FMC Subsea Field Development Challenges and Solution for Tie - In and Connection System
-
Upload
eyoma-etim -
Category
Documents
-
view
879 -
download
58
Transcript of FMC Subsea Field Development Challenges and Solution for Tie - In and Connection System
2/27/2014
Subsea Field Development - Challenges and Solutions for Tie-In and Connection Systems
Session: Focus on Technology
Subsea Australasia Conference19-21 February 2014
Zahid Hasan
AOG 2014
Outline
• Subsea Field Development- Introduction, Top Down Approach and Options
• Tie-In and Connections Systems- Introduction and Options• Comparison and Selection of Tie-In and Connection Systems• Field Development with alternate Tie-In and Connection
systems• Available Connection Systems (New Generation )
1
AOG 2014
Subsea Field Development
• Custom configuration of Subsea equipment
providing a variety of system designs
• Develop field architecture
• Well design and placement
• Host facilities and specification
• Configuration and routing of flowlines, umbilicals
and risers
• Installation Options
• Reduce risk with credible and proven solutions
2
AOG 2014 3
Reservoir& Field
System Solution
Sub-system solution
Available Products
The proposed system solution will be based on
• Technical decision factors,
• Location and Geographical condition
• Regulatory and political factors
• Operator’s preference
• Contractor’s preference
• Individual supplier’s preferences
• Available products and competence
Subsea Field Development- Top Down Approach
AOG 2014
Subsea Field Development – Top Down Approach
Level Main Factors Tie-in & Connection topics
Reservoir, Field,location + Government and Company requirements (= Design Basis)
• Reservoir parameters (pressure, temperatures,gas/oil, size, water depth, well locations etc)
• Process requirements• Geographic location/Environmental conditions• Availability of vessels in region
• Connection parts qualified for parameters• Connection system meets installation and
operational requirements• Can be used/maintained from small vessels
in remote locations
System Solution • Flow assurance philosophy• Hydraulic and injection distribution philosophy• Pigging/commissioning requirements• Retrieval of modules without pulling
jumpers/spools
• Injection volumes, thermal insulation• Multibore vs Monobore System• Subsea Parking of jumpers/spools for
module • Pre-installation and/or batch setting of
jumpers/spools.
Sub-system solution
• Horizontal and/or vertical System• Simple, complex tooling or hydraulic connectors• Guiding, installation requirements• External forces (installation and operation)• Rigid- and/or flexible lines and umbilicals
• Qualified and preferably field proven solutions
• Injection and/or hydraulic distribution through connectors
• Swivel functionality to handle torsion in flexible lines
Available Products • Sizes and capabilities (pressure, temp, capacity, insulation etc)
• Qualification requirements, track record• Installation vessel, methods and procedures• Commissioning requirements• Contingency operations
• Qualified and preferably field proven System• Handling, installation, guiding • Connectors, seals, caps, tools• Procedures
4
AOG 2014 5
Typical Subsea Field Developments Options
• Satellite Tieback
• Cluster Manifold
• Cluster Manifold with Satellite Tieback
• Mixture of ManifoldCluster and remote/inline tiebacks
• Daisy Chained Tieback
• Integrated Template/Manifold
AOG 2014
Outline
6
• Subsea Field Development- Introduction, Top Down Approach and Options
• Tie-In and Connections Systems- Introduction and Options• Comparison and Selection of Tie-In and Connection Systems• Field Development with alternate Tie-In and Connection
systems• Available Connection Systems (New Generation )
AOG 2014 7
What is a Tie-In and Connection System
In reference to Oil and Gas Industry the connection system:
• Joins two pieces of equipment (e.g. tree to wellhead, jumper to hub, etc.)
