

Digital Enablement

HIGH-TEMPEXPERTISEKEEPS THELNG FLOWING
Baker Hughes is providing a
reliable high-temperature
product and delivery solution toa customer in the Asia Pacificregion as part of ongoing efforts
to build one of the world's mostcomplex LNG developments,a mega-project in the Browse
Basin off Australia.

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The Challenge
Our customer has three mega-projects
rolled into one, including the world's largest
offshore facilities located off the north coastof Western Australia, the longest subsea gas
export pipeline in the southern hemisphere,
and onshore LNG processing facilities
near Darwin.
The landmark development's onshore
facilities feature two LNG trains that need
to be constantly fed with gas, as well as
LPG and condensate plants, storage tanks,
utilities and a materials off-loading facility
and jetty.
Moving from Phase 1 into Phase 2a dictatedan economic and technical solution thatwould meet “super-critical” availability anddelivery commitments as initial production
reaches an anticipated plateau. Constraints
in the field off north-west Australia include
high temperatures in a location remote fromexisting service options.
Offshore infrastructure in the basin includes
the world's largest semi-submersible
platform to support hydrocarbon processing
systems, utilities and living quarters. An FPSO
also features for offshore processing.

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The Solution
Our subsea equipment solution for thisdeepwater oil development project reliedon the use of modular product designs thatwere backwards compatible with the existing
infrastructure. The scope of supply included
seven deepwater horizontal trees (three forinjection, four for production), nine subsea
control modules (SCMs), topside and subsea
controls distribution equipment, and verticalconnections systems.
The design incorporated a first-of-its-kind“scale-squeeze” system to treat scalebuild-up in the production lines. A samplingsystem with 3-inch manual valves was also
integrated into the horizontal trees to test
the effectiveness of this innovation.
To address the unique logistical and testing
challenges of the project, Baker Hughes
adopted an integrated approach, withcollaboration from our regional teams basedin Aberdeen and Nailsea in the UK, andSandvika in Norway. Local services based in
Sonils and Cabinda, Angola, led the final
testing and installation, and provided
ongoing support throughout the project,while EPC project management was run outof the UK. Manufacturing also took place inthe UK, as well as in Brazil.
Baker Hughes’ global team coordinatedclosely with all these groups to ensure asmooth operation and the installation of theseven subsea tree systems and tooling was
all achieved within a seven-month period
from December 2014 to July 2015.

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The first-of-its-kind ‘scale-squeeze’ systemtreats scale build-up in the production lines.

The Benefits
Our subsea design delivered significant
TOTEX (CAPEX plus OPEX) savings by enabling
our customer to build on their existing
subsea infrastructure from surrounding fields
and by reducing well intervention costs
through product design innovations. First oilfrom the field was achieved on schedule,with an average production rate of 40,000
barrels of oil (BOE) per day.
The integrated scale-squeeze systemremoved the need for an “injection” choke
insert and eliminated the risk of damage tothe choke’s internal sealing surfaces. It also
added a “piggyback” connection (forcontingency) and is equipped with a hinged
hatch, which protects the connection systemfrom dropped objects. The system enabledconnections to be installed without shutting
down production and minimized the volumeof seawater that had to be removed after
intervention, further reducing nonproductive time.
Integration of the sampling system into thetrees also contributed to cost savings byeliminating the need to install a separate
sampling structure and foundation.
Sampling can now be done at the wellbefore fluid enters the flowline system
without shutting down production.
Information and data from the samples canthen be used to evaluate scale build-up
between squeeze operations andmore accurately calibrate multi-phaseflow measurement.

ENABLINGTECHNOLOGIESDVXT – Our deepwatervertical tree is engineered
for up to 10,000 psi and
10,000 ft (3,048 m) water
depths and enables greaterintervention flexibility,
improving well performanceat lower costs. Each of the
primary tree systemelements areinterchangeable andprovide, where design andpracticality allow, backward
compatibility with theequipment used in theoriginal project. Our
made-to order DVXT
variant can be deliveredin 14 months.

SemStars5™ – SemStars5
is our ultra-reliable
fifth-generation subsea
electronics module for
production control systems
and draws on 40 years ofBaker Hughes’ subsea
experience. The SemStars5’s
Make to Order variants
can be delivered inseven months.

Baker Hughes’ MS-700– The MS-700 can be used
across a wide range ofapplications, including TLP/
spar tieback, subsea
completion and deepwater
drilling. The system comeswith 7 million lbs of total load
capacity, which allows forthree casing strings and up
to 3 million lbs combined
string weight. We can deliver
an MS-700 wellhead system,
supporting multiple casing
configurations from 36
inches through to 7 inches,in around five months.

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Our execution plan in cooperation with
our partners will control installed costs
and minimize operational risks.

The Solution
Baker Hughes designed and is supplying ahighly competitive, optimized subsea
solution that meets the customer's economic
and technical objectives. Equipment includes
support for 10 additional wells based onlarge-bore, high-temperature products from
our Aptara™ range, the only such hardwareon the market. Also included is our flexible
pipe solution.
We built on our extensive Phase 1 knowledgeof the project alongside a regional delivery
model that was very attractive to thedeveloper, including fabrication at
McDermott and proximate service provision.
Baker Hughes further offered an integrated
execution model in partnership with anestablished SURF approach which we believe
results in a commercial structure that is hard
to beat.

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The Benefits
Baker Hughes delivered a fit for purpose
solution for Phase 2a that optimized
economics, assured delivery and availability
and minimized risk. We are further supplying
best in class support services based onin-country infrastructure and extensive
subsea know-how.
Our efforts will provide certainty in missioncritical LNG supply contract commitments
and help to protect and enhance thefinancial and reputational standing of ourclient. Furthermore, our solution approach isdesigned to meet the challenges of a lower
price environment through cost savings.
The combination of Baker Hughes in SPS and
McDermott on SURF provided our customer
with a one-two punch of proven expertiseand collaboration that will help the megaproject hit internal targets and meet external
commitments.
Enabling technology
DWHC MS-700 Wellhead Systems
DVXT Deep Water Vertical XT
Aptara™ HCCS-L Medium Connection System
FLX360 (Mark 1) Connections
SemStar5 Control System
10km of 8" production and 10km of 2.5" gas lift
flexible flowline jumpers including terminations
and bend restrictors
MCS functionality to remove HIPPS
from HMI following decommissioning

165˚C

Temperature of the well fluid as it passes
through the Phase 2a subsea trees.

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Digital Enablement
Enablement
DigitalDIGITALENABLEMENT
Digital has a central
place in the future ofsubsea developments.
We incorporate digitaltechnologies in both
our internal processes
and the solutions wedevelop and deploy
for our customers.

Internally, Digital Enablement manifests
itself in our Brilliant Factory program thatstreamlines our manufacturing andfulfilment process. This has resulted in more
efficient processes and faster fulfilment.
Additionally, we have made major
investments in newer manufacturing
technologies like 3D printing (additive
manufacturing) that allow us to improve thedesign and manufacturing processes andunlock efficiencies that would not havebeen possible with traditional methods.

Digital Enablement is an increasingly
important part of our customer solutions.
These fall into two broad categories:• Field development and optimizationdelivered through development andplanning insights – integrating reservoir
intelligence with well planning, drillinginformation and geo-mechanicalmodelling to ensure optimal reservoir
drainage and field development• Production enhancement and asset
performance management involve an
open, scaleable multi-cloud platform,
with tailored software solutions. We have
solutions that enhance equipment
performance and deliver system healthchecks for field optimization. We use thelatest technology to drive obsolescencemanagement and analysis and prevent
equipment failure through predictive
analytics and failure modelling
Our engageDrilling and engageSubsea
platforms provide real-time remotemonitoring and analytics that drive
equipment uptime and increase
productivity.

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engageSubsea

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Equipment Integrity
Management

150

SPS – NAXYS Acoustic &Electromagnetic Monitoring
Solutions152

Well – SureSENS QPT ELITE
Downhole Gauges

153

Well – SureVIEW Distributed
Temperature Sensing (DTS)
and Distributed Acoustic
Sensing (DAS)

153

Riser SPIRE: Real-Time Sheath
Breach Detection System

154

Riser MAPS: Detection of
Unloaded Tensile Wires in Riser

155

Flow Assurance Management(Flow AM)156

SPS – Virtual Flow Meter (VFM)156

SPS – Distribution Flow
Meter (DFM)

158

Well – Downhole Flow Metering
Solutions (SureFlo™)

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Riser DTS – Distributed
Temperature Sensing

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DIGITAL ENABLEMENT

engageSubsea
engageSubsea is a real-time modular
remote monitoring platform forproactive asset management andinstant troubleshooting which can be
deployed at any stage of field life.
• Reduced downtime, with virtual experts
able to identify and resolve issues fromany location• Instant digital access to documentationand financial statuses, including workorder management• Ability to support comprehensive
monitoring of a facility’s integrityand performance• Trend diagnostics, event prediction
and recommendations for intervention
and maintenance• Live inventory management overview
with tracking of past, present and future
maintenance and recertification events• Proactive obsolescence alerting with
upgrade or last time purchase advice• Advice from flow assurance specialists
on flow regularity and production
optimization50%
reduction in inventory

engageSubsea gives you the ability to
tie together your assets at a global level,significantly reducing regionalized inventory
holding by 50% on a typical five-well field. Itsability to group work orders together can cut
offshore transportation and personnel
requirements by over 60% when supported
by virtual experts.
The modular nature of engageSubsea
means additional digital production
optimization solutions such as subsea
Equipment Integrity Management (Equip IM)
and Flow Assurance Management (Flow AM)
can be integrated to enhance your digitalasset lifecycle management even further.
••••

50% reduction in inventory
Spares optimization
Maintenance management
Real time inventory & workorder management

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DIGITAL ENABLEMENT

engageSubsea includes Equipment
Integrity Management (Equip IM) and
Flow Assurance Management (Flow AM)
to make your operational decision-making
more intelligent and help you optimize
subsea production.
Baker Hughes’ digital solutions combine
advanced hardware, intelligent softwareand trusted services to help you mitigate risk,
improve safety and operate with a reduced
CO2 footprint. A more connected view ofyour operations also improves uptime andefficient operations while reducing cost.
Hardware – Precise sensing andmeasurement technologies deliver critical
data for monitoring, diagnostics andanalytics, providing critical data to support
operations and protect your equipment.
Software – Advanced analytics solutionsdeliver improvements in safety, reliability,and performance of assets throughanalysis of real-time and historical datafrom the subsea production system,
providing system-level insights to
support key operational decisions.
Support – Baker Hughes’ subsea services
are designed to support equipment lifecycle
management and respond swiftly to youroperational needs, including budgeting andplanning of maintenance activities. These
services also connect insights from subsea
analytics with Baker Hughes domain experts
to support equipment troubleshooting andprovide recommendations for performance
optimization.
Lead times on all these solutions dependon the configuration and sensor inputs
you need but can be as low as 4 to
10 months.

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DIGITAL ENABLEMENTEQUIPMENT INTEGRITY MANAGEMENT
Baker Hughes' subsea Equipment Integrity
Management (Equip IM) is a single platform
for proactive monitoring and analysis ofreal-time operations of equipment fromyour well, production system and risers
enabling a range of diagnostics andprognostic capabilities through our powerful
digital analytics engine.
Equip IM delivers an improved understandingof equipment status and remaining usefullife. It enables an intelligent view of subsea
data to support your team in making thebest decisions on when and how to maintainequipment to maximize availability anduptime.
Built on an industry-leading analytics
platform supporting advanced analytics
and artificial intelligence (AI), Equip IM
aggregates subsea data and provides you
with early warnings on maintenance needs,
early system degradation or impending
equipment failure. Smarter maintenanceplanning can be enabled to support life offield by allowing you to set alarms to cover acomprehensive range of configurable
thresholds, rules, and performancedeviations.
Equip IM’s intuitive way of interpretingproduction data from the whole system canresult in smarter decisions in consolidating,deferring or advancing different operations
so that resources are optimized, and the
downtime of unexpected operations is
reduced. Equip IM can help your organization
give you a more intelligent view of theremaining life of components and the overall
health of your system on one asset or aportfolio of assets.
Baker Hughes has more than 30 years’
experience delivering custom Equipment

Integrity Management solutions for subsea– from the well, production system to risers.
Baker Hughes has unrivalled access to thelatest digital analytics and AI technology
through the Baker Hughes Digitalorganization and its various industry
partners, such as c3.ai.
Application Modules
The Equip IM solution builds its intelligencefrom the data of multiple sensors fromproduction system, well and risers. Baker
Hughes customizes sensor solutions andanalytics from configurable modules tomonitor all aspects of your subsea system.
Equip IM leverages sensor inputs and uses
an advanced analytics engine to provides
intuitive and sophisticated data visualizationof all subsea systems independently.
Separate application modules are available
to support detailed analysis of historicalinstrument data, operational trends, andforecasted performance based onreal-time inputs. Monitoring is available
through a single web interface accessible
both, offshore and onshore which tofacilitate collaboration and training ofoperations personnel.

Typical lead time:

5 months

Our subsea Equip IM system is normallydelivered as part of the subsea production
system but can also be supplied as astandalone application within 5 months.

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Equip IM has a number of application modules specifically designed to monitor the following sub-systems intelligently:
Naxys – Acoustic and Electromagnetic Monitoring Solutions
Equip IM Application Modules

Baker Hughes Sensor solutions

Variant

Naxys A5

Naxys A10 & A10E

Controls Equipment Health

Baker Hughes SemStar5 subsea electronics as wellas legacy Baker Hughes subsea electronic
modules–– status and availability of subsea instrumentation and major controls equipment units including Subsea Control Modules (SCMs),
Power Communication and Distribution Modules (PCDMs), and Master Control Station (MCS) among other equipment–– equipment Remaining Useful Life (RUL)–– equipment service history and intervention needs

Electrical Health

Baker Hughes’ Umbilical Monitoring Device (UMD)
and Subsea Line Insulation Monitor (PLIM)–– health of controls electrical system and Subsea Electronic Modules–– health of electrical conductors within the subsea umbilical distribution system, including insulation and capacitance leakage–– trends to enact proactive measures before a complete failure occurs

Communications Health

Baker Hughes Topside and subsea modems,
switches and routers–– status and availability of subsea communications infrastructure–– health of devices, routing, traffic, and applications within the communications network–– network availability and improved understanding of failure conditions and loss of redundancy–– decay or attenuation within communications infrastructure

Hydraulic Health

Baker Hughes Druck and/or Presens–– status and availability of hydraulic control system–– hydraulic fluid usage and calculated leakage–– hydraulic pressures, flows and pump performance–– subsea accumulator performance

Actuator Health (hydraulic)Baker Hughes Druck and/or Presens–– valve operation performance and anomaly detection through analysis of valve profiles–– opening and closing times for each operation, as well as pressure and/or flow transients in supply and return systems–– historical records of valve operations and actuator profiles–– analysis & comparison of multiple valve profiles

SPS Actuator Health (electric)

Baker Hughes IFOKUS electrical actuators–– detailed positioning and operational data

Choke HealthSensor agnostic–– choke position status and actuator operational performance–– flow regime, pressure and/or temperature anomalies and cavitation risks–– variations on choke flow performance indicating potential degradation through erosion

Hydrocarbon leak detection

Baker Hughes Naxys acoustic and electromagnetic
monitoring–– acoustic speed tracking (pump RPM)–– electric VSD frequency monitoring–– slip ratio estimation–– monitoring of harmonics–– resonant frequencies detection–– vibration levels trending–– detection of pump imbalance, electrical ground faults and failure–– pump operation verification and early detection of changes and failures

Well Health

Baker Hughes SureSENS™ QPT ELITE permanent
downhole gauges Baker Hughes SureVIEW™ DTS
and DAS systems–– static and dynamic pressures and temperatures at selected locations within the well–– production performance–– reservoir characteristics and optimal production rates based on dynamic pressure data–– fibre optic data based on distributed acoustic sensing (DAS) and distributed temperature sensing (DTS) to identify contra-flow,
thief zones, and leak detection–– active monitoring of well during start up, production, and shut downs

Risers Health

Baker Hughes SPIRE–– real-time information time and location of outer sheath breach, and location of annular waterBaker Hughes MAPS–– information on unloaded tensile wires

Baker Hughes Riser Distributed Temperature
Sensing (DTS)–– understanding of pipe temperature profile including under ancillary equipment

Various sensors across SPS and well–– erosion rate at choke galleries, pipe bends and fittings–– cumulative erosion effects

Equipment Vibration
Processing equipment Monitoring

Sand Erosion

Data & analytic outputs to determine:

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DIGITAL ENABLEMENTSPS – NAXYS ACOUSTIC & ELECTROMAGNETICMONITORING SOLUTIONS
Baker Hughes' Naxys system uses acoustic
and electric sensor arrays for the nonintrusive monitoring of an entire subsea
installation. Its applications range fromacoustic leak detection to advanced
acoustic and electric monitoring of subsea
machinery and processes.

We are the industry-leader in acoustic andelectromagnetic monitoring technology, withhundreds of installations on more than 30
subsea fields since 2005, with many on the
Norwegian continental shelf. Our technology
enhances your condition-monitoring
capabilities and is critical to detecting leaks
in your system. It also enables you to monitor
your subsea pumps and compressors, aswell as fluid induced vibration, which can bea challenge on long-offset applications dueto the high velocities involved.
With our proven track record and uniquecapability, we can deliver a standalone
Naxys system in around eight months,
though combining the order with other Baker
Hughes subsea production system hardware
is likely to be a cost-effective option. Tighter
integration with our subsea systems
analytics will also provide differentiatedcapabilities for condition monitoring.

Effective leak detection depends on the
differential pressure across leakage, thegas-oil ratio, the distance to leakage, water
depth, obstructions and background noise.
Typical detection thresholds for wide area
coverage in a subsea installation andsurrounding infrastructure (up to 1,640 ft/500m) require a Signal to Noise Ratio greaterthan 6 dB at the sensor location.
Depending on your system architecture, wemight recommend a smaller Naxys A5 unit
be used on each tree or the ‘bird cage’ Naxys
A10 on a central location.
The monitoring system includes acoustic
speed tracking (pump RPM), electric VSD
frequency monitoring, slip ratio estimation,
monitoring of harmonics, resonant
frequencies detection and vibration levels
trending. It also supports your maintenancecycle and ongoing efficient operation byoffering pump imbalance detection, thedetection of electrical ground faults andfailure, pump operation verification andearly detection of changes and failures.

