Deepwater rig & equipment selection

December 2008 Kingdom Drilling Services Ltd.
Deepwater Rig and
equipment selection
Peter Aird:
Schiedam
December 2008

Kingdom Drilling Services Ltd
Objective
Understand the issues
to Optimize* Material,
Tools, Equipment
systems, Environment,
Personnel & Costs to
construct, manage and
service
safe, effective and cost
efficient deepwater well
operations.

Rig Build Schedule
 Rig Construction
 Pre-engineering work
 2-rig commitment (1Q2008 and 1Q2009 delivery);
 Option for 3rd Rig executed (1Q2010 delivery)
 Owner Furnished Equipment (OFE)
 All OFE equipment/vendors selected prior to December 1, 2005
 3rd Party equipment interfaces completed

Rig Build Process
 Cleary define the work process & environments
 Determine Design, Selection Specifications.
 Evaluate rig requirements to meet Design,
Selection Specifications.
 Select and construct rig type, to design,
specifications to deliver
 sustainable, measureable added value to the work
processes involved.
 Put vessel to work
 Inspect.
 Qualify.
 Acceptance.
Assurance

Operational Area(s)
Primary Market: Brasil, Gulf of Mexico, West Africa and Far East/India
Or Designed for Harsh Environment Areas

Fit For Purpose?
 Speed/Acceleration
 Appearance
 Social Status
 Manufacturer
 Maintenance
 Power
 Functionality
 Reliability
 Operating Cost

7
Operating requirements
 Rig build selection process
 Dual, single activity, offline ability needed?
 Drilling operating environment
 Geological aspects
 Met ocean environment
 Maximum water depths
 Well design & well operations to be conducted
 Drilling, development, completing, work-over,
intervention
 Drilling tools and systems equipment required
 Rules and regulations
 Safety management systems

Rig build design drivers (2)
 Exploration
 Flexibility, Mobility, Speed
 Load Capacity
 Capability in Extreme Conditions
 Development
 Delivers Maximum Value $/bbl
 Completion / Intervention Efficiency
 Dual / Concurrent Operations
 Facility Installation Capability
 Template, manifold, flowline pull-in
 ROV tools and equipment, moon pool
facilities
 Decks pace!, cranes maximum lift

System design requirements?
1. Safer, faster, more reliable
than conventional tools &
equipment
2. Flexibility in operation
3. Redundancy vs. simplicity
4. Cost efficiency vs. safety and
environment
5. Control functions
6. Ease of inspection,
maintenance and repair.

Rig system issues
1. Operating requirements
2. Station keeping
required
3. Marine riser and
tensioner systems
4. BOP and auxiliary
requirements
5. Deck load and
materials capacities

Rig Efficiency / Focus Areas
 Reduced environmental
loads
 Drilling & marine equipment
to reduce dead load weights
 Robust, reliable < flat spot
time
 Simplicity, flexibility,
redundancy in design
 Good I.M.R.
 Yet meet all operational
requirements

Reducing Time & $$’s?
14%
26%
23%
5%
9%
2%
9%
2% 3%
7%
Rig Up
Drilling
Pipe H'dlg/tripping
Circ/Cement
Logging
Coring
BOP
Casing
P-Test
Other

Rig selection considerations?
 Water depth & Operating
environment
 Availability, track record
 Competencies (People!)
 Rig equipment downtime
 Inspection maintenance and repair
 Inventory levels, controls
 Regional, regulatory
compliance
 Upgrades, rig and equipment
issues.