• Prevent fluid leakage to the environment• Establish and maintain a seal on a gasket• Withstand external loading (internal pressure,
bending, tension, torsion)
AOG 2014
Tie-in and Connection System Options
Orientation Application Connector type/actuation
Horizontal Pipe sizesNon insulatedInsulatedMono-boreMulti-bore
Mechanical w/”large” toolMechanical w/”small” toolsHydraulic w/contingency
Vertical Pipe sizesNon insulatedInsulatedMono-boreMulti-bore
Mechanical w/”large” toolMechanical w/”small” toolsHydraulic w/contingency
Small-bore Injection lines ROV installation, FLOT + Torque tool or hydraulic
Flying leads Hydraulic distribution and/or injection linesEl/FO jumpers
ROV installation, FLOT + Torque tool
Module connectors
SizesNon insulatedInsulatedMono-boreMulti-bore
Mechanical ”small” toolHydraulic w/contingency
8
AOG 2014
Outline
9
• Subsea Field Development- Introduction, Top Down Approach and Options
• Tie-In and Connections Systems- Introduction and Options• Comparison and Selection of Tie-In and Connection Systems• Field Development with alternate Tie-In and Connection
systems• Available Connection Systems (New Generation )
AOG 2014
Selection of Connection System
Challenges:• Design Basis and Customer
Requirements• Many needs in one field• Intervention Strategy • Reuse of existing tooling• Cost evaluation criteria• Interfaces
– Internal interfaces in Subsea Production System
– Interfaces to pipeline/flowline
• External forces • Physical interfaces • Handling and installation • Installation procedures
• Knowledge and experience of involved personnel
• Personal and cultural preferences based on experience
Reservoir, Design Basis, Field layout
System, Flow assurance, Hydraulic
and injection fluid distribution
Pipe sizes
Horizontal
Multi-bore or Flying Leads+ small-bore
Insulated connectors
Not insulated
Vertical
Multi-bore or Flying Leads+ small-bore
Insulated connectors
Not insulated
Module
10
AOG 2014
Vertical vs Horizontal Tie-In Systems Selection• Regional preferences and customer preferences• Total installed cost• Field architecture (on-template wells, off-template well clusters
and wide area distribution wells)• Ease of fabrication (onshore/ offshore)• Lifting capacity of the installation vessel • Ease of performing jumper installation• Ease of Tree and / or Manifold retrieval• Regional requirement for overtrawlability and hence minimum
height protection structures (i.e. North Sea applications).• Avoidance of trapped water and potential hydrate formation• Multi-phase and Wet Gas meters location (Need to be in a vertical
leg for proper performance)
11
AOG 2014
Rigid Vs Flexible Jumpers
• Selection of Rigid or Flexible jumpers is dependant on– Field Layout– Design Requirement (Pressure, Temperature etc.)– Material Philosophy– Insulation Requirement– Fluid in bore– Total Installed Cost
12
AOG 2014
Outline
13
• Subsea Field Development- Introduction, Top Down Approach and Options
• Tie-In and Connections Systems- Introduction and Options• Comparison and Selection of Tie-In and Connection Systems• Field Development with alternate Tie-In and Connection
systems• Available Connection Systems (New Generation )
Typical Production DC Layout – Vertical Mono-bore connections
SDU
SRM
UTH
EFL and HFL jumpers(elec, hyd, chem)
FCM
EHXT
SCM
M spools and vertical connections
10” PLET Jumpers(Vecon Connectors)
MCMManifold
10” Flowline (PIP)
10” Flowline (PIP)
UTH
Methanol 2” jumpersKC4-3 vertical connections
Umbilical(elec+fibre+hyd+chem+ 5x1.5” for methanol)
14
Typical Production Drill Centre with vertical connections
15
AOG 2014
Drill Center with Vertical Rigid Spools
16
Typical Production DC Layout withHorizontal multi-bore well jumpers/connectors
• No SDU (Distribution in manifold)• All horizontal connections• Multi-bore connections (XT to manifold)
