Deep water marine drilling CLIP riser - Presstogo

© 2012 Aker Solutions part of Aker

Deep water marine drilling CLIP riserONS 2012

Drilling risersJuly 2012Slide 1


Index

July 2012 Drilling risersSlide 2

1. Introduction & Background

2. General characteristics of the CLIP Riser

3. The function of the CLIP connector

4. Marine Riser Tools, Special Joints and other Components

5. CLIP Riser in operation

6. Manufacturing of CLIP risers – where & how

7. Previous and Current Projects and Deliveries

8. Financial impact

9. Summary


Core values



Main locations – Drilling risers


Riser PlantPort Klang, Malaysia

Head officeOslo, Norway

Riser PlantRio Das Ostras

Brazil

Riser Tools Centre of

ExcellenceMobile, AL, USA

Sales OfficeSingapore

Sales OfficeHouston

Sales OfficeRio De Janeiro


Background


■ Developed by the Institut Francais du Petrol and Framatome, a Division of Cruesot-Loire

■ Aker Solutions is licensed by IFP and Framatome to Manufacture the CLIP Riser

■ Developed Specifically for Deepwater Drilling after a 5 Year R & D Program

■ Mainly Distinguished by Breech-Block Type Connection


Index


1. Introduction and background

2. General characteristics of the CLIP riser


4. Marine riser tools, special joints and other components

5. CLIP riser in operation

6. Manufacturing of CLIP risers – where and how

7. Previous and current projects and deliveries

8. Financial impact

9. Summary


General characteristics


■ Shortest tripping time as proven in the field

■ Most secure connection: fully opened or closedpositions only

■ No threading, bolting or preloading

■ Easy stabbing even with misalignment

■ Stress concentrations minimized so as to never exceed 2/3rd of yield

■ Reduced maintenance due to trouble freedesign


General characteristics


■ Dual row of lugs provides a 360 degree

distribution of the axial load

■ Connector is a class H, 3,500,000 Lbs. API-16R

■ Up to 6 peripheral lines: hydraulic lines, kill and

choke lines, booster lines and chemical lines

■ Main tube X-80, DSAW pipe

■ H2S service kill, choke and booster lines


A full riser system provider


■ Main CLIP riser joints

■ Typical length 75 ft, 133 joints needed for a 10 000 ft riser

■ Pup joints

■ Normally a range of 4-6 pup joints of different length in 5 ft intervals

■ Special joints

■ Special joints to handle the interface between rig/riser and BOP/riser

■ Special joints to fulfill different operational needs

■ Tools

■ Tools for running and handling the riser, including spider and gimbal

■ Buoyancy & riser protection

■ Joints that are not dressed with buoyancy are often equipped with riser

protection

■ Services

■ Before and during delivery: project management, engineering etc.

■ After delivery: life cycle services


CLIP riser configuration

Rig floor 10,065ft

Wellhead Bevation 0,0ft

BOP

LMRP

Spider/Gimbel/Load Plate

Flex Joint

10,000ft

20,9 ft

35,6 ft

60 ft

9650 ft

DAT Tensioner


Index









8. Financial impact

9. Summary


Typical riser joint


Male Connector

Female Connector


CLIP male connector assembly


■ Pin, locking ring, guide plate and replaceable pins


CLIP pin connector


Stabbing nose

Seal carrier

Load shoulder


CLIP female connector assembly


■ Female connector and peripheral line receptacles


CLIP female connector


■ Two rows of breech locks - four main supports for true peripheral lines


CLIP connector locking ring


Location for index block

Rotational hole for locking

Hole for sealcutting

and replacement

Lubrication hole


CLIP riser make up



Cross section – CLIP connector assembly


■ Description

■ Connector is a “bayonet” type

■ Composed of 3 forged elements

■ Locking on 360º by two rows

of lugs

■ No pre-load required to

achieve full capacity

■ Main advantages

■ Fast make-up/break-out

■ Robust

■ Safe & Reliable operation


Peripheral lines


■ Peripheral lines are fitted with replaceable pins

■ Pins can be replaced in the field with no need for welding


Replacing peripheral lines



Unlocking and locking



Index









8. Financial impact

9. Summary


Flex joints

July 2012Slide 24

■ Lower flex joints are used to allow

angular misalignment between the

riser and the BOP stack, thereby

reducing the bending moment on

the riser.

■ Upper flex joints are used at the top

of the riser to allow for the motion of

the rig.