14
Rig Comparisons

15
Water Depth Cost Comparison
Semi submersible costs
Key Systems &
components
Water depth
1,000 ft 10,000 ft
1.Station keeping
- Anchors/winches/chains
- Dynamic positioning/thrusters
- Fuel consumption
$40 million
-
10-20 t/d
-
$85 million
10-60 t/d
2. Marine riser system $5 million $20 million
3. Tensioning System $8 million $15 million
4. Blow out prevention & control
systems
$12 million $25 million
5. Cost of hull (Size and VDL) $150-250
million
$250-350
million
6. Day rate cost $180-350
K/day
$400-600 K/day

Conventional Approach
Large Vessel required for:
 Deckload capacity
 Environmental loadings
 Riser tensioning
Mud/cement storage
volumes
 Positioning system
Dynamic Positioning –
Generators, fuel, thrusters
Anchored – winches,
anchor system weight
Tensioners
Riser
Angle
Anchoring
System
Deck Load
Mud Weight
Currents
Water Depth
Downside
$400.K – $600.K /day

Upgrading Existing Rigs?

Rig data form: SBOP example
Well data time form Downtime
Days on
location
Remarks
Well
On
location
date
Well
area
Water
depth
(>1000m
)
Start of
well
Moorin
g (hrs)
Run
SBOP
(hrs)
TD
TVD
(mtrs)
Spud
to TD
(days)
Pull
SBOP
(hrs)
End of
well
Moorin
g (hrs)
WO
W
(hrs)
Rig
Eqpt
(hrs)
Sub
surfac
e (hrs)
well 1
24/03/200
0Balikpapan 1807 m 39 hrs 1 hrs 4640 m 15 days 1 hrs 38 hrs 0 hrs 3 hrs 0 hrs 23 days2 AHV's
well 2
12/04/200
well 3
23/05/200
well 4
07/06/200
1Brunei 723 m 55 hrs 1 hrs 2168 m 7 days 1 hrs 35 hrs 30 hrs 4 hrs 0 hrs 17 days
23hrs waiting on
loading boat 1 AHV
well 5
24/06/200
1Brunei 1023 m 41 hrs 1 hrs 2832 m 15 days 1 hrs 28 hrs 0 hrs 0 hrs 0 hrs 21 days1 AHV
well 6
11/07/200
1Brunei 836 m 36 hrs 1 hrs 2338 m 5 days 1 hrs 33 hrs 0 hrs 1 hrs 0 hrs 14 days1 AHV
well 7
03/01/200
2Balikpapan 1368 m 30 hrs 1 hrs 3034 m 5 days 1 hrs 23 hrs 0 hrs 1 hrs 0 hrs 11 days
Cantenary system
2AHV's
well 8
14/01/200
2Balikpapan 1711 m 28 hrs 1 hrs 4357 m 15 days 1 hrs 37 hrs 0 hrs 1 hrs 0 hrs 18 daysTaut leg system 1AHV
well 9
01/02/200
2Balikpapan 1553 m 40 hrs 1 hrs 3984 m 15 days 1 hrs 20 hrs 0 hrs 3 hrs 0 hrs 27 days
Taut leg system 1AHV,
DST
well 10
28/02/200
2Balikpapan 1605 m 22 hrs 1 hrs 3877 m 9 days 1 hrs 20 hrs 0 hrs 2 hrs 0 hrs 14 daysTaut leg system 2AHV
Any other relevant rig-related operational aspects:
1452 m 35 hrs 1 hrs 3705 m 11 days 1 hrs 29 hrs 3 hrs 1 hrs 0 hrs 19 days
18