Typical lead time:

10 months

Our Make to Order Naxys acoustic andelectromagnetic monitoring solution canbe delivered in 8 months.

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DIGITAL ENABLEMENTWELL – SURESENS QPT ELITEDOWNHOLE GAUGESOur SureSENS™ QPT ELITE permanent
downhole gauges measure static anddynamic pressures and temperatures atselected locations within the well. They offer
best-in-class capability and represent a
step change in reliability and accuracy. The
gauges have an industry-leading pressure
resolution of 0.0001 psi, enabling moreaccurate reservoir modeling and flow
measurement, and it is possible to install up
to 32 gauges on the same cable.

Baker Hughes is the industry leader in
downhole gauge and monitoring technology
with proven track record dating back to the
1960s and thousands of SureSENS™ gauges
installed in all varieties of applications
globally. They are AWES and IWIS compliant,with fully qualified downhole and subsea
technology.
The static pressure information recorded canbe used to determine production
performance, calculate reserves, andprovide input to reservoir simulations, while
the dynamic pressure data can help
determine reservoir characteristics andoptimize production rates.

WELL – SUREVIEWDISTRIBUTED TEMPERATURESENSING (DTS) AND
DISTRIBUTED ACOUSTICSENSING (DAS)Our SureVIEW™ DTS and DAS systems areboth industry-leading fiber optic systems
comprising interrogators and downhole
technology. Independently tested by amajor IOC, they handle fiber optic wellmonitoring in a reliable, accurate andcost-effective solution that is designed tomeet any well monitoring need by providing
customized, actionable intelligence in avariety of downhole environments.
With hundreds of permanent DTS
installations in high-pressure/hightemperature (HPHT) environments globally,
we have extensive experience with fiber optic
well monitoring and can operate DTS andDAS using the same downhole fiber. Our
marinized subsea DTS interrogator is also
fully qualified to subsea control standards
IWIS and ISO 13628-6.
The systems support the identification ofcontra-flow, thief zones and leak detection,
giving you intelligent control of your reservoir.
They enable injection profiling and waterflood optimization, to help maintain reservoirpressure, and provide gas cap detection, gas
lift monitoring and hydrate monitoring.

Typical lead time:

Typical lead time:

We can deliver a SureSENS™ QPT ELITE
permanent downhole gauge in 5 months.

A Make to Order SureVIEW optical system
can be delivered in 5 months.

5 months

5 months

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DIGITAL ENABLEMENTRISER SPIRE – REAL-TIME
SHEATH BREACH
DETECTION SYSTEMSPIRE is a real-time riser outer sheath breachand flooded anulus detection system.
During pipe manufacture the pipe is SPIRE
enabled by electrically isolating an existing
load carrying tensile wire.
At the client request we can provide andinstall the controller instrument and detector
to monitor for sheath breach. Benefits
include; real-time information time andlocation of breach, and location of annularwater, detection reliability, very small
equipment footprint, deployable as eithera monitoring system or as an inspection
service and has a current tested rangeof 3.64km through a five sectioned pipe
comprising of flowline to riser.

Typical lead time:

5 months(Dependent on pipe lead time)

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DIGITAL ENABLEMENTRISER MAPS – DETECTION
OF UNLOADED TENSILEWIRES IN RISER

Riser MAPS is a powerful, rugged and proventechnology that gives stress data on wires. It
can detect unloaded wires even underancillary equipment (up to end termination
and under bend stiffener) +/-15m reach. It
offers unloaded wire detection resolution toindividual wires with both, inner and outerwires being analysed.
Riser MAPS monitors tensile wire integrity
continuously and provides real-timereadings. It is installed outside the riser’souter sheath. Hence it poses no risk to riser
integrity and can be installed on new risers
or on existing risers in situ.

Typical lead time:

5 months

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DIGITAL ENABLEMENTFLOW ASSURANCE MANAGEMENT (FLOW AM)
Baker Hughes' subsea Flow AssuranceManagement (Flow AM) solution is based ona simpler and lower cost system forenabling production data from each well inthe subsea production system. This systemaggregates data from the entire subsea
production system, including wells andrisers, and provides an accurate view of yourflows and phase fractions throughout the
network to support your operation decisions.
Production engineers who actively monitor
subsea production data for potential flow
assurance risks (such as hydrates, wax anderosion) can benefit from FlowAM’s data
aggregation, visualisation and analytics
insights for the entire subsea production
network through a single intuitive userinterface.
For technical authorities and project leads
recommending flow metering strategies,
Flow AM offers attractive solutions for
production allocation that support small
subsea infrastructures and can achieve youraccuracy requirements with reduced costand lead times.
Baker Hughes' Flow AM solution supports
effective decision making and provides
greater intelligence, accuracy anddescription of subsea flowing conditions by
integration of flow metering solutions fromthe production system, wells and risers
through advanced analytics.

SPS - VIRTUAL FLOWMETER (VFM)

Our Subsea Virtual Flow Meter (VFM) is adigital analytics tool that provides oil, gas
and water flow rate estimation for single
phase or multi-phase production flows, aswell as flow estimation for water-injection,
gas-lift or chemical-injection networks. It
uses robust physics-based flow models,
optimized within a Bayesian probabilistic
framework, to provide clear, accurate andflexible analysis of all flows and individual
instrument measurements.
Working with the latest industry-standard
correlations, our VFM offers true visibility ofyour subsea production system, helping you
to control and maintain a balanced andefficient network. With its high accuracy andthe flexibility to expand, our VFM can be used
to complement your physical multi-phaseflow meters — or to replace them entirely.
We can supply a Make to Order VFM inaround four months, and it uses typicalinstrumentation from the subsea gathering
network, including downhole pressure andtemperature sensors on each tree; wellheadpressure and temperature sensors, for both
upstream and downstream production, and/or gas lift choke valves; pressure andtemperature sensors within the subsea
networks (such as manifold headers); andtopside/arrival pressure, temperature, andflow measurements if available.

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DIGITAL ENABLEMENT

Field-wide models are considered within
the VFM and include wells, chokes,
manifolds, venturis and flowlines. We use
a modular approach to represent yoursubsea production field architecture –interconnecting different component models
and assuming mass continuity of the fluids.
By considering your entire subsea production
system, the VFM employs a data-fusion
approach that also allows ‘gracefuldegradation’ of the estimation accuracy
should one or more sensors be lost.

Typical lead time:

4 months

A Make to Order VFM can be deliveredin around 4 months.

Flow Assurance Management (Flow AM)
Flow AM Application
Modules

Baker Hughes Sensor solutions

Data and analytic outputs to determine:

Flow Meter

Baker Hughes Virtual Flow Meter (VFM)–– oil, gas and water flow rate estimation for all wells–– single-phase flow rate estimation for water and/or gas injection wells, gas lift applications,or chemical injection applications–– flow regime and operating conditions at any point within the production network (including
virtual pressure, temperature and flow estimates)

Baker Hughes Distributed Flow Meter(DFM) – enhanced VFM solution that
includes a water fraction meter andventuri meters for each well–– water properties fluctuations such as salinity–– same as other outputs as the VFM with improved accuracy, particularly on water fraction
detection and quantification;

Well Flow Meter

Baker Hughes Downhole Flow Meters:
SureFLO™ 298
SureFLO™ 298EX–– high accuracy downhole flow measurements of two phases with standard or divergent venturi
deviceRisersBaker Hughes Riser DTS–– understanding of pipe temperature profile including under ancillary equipment during start up,
operational and shutdown conditions

HydrateAnalytics application based on
Baker Hughes Virtual Flow Meter (VFM)
sensors–– hydrate formation conditions in gas, oil, condensates under normal operation, shutdown,
startup–– minimum inhibitor dose required to prevent hydrate formation at a given pressure

Wax

Analytics application based on
Baker Hughes Virtual Flow Meter (VFM)
sensors–– wax formation conditions during production operations using compositional modeling of gas,oil and wax phases; considers oil with suspended wax particles and allows quantitative analysis
of wax precipitation

Sand production

Sensor agnostic (Baker Hughes Sensors
in development)–– sand production rate and at each well

Chemical Injection

Analytics application–– chemical injection flow rate requirements for each well–– Active monitoring of production condition as well as start ups and shut downs

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DIGITAL ENABLEMENTFLOW ASSURANCE MANAGEMENT (FLOW AM)
SPS – DISTRIBUTEDFLOW METER (DFM)

Our Distributed Flow Metering Solution
combines distributed physicalmeasurements and virtual flow metering
technology to handle complex production
applications and enhance accuracy andinsights across the gathering network. It
integrates our subsea Virtual Flow Meter(VFM) with venturi meters and a water
fraction meter at the tree, enablingcomparable multi-phase flow metering
accuracy but with a simplified set up.
The solution relies on Baker Hughes’ provendigital capabilities in software development
and integrated analytics, along with ourstrong knowledge across intelligent subsea
production systems. The concept of ourDistributed Flow Metering Solution wasproven using more than three years’ datafrom a North Sea application. We haveconsiderable experience of delivering therequired instrumentation and system
integration and can activate this innovative
solution within a 12-month lead time.

Our VFM provides a system/network view offlows across your production network andcan even allow automatic reconciliation of
topside measurements if they are available.
It uses typical subsea instrumentation andcan be considered on both, green and brownfields. Complementing this technology withdiscrete instruments for water fraction andsalinity measurement improves accuracy for
detection of water breakthrough.
Bringing this together, the Distributed Flow
Metering Solution enables you to remove
complex subsea flow meters, such as a Wet
Gas Flow Meter (WGFM) or Multi-Phase Flow
Meter (MPFM) and to reduce the weight ofand simplify the tree structure by eliminating
the need for a Flow Control Module.

Typical lead time:

12 months

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WELL - DOWNHOLE FLOWMETERING SOLUTIONS(SUREFLO™)

We introduced the first downhole flow
measurement system in the industry in1993 and have more than 25 years ofexperience using standard downhole
venturi and quartz electronic gauges. As aresult, our SureFLO family of downhole flow
meters have been engineered to measurea wide range of well applications and fluid
properties. They provide a complete suiteof downhole information that comprises
flow rate, surface gas flow rates, water cut,gas breakout indicator and real-timepressure and temperature measurements,
and are available with a lead time ofaround five months.

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Our SureFLO 298EX flowmeter is the industry’s
first full-bore access downhole electronic
flowmeter and incorporates our proprietary,high resolution quartz gauges. With
unrestricted access, it enables full production
and can achieve a high-accuracy
measurement of 98%. The specialized designof the SureFLO 298EX system means you canmeasure flow without having an internal
diameter restriction in the wellbore.
SureFLO downhole flow meters can be usedin both, liquid and gas environments acrossproducer or injector wells. By adding
permanent pressure and a temperaturegauge above or below the SureFLO 298
carrier, a measurement of the produced fluid
fraction can also be made.

Our SureFLO 298 flowmeter can achieve thehigh-accuracy flow measurement of 98%
required for production allocation. The
flowmeter features a customized venturi
design that can handle a variety of
production rates and fluid properties.
Using a wireline retrievable venturi sleeveand high-accuracy quartz gauges, theSureFLO 298 also provides the highest
available measurement accuracy and has
been approved by the Bureau of Ocean
Energy Management, Regulation and
Enforcement (BOEMRE) for well allocation
purposes in the Gulf of Mexico.

Typical lead time:

5 months

A make to order SureFLO 298 or 298EX
can be delivered in 5 months.

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DIGITAL ENABLEMENTRISER DTS – DISTRIBUTEDTEMPERATURE SENSING

Baker Hughes’ Riser Distributed Temperature
Sensing (DTS) systems are industry-leading
fiber optic systems comprising interrogatorsand pipes enabled by embedding opticalfibre technology within the tensile wire layerof the pipe.
This reliable and sturdy technology gives
real time pipe system temperature profilingto indicate flow assurance problems(hydrate formation, waxing) and,
understanding of pipe temperature profile
including under ancillary equipment. It canmonitor pipe during “cool down” periods
and can, in certain circumstances, indicate
system disturbances, buoyancy movement/
bend stiffener damage.

Typical lead time:

5 months(Dependent on pipe lead time)

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SUBSEA
CONNECTSOLUTIONS
Subsea Connect Solutions areoutcome-based solutions that we havecreated to address specific customer needs
and problems. These solutions provide aseamless approach that brings together theentire Baker Hughes portfolio from thereservoir to the top side. This minimizes
interfaces and the associated inefficienciesdelivering real value.
Across Baker Hughes, we work together with our customers on theevaluation, creation, development, and commercialization ofoutcome-based solutions that take advantage of our unique portfoliothat extends from the reservoir to the top side.

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Seamless Tiebacks

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Intervention Solutions

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SUBSEA CONNECT SOLUTIONSSEAMLESSTIEBACKS

Our Seamless Tieback solutions are designed to
improve project economics dramatically by providing
pre-designed, pre-configured and pre-engineered
systems. These solutions cover the full scope fromreservoir engineering, integrated well services, wellconstruction, completions, SPS, SURF and tieback to
an existing host. With a lead time that is slashed by
up to 40% these solutions reduce time to first oil/gas,
reduce payback time and boost returns.

Challenges facing
mature basins
In well-developed basins like the UK’s North
Sea and the Gulf of Mexico in the US, it iscommon to come across prospects or fields
that typically hold less than 50 million barrelsof oil equivalent reserves. These volumes areoften insufficient to justify investment indedicated processing facilities, but favour
instead, solutions that leverage the maturityof the regions, by utilising existing processing
facilities on adjacent developments, withspare capacity.
Whilst this ‘tie-back’ solution is a largely
established model, the economics of suchfields often remain marginal. Operators andinvestors hence continue to challenge theindustry to develop more innovative systems,
that serve to better meet their economic
outcome needs.

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Subsea Connect’s
Seamless Tieback
SolutionsThrough our increasingly early andcollaborative partnerships, Baker Hughes
fully understand the priorities of ourcustomers and their investors in this arena.
We are hence delighted to announce that inapplying our Subsea Connect philosophies
we have now developed off-the-shelf,
system solutions, that requires minimal
bespoke design, benefit from standard,
stocked products and consequently canbe installed in less than a year from order.
These ‘turnkey’ tie back system solutions are
truly unrivalled, providing fast, reliable andsimply, the most economically compellingoutcomes for our customers.
Our systems are 10Kpsi rated and caterto both, medium/shallow water anddeep-water applications. They support
up to 4 wells in each instance, at step out
distances of up to 15km to the host facility.
The functionality of the systems fully caters
to the widest range of operating envelopes,
and has been designed to address thevast majority of all developments inthese environments.

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By featuring a comprehensive array ofmonitoring, control, and chemical injection
capability, we are able to standardise on
many of the traditionally bespoke elements,
limiting the project design effort to simply
configuring the system to the specific fieldlayout requirements
But we don’t stop there: As a true applicationof our Subsea Connect Model, our solution
potentially offers even greater value, bychallenging the traditional boundaries andfully leveraging Baker Hughes’ breadth ofcapability, to provide truly seamless reservoir
to topsides solutions.

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An important element of the Subsea
Connect philosophy is our decision to alignour interest with those of our customers.
To reinforce our commitment to ourpartnerships with customers we offer
outcome-based commercial models –with further options for financing toqualifying candidates.
In summary, our Seamless Tieback Solutions
are game-changing – they are faster, more
economic and more robust than anythingelse on the market today and are fully
underpinned in certainty of outcome,by the four pillars of Subsea Connect.

It is a fact, for instance, that our Integrated
Well Services solutions have a proven trackrecord of slashing drilling and completion
times by up to 50% over conventionalmodels, and so looking to a fully integrated
subsurface – subsea solution is tangible,and can only serve to deliver even greater
value to our customers – across thecomplete scope of the project, not justthe subsea scope!

We go beyond any other solution by fully leveraging
Baker Hughes’ breadth of capability, to provide truly
seamless solution across the complete scope of the
project, not just subsea!

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SUBSEA CONNECT SOLUTIONSINTERVENTIONSOLUTIONSOur Subsea Connect Intervention Solutions
are designed to deliver up to 50% cost out
reduction and 50% increase in productivity byleveraging our best in class technology, talentand project management expertise. We areable to achieve this by integrating individual
products, services and technologies into asingle seamless solution that is focused on
the best possible outcome for our customers.

Baker Hughes can leverage its global
workforce and services bases to mobilize
an LWI solution in about 20% of the time ofa traditional riser.

We harness our 40+ years of product andtechnology leadership in the subsea industry
to design and deliver a differentiated service
offering in subsea well intervention. Baker
Hughes has a strong track record of
supplying riser based intervention systems,
sometimes referred to as Completion Work
Over Risers (CWORs) and Intervention Work
Over Control Systems (IWOCS). The evolution
in technology allows us to package thistraditionally rig based capability intomono-hull Light Well Intervention Solutions
or Services (LWIS). This is a relatively new
addition to the Baker Hughes services
portfolio. In a brief period of time Baker
Hughes has acquired a comprehensive
portfolio of technology and technicalexpertise that translates into around 30%of the overall market capacity. Our value
proposition is simple: ‘Any well, any service
and any commercial model.’Our Subsea Connect Intervention Solutions
are a truly integrated offering that enable
us to deliver unparalleled value to ourcustomers. By bringing along Baker Hughes’
proven track record in adjacent services
such as reservoir, well services, well access,best-in-class service facilities, personnel,
and project management and digital tools,
we deliver a totally different economic return
model to our customers.
First, we pull together the best technology
solutions to connect to the well and workinside the well, supported by a large
multi-disciplined workforce and shop
support infrastructure around the globe.
With a track record of over 100 agonistic

wells (meaning not only Baker Hughes
trees, well heads, completions but those
supplied by other OEMs too) we havecredibly demonstrated our ability to workwith any equipment.
Next, we ensure we have the optimal
partners based on location and application.
Then, we plan the operation/campaign,
ensuring we configure or engineer all
services to provide a seamless “one-stopshop” solution that addresses ourcustomer’s priorities.
Finally, where appropriate, we bring ininnovative commercial models that ensure
full alignment of all concerned parties.
To illustrate the above, if we take for instance,
a well in 3,048 metres (10,000 ft) water
depth, around 100 miles offshore andconsider the planning, mobilisation, transit
and site readiness, Baker Hughes canmobilize a solution in around 20% of the timeof a traditional riser to service. Additionally,
we have a proven track record of safe andfast operations. This productivity saving,along with a large globally mobile work force
deployed through our global infrastructure,ensures we can deliver real and measurable
value to our customers e.g., increased
production, extended life of field, payback
time of cost of operation.
Our focus remains on applying our uniqueportfolio, extending from the reservoir to the
top side, to drive real and measurable value
to our customers – a truly new way of subsea
well interventions.