■ Intermediate flex joints can be

installed at an intermediate level in

the riser string below the telescopic

joint to reduce stresses in the riser.Upper Flex JointLower Flex Joint

Drilling risers


Termination adapter


■ For connecting the riser string to the

LMRP

■ Subsea actuated gate valve

■ Kick-outs for connecting the peripheral

lines to the LMRP/BOP


Soft hangoff joint


■ Used to hang off the riser string in the tension

ring when environmental conditions exceed the

limits for safe operation

■ Roller bearing to allow lateral movement of the

vessel


Telescopic joint


■ Compensate for the vertical displacement of the vessel.

■ Bearing system to permit rotation of the vessel around the riser.

■ Configured with an outer and inner barrel. The outer barrel is connected to the drilling

riser, while the inner barrel is connected to the drilling vessel.

■ Collet connector assembly, to permit interlocking the Inner and outer barrels during

running and retrieval.

■ Goosenecks for terminating the peripheral lines to the rig auxiliary hoses.


Telescopic joint

Drilling risers

Roller

Bearing and

Bearing

Housing

Outer Barrel

Inner Barrel with

Female CLIP

Connector

Male CLIP

Connector

Assembly c/w

Guide Plate

Lifting Lug

Collet

Connector

Triple

Packer


Telescopic joint (goosenecks)


■ The gooseneck system enables the riser peripheral lines to terminate and drape hoses to be attached at the gooseneck outlets.

■ Welded into the outer barrel on a telescopic joint

■ The goosenecks consist of two forged halves that are machined and welded together.


Tension ring


■ The riser tension ring is attached

to the tiser telescopic joint

■ Provides the structural interface

between the rig tensioner system

and the marine riser

■ The tensile load to support the

riser is transmitted from the rig

tensioners through the tension

ring to the outer barrel of the

telescopic joint

■ The tension ring come as solid,

hinged or split


Tension ring with tensioner



Spacer joint


■ Used to bridge the distance between the telescopic joint and diverter and allow for

correct space out of the telescopic joint


Fill-up valve


■ Allows the Riser to fill with water to prevent the collapse of the riser string due to

pressure differences by sea water pressing on the exterior of the riser string if drilling

mud exits the riser during operation.


Bay handling tool


■ Moves riser joints in and out of the riser

bay vertical storage area

■ Is designed to hold the load of one riser

joint at a time in vertical position only

■ Locks onto the lower set of lugs of the

CLIP female connector

■ Remotely operated by the crane

operator


Bay handling tool



Test tool


Peripheral line seals are tested as the

riser joints are made up during tripping of

the riser

The peripheral lines boxes and pin

connections must be tested when

tripping the riser to insure pressure

integrity of the lines


Test tool



Test tool on LMRP



Spider, gimbal and load plate


Spider consists of 4 hydraulic rams

that will support and hang-off the

riser string.

Gimbal has 6 elastomeric bearings

that absorbs the loads and are able

to withstand 6 degrees movement.

Load Plate transfers the load from

the Riser/Spider/Gimbal to the rotary

table


Spider with rams extended



Spider and gimbal



Landed in spider



Hydraulic and manual running tools


Picks up and delivers riser joints

from/to vertical set- back in-

chute. Allows also for horizontal

pick-up from trolley.