Umbilical(elec+f ibre+hyd+chem+ 5 x1.5” for methanol)
SRM
FCMEHXT
SCM
XT Jumpers6” prod + 2” methanol + elec + hydUCON multi bore horizontal
10” PLET Jumpers(UCON mono bore horizontal)
MCM
Manifold
10” Flowline (PIP)
10” Flowline (PIP)
SCM
MCMManifold
Mono-bore DC
Multi-bore DC
17
AOG 2014
Typical Production Drill Centre with horizontal connections
18
Drill Center with Horizontal Rigid Spools
19
Drill Centre with Vertical Rigid Spools
20
As Built Drill Centre
21
AOG 2014
Outline
22
• Subsea Field Development- Introduction, Top Down Approach and Options
• Tie-In and Connections Systems- Introduction and Options• Comparison and Selection of Tie-In and Connection Systems• Field Development with alternate Tie-In and Connection
systems• Available Connection Systems (New Generation )
Different Connection SystemsHistorical - Integral Hydraulic
and Mechanical / CAT Tie-in Systems
UCON ROV-Tool
Mechanical Tie-in System
TORUS IV
ROVCON
STABCON
TORUS III MAX - CAT & CAT-Lite
UTIS
• Used Large tools• Longer installation time
UCON-H
UCON-V
Collet or Clamp
Clamp
Collet
23
AOG 2014
Standard Connection Systems
Connection Systems
Horizontal
UCON-H
UCON-H-12 UCON-H-12 INS UCON-H-18 UCON-H-18
INS UCON-H-22
Stabcon MK2 Rovcon MK2
Vertical
UCON-V-KC UCON-V--KL
KLV-8 (MAX) KLV-10 KLV-14 KLV-16
Torus-III
Smallbore Module Connectors
Manifold System
Well Completion
Systems (XTs)
Well Access Systems (Riser)
Process
• UCON Family – UCON-H, Horizontal– UCON-V, Vertical
• Based on the same family of standards– Collet Connectors (KC)– Clamp Connectors (KL)
• The core collet and clamp connectors use the same mono-bore and multi-bore hubs/connector bodies and Seals
• The design and qualification philosophy is that qualified seals can be used in all connectors.
24
AOG 2014
KC/KL connector family
KC4-10 KC4-12KC4-14
KC4-27
KL4-10 KL4-12
KL4-18
KL4-27
KC4-34KC4-18
KL4-16
Max pipe OD (Inches)
KC4-16
KL4-14
KC4-22
12.75” 14” 16” 18” 20” 24” 30” 36”
25
AOG 2014
UCON-H Product Family• 4 versions available today• UCON-H-22 is available Q1 2014
UCON-H-22
UCON-H-18
UCON-H-12, insulated
UCON-H-12UCON-H-18, insulated
• Basic ROV manipulator held tooling
• Mono-bore and Multi-bore
• Integral Insulated or non-insulated
• Horizontal or Vertical
• Guideline or guideline-less operations
• No interface with seabed during installation and connection
26
AOG 2014
UCON-H Multibore Connections
Umbilical Termination Head (UTH)
Insulated Multibore Welljumper Termination Head(6 + 2x1.5 + 8 HL)
27
AOG 2014
UCON-H Connection System
Multi-bore KC4 Connector
6” + 2x1.5” + Hyd + chem + EL
• Stroke-in and connect• Rigid Spools (mono/multi bore)• Flexible lines / umbilicals• Pig Launchers /Receivers• Pig Loops
28
AOG 2014
Connection System Installation
UCON-H SystemROVCON System
29
UCON-H Video
AOG 2014
Installation/Parking of Connection System without Production Equipment
Tubing Head (U Loop) Flowbase System (Flexible Flowloop)
Tubing Head (Without U Loop) for UCON System
• Simpler Parking/pre-installation of well jumper
• Direct interface with Tree hub
30
Installation of UCON System without Production Equipment
31
Conclusions
• Tie-in and Connection system selection is fundamental to an
economic field development
• Vertical & or Horizontal tie-ins with rigid and or flexible pipe may be
selected – feature common connectors and hubs
• UCON Connection system reduces total installed cost
• Simplified ROV deployed Tooling reduces installation time
• Integral Thermal Insulation available vs. adding “dog houses”
improves thermal performance and reduces cost
• Subsea parking & pre-installation of jumpers without Subsea
production equipment is enabled
• Reduced personnel onboard vessels and simplified maintenance
• Wide Pipe range available
32
Thank You