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SUBSEA 101

Selecting the optimal products for your system needs
is complex. We have frameworks to guide yoursubsea design.
This section describes the rationale behind the effective
selection of a subsea control system.

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Overview

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Critical Factors

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Functional assessments

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Conclusion

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SUBSEA 101
The purpose of this section is tohelp define the rationale behindthe effective selection of subsea
control system architectures andtechnologies. We will consider thevarious options and choices to bemade and then look at how thesecan be applied across a seriesof four scenarios.

Find more Subsea 101
case studies online
Similar papers cover equipment selection
criteria in different geographies, water
depths and customer challenges.
www.bakerhughes.com/subsea-101

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Overview
The effective selection of control systemarchitectures and technologies can havea significant positive bearing on subsea
production system economics, throughreduced subsea hardware and associatedinstallation, maintenance and intervention.
Step-out distances, field-size and phasingof production, data refresh rates, subsea
instrumentation and topside/downhole
interfaces all have an impact on the productand technology choices to be made in thecontrol system. This is overlaid with the needfor high production availability over the life of
the asset, with the provision for cost-efficient
future field-expansion and non-disruptive
obsolescence management of theequipment and electronics.
Good early engagement between an
experienced and capable controls
equipment vendor and the asset operator isimperative in balancing capital outlay for theasset with life-of-field requirements, which
may be as long as 50 years. This needs to beunderpinned with a choice of well-defined,
make-to-order, low cost and cycle products,
the repeatability of which underpins control
system reliability and operational excellence.
Furthermore, experienced control systemvendor capability in power, communications
and, crucially, network analysis will help
to support good decision-making in fielddevelopment – from the initial concept rightthrough to the final field upgrade.
This section considers the technical andcommercial considerations made whenselecting the optimal control system for any
given application and the relative impactsof the above on asset capital outlay andlife-of-field costs, along with production
availability and control system performance.

The critical factors that affect any electrical distribution
network are offset distances and power delivery.

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2. Electrical physical constraints
Subsea control systems are affected bypower losses through the electricaldistribution system and, if copper-based,
the degradation of communication signals
from the topside to the asset. As theumbilical length (offset) increases, themaximum achievable data-rate decreases
for copper-based communications. This isso because the higher frequency-carrier
required for these data-rates is subject
to higher attenuation. This is illustrated in
Figure 2.

High• Cross-talk Cross-talk is the leakage ofcommunications from a first line into asecond line, where it is seen as noise,decreasing the signal to noise ratio (SNR)of the transmission on that line.
Communication cores within an umbilicalare typically twisted-quads, which aredesigned to reduce electrical noise pickup
on the signal wires from cross talk;however, cables are not usually screened
from cross-talk as this leads to higher
attenuation of the communications signal.
The separation and materials between
cores, the capacitance, and the resistiveand inductive load will also impact
communications performance.

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We’ll look at how we leverage these power
and voltage options in the four field scenarios
addressed on the following pages.

Figure 1: Baker Hughes system operating voltages

0k

Subsea Connect
Solutions1. Field power demands
The critical factors in offshore electrical
distribution networks are offset distancesand field power-consumption requirements.
The chart in Figure 1 provides an overview
of Baker Hughes’ system operating voltages,
with respect to system power requirements
and offset distance.

We now consider the five critical factors facing
any operator when it comes to determining
control system architecture and network
topologies. They are namely: field power
demands; electrical physical constraints; data
refresh rates; topside control systems; andsubsea instrumentation interface protocols.

System power requirement (W)Digital Enablement

System offset from host (km)
600V

1kV

2kV

3kV

3kV (LF)

HV-DC

Detailed Specifications
and Data Sheets• Umbilical parameters A reduction in the
cross-sectional area of copper cores
will reduce the umbilical overall cost,
but it will also reduce the communication
throughput and/or communication
distance. Cable parameters can vary
substantially between different umbilicals.
The presence of steel hydraulic tubes andcable screens can increase attenuation of
the signals and affect the communication
distance and data-rates. Umbilicals may
also contain 3-phase High Voltage cables
for subsea pumps, where the higher
harmonic frequencies of the power source
may interfere with the communications
frequencies.
The electrical analysis of the field considers
all these aspects in balancing equipment
cost with field performance (data refresh
rates). We use detailed analysis tools,
developed with modem developers, todetermine suitability of the system and to
define optimum transmit and receive levels.
The analysis establishes that satisfactory
system performance can be achieved
for the worst-case maximum loadconditions assuming worst-case umbilicalcharacteristics. The analysis capability canalso be used for umbilical selection, designand optimization.

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For fibre optics, the analysis simulates andconfirms that for each link to each well there
is an adequate link sensitivity margin whilst
maintaining sufficient link overload margin.
Analysis will also define the requirement
for attenuation to protect the sensitive
fiber optic transceivers.

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The minimum load case confirms thatthe voltages supplied to all the cables,
connectors and subsea equipment do not
exceed maximum limits, by analysing the drill
center with the shortest offset when minimal
equipment is installed and at idle load.

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3. Data refresh rates
We provide a suite of communications
solutions to cover a range of refresh rates
and offset distances, as shown in Figure 3.
This ensures that a suitable communications
medium can be selected for the application,
whether that is communicating to the field,
or communications within the field.

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Detailed Specifications
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We also have experience of providing
fully integrated topside systems. In thisconfiguration, all controls logic (including
shutdowns, interlocks, alarms) is performed by
the DCS. Here, we provide a ‘subsea gateway’that converts topside communication into
proprietary communication protocols for
subsea communication and adds prioritizationand timestamping headers to the messages.

4. Topside control systems
Topside control systems typically fall into
three categories, usually chosen depending
on customer preference/experience and any
topside real-estate constraints. Our mostcommonly requested topside solution andstandard offering is to deliver a standalone
MCS which communicates with and controls
the subsea equipment, and which isconnected to the ICSS/DCS through anagreed interface (typically Modbus TCP/IP,
OPC UA or MDIS).

A third configuration is a standalone MCS
together with an ICSS ‘node’. In thisconfiguration, we are responsible for thedevelopment, testing and integration
between the MCS and the subsea node of
the ICSS. This ICSS node is integrated into theremaining ICSS nodes on the platform using
the ICSS supplier’s proprietary hardware/
software interfaces. The advantage of thisconfiguration is that it reduces integration
testing from the commissioning scope.

Through this interface, the MCS will hand-off
any/all required data to the ICSS/DCS and will
respond to commands from the ICSS/DCS
to control elements of the subsea system.

Figure 3: Baker Hughes communications toolbox

100M

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Baker Hughes has previously integrated
control systems with all major ICSS/DCS
suppliers, including Yokogawa, Kongsberg,
Honeywell, ABB and Siemens.

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5. Subsea instrumentation interface
protocols
In terms of protocol interfaces to subsea
instrumentation and devices, we work to
the following industry standard interfaces
provided by SemStar5.
• SIIS L1 Although used increasingly lessfrequently in greenfield applications,
SIIS (Subsea Instrumentation Interface
Standardization) Level 1 encompasses
4-20mA instrumentation. SemStar5 has
highly accurate, individually calibrated
4-20mA inputs in both 2 and 4 wireconfigurations. Each channel isindividually protected against overcurrent for additional protection
against channel failure.
• SIIS L2 All CANbus SIIS Level 2 devices utilise
the CANOpen protocol in accordancewith CiA 443 profile. To communicate
to the devices from Topside, Baker Hughes
uses a CANopen Gateway which forms
part of the CAN process running on eachSensor Support Module (SSM) or Fieldbus
Support Module (FSM) within the SemStar5.
This gateway conforms to the CiA 309
specification and provides a low-level
access to and control of device to which
the SEM connects. It is primarily provided
for maintenance tasks and provides directaccess to objects in the CANopeninterface of the devices connected.
• SIIS L3 SemStar5 supports multiple SIIS
Level 3 Ethernet interfaces with Low,
Medium and High-Power requirements.
At the ‘physical layer’, the Ethernet links
to the instrument come with a defaultof 100Base-TX Full Duplex.

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Functional Assessments
The following scenarios consider fordifferent, but typical greenfield andbrownfield developments and walk you
through the functional and commercial
assessments that are required to identify
the most appropriate control system.
Scenario 1: Small ‘greenfield’ development,
short-medium offset
The cash-flow constraints and the required
rapid return on investment often associatedwith small greenfield developments,
necessitate minimal capital outlay on
subsea and topside equipment, along withlow operational expenditure.
In these circumstances, decisions relating tocontrols equipment and system architecture
can have a proportionally larger impact
on the financial viability of the investment.
Therefore, control system design for small
field developments is usually focused onminimising the need for subsea controls
equipment and connections.
These smaller fields are typically low or
low-medium well-count assets, at short
offsets from the shore or a platform, often
less than 20Km. This means communications
may be super-imposed onto the umbilicalpower cores, in a Comms-On-Power (COPS)
configuration, thus leveraging existingcopper in the umbilical and keeping
umbilical costs to a minimum.
Furthermore, COPS network is distributed to
the wells over a redundant Multidrop (MD)bussed network. Here, a master modem islocated in the topside controls equipment
and communicates with slave modems, or
network ‘nodes’ in the subsea equipment
at each well. This configuration type isillustrated in Figure 4.

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Baker Hughes has supplied Redundant
Bus communications since 1993. We havestandardized the maximum number ofnodes on the bus to six; this being an
optimum compromise between offset,
number of nodes, and topside data
refresh rates. Most of the cost-efficiency
comes from the minimal use of subsea
electrical wet-mates connectors and theabsence of subsea fiber optic wet-mateconnectors.
Subsea heavy-power consumers arealso kept to a minimum in order to keep
the field voltage down. This helps
minimize the size of the copper-core in
the umbilical, which is another significant
cost-driver. In a Baker Hughes system, no
subsea transformer is required for either
a 600V or 1000V system.
If the initial greenfield project is the firstphase for a larger project and control
system provision is required for future
expansion, then the same costconstraints exist, but we must ensure
a balance is reached between initialcost outlay and future costs. This is
explored further in scenario 3.

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Figure 4: Multi-drop communications

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Scenario 2: Large ‘greenfield’
development, medium-long offset
In larger, longer offset systems, efficient
power management becomes much moreof a focus for the control system design. In
addition to a large well count, these systems
typically have heavy-power consuming
subsea instruments for monitoringand managing flow-assurance overa long-distance.
To mitigate power losses in longer umbilical,
transmission voltage in the topside power
equipment is stepped up, and then steppeddown again in the subsea field to ensure
subsea electrical wet-mate connection costs
are kept to a minimum.
Likewise, fiber optic communications are
the preference for medium to long offset
control systems to mitigate any degradationof communication signals from the topsideto the asset. Fiber optic communications
are converted subsea to copper-based
communications using the Power &Communications Distributions Module(PCDM). This ensures costly subsea fiber
optic wet-mate connectors are minimized
and improves the overall availability of thecontrol system.
The PCDM also routes the communications
subsea. Subsea-routing has become key tomany subsea field developments and Baker
Hughes’ track record in subsea-routing forlong-offset assets has underpinned the next
generation of subsea communications
development through SemStar5. Commonly
known as point-to-point networks,‘Redundant Star’ communications provide
high bandwidth and faster update rates
for complex, high bandwidth-preferred
instruments such as a Multi-Phase Metersand Acoustic Leak Detectors where higher
bandwidth offers a greater level of resolution.
This configuration type is illustrated in
Figure 5.

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In addition to enabling efficient subsea
physical connectivity, the PCDM is a toolin cost-effective and availability-sensitive
network design. In general, the control
system design will seek to minimize subsea
components to simplify subsea data
management over such a large topology,
thus reducing capital outlay and the riskof networks difficulties during operations.

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Scenario 3: Upgrade and expansionof existing control systems
In a severely cost-conscious environment,
phased subsea field-development is highly
desirable. As such, in recent years, Operators
have tended to typically develop a small,
low-capital initial phase of a project, perhaps
2-6 wells in size, before expanding the field
into latter, larger phases.
In this scenario, the SPS Control System must
be architecturally designed for a low-cost
first phase that will facilitate positive cash
flow without obstructing the projecttechnically or commercially in the future.
This differs from the ad-hoc expansion more
often seen in brownfield field expansion.

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Figure 5: Point-to-point communications (only one power/communication channel is shown)

The PCDM contains a Layer 3 managed
switch that converts optical signals tocopper signals for onward transmission toeach of the subsea modules in the star. Layer
3 switches allow finer control in data-routing
through a system. The Layer 3 subsea
network topology is hierarchical and aidsin the separation and prioritization ofsubsea messages with good traceability.
Providing multiple active routes and finer
control, the PCDM can direct packets to theirdestination via a more deterministic routein link failure modes. It can also increase
communications redundancy and availabilityby ‘cross strapping’ between A and B units. In
the event of distribution failure (umbilical or
UTA to PCDM), this enables communications
from the good channel PCDM to be routed
to the failed channel PCDM, and maintains
A and B communications to the units
downstream of the PCDMs.

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The main driver of the total-installed-cost(TIC) of a small first phase is the diameterand type of the composite umbilical. So it
makes sense to keep the umbilical capitaloutlay to a minimum. A second umbilicalmight be laid for later phases, but it’s obviously
preferable to lay only one main dynamic
umbilical for a field, particularly whenrequired for long-offset or in deep water.
Control system expansion
To ensure umbilical costs are kept to aminimum, Operators and Subsea Equipment
Vendors need to collaborate to optimize
the expansion capacity of each elementof the SPS:
• Expandable power systems One way is
to minimize the copper power cores in theumbilical is to utilise any ‘spare’ cores as
the field expands, potentially at the costof system redundancy and reliability(although not necessarily availability). With
the MTBF of our electronic-based subsea
equipment proven to be +150yrs, there’s
a case for dialling down the levels of
redundancy and reversing the aversion
to single-point failure.
If power-switching/power-isolation between
the SCMs is required, it can be done fromswitches in the topside control cabinets
to limited wells for the initial phase, later
replaced and expanded with subsea
switching modules, such as within the
PCDMs; thereby, freeing-up copper coresin the umbilical for power delivery in thelatter phases.
In terms of power capacity, adding subsea
power nodes to an existing umbilical should
not be a problem. It may require a larger UPS
during power expansion, should the topside
capital constraints create limits on the firstphase, and, of course, additional topside
real-estate will need to be planned inadvance for extra MCS/UPS cabinets,
batteries, and other equipment.

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Digital Enablement• Expandable hydraulic services System
hydraulic pressure drop as subsea process
valves are opened is easily manageable
subsea, as our SCMs have in-situ
accumulation, as shown in Figure 6;
so, with each deployed SCM further
accumulation is added to the field.
Where hydraulic pressure drop is a concern,for example when requiring simultaneous
operation of chokes over a large expanded
field, battery-powered electric actuatorssuch as the Ifokus LP-REAs provide ondemand Choke actuation, while drawing
only 1 Amp at 48 W to recharge (after 3 full
Choke cycles) when the demand has passed.
The Hydraulic Power Unit (HPU) might besized for the initial phase, with extra fluid
reservoirs plumbed-in only when neededon latter phases. The pumps may not evenneed to be replaced, providing that a longer
pressurisation period is acceptable forthe field – often a function of equipment
remediation limitations.
Regarding subsea hydraulic distribution, here
the Baker Hughes UMSIRE-compliant
Compact UTA would be sufficient to breakout the umbilical for the first phase. For later
phases, the same UTA can be linked into a
Subsea Distribution Unit (SDU) or landed out
on a larger structure, such as a manifold.
• Expandable subsea communications
networks In a composite umbilical, adding
optical fibre in between the tubing will notincrease the overall composite size; here
we are simply swapping filler material withfibre bundles. It is therefore commercially
feasible to have fiber all the way from thetopside to the SCMs for the first few wells,
thereby initially avoiding the need for
subsea routing.
As the field is expanded and the cost of
proliferating subsea fiber optic wet-mateconnectors becomes prohibitive, the Optical
Flying Leads could be re-routed by ROV to
Baker Hughes PCDMs, which in turn would

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route via SHDSL modem technology to the
new wells. The modular ‘any card, any slot’
capability of SemStar5, means both opticaland DSL modems would be fitted at low costto all SEMs to ensure SCM commonality
across the phases. Any internal SEM routing
between the modems is simply dealt withby the ‘SemStar5 Ethernet Backplane’.

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Figure 6: Baker Hughes Modpod, withstandard in-situ Accumulator

The alternative is simply to use Commson-Power or ‘COPS’ multi-dropped
communications to the SCMs, where thecommunications signal is super-imposedon the umbilical power cores. We would use
modern Quadrature Amplitude Modulation(QAM) techniques to maximize the offset andbandwidth to the subsea nodes.
• Expandable software Our SCADA systems
are based on drag-and-drop, pre-tested
GE Cimplicity software. This makes adding
wells to a first phase an iterative task withsimple regression testing. The HMI canalso be readily expanded, again throughdrag-and-drop icons and software.
Our standard approach of using unlimited
Layer 3 routed networks for subsea
communications means system nodes(SEM cards, subsea routers, instruments,etc.) can be infinitely added without anyof the risks associated with large unwieldly
Layer 2 routed networks. We also use
dynamic networks as standard, essentially‘plug-and-play’ network expansion, rather
than using static networks, which would
require a network specialist offshore toreconfigure the IP-networks as the field
is expanded.
In summary: through cost-focused control
system design, experienced analysis,
excellent network practices, and modular
expandable system components, there is
no reason that the first phase of a fielddevelopment should carry any of the burden
or cost of future field expansion.