Able to lift the entire riser string

with BOP

The running tool connects to the

female CLIP connector of the

riser joint below using its

integrated male CLIP connector

The running tool may be

provided as both a

Manual

Hydraulic tool

Hydraulic running tool

Hydraulic running tool

Manual running tool


Index


1. Introduction & Background

2. General characteristics of the CLIP Riser


4. Marine Riser Tools, Special Joints and other Components

5. CLIP Riser in operation

6. Manufacturing of CLIP risers – where & how

7. Previous and Current Projects and Deliveries

8. Financial impact

9. Summary


Horizontally stacked



Stored vertically - box up



Being delivered to the rig floor – in chute



Being delivered to rig floor



Running CLIP riser



Running CLIP riser



Locking the connectors



Landing CLIP riser in spider



part of Aker


Index








7. Previous and current Projects and deliveries

8. Financial impact

9. Summary


Manufacturing and service locations


Port Klang,

Malaysia

Verdal,

Norway

Rio Das Ostras,

Brazil

Mobile, AL

USA


High Tech Manufacturing Centre

Port Klang Free Zone – Pulau Indah 2005


© 2011 Aker Solutions

part of Aker

High Tech Manufacturing Centre

Port Klang Free Zone – Pulau Indah 2010

Drilling Risers

Fabrication

Controls

Trees

Office Building

Subsea Structures

Process Packages

Drilling Risers

Subsea

Control

Module

Blasting &

Paint

Office Building

Machining

Warehouse

150,000 square meters land

37,000 square meters under roof

Trees

Machining

July 2012 Drilling risers


Plant - Rio das Ostras 2003



Aker Solutions - Rio das Ostras 2011


Office & training

centre

Aker Subsea

Workshop

Aker Drilling Riser

manufacturing


Manufacturing – CLIP riser joint


Cutting Bevelling Pre Heating Welding

NDT- Dimensional NDT - Ultrasonic NDT - Hardness NDT–Magnetic Particles

Heat Treatment Pressure Test Painting Assembly


Index









8. Financial impact

9. Summary


20 CLIP risers in operation offshore


■ Sonat

■ Discoverer Seven Seas* 6000 ft 1981

■ Pride International

■ Pride Africa 6300 ft 1999

■ Pride Angola 6300 ft 1999

■ Pride Replacement Riser 2300 ft 1999

■ Pride Spare 6300 ft 2000

■ Transocean/GlobalSantaFe

■ Development Driller I 7500 ft 2002

■ Development Driller II 7500 ft 2002

■ GlobalSantaFe Spare 7500 ft 2003

■ Development Driller III 7500 ft 2009

■ Luanda 7,500 ft 2010

■ TMT

■ TMT1 Platinum Explorer 7,500 ft 2010

* 18 5/8’’ Riser. No longer in service


20 CLIP risers in operation offshore cont’d


■ Aker Drilling

■ Aker Barents 2500 ft 2009

■ Aker Spitsbergen 2500 ft 2009

■ Aker Extension 5000 ft 2010

■ Maersk

■ Developer 10,000 ft 2009

■ Discoverer 10,000 ft 2010

■ Sevan

■ Driller 10,000 ft 2010

■ Quieroz Galvão

■ Olinda Star 2500 ft 2009

■ Gold Star 6600 ft 2010

■ Lone Star 8,000 ft 2010

■ Alpha Star 8,000 ft 2010

■ CNOOC

■ Mandarin Driller 10,000 ft 2010


CLIP risers on order


■ TMT

■ TMT 2 7,500 ft 2011

■ TMT 3 7,500 ft 2011

■ TMT 1 Extension 2,500 ft 2011

■ Grupo R

■ Grupo R 2 7,500 ft 2011

■ Grupo R1 Extension 2,500 ft 2011

■ Atwood Oceanics

■ Osprey 6,600 ft 2011

■ Atwood 11 10,000 ft 2011

■ Sevan

■ Brazil 8,000 ft 2012


CLIP risers on order


■ Frigstad

■ Scarabeo 9 10,000 ft 2011

■ Frontier

■ Bully 1 8,300 ft 2011

■ Bully 2 8,300 ft 2011

■ Maersk

■ Maersk 3 7,500 ft 2011

■ Maersk Spare 7,500 ft 2011


Index









8. Financial impact

9. Summary


Time saving


The time saved in operation has a significant financial impact

CLIP breechlock

Make-up tool (steel bar)

Flanged riser

Hydraulic torque wrench

versus


Financial gain with CLIP connector compared with

conventional flanged riser


■ Consideration to estimate 25 years operational cost saving between flanged and CLIP

riser:

Rig rate per year

Number of trips per year

Annual savings

25 years saving

Rig rate per day Water

depth

Total No. of

joints run

Flanged risers run per

hour

100’ lengths

Total flanged

riser time &

costs per trip

CLIP risers run

per hour

100’ lengths

Total CLIP riser

time & costs per

trip

Total CLIP

savings per

tripRig rate per hour

$450 000 10 000 133 2.5 joints per hour 53.20 hours 7 joints per hour 19 Hours 34.2 Hours

$18 750 $997 500 $356 000 $641 000

Rig rate per year Number of trips per year Estimated annual savings Estimated 25 year savings

$164 250 000 4 $2 560 000 $64 100 000


Index









8. Financial impact

9. Summary


Summary in brief


■ This breech locking mechanism is designed to offer the operators a means of saving

substantial make up time, as compared to a conventional flanged-type riser joint, with

total safety when drilling in deep waters

■ Average make-up time to make up the pin/box connection of the CLIP riser is 11

seconds. The two connectors are stabbed together and the locking ring is rotated 45

degrees

■ Most secure connection: fully opened or closed positions only

■ Key safety feature: minimizes dropped object as no bolts are used to make up theconnection between the two joints

■ Field experience has shown that six to eight joints can be run per hour

■ No threading, bolting or preloading

■ Easy stabbing even with misalignment

Operational time savings and safety enables financial benefits

© 2012 Aker Solutions part of AkerJuly 2012 Drilling risersSlide 71

Thank you very much for

your attention


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Drilling risersJuly 2012Slide 72

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Deep water marine drilling CLIP riser - Presstogo