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Control System Upgrades
When considering the life-of-field costs ofany control system it is essential to plan for
the inevitable obsolescence of the subsea
and topsides hardware; in particular,
the control system electronics. Proactive
obsolescence management will help toensure that topside and subsea equipment
can be upgraded with minimal disruption
to ongoing production operations.

Scenario 4: Tiebacks into a non-Baker
Hughes system
Many fields are limited by their original
expansion case, where perhaps
latter extensions and tiebacks were
unanticipated. The challenge for these
unanticipated phases is how to expand
the field beyond original expectations
with minimum capital outlay and little
or no disruption to ongoing production.

The evolution of subsea electronics over the
past 30 or more years shows the scale ofobsolescence management required tokeep fields producing and the importanceof backwards compatibility. The SemStar5
is backwards compatible with all prior SEM
variants and Figure 7 shows three options for
upgrading an existing Baker Hughes control
system, where technology and backwards
compatibility can be used to minimize
expense and disruption.

The optimum solution often means utilisingexisting asset infrastructure, such as thetopsides and subsea equipment and often
the same umbilical. However, the OriginalEquipment Manufacturer (OEM) for the earlyphases may well have used proprietary
protocols for communication to the subsea
hardware, making this challenge particularly
difficult; there is no ‘plug & play’ option here.

Option 1 is the most disruptive and costly,
but cleanest upgrade, solving obsolescence
subsea and topside simply by swappingout both subsea and topside equipment.
In Option 2, only the subsea equipment is
upgraded, including the SCM. In Option 3,
just the SEM is upgraded in a refurbishedlegacy SCM.
Options 2 and 3 are often deployed in aphased implementation, eventually
upgrading all the subsea SCMs and SEMs.
For both these options ‘SEMulation’ is utilized,
where the new SemStar5s emulate thelegacy SEMs they replace, using existing
protocols to talk with the MCS. This means theoperator will see no change from the MCS,
despite having mitigated obsolescence inthe subsea equipment.

This is where Baker Hughes technology suchas ‘concurrent’ or ‘dual-band’ communications
may help, to add non-OEM topsides andsubsea equipment, without the need forthe capital and installation costs of a new
field umbilical. In this scenario the original
field umbilical is utilised to host the new
equipment power and communications forthe field expansion, without disrupting powerand communications to the OEM equipment.
Optimal use is made of any existing umbilicalcores. If any spare cores in the umbilicals
are used to host the new power andcommunications, which is known as‘concurrent communications’, there islittle risk of affecting the existing system.
If umbilical cores are shared between the
new and old equipment, by transmitting at
sufficiently separate frequencies, in what is
known as ‘dual-band communications’, thencommunications filtration will be required toensure communication frequencies do not
overlap and cause disruption.

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The decision tree, shown in Figure 8, shows
how the level of risk of disrupting the existing
system increases as more sharing of coresis required within the umbilical. This is
mitigated by increased levels of topsideand subsea communications filtration,
as seen in the decision tree.

Figure 7: Options for upgrading obsolete Topsideand Subsea Electronics

1 Full control system
Exisiting
MCS
LegacySCM

2 Control upgrade subsea

New MCS
ModPod SCM

SemStar5

Once we have carefully analysed theexisting frequencies on the umbilical, we
use a multi-band, Quadrature Amplitude
Modulation (QAM) modem in theseapplications to provide a specificcommunications frequency. Done correctly,
this can save $millions in expanding
existing assets.

Existing MCS
ModPod SCM

SemStar5

LegacySEM

3 Control refurb subsea

LegacySCM

In conclusion
At Baker Hughes, a combination of early andongoing engagement; experienced systems
engineering capability; and products
designed for low TOTEX and high availability
ensures that our Subsea Control Systems arecommercially and technically optimized
throughout the life of the asset.

Existing MCS
SemStar5‘SEMulation’Figure 8: Concurrent and Dual-bandcommunications decision tree

Analysis only

4 Coresavailable

COPS on spares
Active pairis power only

2 Coresavailable
Active pairis COPS

Umbilical

COPS

No sparecores in Quad
CAPS

Concurrent COPS
on spares

Concurrent CAPS
(comms blocking filter)

Dual-band comms(tailored comms filter +comms blocking filter)
Use legacy power as
COPS (subsea comms
blocking filter)
CAPS (tailored comms
filter + subsea comms
blocking filter)

Increasing risk to legacy system

Spare coresin QuadDetailed Specifications
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400

More than 400 Baker Hughes Subsea
Electronic Modules (SEMs) in active
production were deployed pre-2000.
Total Baker Hughes SEMs deployed by
2020 will by 1500+.

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Detailed Specifications
Specifications
and Data Sheets

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DETAILED
SPECIFICATIONSAND DATA SHEETS
We have re-engineered our portfolio to develop structured
products that fall into three categories:

Make to Order (fully engineered to meet typical requirements
resulting in faster lead times and lower costs)
Configure to Order (configured using standard components
and sub-assemblies requiring minimal additional
engineering hours)
Engineer to Order (engineered solutions to addressapplications that fall outside our regular boundaries
and options)

Detailed Specifications
Specifications
and Data Sheets

183

Subsea Wellheads

184

Subsea Trees

186

SubseaControl Systems

202

Subsea Manifolds
and Pipeline Products

212

Subsea Connection Systems

223

Subsea Well Access Systems

226

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Detailed Specifications
and Data Sheets

Subsea Systems

Subsea Wellheads
With half a century offield-proven experienceand more than 5,000
wellhead installations
worldwide, our subsea
systems set the industry
standard.

MS-700MS-800

Aptara™ SFX Wellhead
Solution

FeatureMake to Order

Make to Order

Make to Order

Variant

2 Options

2 Options

3 Options

Structural
Mandrel size (inches)27

27 / 30

27 / 30

Bending capacity (lbs-ft)

5.25 mm5.25 / 7 mm

5.25 / 7 mm

Casing program (inches)

36 x 28 x 20 x 16 x 13 x 936 x 28 x 22 x 18 x 16 x 14 / 13 x 10⁄936 x 28 x 22 x 18 x 16 x 14 / 13 x 10⁄9

Casing load (lbs)

7 mm

8 mm

8 mm

Hanger positions

3

3

3

20,000 above; 7,500 below

20,000 above; 7,500 below

20,000 above; 7,500 below

Pressure, temperature and lockdown
Pressure rating (psi)Temperature

35°F to 350°F (2° C to 177° C)

35°F to 350°F (2° C to 177° C)

35°F to 350°F (2° C to 177° C)

Lockdown per seal (kips)

750

750

750

Fatigue
Fatigue loading

NormalNormalExtremeMaterials

8630 HP / 4130 LP

8630 HP / 4130 LP

F22 and A707
DNV C curve tested welds
DNV C curve tested connector

Below mudline hangers (maximum)

52

Subsea Wellheads

54

Aptara™ SFX
Wellhead Solution

55

MS-80056MS-70057

Ulti-Max GT

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Options

16-inch 5,000 psi @ 725 kips

18-inch 5,000 psi @ 500 kips

18-inch 5,000 psi @ 500 kips

16-inch 10,000 psi @ 2,000 kips

16-inch 10,000 psi @ 2,000 kips
Available in MS-700 variant

184

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185

Subsea Systems

Ulti-Max GT
FeatureSubsea Wellheads
With half a century offield-proven experienceand more than 5,000
wellhead installations
worldwide, our subsea
systems set the industry
standard.

Make to Order

Diameter x wall thickness (inches)

20 x 0.438

20 x 0.500

20 x 0.625

20 x 0.812C

22 x 0.750

22 x 0.812

22 x 0.875

22 x 1.000

22 x 1.500

Connector material (ksi)

70

80

70

80

70

80

80

95

70

80

70

80

70

80

70

80

70

80

Compatible pipe grades

X56,
X65,
X70

X80

X56,
X65,
X70

X80

X56,
X65,
X70

X80

X56,
X60

X65,
X70

X56,
X65,
X70

X80

X56,
X65,
X70

X80

X56,
X65,
X70

X80

X56,
X65,
X70

X80

X56,
X65,
X70

X80

Tension (kip)A

1,884

2,153

2,144

2,450 2,663 3,043

2,937

3,426 3,505 4,006 3,784

4,324 4,065 4,646

4,618

5,278

6,762

7,728

Compression (kip)B

1,884

2,153

2,144

2,450 2,663 3,043

2,937

3,426 3,505 4,006 3,784

4,324 4,065 4,646

4,618

5,278

6,762

7,728

Bending (kip-ft)A

752

859

850

971

1,128

1,316

1,715

1,611

1,841

1,967

1,933

2,209

2,706

3,092

Internal pressure (psi)A

3,062 3,500 3,494 3,994 4,364 4,988 4,852 5,660 4,759 5,439

5,149

5,885 5,546 6,338

6,330

7,235

9,433 10,780

Collapse pressure (pis)A-520

Anti-rotation capacity (ft-lbs)D

49,500 56,500 49,500 56,500 49,500 56,500 56,500 62,500 55,000 62,500 55,000 62,500 55,000 62,500 55,000 62,500-520

Max. OD/Min. ID (in)

-770

1,042

-770

1,191

1,501

1,721

-1,520 -1,520 -2,590 -2,820 -1,920 -1,980 -2,310 -2,430 -2,700 -2,880 -3,690 -3,870 -8,520 -9,460

21.88/18.62

21.88/18.25

TBD

24.182/19.88

TBD

Pin/Box length (in)9.32/9.24

12.19/12.19

TBD

Make-up loss (in)

6.86

8.66

TBD

Weight (lb)

291

477

TBD

A Capacity values are calculated at yield per API 5C3
B Compression capacities are calculated at buckling
C For this size only, the connector yield strength is higher than the pipe to meet pipe capacity (a design that meets pipe capacity withsame yield strength is currently in development)
D Assumes 3 anti-rotation keys installed
52

Subsea Wellheads

54

Aptara™ SFX
Wellhead Solution

55

MS-80056MS-70057

Ulti-Max GT

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

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Subsea Systems

Aptara™ Lightweight Compact Tree

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52
58
60

Make to Order
Option 1

Option 2

Option 3

Option 4

Option 5

Configure to Order

Production bore size (inches)

51⁄8

51⁄8

51⁄8

71⁄16

71⁄16

Annulus bore size (inches)

21⁄16

21⁄16

21⁄16

21⁄16

21⁄16

Pressure rating (psi)10,00010,00010,00010,00010,000

ISO 10423 PSL

PSL 3GPSL 3GPSL 3GPSL 3GPSL 3G

Temperature rating (storage)

0ºF to 122ºF(-18°C to 50°C)

0ºF to 122ºF(-18°C to 50°C)

0ºF to 122ºF(-18°C to 50°C)

0ºF to 122ºF(-18°C to 50°C)

0ºF to 122ºF(-18°C to 50°C)

Temperature rating(operating)

0°F to 300°F
0°F to 300°F
0°F to 250°F(-18°C to 149°C) (-18°C to 149°C) (-18°C to 121°C)

Temperature rating
downstream choke-50°F to 300°F -50°F to 300°F -50°F to 250°F -50°F to 300°F -50°F to 250°F -51°F to 300°F(-46°C to 149°C) (-46°C to 149°C) (-46°C to 121°C) (-46°C to 149°C) (-46°C to 121°C) (-46°C to 149°C)

Depth capability

Up to 10,000 ft(3,048 m)

Up to 10,000 ft(3,048 m)

Up to 10,000 ft(3,048 m)

Up to 7,217 ft(2,200 m)

Up to 7,217 ft(2,200 m)

6,561 ft
(2,000 m)

FAT

API 17D

API 17D

API 17D

API 17D

API 17D

S561

Trim level

HH x EE

HH x EE

HH x EE

HH x EE

HH x EE

Insulation

No

No

No

No

No

Tubing head spool

Yes

Yes

No

Yes

No

15,0000°F to 300°F
0°F to 250°F(-18°C to 149°C) (-18°C to 121°C)

Yes

Tubing hanger size (inches)

135⁄8

183⁄4

183⁄4

183⁄4

183⁄4

Electrical downhole functions

2

2

2

2

2

Subsea Wellheads

Hydraulic downhole functions

7

9

7

9

7

Subsea Trees

Production isolation valve

No

No

No

No

No

Yes / ManualGas lift

No

No

No

No

No

Yes

Production choke
configuration

Fixed – Cap
Retrievable

Fixed – Cap
Retrievable

Fixed – Cap
Retrievable

Fixed – Cap
Retrievable

Fixed – Cap
Retrievable

Chemical metering

Yes

Yes

Yes

Yes

Yes

Tubing hanger

5-inch nom

5-inch nom

5-inch nom

7-inch nom

7-inch nom

Tubing thread

51⁄2-inch –27# Vam Top

51⁄2-inch –27# Vam Top

51⁄2-inch –27# Vam Top

71⁄16-inch –32# Vam Top

71⁄16-inch –32# Vam Top

Hydraulic working pressure – LP (psi)

5,000

5,000

5,000

5,000

5,000

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

FeatureVariant

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

1 off DHPT canbe swapped for
Optical Feed
Thru System.

-

X-Over pup

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Subsea Systems

Aptara™ Lightweight Compact Tree (continued)

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

Option 1

Option 2

Option 3

Option 4

Option 5

Configure to Order

Hydraulic working pressure – HP (psi)10,00010,00010,00010,00010,000Top connection

720 HD HUB

720 HD HUB

720 HD HUB

720 HD HUB

720 HD HUB

Bottom connection(XT & THS)HT-H4
connector

HT-H4
connector

HT-H4
connector

HT-H4
connector

HT-H4
connector

Controls provider

Baker Hughes

Baker Hughes

Baker Hughes

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Baker Hughes

Baker Hughes

Baker Hughes

Flowline connection system

Horizontal

Horizontal

Horizontal

Horizontal

Horizontal

DWHT-H4
Connector

Vertical

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Subsea Systems

D – Series Summary
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

5" DHXT
Structured Product Boundaries

7" DHXT
Structured Product Boundaries

DVXT
Structured Product Boundaries

FeatureMake to Order

Make to Order

Make to Order

Variant

Multiple

2 options

3 Options

Prod. Bore Size (inches)

51⁄8

71⁄16

51⁄8 / 71⁄16

Ann. Bore Size (inches)

21⁄16

21⁄16

21⁄16

Configure to Order

Pressure rating

10,000psi

15,000psi

10,000psi

PSL3

PSL3G

PSL3

Temperature Rating (Storage)

0°F to 122°F(-18°C to 50°C)

Temperature Rating (Operating)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

0°F to 300°F(-18°C to 149°C)

0°F to 335°F(-18°C to 168°C) for 7

Temperature Rating
Downstream Choke-51°F to 250°F(-46°C to 121°C)

0°F to 300°F(-18°C to 149°C)-51°F to 250°F(-46°C to 121°C)-51°F to 300°F(-46°C to 149°C)-31°F to 300°F(-35°C to 149°C)-51°F to 335°F(-46°C to 168°C) for 7

Insulation

Optional

Optional

No

Yes

No

Yes

Depth Capability

6,561ft (2,000m)

10,000ft (3,048m)

10,000ft (3,048m)

10,000ft (3,048m)

4,921ft (1,500m)

10,000ft (3,048m)

FAT

IOGP S561

API 17D

API17DIOGP S561

API17DIOGP S561

Trim level

HH x EE

HH x EE

Flow Control Module

Optional

Yes

Tubing Head Spool

N/A

N/A

Electrical downhole functions

2

Up to 2

1

Up to 8No

Up to 2

1

Up to 2

4

Up to 81, 3, 7Up to 9Yes

Optional

Yes

Subsea Trees

Chemical metering

Optional

No

Electrical Submersible Pumps

No

No

66

HH x EE

No

58

64

PSL3G

Yes

8

D-Series for Deep
Water Depths

PSL3
0°F to 122°F(-18°C to 50°C)

Yes

Hydraulic/Chemical downhole functions

62

10,000psi
PSL3G0°°F to 122°F(-18°C to 50°C)

Subsea Wellheads

Aptara™ Lightweight
Compact Tree

Configure to Order

API PSL

52

60

Configure to OrderNo

No

Gas Lift System

Optional

No

Sand Detector

Optional

Yes

No

Optional

Yes

M-Series for Medium
Water Depths

Choke type

Production

Production

Production

S-Series for Shallow
Water Depths

Production,
InjectionA

Production,
InjectionA

Prod Choke CV

Cv185 / Cv250

Cv400

Cv750

Cv205 or Cv750

Cv250

Prod Choke Configuration

ROV Insert retrievable
or FCM retrievable

FCM Retrievable

ROV insert
retrievable

ROV Insert
retrievable or
FCM Retrievable

FCM Retrievable

Flowmeter

None

None

WGFM, MPFM, SPFM

None

WGFM, MPFM, SPFM

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

InjectionA

WGFM, MPFM, SPFM

No

Yes

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189

Subsea Systems

D – Series Summary (continued)

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

5" DHXT
Structured Product Boundaries

7" DHXT
Structured Product Boundaries

DVXT
Structured Product Boundaries

Make to Order

Make to Order

FeatureMake to Order

Variant

Multiple

2 options

3 Options

Wellhead Connector
Secondary Lock

Yes

Yes

Yes

Wellhead Connector
secondary Unlock

Yes

Yes

Yes

Drill Through capability

Optional

Optional

N/A

5 Nom or 7 Nom with
5 outlet

7 Nom (6-1⁄4 outlet)

5 or 7

Tubing Hanger (inches)

Configure to Order

Configure to Order

Working Pressure - LP

5,000psi

5,000psi

5,000psi

Working Pressure - HP

10,000psi

10,000psi

10,000psi

Top Connection (inches)

183⁄4, 10k, H4,
Extended Mandrel

183⁄4, 10k, H4,
Extended Mandrel

183⁄4, 10k, H4,
Extended Mandrel

Bottom connection

DWHT-H4 connector

DWHT-H4 connector

DWHT-H4 connector

Wellhead Size (inches)

36

36

36

Configure to Order

N/A

Controls type

Electro-hydraulicElectro-hydraulicElectro-hydraulicControls provider

Baker Hughes

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Baker Hughes

Baker Hughes

Flowline connection system

Vertical /Horizontal

Vertical or
Horizontal

Horizontal,
Mono / Dual /Multi - bore

Horizontal,
Mono / Dual

Horizontal,
Multi-bore

Horizontal,
Mono / Dual /Multi - bore

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Subsea Systems

DVXT Structured Product Boundaries
FeatureSubsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

Make to Order

Configure to Order

Variant

Option 1

Option 2

Option 3

Production bore size (inches)

51⁄8

71⁄16

71⁄16

Annulus bore size (inches)

21⁄16

21⁄16

21⁄16

Pressure rating (psi)10,00010,00010,000

ISO 10423 PSL

PSL 3GPSL 3GPSL 3G

Temperature rating (storage)

0°F to 122°F(-18°C to 50°C)

0°F to 122°F(-18°C to 50°C)

0°F to 122°F(-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F(-18°C to 121°C)

0°F to 335°F(-18°C to 168°C)

0°F to 335°F(-18°C to 168°C)

Temperature rating downstream choke-51°F to 250°F(-46°C to 121°C)-31°F to 300°F(-35°C to 149°C)-31°F to 300°F(-35°C to 149°C)

PSL 3-50°F to 300°F(-46°C to 149°C)

Insulation

No

No

No

Yes

Depth capability

6,561 ft (2,000 m)

4,921 ft (1,500 m)

4,921 ft (1,500 m)

10,000 ft (3,048 m)
S561

FAT

API17D

API17D

API17D

Trim level

HH x EE

HH x EE

HH x EE

Flow Control Module

Yes

Yes

Yes

No

Tubing head spool

Yes

Yes

Yes

No

Electrical downhole functions

1

1

1

2

Hydraulic/chemical downhole functions

7

1

3

9

Chemical metering

No

Yes

Yes

Yes

ESP

No

No

No

Gas lift

No

No

No

Yes

Sand detector (non intrusive) downstream of choke

No

Yes

Yes

Yes

Choke type

ProductionA

ProductionA

ProductionA

Production choke CV

CV205

CV750

CV750

CV250

Production choke configuration

ROV insert retrievable

Fixed on FCM

Fixed on FCM

FCM retrievable

Wellhead connector secondary unlock

Yes

Yes

Yes

Wellhead connector secondary lock

Yes

Yes

Yes

Hyd, working pressure / hydraulic working pressure – LP (psi)

5,000

5,000

5,000

Hyd, working pressure / hydraulic working pressure – HP (psi)10,00010,00010,000Top connection

183⁄4-inch / 10k / H4 /extended mandrel

183⁄4-inch / 10k / H4 /extended mandrel

183⁄4-inch / 10k / H4 /extended mandrel

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

Bottom connection

DWHT-H4 connector

DWHT-H4 connector

DWHT-H4 connector

98

Subsea Connection Systems

Controls provider

Baker Hughes

Baker Hughes

Baker Hughes

110

Subsea Well
Access Systems

Flowline connection system

Vertical / monobore

Horizontal / multibore

Horizontal / multibore

A

Injection Make to Order trees available

Horizontal / concentric /dual / multi

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Detailed Specifications
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Subsea Systems

7-inch Production DHXT Structured Product Boundaries
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

Option 1

Option 2

Configure to Order

Prod. Bore Size (inches)

71/16

71/16

Ann. Bore Size (inches)

21/16

21/16

Pressure rating (psi)10,00010,000API PSL

PSL3G

PSL3G

PSL3

Temperature Rating (Operating)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

0°F to 300°F (-18°C to 149°C)

Temperature Rating Downstream Choke -51°F to 250°F (-46°C to 121°C)-20°F to 250°F (-29°C to 121°C)-51°F to 300°F (-46°C to 149°C)

Insulation

No

No

Yes

Depth Capability

10,000ft (3,048m)

10,000ft (3,048m)

FAT

API17D

API17D

Trim level

HH x EE

HH x EE

IOGP S561

Flow Control Module

Yes

Yes

No

Electrical downhole functions

1

1

Up to 2

Hydraulic/ Chemical downhole functions 4

4

Up to 8Chemical metering

Yes

Yes

No

Gas Lift System

No

No

Sand Detector

Yes

Yes

No

Choke Type

Production

Production

Injection A

Prod Choke CV

Cv400

Cv400

Cv750

Prod Choke Configuration

FCM Retrievable

FCM Retrievable

ROV insert retrievable

Flowmeter

None

WGFM

WGFM, MPFM, SPFM

Wellhead Connector Secondary lock

Yes

Yes

Wellhead Connector Secondary Unlock

Yes

Yes

Drill Through capability

Optional

Yes

Tubing Hanger (inches)

7 Nom (6-1/4 outlet)

5 Nom

Tubing Hanger Sealing

Metal to Metal

Metal to Metal

Working Pressure - LP

5,000psi

5,000psi
10,000psi

Working Pressure - HP

10,000psi

Top Connection (inches)

18-3/4, 10k, H4, Extended Mandrel

18-3/4 10k, H4, Extended Mandrel

Bottom Connection

DWHT-H4 connector

DWHT-H4 connector

Wellhead Size (inches)

36

36

Controls TypeElectro-hydraulicElectro-hydraulicControls provider

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Flowline connection system

Horizontal, Multi-bore

Horizontal, Mono-bore

Horizontal, Dual-bore

191

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Subsea Systems

5-inch DHXT Structured Product Boundaries
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52
58
60

Subsea Wellheads
Subsea Trees
Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order Production Trees

Variant

Maximum functionality

Configure to Order

Prod. Bore Size (inches)

51/8

Ann. Bore Size (inches)

21/16

Pressure rating (psi)10,00015,000API PSL

PSL 3

PSL3G

Temperature Rating(Storage)

0°F to 122°F (-18°C to 50°C)

Temperature Rating (Operating)

0°F to 250°F (-18°C to 121°C)

0°F to 300°F (-18°C to 149°C)

Temperature Rating Downstream
Choke-51°F to 250°F (-46°C to 121°C)-51°F to 300°F (-18°C to 149°C)

Insulation

No

Yes

Depth Capability

Up to 6,561ft (2,000m)

10,000ft (3,048m)

FAT

IOGP S561

API 17D

Trim level

HH x EE

Flow Control Module

Optional

Electrical downhole functions

2

Less than 2

Hydraulic/ Chemical downholefunctions8Less than 8

Chemical metering

Optional

Electrical Submersible Pumps

No

Gas Lift System

Optional

Sand Detector

Optional

Choke Type

Production

Injection A

Prod Choke CV

Cv185

Cv250

Prod Choke Configuration

ROV Insert retrievable or FCM
retrievable

Flowmeter

None

WGFM, MPFM, SPFM

Wellhead Connector Secondary lock Yes
Wellhead Connector Secondary
UnlockYes

Drill Through capability

Optional

Tubing Hanger (inches)

5 Nom or
7 Nom with 5 outlet

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Subsea Systems

5-inch DHXT Structured Product Boundaries(continued)
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order Production Trees

Variant

Tubing Hanger Sealing

Metal to Metal

Working Pressure - LP (psi)

5,000Working Pressure - HP (psi)10,000Top Connection (inches)

183/4, 10k, H4, Extended Mandrel

Bottom Connection

DWHT-H4 connector

Wellhead Size (inches)

36

Controls

Baker Hughes

Choke provider

Baker Hughes

Flowline connection system

Vertical/ Horizontal
Mono-bore/ Dual-bore

Configure to Order

Detailed Specifications
and Data Sheets

193

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194

Subsea Systems

M – SERIES SUMMARY

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMHXT Structured Product Boundaries

MVXT Structured Product Boundaries

Make to Order

Make to Order

Configure to Order

Configure to Order

Variant

2 Options

2 Options

Production bore size (inches)

51⁄8

51⁄8

Annulus bore size (inches)

21⁄16

21⁄16

Pressure rating (psi)10,00010,000Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

0°F to 250°F(-18°C to 121°C)

0°F to 300°F(-18°C to 149°C)

Temperature rating downstream choke

0°F to 250°F(-18°C to 121°C)-50°F to 300°F(-46°C to 149°C)

0°F to 250°F(-18°C to 121°C)-50°F to 300°F(-46°C to 149°C)

Insulation

No

Yes

No

Yes

Depth capability

820 ft (250 m) Diver

2,460 ft (750 m) ROV

820 ft (250 m) Diver

2,460 ft (750 m) ROV

FATAPI17DS561

API 17D

S561

Trim level

HH x EE

Flow Control Module

N/A

Tubing head spool

N/A

No

Electrical downhole functions

1

1

Hydraulic/chemical downhole functions

5

5

Chemical metering

No

Electrical submersible pumps

OptionalNo

Gas lift

Optional

Yes

Sand detector

No

Yes

No

Choke type

ProductionA / Gas lift

ProductionA

ProductionA

Production choke CV

CV185 / CV65

CV250

CV185

Production choke configuration

ROV release

Fishing protection

Yes

None

Yes

None

Wellhead connector secondary lock

Yes

Yes

Yes

Yes

Wellhead connector secondary unlock

Yes

Drill through capability

No

Yes

Tubing hanger

5-inch nominal

7-inch nominal 5-inch outlet 5-inch / 7-inch

71⁄16

0°F to 122°F (-18°C to 50°C)

HH x EE
Yes

Yes

N/A

No

Yes

Yes

CV250

ROV insert

Yes
N/A

N/A

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195

Subsea Systems

M – SERIES SUMMARY (CONTINUED)

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

MHXT Structured Product Boundaries

MVXT Structured Product Boundaries

FeatureMake to Order

Make to Order

Variant

2 OptionsHydraulic working pressure – HP (psi)10,000

Hydraulic working pressure – LP (psi)3,000

Top connection (inches)

183⁄4 / 10k / H4

Bottom connection

HT-H4 connector

Wellhead size (inches)

30

Controls type

Electro-HydraulicElectro-HydraulicControls provider

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Fishing protection

Fisher friendly

None

None

NORSOK

Guidance

No

Flowbase

Flowbase

Guide base

Electrical Submersible Pump (ESP)

Yes

No

Yes

Flowline connection system

Diver flange

Diver flange

Horizontal / template

A

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Injection Make to Order trees available

Configure to Order

Configure to Order

2 Options

10,0005,000

5,000 (CTO)
183⁄4 10k H4 mandrel
MD H-4 connector

36

30

36

Baker Hughes

Remote horizontal /template

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196

Subsea Systems

MHXT Structured Product Boundaries
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order Production Trees

Variant

Option 1

Option 2

Configure to Order

Production bore size (inches)

51⁄8

51⁄8

Annulus bore size (inches)

21⁄16

21⁄16

Pressure rating (psi)10,00010,000

ISO 10423 PSL

PSL 3

PSL3G

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

0°F to 300°F (-18°C to 149°C)

Temperature rating downstream choke

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)-50°F to 300°F (-46°C to 149°C)

Insulation

No

No

Yes

Depth capability

820 ft (250 m) Diver

820 ft (250 m) Diver

2,460 ft (750 m) Diver

FAT

API17D

API17D

S561

Trim level

HH x EE

HH x EE

Electrical downhole functions

2

2

Hydraulic/chemical downhole functions

5

5

Chemical metering

No

No

Electrical submersible pumps

No

Yes

Gas lift

Yes

No

Choke type

ProductionA

ProductionA

Gas lift

Prod choke CV

CV185

CV185

CV250

7 (71⁄16 only)

Yes

Production choke configuration

ROV Insert Retrievable

ROV Insert Retrievable

Diver release

Fishing protection

No

FriendlyNORSOK

Wellhead connector secondary lock

Yes

No

Yes

Wellhead connector secondary unlock

Yes

Yes

Drill through capability

No

No

Yes

Tubing hanger

5-inch nominal

5-inch nominal

7-inch nominal 5-inch outlet
5,000

Hydraulic working pressure – LP (psi)

3,000

3,000

Hydraulic working pressure – HP (psi)10,00010,000Top connection (inches)

183⁄4 / 10k / H4

183⁄4 / 10k / H4

183⁄4 / 10k / H4 mandrel
DWHT-H4

Bottom connection

MD HT-H4 connector

HT-H4 connector

Wellhead size (inches)

30

36

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and Data Sheets

Subsea Systems

MHXT Structured Product Boundaries (continued)

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order Production Trees

Variant

Option 1

Configure to Order
Option 2

Controls provider

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Well type

Satellite

Satellite

Template

Flowline connection system

Diver Flange

Diver Flange

Remote Horizontal

A

Injection Make to Order trees available

Direct/3rd party

197

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198

Subsea Systems

S – SERIES SUMMARY
Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

SHXT Structured Product Boundaries

SVXT Structured Product Boundaries

FeatureMake to Order

Make to Order

Variant

2 Options

2 Options

Production bore size (inches)

51⁄8

5

Annulus bore size (inches)

21⁄16

21⁄16

Pressure rating (psi)

5,000

6,500

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

Temperature rating downstream choke

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

Insulation

None

None

Depth capability

262 ft (80 m)

328 ft (100 m)

Configure to Order

S561

API17D

Configure to Order

FAT

API17D

Trim level

HH x EE

S561

Flow control module

N/A

N/A

N/A

N/A

N/A

N/A

N/A

HH x EE

Tubing head spool

N/A

Electrical downhole functions

1

1

Hydraulic/chemical downhole functions

5

2

Chemical metering

No

Electrical submersible pumps

No

No

No

Gas lift

No

Yes

Optional

Sand detector

No

No

Choke type

ProductionA

ProductionA

Production choke CV

CV185

CV185

Production choke configuration

ROV insert retrievable

Fishing protection

No

Tubing hanger (inches)

5 nom

5 nom

Hydraulic working pressure – LP (psi)

3,000

3,000

Hydraulic working pressure – HP (psi)

7,500

7,500

Top connection (inches)

135⁄8 Hub

135⁄8 Hub

Bottom connection (inches)

135⁄8 CH-8

135⁄8 CH-8

No
No

CV250

Diver insert retrievable
Yes

No

Yes

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Detailed Specifications
and Data Sheets

199

Subsea Systems

S – SERIES SUMMARY (CONTINUED)

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

SHXT Structured Product Boundaries

SVXT Structured Product Boundaries

FeatureMake to Order

Make to Order

Variant

2 Options

Wellhead size (inches)

135⁄8Controls type

Electro-hydraulicControls provider

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Flowline connection system

Diver

Diver

A

Injection Make to Order trees available

Configure to Order

Configure to Order

2 Options135⁄8
Direct hydraulicElectro-hydraulic

Direct hydraulicThe Future of
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Subsea Systems

SVXT Structured Product Boundaries

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

Option 1

Option 2

Configure to Order

Production bore size (inches)55Annulus bore size (inches)

21⁄16

21⁄16

Pressure rating (psi)

6,500

6,500

ISO 10423 PSL

330°F to 122°F (-18°C to 50°C)

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

Temperature rating downstream choke-50°F to 250°F (-46°C to 121°C)-50°F to 250°F (-46°C to 121°C)

Insulation

No

No

Depth capability

328 ft (100 m)

328 ft (100 m)

FAT

API17D

API17D

Trim level

HH x EE

HH x EE

Electrical downhole functions

1-off

1-off

Hydraulic/chemical downhole functions

2-off

2-off

Gas liftNo

Yes

Choke type

ProductionA

ProductionA

Production choke CV

CV185

CV185

Production choke configuration

Diver insert retrievable

Diver insert retrievable

Fishing friendly protection

Yes

Yes

Hydraulic working pressure – LP (psi)

3,000

3,000

Hydraulic working pressure – HP (psi)

7,500

7,500

Top connection (inches)

135⁄8 Hub

135⁄8 Hub

Bottom connection (inches)

135⁄8 CH-8

135⁄8 CH-8

Wellhead size (inches)

135⁄8

135⁄8

Controls type

Electro-hydraulicElectro-hydraulicControls provider

Baker Hughes

Baker Hughes

Choke provider

Baker Hughes

Baker Hughes

Flowline connection system

Diver Flange

Diver Flange

A

Injection Make to Order trees available

3G

S561

Direct Hydraulic200

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Subsea Systems

SHXT Structured Product Boundaries

Subsea Trees
Baker Hughes completed its
first subsea tree systeminstallation in 1962. Since
then, we have installed
more than 1,400 subsea
trees worldwide and areat the forefront of oil andgas field developments.

52

Subsea Wellheads

58

Subsea Trees

60

Aptara™ Lightweight
Compact Tree62

D-Series for Deep
Water Depths

64

M-Series for Medium
Water Depths

66

S-Series for Shallow
Water Depths

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

Option 1

Option 2

Configure to Order

Production bore size (inches)

51⁄8

51⁄8

Annulus bore size (inches)

21⁄16

21⁄16

Pressure rating (psi)

5,000

5,000

ISO 10423 PSL

33Temperature rating (storage)

0°F to 122F (-18°C to 50°C)

0°F to 122F (-18°C to 50°C)

Temperature rating (operating)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)
0°F to 250°F (-18°C to 121°C)

Temperature rating downstream choke

0°F to 250°F (-18°C to 121°C)

Insulation

None

None

Depth capability

328 ft (100 m)

328 ft (100 m)

FAT

API17D

API17D

Trim level

HH x EE

HH x EE

Electrical downhole functions

1-off

1-off

Hydraulic / chemical downhole functions

1-off

1-off

Gas liftNo

Yes

Choke type

ProductionA

ProductionA

Production choke CV

CV185

CV185

Production choke configuration

Diver insert retrievable

Diver insert retrievable

Fishing friendly protection

N/A

N/A
5

Tubing hanger (inches)

5

Hydraulic working pressure – LP (psi)

3,000

3,000

Hydraulic working pressure – HP (psi)

7,500

7,500

Top connection (inches)

135⁄8 Hub

135⁄8 Hub

Bottom connection (inches)

135⁄8 CH-4

135⁄8 CH-4

Wellhead size (inches)

135⁄8

135⁄8

Controls type

Direct Hydraulic

Direct Hydraulic

Choke provider

Baker Hughes

Baker Hughes

Flowline connection system

Diver Flange

Diver Flange

A

Injection Make to Order trees available

3G

S561

5

Yes

Electro-Hydraulic201

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Subsea Systems

Subsea Electronics Module – SemStar5

Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Make to Order

Make to Order

Variant

1 Option
Low Power

1 Option
Medium Power

1 OptionHigh PowerPower consumption< 150 W

< 200 W

< 300 W

Operating environment

23°F to 284°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

23°F to 284°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

23°F to 284°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

DHPTG interface

Baker Hughes / Schulmberger / Well
Dynamics

Baker Hughes / Schulmberger / Well
Dynamics

Baker Hughes / Schulmberger / Well
Dynamics

Communications type

Standard: 2-wire CAPS DSLOptions: 5-wire Standard: 2-wire CAPS DSLOptions: 5-wire Standard: 2-wire CAPS DSLOptions: 5-wire
CAPS Ethernet, 2-wire COPS APCMCAPS Ethernet, 2-wire COPS APCMCAPS Ethernet, 2-wire COPS APCM

DCV Drives (M = momentary /C = continuous)

Up to 28 (M)Up to 26 (M)Up to 2 (M / C)

Up to 24 (M)Up to 4 (M / C)

SIIS L1 interfaces

Up to 4 off 2-wire

Up to 2 off 4-wire
Up to 2 off 2-wire

Up to 2 off 4-wire
Up to 2 off 2-wire

SIIS L2 interfaces

2 off

5 off

8 off

SIIS L3 interfaces

1 off

2 off

3 off

SCM flowmeters

4 off

5 off

5 off

SEM pressure vessel

Bucketless (sea water wetted)

Bucketless (sea water wetted)

Bucketless (sea water wetted)

Dimensions – dia x L/mm

275 x 912

275 x 912

275 x 1,155

Weight/max< 286 lbs (130 kg)<309 lbs (140 kg)<341 lbs (155 kg)

202

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Subsea Systems

ModPod – Subsea Control Module (SCM)
Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77
82

Hydraulic Power
Generation
Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Configure to Order

Configure to Order

Configure to Order

Variant

Option 1

Option 2

Option 3

Option 4

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

Depth capability

6,561 ft (2,000 m)

9,842 ft (3,000 m)

Size – W x D x H (mm)770 x 770 x 1,550

Weight in air

4,409 lbs (2,000 kg)

Weight in water

3,527 lbs (1,600 kg)

Testing

Std Testing (Std FAT/
Hyperbaric and SRT)

Quality requirements

Baker Hughes VGS applied

Client specs

Lockdown interface

Podlock

Podlock

Podlock

Podlock

Material restrictions

PMI to VGS

Podlock-201 podlock-201 podlock

-210

-210

Enclosed

4 piece skirt

Open

Project pressure units

Bar

Cleanliness requirement

SAE AS 4059 Class 6B-F

SAE AS 4059 Class 6B-F

SAE AS 4059 Class 6B-F

SAE AS 4059 Class 6B-F

System fluid: non-environmental(Grade A – D)

Castrol Transaqua HT2

Oceanic HW443

Oceanic HW540

Oceanic HW540P

System fluid: environmental (Grade E)

Oceanic HW540E

Test fluid

Castrol Transaqua HT2

Oceanic HW443

Hunting T-O series coupler

Delrin poppet seal

Peek poppet seal

DCV version

Mark 2.0

Mark 2.1

DCV type

Bi-stable

Mono-stable

Supply arrangement

Dual hydraulic supplies

Flow meters

No flow meters

4-20mA flow meters

CANbus flow meters

Number of hydraulic functions

Up to 18

Up to 42

Up to 42

Up to 42

Supply accumulators

2 LP bladder type

1 LP and 1 HP bladder type

2 LP piston type

1 LP and 1 HP piston typePressure transducers

Single element type

Dual element type

HP SCSSV return vent arrangement

Vents directly to sea

Vents via the SCMMB

IWC return vent arrangement

Vents directly to sea

Vents via the SCMMB

Return line override connections

None

Return line override
connections

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205

Subsea Systems

ModPod – Subsea Control Module (SCM) (continued)

Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Configure to Order

Configure to Order

Configure to Order

Variant

Option 1

Option 2

Option 3

Option 4Function line flow controllers (FLFCs)

None

Fit to each LP function
line as required

Flow restrictors

None

Fit to each function line
as required

LP working pressure (psi)5,000

Up to 5,000

Up to 5,000

Up to 5,000

HP working pressure (psi)10,000Up to 10,000

Up to 10,000

Up to 10,000

SCM base connector manufacturer

Siemens Tronic

Teledyne ODI

SCM base connector quantity

Up to 6

Number of ways

4

7

SCM cover connector manufacturer

Siemens Tronic

Teledyne ODI

SCM cover connector quantity

Up to 6 (overall)

Number of ways

4

7

Number of SEMs

2

1

Installation tooling

RCR tool

Warning and instruction language
requirements

EnglishDocumentation

Generic Baker Hughes
documents anddrawings

SCM markings

Front indication only / single
color RAL 2004

TRS requirements

UK and EU only

12

12

Project specific format
and content

Australian

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Subsea Systems

Subsea Communications and Routing – Power Communications Distribution Module

Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Make to Order

Make to Order

Variant

2 Options
6 Slot Manifold

2 Options
8 Slot Manifold

2 Options
10 Slot Manifold

Power consumption
including SIIS 2 Power< 250 W

< 250 W

< 500 W
300 V – 600 V

Input supply

Number of output channels

300 V – 600 V

300 V – 600 V

500 V – 1,000 V

500 V – 1,000 V

Up to 6 SHDSL / Ethernet + 1 Ethernet

Up to 6 SHDSL / Ethernet + 2 Ethernet

Up to 11 SHDSL / Ethernet

Power switching

Optional

Optional

Optional

Weight/max< 2,860 lbs (1,300 kg)<3,080 lbs (1,400 kg)<3,410 lbs (1,550 kg)

SIIS2 + power1 x 30 W

1 x 20 W

2 x 30 W

FeatureOptions

Options

Options

Communications range

Optical to 74 mi (120 km)

SHDSL Steel Tube 15 km

SHDSL Thermoplastic

Operating environment

23°F to 104°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

23°F to 104°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

23°F to 104°F (-5°C to 40°C)
at 9,842 ft (3,000 m) water depth

Input communications

SHDSL / Optical

SHDSL / Optical

SHDSL / Optical

Output to infield units

CAPS Ethernet / SHDSL+ 300 to 600VAC

CAPS Ethernet / SHDSL+ 300 to 600VAC

CAPS Ethernet / SHDSL+ 300 to 600VAC

Ethernet range

<70 m

<70 m

<70 m

SHDSL range

Up to 9 mi (15 km) Steel Tubed
Up to 9 mi (15 km) Steel Tubed
Up to 9 mi (15 km) Steel Tubed
Umbilical / 19 mi (30 km) Thermoplastic* Umbilical / 19 mi (30 km) Thermoplastic* Umbilical / 19 mi (30 km) Thermoplastic*

SHDSL bandwidth

To 192 kbps up to 5.7 Mbps

To 192 kbps up to 5.7 Mbps

To 192 kbps up to 5.7 Mbps

Dimensions – W x D x H (mm)770 x 770 x 1,841

770 x 770 x 1,841

770 x 770 x 1,841* Depending on umbilical properties

206

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Subsea Systems

Subsea Distribution System – Subsea Power Distribution and Management – Subsea Transformer Module

Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

FeatureMake to Order

Variant

1 Option

Primary: single phase multip-tap
winding rating

20 kVA 50 / 60 Hz 1kV / 1.7 kV & 3 kV

Primary: 3 phase winding rating

Configure to Order

Configure to Order

30 kVA 50 / 60 Hz 1.7 kV

30 kVA 50 / 60 Hz 3 kV

Secondary: single phase windings
No & Rating

6 off 6 kVA 600 V

6 off 6 kVA 600 V

6 off 6 kVA 600 V

HV input power connector

3 / 4 way male tronic / ODI

3 / 4 way male tronic / ODI

3 / 4 way male tronic / ODI

LV output power connector

12 way female tronic / ODI

12 way female tronic / ODI

12 way female tronic / ODI

CP connector

7 way female tronic / ODI

7 way female tronic / ODI

7 way female tronic / ODI

Water ingress monitor

Yes

Yes

Yes

Galvanic insulation between
windings (IR)>1G ohm>1G ohm>1G ohm

Depth rating

9,842 ft (3,000 m)

9,842 ft (3,000 m)

9,842 ft (3,000 m)

Temperature rating

Op 23°F to 104°F (-5°C to 40°C)
Store 0°F to 122°F (-18°C to 50°C)

Op 23°F to 104°F (-5°C to 40°C)
Store 0°F to 122°F (-18°C to 50°C)

Op 23°F to 104°F (-5°C to 40°C)
Store 0°F to 122°F (-18°C to 50°C)

Color

Orange (RAL2004)

Orange (RAL2004)

Orange (RAL2004)

Dimensions (h x w x d) (mm)1,550 x 770 x 770

1,550 x 770 x 770

1,550 x 770 x 770

52

Subsea Wellheads

Lifting mandrel

ISO13628-8 Type A

ISO13628-8 Type A

ISO13628-8 Type A

58

Subsea Trees

Mass/max

4,400 lbs (2,000 kg)

4,400 lbs (2,000 kg)

4,400 lbs (2,000 kg)

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

207

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208

Subsea Systems

Hydraulic Power Generation – Hydraulic Power Unit – HPU
Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

FeatureMake to Order

Make to Order

Make to Order

Variant

1 Option

1 Option

1 Option

Region

North Sea

Asia Pacific

Africa / N. America

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

23°F to 104°F (-5°C to 40°C)

Depth capability

Topside on shore only

Topside on shore only

Topside on shore only

Size W x D x H (mm)Up to 9,000 x 3,000 x 3,300

Up to 9,000 x 3,000 x 3,300

Up to 9,000 x 3,000 x 3,300

Weight in air

Up to 55,115 lbs (25,000 kg)
Dry weight		

Up to 55,115 lbs (25,000 kg)
Dry weight		

Up to 55,115 lbs (25,000 kg)
Dry weight		

Weight in water

N/A

N/A

N/A

Std testing

Std testing

Std testing

Std + 3rd party witness

Quality requirements

Std ITPStd ITPStd ITP

Customer ITP + 3rd party
inspection

Structural skid design

Base Skid / Frame
Construction Structure iaw
DNV 2.7-3 Slings iaw DNV 2.7-1

Base Skid / Frame
Construction Structure iaw
DNV 2.7-3 Slings iaw DNV 2.7-1

Skid material

Coated Carbon Steel

316L Stainless Steel

316L Stainless Steel

Hazardous area rating

Zone 1

Zone 1

Zone 1Subsea Wellheads

Ingress protection

IP 66 / pump motors to be IP 56 IP 66 / pump motors to be IP 56 IP 66 / pump motors to be IP 56

58

Subsea Trees

Noise level<90 dB at 1 m<90 dB at 1 m<90 dB at 1 m

Protection

N/A

N/A

N/A

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Field Driven

Testing

52

68

Configure to Order

Material restrictions

No PMINo PMINo PMIPMIWorking pressures (psi)

LP: 5,000 / HP: 10,000

LP: 5,000 / HP: 10,000

LP: 5,000 / HP: 10,000

Field Driven

Cleanliness requirement

SAE AS 4059E Class 6 (B-F)

SAE AS 4059E Class 6 (B-F)

SAE AS 4059E Class 6 (B-F)

Tubing material

AISI 316-316L

AISI 316-316L

AISI 316-316L

Reservoirs

Separate supply andreturn reservoirs
manufactured as one unit

Separate supply andreturn reservoirs
manufactured as one unit

Separate supply andreturn reservoirs
manufactured as one unit

Level monitoring

Sight level gauges c/w
isolation valves, integral
check valves and drain
connection. Remote: Leveltransmitters, removable
without draining, ESD outputs,

Sight level gauges c/w
isolation valves, integral
check valves and drain
connection. Remote: Leveltransmitters, removable
without draining, ESD outputs,

Sight level gauges c/w
isolation valves, integral
check valves and drain
connection. Remote: Leveltransmitters, removable
without draining, ESD outputs,

Accumulation

Bladder and piston (up to 54 L) Bladder and piston (up to 54 L) Bladder and piston (up to 54 L)

Pumps

2off LP / 2off HP /1off Re-circulating

2off LP / 2off HP /1off Re-circulating

2off LP / 2off HP /1off Re-circulating
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209

Subsea Systems

Hydraulic Power Generation – Hydraulic Power Unit – HPU (continued)

Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

70

SemStar5 Subsea
Electronic Module

71

ModPod74

Subsea Communications
and Routing

78

Subsea Distribution
System (SDU/UTA/UTH)

77

Hydraulic Power
Generation

82

Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Make to Order

Make to Order

Variant

1 Option

1 Option

1 Option

Region

North Sea

Asia Pacific

Africa / N. America

Instrumentation (local gauges)

All externally mounted
including: Individual pump
outputs, Common pump
output headers, Output
headers, ESD outputs, Fluidside of accumulators,
Accumulator pre charge

All externally mounted
including: Individual pump
outputs, Common pump
output headers, Output
headers, ESD outputs, Fluidside of accumulators,
Accumulator pre charge

All externally mounted
including: Individual pump
outputs, Common pump
output headers, Output
headers, ESD outputs, Fluidside of accumulators,
Accumulator pre charge

Instrumentation (remote)4-20 mA Pressure transmitters 4-20 mA Pressure transmitters 4-20 mA Pressure transmitters
includingincludingincludingHydraulic output

4 x LP A / 4 x LP B / 4 x HP A /4 x HP B

4 x LP A / 4 x LP B / 4 x HP A /4 x HP B

Configure to Order

Field Driven

4 x LP A / 4 x LP B / 4 x HP A /4 x HP B

Hydraulic system

Open Loop (ESD vent to tank)Open Loop (ESD vent to tank)Open Loop (ESD vent to tank)

Local control panel

Yes

No

No

LP tubing size (inches)

1⁄2

1⁄2

1⁄2

HP tubing size (inches)

3⁄8

3⁄8

3⁄8

LP fittings

LP: NPT

LP: NPT / Gyrolok

LP: NPT / Gyrolok

HP fittings

HP: Cone and threaded

HP: Cone and threaded

HP: Cone and threaded

Closed loop

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Subsea Systems

Aptara™ FLX360 Multi-Quick Connection System
Subsea Control
Systems
All of Baker Hughes’ control
system equipment isdesigned for reliability, fromour uniquely-latched FLX360
hydraulic Stabplates, to ourultra-reliable electronics
module, the SemStar5.

FeatureMake to Order

Variant

1 Option

Configure to Order

Configure to Order

Temperature rating (storage)

0°F to 122°F (-18°C to 50°C)

Temperature rating (operating)

23°F to 104°F (-5°C to 40°C)

Depth capability

9,842 ft (3,000 m)

Size – W x D x H (mm)600 x 600 x 400 (fixed plate)
451 x 395 x 520 (flying plate)

Weight in air

Fixed plate: 308 lbs (140 kg)
Flying plate: 220 lbs (100 kg)

Weight in water

Fixed plate: 243 lbs (110 kg)
Flying plate: 174 lbs (79 kg)

Testing

Std Testing

Std + SRT

Std + 3rd party witness

Quality requirements

Standard ITP

Customer ITP

Customer ITP + 3rd party inspection

Acid injection system

Included

Anode material

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

Material restrictions

No PMI

Positive Material Identification (PMI)

Tubing material

316L / 3.1 certification level

Inconel 625 / SuperDuplex / 6Mo

Inconel 625 / SuperDuplex / 6Mo

Project pressure units

Bar

Cleanliness requirement

SAE AS 4059 Class 6B-F

Coupler size

Up to : 12 x 1⁄2-inch

Inconel 625 / SuperDuplex / 6Mo

Inconel 625 / SuperDuplex / 6Mo

Up to : 4 x 1-inch
Number of lines

Up to 16

Pressure rating

Up to 690 bar in all lines
Up to 1-inch OD

70

SemStar5 Subsea
Electronic Module

71

ModPodTubing size

74

Subsea Communications
and Routing

Tube tail type

316L / 3.1 certification level

Tooling

FLX360 Tool

Linear offset

100 mm – all directions

Angular misalignment±25 degrees

Rotational misalignment±20 degrees

Mate and de-mate timing<3 minutes

Documentation

Std Doc Pack

Tooling markings

Locked / unlocked indication

Third party design DVR

Not supplied

78
77
82

Subsea Distribution
System (SDU/UTA/UTH)
Hydraulic Power
Generation
Aptara™ FLX360
Multi-Quick Connection
System84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Third party option

210

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Subsea Systems

Aptara™ Modular Compact Manifold
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

FeatureMake to Order

Variant

2 Options

Connector orientation

Horizontal

Configure to Order

VerticalNumber of slots

6

4

Number of headers

Option 1: 6-slot Dual production

Option 1: 4-slot Dual production

Option 2: 6-slot Dual production w/ Gas lift

Option 2: 4-slot Dual production w/ Gas lift

Distribution

Standalone SDU

Co-located on Foundation

PiggingRound trip with external pigging loop

External PLR (ROV or remotely operated ROPL)

Standards

ISO 10423, ISO 13628, (API spec. 6A, 17D & RP 17P, 17R) ISO
19900 & 19902

RP 17P, 17R) ISO 19900 & 19902

ASME B31.8, ASME B31.3 & DNV RP-F112
TRL rating

7 for core components

Pressure rating (psi)10,000psi branch valve block
5,000psi Manifold

Temperature rating-20°F to 250°F (-29°C to 121°C)

Water depth rating

6,561 ft (2,000 m)

Design life (years)

25

10,000psi branch valve block
10,000psi Manifold

Up to 50

Prod. header size / NPS (inches)10

12

Prod. branch size / NPS (inches)6-

Gas lift / MEG header / NPS (inches)64

Gas lift / MEG branch / NPS (inches)

2

Material class

Production: Block - LAS fully clad HH / Piping - Super
Duplex Gas lift: Super Duplex

Production: Block - LAS fully clad HH / Piping - Cladcarbon steel Gas lift: Super Duplex

52

Subsea Wellheads

58

Subsea Trees

Dropped object

5kJ point load (Ø100mm)

68

SubseaControl Systems

Barrier philosophy

Dual isolation for prod.
Single isolation for gas lift

Single isolation for prod.
Single isolation for gas lift

84

Subsea Manifolds andPipeline Products

Dual bore concentric

86
88

Aptara™ Modular
Compact Manifold
Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Bore configuration

Single bore

Piggable ID variation

Within ±5%

Levelling±3° passive

Foundation type

MudmatSuction anchor

Wet-parking of well Jumpers and flowlines

Provided on foundation mounted landing beam (toallow manifold module retrieval independently offoundation)

None

Cross over between headers

Not included

included with ROV or Hyd valve

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Subsea Systems

Aptara™ Modular Compact Manifold (continued)
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Configure to Order

Variant

3 Options

Piggable bend radius

5D

Landing speed (m/s)

0.5

Lifting

4-point lifting with slings

Insulation

If required, high performance thermal insulation
systems

Jumper type

Flexibles

RigidsConnection system

HCCS-L

VCCS

Caps

Low-pressure/deployment caps

High-pressure caps

Stab plates

FLX360

Header valve

Ball valve, ROV (Fail As-is), Upstream side

Hydraulic fail safe close (FSC), Upstream side

Branch valve

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

CIMVs

Not included

1-off on each header

Hyd. compensation

Closed loop

Subsea Control Module (Retrievable)

1x dedicated SCM

PT sensor

2x (one off on each header)Acoustic sand detector

2x (one off on each header non-intrusive clamp on)

Pig detector

1x (on pigging loop non-intrusive clamp on)

2x (one off on each header non-intrusive clamp on)

Retrievable control units

None

PCDM's or EDU's co-located on foundation

2x dedicated SCM or XT controlled

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Subsea Systems

Deepwater Vertical Cluster Manifold – DVCM
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68
84

FeatureMake to Order

Variant

2 Options

Connector orientation

VerticalConfigure to Order

Number of slots

4

6

Number of headers

Option 1: Dual production
Option 2: Dual production with gas-lift

Single / dual prod. + MEG / gas lift

Distribution

Standalone SDU

Integrated SDU

PiggingRound trip with external pigging loop

External PLR (ROV or remotely operated ROPL)

Standards

ISO 10423 / ISO 13628 / (API spec. 6A / 17D and RP 17P /17R) ISO 19900 and 19902

ISO 10423 / ISO 13628 / (API spec. 6A / 17D and RP 17P /17R) ISO 19900 and 19902

ASME B31.8 / ASME B31.3 and DNV RP-F112
TRL rating

7

Pressure rating (psi)

5,000

7,500 to 10,000

Temperature rating-20°F to 250°F (-29°C to 121°C)

291°F (144°C)

Water depth rating

6,561 ft (2,000 m)

9,842 ft (3,000 m)

Design life (years)

25

Up to 50

Prod. header size, NPS (inches)10

8 / 12 / 14

Prod. branch size, NPS (inches)68

Gas lift or MEG header, NPS (inches)46

Gas lift or MEG branch, NPS (inches)

2

Material classFF

HH / EE

Dropped object

5 kJ point load (Ø100 mm)

Up to 20 kJ

Barrier philosophy

Dual isolation for prod.

CustomSubseaControl Systems

Bore configuration

Single bore

Dual bore concentric (for GL / MEG)

Piggable ID variation

Within ±5%

Within ±5%

Subsea Manifolds andPipeline Products

Levelling±3° passive (with center column)

Active with ROV hyd. jacks

Foundation type

Single anchor suction pile

Skirted mudmat

Wet-parking

Not included

Separate skids

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Flowmeter

Not included

Provided through each branch, outlet to main header

Piggable bend radius

3D

5D

Landing speed (m/s)

0.5

Lifting

4-point lifting with slings

Lifting frame

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Detailed Specifications
and Data Sheets

Subsea Systems

Deepwater Vertical Cluster Manifold – DVCM (continued)
FeatureMake to Order

Subsea Manifolds
and Pipeline Products

Variant

2 Options

Insulation

If applicable, high performance thermal insulation
system can be provided

If applicable, high performance thermal insulation
system can be provided

Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

Jumper type

Rigid

Flexibles with gooseneck

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Configure to Order

Connection system

VCCS 300 and 450

450 dual bore concentric

Caps

Low-pressure / deployment caps

High-pressure caps

Stab plates

FLX360

Header valve

Ball valve / ROVHydraulic fail safe open (FSO)

Branch valve

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

CIMVs

Not included

Optional

Hyd. compensation

Closed loop & locally on each actuator

Common sea-chest with accumulators

Control system

1x SCM

2x SCM

PT sensor

2x (one off on each header)As required

Acoustic sand detector

2x (one off on each header non-intrusive clamp on)

As required

Pig detector

2x (one off on each header non-intrusive clamp on)

As required

Retrievable control units

Not included

2x retrievable PCDMs / EDUs

215

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Subsea Systems

Deepwater Horizontal Cluster Manifold – DHCM
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

FeatureMake to Order

Variant

2 Options

Connector orientation

Horizontal

Number of slots

4&6

8

Option 1: Dual production with gas-lift (oil)
Option 2: Dual production with MEG (gas)Single prod. + MEG / gas lift + service

Distribution

Integrated SDU

Standalone SDU

PiggingRound trip with external pigging loop

External PLR (ROV or remotely operated ROPL)

Standards

ISO 10423 / ISO 13628 / (API spec. 6A / 17D and RP 17P /17R) ISO 19900 and 19902

ISO 10423 / ISO 13628 / (API spec. 6A / 17D and RP 17P /17R) ISO 19900 and 19902

ASME B31.8 / ASME B31.3 and DNV RP-F112

ASME B31.8 / ASME B31.3 and DNV RP-F112

TRL rating

7

7

Pressure rating (psi)

5,000

7,500 to 10,000

Temperature rating-20°F to 250°F (-29°C to 121°C)

291°F (144°C)

Water depth rating

6,561 ft (2,000 m)

9,842 ft (3,000 m)

Design life (years)

25

Up to 50

Prod. header size, NPS (inches)

10 (oil) / 16 (gas)12 / 14 / 18

Prod. branch size, NPS (inches)

6 (oil) / 8 (gas)Multibore
4/6

Gas lift or MEG branch, NPS (inches)

Subsea Wellheads

58

Subsea Trees

68

Horizontal

Number of headers

Gas lift or MEG header, NPS (inches)

52

Configure to Order

2

Material classFF

HH / EE

Dropped object

5kJ point load (Ø100 mm)

Up to 20KJ

Barrier philosophy

Dual isolation for prod.

CustomSubseaControl Systems

Bore configuration

Single bore

Dual bore concentric / multi-bore

Piggable ID variation

With in ±5%

Within ±5%84Subsea Manifolds andPipeline Products

Levelling±3° passive

Active with ROV hyd. jacks

Foundation type

MudmatMulti pile suction anchor

86

Aptara™ Modular
Compact Manifold

Wetparking

Provided on foundation mounted landing beams

Provided on foundation mounted landing beams

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Flowmeter

Not included

Provided through each branch, outlet to main header

Piggable bend radius

3D

5D

Landing speed (m/s)

0.5

0.5

Lifting

4-point lifting with slings

4-point lifting with slings

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and Data Sheets

Subsea Systems

Deepwater Horizontal Cluster Manifold – DHCM (continued)
FeatureMake to Order

Subsea Manifolds
and Pipeline Products

Variant

2 Options

Insulation

If required, high performance
thermal insulation systems

If required, high performance
thermal insulation systems

Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

Jumper type

Rigid

Flexibles with integrated connector

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

Configure to Order

Connection system

HCCS-L Small / Medium and Large

HCCS-L Small / Medium and Large

Caps

Low-pressure / deployment caps

High-pressure caps

Stab plates

FLX360

Header valve

Ball valve / ROVHydraulic fail safe open (FSO)

Branch valve

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

CIMVs

Not included

Can be provided

Hyd. compensation

Closed loop & locally on each actuator

Common sea-chest with accumulators

Control system

1x SCM

2x SCM

PT sensor

2x (one off on each header)As required

Acoustic sand detector

2x (one off on each header non-intrusive clamp on)

As required

Pig detector

2x (one off on each header non-intrusive clamp on)

As required

Retrievable control units

2x retrievable PCDMs / EDUs

On Standalone SDU

217

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Subsea Systems

Shallow Water Multi-flowbase (MFB)
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

2 Options

Connector orientation

Horizontal

Configure to Order

Number of slots

4

6

Number of headers

Option 1: Single production with gas lift
Option 2: Single production with gas lift andwater injection

Dual production

Distribution

Standalone UTA/Flying leads

PiggingRound trip with external pigging loop

Standards

ISO 10423, ISO 13628, (API spec. 6A, 17D & RP 17P, 17R) ISO 19900 & 19902

External PLR (ROV or remotely operated ROPL)ASME B31.8, ASME B31.3 & DNV RP-F112
TRL rating

7 core components

Pressure rating (psi)5,000

As required
As required

Temperature rating-20°F to 250°F (-29°C to 121°C)

Water depth rating

Diver depth

Design life (years)

25

Up to 50
8, 12 or 14

Prod. header size, NPS (inches)

10

Prod. branch size, NPS (inches)6

Gas lift or MEG header, NPS (inches)

4 or 6

Gas lift or MEG branch, NPS (inches)2

8Material classFF

Dropped object

Per NORSOK/ISO Multi-well structure

HH or EE

Barrier philosophy

Single isolation

Bore configuration

Single bore

Piggable ID variation

Within ±5%

Levelling±3° passive

Protection structure

NORSOK compliant, integrated

Manifold Retrievability
WHLR System

Dual isolation

Within ±5%

Skirted mudmat

Fixed pipe-work, diver replaceable valve with flange ends
Provided

Foundation

MudmatWetparking for flowlines

Provided on foundation mounted landing beams

Flowmeter–

Mudmat with piling or suction can

Can be accommodated

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Solutions

Subsea 101

Detailed Specifications
and Data Sheets

Subsea Systems

Shallow Water Multi-flowbase (MFB) (continued)

Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

2 Options

Configure to Order

Piggable bend radius

3D

Landing speed (m/s)

0.5

Lifting

4-point lifting with slings

Insulation

If required, high performance thermal insulation
systems

Connection system+

Diver Flanges or Diverless HCCS-L

ICARUS
High-pressure caps

Caps

Low-pressure/deployment caps

Stab plates

FLX360

Header valve

Ball valve, ROV

5D

Hydraulic fail safe open (FSO)

Branch valve

Gate valve, ROV

Gate valve - Hydraulic

CIMVs

Not included

Optional

hyd. compensation

Closed loop & locally on each actuator

Common sea-chest with accumulators

Control system–

Dedicated SCM

PT sensor

1 off on each header

As required

Acoustic sand detector

1 off on each header, non-intrusive clamp on

As required

Pig detector

1 off on each header, non-intrusive clamp on

As required

Retrievable control units

Retrievable UTA, Flying leads, (PCDM/EDU if required)

219

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220

Subsea Systems

Template Manifold
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

FeatureMake to Order

Variant

2 Options

Connector orientation

Horizontal

Configure to Order

Number of slots

46

No. of headers

Dual production

Single / dual prod. + MEG / gas lift (& service)

Distribution

Integrated SDU

Standalone SDU

PiggingRound trip with external pigging loop

External PLR (ROV or remotely operated ROPL)

Standards

ISO 10423 / ISO 13628, (API spec. 6A / 17D & RP 17P / 17R)
ISO 19900 & 19902
ASME B31.8 / ASME B31.3 & DNV RP-F112

TRL rating

7

Pressure rating (psi)

5,000

7,500 to 10,000

Temperature rating-20°F to 250°F (-29°C to 121°C)

291°F (144°C)

Water depth rating

1,640 ft (500 m)

1,640 ft (500 m)

Design life (years)

25

Up to 50
8, 12 / 14

Prod. header size / NPS (inches)

10

Prod. branch size / NPS (inches)

6 + service + controls in a multibore

Gas lift / MEG header / NPS (inches)

4/6

Gas lift / MEG branch / NPS (inches)2

8Material classFF

HH / EE

Dropped object

5kJ point load (Ø100mm)

Up to 20kJ
Single isolation for injection

52

Subsea Wellheads

Barrier philosophy

Dual isolation for prod.

58

Subsea Trees

Bore configuration

Production + service + controls

68

SubseaControl Systems

Piggable ID variation

Within ±5%

Levelling±3° active by ROV suction control feature

84

Subsea Manifolds andPipeline Products

Within ±5%

Protection structure

NORSOK compliant, integrated

Separately installed

Foundation

4 can suction pile

Multi-suction pile86

Aptara™ Modular
Compact Manifold

Wetparking for flowlines

Provided on foundation mounted landing beams

Provided on foundation mounted landing beams

88

Cluster Manifold

Flowmeter

Dedicated on XT

Manifold mounted

90

Template Manifolds

Piggable bend radius

3D

5D

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

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Solutions

Subsea 101

Detailed Specifications
and Data Sheets

Subsea Systems

Template Manifold (continued)

Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

3 Options

Configure to OrderLanding speed (m/s)

0.5

0.5

Lifting

4-point lifting with slings

4-point lifting with slings

Insulation

If required, high performance thermal insulation
systems

If required, high performance thermal insulation
systems

Connection system

HCCS-L Small / Medium & Large

HCCS-L Small / Medium & Large

Caps

Low-pressure / deployment caps

High-pressure caps

Stab plates

FLX360

3rd party

Header valve

Ball valve / ROVHydraulic fail safe open (FSO)

Branch valve

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

Gate valve, hydraulic fail safe close (FSC) to header
inlets and ROV isolation

CIMVs

Not included

Optional

Hyd. compensation

Closed loop & locally on each actuator

Common sea-chest with accumulators

Control system

1x SCM

As required

PT sensor

1 off on each header

As required

Acoustic sand detector

1 off on each header, non-intrusive clamp on

As required

Pig detector

1 off on each header, non-intrusive clamp on

As required

Retrievable control units

2x retrievable PCDMs / EDUs

As required

221

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Subsea Systems

Pipeline Products and Solutions – High Integrity Pipeline Protection System (HIPPS)
Subsea Manifolds
and Pipeline Products
Our product portfolio
covers everything you needto integrate your subsea
production system andensure safe and efficient
fluid transfer from yourtrees to your risers.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

86

Aptara™ Modular
Compact Manifold

88

Cluster Manifold

90

Template Manifolds

94

Pipeline Products
and Solutions

98

Subsea Connection Systems

110

Subsea Well
Access Systems

FeatureMake to Order

Variant

3 Options

Prod. header size / NPS (inches)

8/6

Design pressure (psi)10,000 / 5,000

Temperature range

0°F to 250°F (-18°C to 121°C)

Valve close time/sec<10

Material class

FF / EE

Dropped object

5kJ point load (Ø100mm)

Barrier philosophy

Dual isolation for production

Bore configuration

Single bore

Piggable ID variation

Within ±5%

Levelling±3° passive

Foundation type

MudmatWetparking

Provided on foundation mounted landing beams

Landing speed (m/s)

0.5

Lifting

4-point lifting with slings

Insulation

If required, high performance thermal insulation systems

Jumper type

Rigid

Connection system

HCCS-L Small, Medium & Large

HIPPS valve

Gate valve, hydraulic operated FSC

Hyd. compensation

Closed loop & locally on each actuator

Control system

1x dedicated SCM

PT sensor

4 off on header

Voting scheme

2004 / 2003

SIL rating

SIL3

Delivery time

12 months

222

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Subsea Systems

Connection Systems
Subsea Connection
Systems
You can count on thereliability and safety ofBaker Hughes’ subsea
clamp connection systems,
even in the mostdemanding environments.

HCCS

Pipe size (inches)

4 - 22

HCCS-L: 4 - 18

HCCS: 18 - 427

7

Qualification
TRL rating

API 6A/17D & API 17R

Design Pressure rating

7

GX seal rating: 15,000 psi for ID <=275mm 10,000 psi for ID>275mm

Temperature rating-51F to 356F (-46C to 180C)

Water depth rating

Depth rating:
11,482ft (3,500m) for Up to 18
9,843ft (3,000m) for Up to 22

Depth rating:
11,482ft (3,500m) for Up to 18

Depth rating:
9,843ft (3,000m) for Up to 228,202ft(2,500m) for Up to 42

Design life

20 - 50 yrs (limited by cathodic
protection of parent structure)

20 - 50 yrs (limited by cathodic
protection of parent structure)

20 - 50 yrs (limited by cathodic
protection of parent structure)

Load capacity

See respective load charts

See respective load charts

See respective load charts

Bore configuration

Single bore, dual bore

Single bore, dual bore, multibore

Single bore

Hub cleaning

ROV flyable cleaning tools for male
& female hub

ROV flyable cleaning tools for male
& female hub (except M2 & M5)

ROV flyable cleaning tools for male
& female hub (except M2 & M5)

Black seal test arrangement

Provided on outboard hub

Provided on inboard hub

Provided on inboard hub

Connection tools

Seal surface cleaning tool; torquetool and hotstab

Seal surface cleaning tool; stroking tool;
torque tool and hotstab

Seal surface cleaning tool; Seal replacement
tool, stroking tool; torque tool and hotstab

Caps

HP caps; test caps; LP cap; flooding cap;
protection caps

Wet parking

On separate parking skids, if needed

Clamp position

Outboard mounted

HP caps; test caps; LP cap; flooding cap; protection caps
On foundation or tubing head spool (if required)

Options

VCCS

HCCS-L

Bore configuration

Dual-concentric or multibore

Dual-concentric or multibore

HCCS

Insulation

Can be provided with extended cool down time
ROV flyable seal replacement tool with stroking
tool

SubseaControl Systems

Flexible

Gooseneck can be provided or complete jumper Integrated end-fitting on hub
with full 360° swivel, installation tool–

Subsea Manifolds andPipeline Products

Flowmeter

Option to mount on the gooseneck or jumper

Option to mount on termination–

Umbilical termination

NA

With multiborehub, compact
electrical termination – ref. MHC UTA–

Pig launcher

Option to integrate PLR

Option to integrate PLR on termination

Option to integrate PLR on termination

Open-PLET

NA–

Proprietary PLET deployment system tosimplify PLET installation for independent
installation of PLET and pipeline

Contingency tools

Stroking tool; seal replacement tool; basket andclamp cutting tool

Seal replacement tool, basket
and clamp cutting tool

Clamp cutting tool

Subsea Wellheads

58

Subsea Trees

68
84

Subsea Connection
Systems

100

Vertical Clamp
Connection Systems

101

Horizontal Clamp
Connection Systems

110

Aptara™ HCCS-L

Seal replacement

52

98

VCCS

Functional specifications

Subsea Well
Access Systems

Metrology interface

Proprietary heatbank with extended cool down time
ROV flyable seal replacement tool

Can be provided on caps–

223

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Subsea Systems

Vertical Clamp Connection System (VCCS) Standard Sizes

Subsea Connection
Systems
You can count on thereliability and safety ofBaker Hughes’ subsea
clamp connection systems,
even in the mostdemanding environments.

System Size

Pipe Size, NPS (inches)Standard Seal Size, ID mm

VCCS 300

4

100

6

140

6

140

8

185

8 + 2 dual bore (concentric)

C175 A250-275

10

235

12

275

12

275

14

320

16

365

18

400

18

400

22

505

VCCS 450

VCCS 520

VCCS 580

VCCS 720

Vertical Clamp Connection System (VCCS) ToolingStandard Tooling

Optional Tooling

Torque tool and calibration unit

Stroking tool

Inboard hub cleaning tool

Outboard hub cleaning tool

ROV hot stab

Seal replacement tool
Tooling basket

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection
Systems

100

Vertical Clamp
Connection Systems

101

Horizontal Clamp
Connection Systems

110

Subsea Well
Access Systems

Inspection tool
Gooseneck lifting adaptor

224

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Subsea Systems

Horizontal Clamp Connection Systems (HCCS) Standard Sizes

Subsea Connection
Systems

System Size

Clamp Size

Pipe Size, NPS (inches)Standard Seal Size, ID mm

HCCS-L small

300

4 or less

100

6

140

8

185

8 + 2 dual bore (concentric)

C175 A250-275

10

235

HCCS-L medium450

You can count on thereliability and safety ofBaker Hughes’ subsea
clamp connection systems,
even in the mostdemanding environments.
HCCS-L large

520

580

12

275

Multibore 450-V1A | V1B | V1C | V1D

19x SX22 | 15x SX22 | 11x SX22 | 5x SX22

Multibore 450-V2

14x SX22 + 2x SX44

Multibore 450-V3

8x SX22 + 6x SX44

14

320

Multibore 520-V1

12x SX22 + 6x SX44

16

365

18

400
400

HCCS 22

720

18
22

505

HCCS 30940

20 or 22600

24 or 26

680

HCCS 36M2

32 to 36

870

HCCS 42M5

38 to 421020

Horizontal Clamp Connection Systems (HCCS-L/HCCS) Tooling52

Subsea Wellheads

Standard Tooling

Optional Tooling58

Subsea Trees

Stroking tool

Seal replacement tool (HCCS-L)

68

SubseaControl Systems

Torque tool and calibration unit

Inspection tool

Inboard / outboard hub cleaning tool

Flowline lifting tool (FLT)ROV hot stab

Cap replacement tool (HCCS sizes)

Tooling basket

Connection override tooling package

84

Subsea Manifolds andPipeline Products

98

Subsea Connection
Systems

100

Vertical Clamp
Connection Systems

101

Horizontal Clamp
Connection Systems

110

Subsea Well
Access Systems

Installation guidepost
Seal replacement tool (HCCS)

225

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226

Subsea Systems

Open Water Completion Workover Riser System – CWOR
Subsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

112
113

Open Water Completion
Workover Riser (CWOR)
Installation and Workover
Control Systems (IWOCS)

FeatureMake to Order

Variant

Option 1

System production size (inches)

73⁄8

Configure to Order

Configure to Order

51⁄8

61⁄8

System annulus size (inches)

2 nom

2 nom

2 nom

Pressure rating (psi)10,00010,00010,000Design life

25 years

25 years

25 yearsTemperature range

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

0°F to 250°F (-18°C to 121°C)

Max water depth

9,842 ft (3,000 m)

9,842 ft (3,000 m)

9,842 ft (3,000 m)
API RP 17G

Test and qualified

API RP 17G

API RP 17G

Trim level

E-E with H 2S trim

E-E with H 2S trim

E-E with H 2S trim

Quality requirements

Standard ITPStandard ITPStandard ITP

Product service level

PSL 3GPSL 3

BSEE compatible

Yes

BSEE certified

No

Yes

Autoshear

Yes

No

Deadman

Yes

No

Safety integrity level scope

SIL-2 of controls system only

Not applicable

Full SIL-2

Safety integrity level coverage

SIL-2 of ESD, EQD and Deadman,
Autoshear

SIL-2 of ESD / EQD

Full SIL-2

LRP & EDP production bore size (inches)73⁄8

LRP & EDP annulus bore size (inches)

21⁄16

LRP barrier No.1 sealing direction

Seal from below

non-sealing

LRP barrier No.1 function

Safety Head

Grip / seal

Grip

LRP barrier No.2 sealing direction

Seal from below

Bi-directional

Not required
Shear and Seal Gate

LRP barrier No.2 function

Safety HeadGate

LRP barrier No.3 sealing direction

Bi-directional

Seal from above

LRP barrier No.3 function

Gate

Shear and Seal GateEDP RV sealing direction

Bi-directional

Seal from above

EDP RV function

Gate

Shear and Seal Gate

Stress joint

Yes

Stress joint production bore (inches)

73⁄8

Riser safety joint

Not required

Simple frangible bolts

Production riser typeMono-bore

Dual bore

Telescopic pressure balanced

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Subsea Systems

Open Water Completion Workover Riser System – CWOR (continued)

Subsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

112
113

Open Water Completion
Workover Riser (CWOR)
Installation and Workover
Control Systems (IWOCS)

FeatureMake to Order

Variant

Option 1

Configure to Order

Configure to Order

Annulus type

Flexible Hose

Coiled Tubing

Dual bore riserNo

Lubricator valve

Yes

Lubricator Valve Production bore (inches)

73⁄8

63⁄8

Dual Lubricator Valve

No

Yes

Lubricator Valve dual use with Open waterand In-riser

No

Yes

Lubricator valve sealing direction

Bi-directional

From above only

Lubricator Valve pump through

Yes

No

Lubricator Valve Chemical injection

Yes

Tension Joint

Yes

No

Cased Wear Joint

Yes

No

SwivelYes

No

Surface Test Tree

Yes

No

STT production bore (inches)73⁄8 (mono-bore)

Controls system

Electro-hydraulic (Multi-plex)

Direct Hydraulic

WOCM location

EDP – retrievable

Not applicable

Cleanliness requirement

SAE AS 4059 Class 6B-E

Control fluid

HT-2

Alternative considered

Working pressure – LP

3,000

5,000

Working pressure – HP

10,000Material

316⁄316L

LRP lower interface

Clamp

LRP lower connector

Included625

6Mo

Not part of scope

EDP connector high angle release

Yes

No

EDP upper interface

HydraulicManualRiser

Casing Riser

Drill Pipe Riser

STT upper wireline interface adapter (inches)111⁄2 4-ACME OTIS Quick Union

Alternative considered

STT lower Interface (inches)

135⁄8 flange

STT KW interface

Clamp

STT PW interface

Clamp

Alternative considered
Alternative considered

Warning and instruction language requirements

EnglishProject specificNot part of scope

227

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Subsea 101

Subsea Systems

Installation and Workover Control System – IWOCS
FeatureSubsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

Configure to Order

Variant

Physical properties typical
Dimensions – L x W x H (mm)9,144 x 2,550 x 3,150

WeightMax Unit Gross weight 55,115 lbs (25,000 kg)

Temperature rating

Operating: 14°F to 104°F (-10°C to 40°C); Storage: -4° F to 122° F (– 20°C to 50˚C); Relative humidity: 20% to 80%

Required utilities
Power

Rig Three Phase – Motors

440 VAC 63A 50⁄60 Hz – Max +/- 10%

Single Phase – UPS

230 VAC 16C A 50⁄60 Hz Max +/- 10%

Rig Single Phase – WOCS

230 VAC 16C A 50⁄60 Hz Max +/- 10%

Air

Instrument air

6-8 Bar

Water supply (A/C)

Chilled water

10-30 L/min @ 5-8°C max 3 bar

Unit features
Frame works
Design standard

DnV 2.7-1

Handling

4 leg lifting sling, tugger, ISO corners on each side of base frame, skid mounted forklift pockets

Access

Entrance door to the MCP room through air lock. Door to the HPU room from inside the MCP room.

Hydraulic output

Qty

Regulated pressure

Low pressure

According to hyd schematic

0-5,000 psi

Medium pressure

According to hyd schematic

0-10,000 psi

High pressure

According to hyd schematic

0-12,500 psi (15,000 psi)

Test lines

2 (typical)

0-12,500 psi / 0-5,000 psi

Return lines (psi)13,000 psi (M.W.P.)

Pumps / motors (typical configuration)
Low pressure / flushing

Supply pressure

690 Bar

Drive type

Electric

Qty

2

Motor rating

15 kW

Flow Rates

10.0 L/min

84

Subsea Manifolds andPipeline Products

Supply pressure

863 Bar98

Subsea Connection Systems

Drive type

Electric

Qty

2

110

Subsea Well
Access Systems

Motor rating

15 kW

Flow Rates

5.0 L/min

112

Open Water Completion
Workover Riser (CWOR)

113

Installation and Workover
Control Systems (IWOCS)High pressure

228

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Subsea 101

229

Subsea Systems

Installation and Workover Control System – IWOCS (continued)
FeatureSubsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

Configure to Order

Variant

Circulation / filling(including filling lance)

Supply pressure

10 BarDrive type

Electric

Qty

1

Motor rating

1.5 kW

Flow Rates

30.0 L/min

Reservoirs
Volumes

Supply1,000 L

1,000 L

1,000 L

Return1,000 L

1,000 L

1,000 L

Dirty Return500 L (ext res.)

500 L (ext res.)

500 L (ext res.)Accumulators (Scalable to project requirements)
Design standards

ASME VIII, Division 1 / PED

Low pressure

Type:

PistonM.W.P:

690 barType:

PistonM.W.P:

871 barHigh pressure

Instrumentation / Control
Instrumentation
GeneralTransmitter data input to control logic and on screen display.

Pressure transducers

LocationsDownstream of pumps, filters, regulators and at hydraulics outputs

Signal Output

4 – 20 mA

Locations

1 off System Supply Flowmeter is installed upstream Pressure Regulator distribution for verification of
volume for LP functions. 1 off HP Flowmeter is installed upstream Pressure Regulator for verification of
volumes for the HP functions

Flow meter

Accuracy± 0.25% scale range

1 off Subsea Return & 1 off System Return flowmeter with by-pass installed downstream Return Filter
for verification of return volume

52

Subsea Wellheads

58

Subsea TreesType

Turbine Flow meters, with totalizer Turbine Flow meters, with totalizer Turbine Flow meters, with totalizer

68

SubseaControl Systems

Signal Output

4 – 20 mA

Accuracy± 0.25% scale range

Level transducers

Locations

Reservoirs

Reservoirs

Reservoirs

Signal Output

4 – 20 mA

Accuracy± 0.25% scale range

Pressure gauges

Locations

Various Locations within system Various Locations within system Various Locations within system

Type

Bourdon84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

112

Open Water Completion
Workover Riser (CWOR)

113

Installation and Workover
Control Systems (IWOCS)

Accuracy± 1% scale range

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Subsea 101

230

Subsea Systems

Installation and Workover Control System – IWOCS (continued)
FeatureSubsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

Configure to Order

Variant

Gas detector

Location

Dirty Return Tank (External tank) Dirty Return Tank (External tank) Dirty Return Tank (External tank)Type

Flame detector

Sieger Optima Plus 0-100%LEL Methane, IR point gas detector

Signal Output

4 – 20 mA

Accuracy± 1% scale range

Type

2 ch. Loop Powered Fire /Smoke Detector

2 ch. Loop Powered Fire /Smoke Detector

2 ch. Loop Powered Fire /Smoke Detector

Programmable Logic Controller (Scalable to project requirements)
GeneralThe PLC contains a central rack with processor module, interface modules and 3 expansion racks, Safety and Non-safety digital input/ output modules and analogue input modules.
The PLC controls at all times all the pumps and DCV valves initiated from VDU screens on the operator stations, manual start and stopof pumps is controlled from the motor starter panel located in the HPU. The PLC also monitors all HPU instruments such as pressuretransmitters and status indicators on the input / output modules.

Manufacturer

Siemens

Siemens

Type

Simatic CPU

Local Control – HPU
The HPU has the following local
control and monitoring
functions:

Local Pump Control Panel for System pumps and Circulation pump
Regulator panels (Note that the most commonly used main regulators are installed in the MCR)
Manual operation of all solenoid valves
Manual valves for selected hydraulic outlet lines
Pressure gauges on all hydraulic outlet lines
Level gauges on reservoirs
Accumulator panel
Flushing panel
Isolation valves and crossover loops for system service and maintenance.
Emergency Stop push button on all electrical motors
Push button for forced start on System Pumps

52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

Operator stations function as HMI and provide a graphical interface to the process, i.e. mimic pictures to control the processes.
There are 2 Local Control Panels (LCP) and 1 remote control Station.

98

Subsea Connection Systems

110

Subsea Well
Access Systems

The LCP consist of a double (redundant) PC system for interfacing to two separate VDUs in the MCP. The same information is available
at both VDUs. Operator can choose which screen to operate from for control and visualization of the WOCS.

112

Open Water Completion
Workover Riser (CWOR)

113

Installation and Workover
Control Systems (IWOCS)

Local clogging indicator on filters
Manual hydraulic fluid cleanliness system (sample points)
HMI Interface

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and Data Sheets

Subsea 101

Subsea Systems

Installation and Workover Control System – IWOCS (continued)
FeatureSubsea Well
Access Systems
Baker Hughes has a long
history of providing safe,
efficient and reliable Well
Access services. In addition
to equipment you canpurchase outright, wehave an extensive
portfolio of rental tools
and equipment to support
operations from installationand commissioning rightthrough to decommissioning.
This comprehensive fleet
can meet the needs oflong and short-term
rental contracts, providing
well-maintained equipment
for subsea contracts.

Configure to Order

Variant

Main Interfaces
Hydraulic Connections (Scalable to project requirements)
Workover umbilical MQC plate:

7 way stabplate

LP Hotline Outlet:

2 off

LV umbilical MQC plate:

5 way stabplate

HP Hotline Outlet:

2 off

SFT MQC plate:

8 way stabplate

Filling point Hydr.Fluid:

1 off

Fluid to dirty return tank

1 offElectrical Connections
Rig utilities

Jumpers terminated in Ex junction box

UPS

Jumpers terminated in Ex junction box

MCS comms

Jumpers terminated in Ex junction box (Electrical connectors for subsea power and optical comms)

Materials
Structure
Frameworks

Structural Steel

Components
Reservoir

AISI 304 Stainless Steel

Accumulators

17-4 PH – Martensitic Stainless Steel

Valves and hardware

316 Stainless Steel

Tubing316 Stainless Steel

Testing and Certification
Testing
52

Subsea Wellheads

58

Subsea Trees

68

SubseaControl Systems

84

Subsea Manifolds andPipeline Products

98

Subsea Connection Systems

110

Subsea Well
Access Systems

112

Open Water Completion
Workover Riser (CWOR)

113

Installation and Workover
Control Systems (IWOCS)Function test

ISO 13628-7

Load testing

DnV 2.7-1 / DnV 2.7-3

Ventilation / purging

EN 50381

Certifications
Components

CE Marked

Electrical equipment

IECEx

Non-electrical equipment

ATEX

Lifting

DnV 2.7-1

231

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Detailed Specifications
and Data Sheets

CONTACT US
We serve our customers from our headquarters in
Bristol, United Kingdom and have a network of offices
across the world to meet the needs of our global
customer base.

Oilfield Equipment
Headquarters
2630 The QuadrantAztec West
Bristol
BS32 4GQ
United Kingdom
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Singapore, SG 629876
Singapore
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Dyce
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AB21 9LA
United Kingdom
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Avenida Republica do Chile
330 Ventura Corporate
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Rio de Janeiro, RJ 20031-170
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www.BakerHughes.com/SPScatalog

Middle East, North Africa,
Turkey and India
Po Box 567
Technopark
Dubai
United Arab Emirates
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3300 N. Sam Houston
Parkway East, Houston
TX 77032-3411
US
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Street No. 927/928
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PO Box 54255
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www.BakerHughes.com/contact-us

Disclaimer©2020 Baker Hughes, (“Baker Hughes”).
All rights reserved. Baker Hughes provides
this information on an “as is” basis forgeneral information purposes. Baker Hughes
does not make any representation as to theaccuracy or completeness of the informationand makes no warranties of any kind,
specific, implied or oral, to the fullest extent
permissible by law, including those ofmerchantability and fitness for a particularpurpose or use. Baker Hughes hereby
disclaims any and all liability for any direct,
indirect, consequential or special damages,
claims for lost profits, or third party claims
arising from the use of the information,
whether a claim is asserted in contract, tort,
or otherwise. Baker Hughes reserves the rightto make changes in specifications andfeatures shown herein, or discontinue theproduct described at any time without noticeor obligation. Contact your Baker Hughes
representative for the most current
information. The Baker Hughes logo is atrademark of Baker Hughes.

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Bristol, UK

Houston, USA

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Solutions

Subsea 101

Moscow, Russia

Dubai, UAE
Lagos, Nigeria

Rio de Janeiro, Brazil

Singapore

Detailed Specifications
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233