Rig data form: 5th gen drillship
Well data time form Downtime
Days on
location
Remarks
Well
On
location
date
Well area
Water
depth
(>1000m)
DP Ops
Start of
well (hrs)
Run
SBOP
(hrs)
TD TVD
(mtrs)
Spud to
TD
(days)
Pull
SBOP
(hrs)
DP ops
end of
well (hrs)
WOW
(hrs)
Rig
Eqpt
(hrs)
Sub
surface
(hrs)
1 Dec-00Brazil 2483 m 74.0 hrs 4555 m 35 days 43.0 hrs 76.0 hrs 7.0 hrs 44 days
2 Jan-01Brazil 2391 m 51.0 hrs 4641 m 21 days 44.0 hrs 4.0 hrs 23.5 hrs 30 days
3 Feb-01Brazil 1639 m 32.0 hrs 3724 m 23 days 30.0 hrs 30.0 hrs 0.0 hrs 39 days
4 Apr-01GOM 1339 m 46.0 hrs 3303 m 14 days 34.0 hrs 3.0 hrs 18.5 hrs 28 days
5 May-01GOM 1170 m 42.0 hrs 3580 m 37 days 27.0 hrs 40.0 hrs 0.0 hrs 49 days
6 Jul-01GOM 1486 m 36.0 hrs 2398 m 7 days 27.0 hrs 1.0 hrs 0.0 hrs 15 days
7 Jul-01GOM 1281 m 28.0 hrs 3658 m 17 days 25.0 hrs 22.5 hrs 11.0 hrs 0.0 hrs 62 days
8 Sep-01GOM 1551 m 41.0 hrs 4184 m 35 days 26.0 hrs 17.0 hrs 0.0 hrs 43 days
1668 m 43.8 hrs 3755 m 24 days 32.0 hrs 22.5 hrs 22.8 hrs 6.1 hrs 39 days
19

Comparative evaluation
 SE Asia
 Benign environment
 Complex difficult wells
 Little infrastructure
 Support facilities
limited
 Few rigs to select from
 Pre-lay and AHSV
needed to support ops
 GOM 5th Gen Drillship
 Mob –demob costs
 Much higher day-rate
 High equipment
downtime
 Longer on wells
 DP
 Less support
requirements
 More difficult to crew
up for?

New approach?

System and key
operational
considerations

Key work areas (1)
 Drill-floor
BHA and ad-hoc component handling
SIMOPS
 Moon-pool
Conductors, guide, flow bases
Subsea equipment, trees, manifolds etc
SIMOPS

Rig Floor & Moonpool
 Flexibility for pipe
handling, casing,
and riser at rig floor
 Moonpool flexibility
for BOP/riser,
SXTree systems,
concurrent
operations

Drill Floor – Starboard Side
 Main rotary and
drawworks
 Rotary B in
background
 Pipe/casing racking
(aft)
 Vertical Riser
storage (Fwd)

Main Particulars - Moonpool
 NLine Riser tensioner
 Skiddable system to reach
underneath A or B
 Wet store riser hang-off option (stbd
side)
 BOP Handling (stbd)
 BOP & LMRP
 SXTree handling (port)
 Staging area for trees
 Can handle accessory items (EDP,
LRP, tubing spool)
 Underhull Guide
 Guide for each rotary

Kingdom Drilling Services LtdKingdom Drilling Services Ltd2008

Moonpool

Key work areas (2)
 Mud pits and fluids management
BHA and ad-hoc component handling
 BOP’s and marine risers
BOP’s and marine riser operations inter-faces
etc.
 Cementing
 3rd party equipment

Mud pits & fluid management
 LP circulating system
 Fluid storage
 Riser-less drilling, drilling,
completion
 Dual mud system
capability?
 HP circulating system
 Solids control
 Shakers, centrifuge
 Well control
 Degasser, poor boy,
diverters systems

31
Fluids/cement management

Main Particulars – LP Mud
 Pit Design
 Split system; can treat two different
drilling fluid systems simultaneously
 750 m3 (4500 bbls) each
 bulk system can supply at least two
mud surge tanks at the same time.
 Solids control
 Gravity feed
 Split shaker banks to provide reduced
time to change fluids
 Cuttings Handling
 Provision for cuttings drier, blower,
cuttings boxes
 Mud Additive/Mixing system
 Completion Fluids
 Configured for reduced time to change
to completion fluid

BOP/Riser/Well Control
 BOP:
 Hydril 15 ksi 6 ram 2x 10 ksi annulars;
 BOP Controls:
 Hydril Multiplex
 Emergency BOP Controls: Acoustic,
ROV panel
 Riser:
 75’ joint length; Kvaerner Clip Connection
 Service Lines: 4” ID 15 ksi C/K lines; mud
boost line; 2x hydraulic line
 Annular type diverter
 Well Control:
 CK manifold & MGS
 Annular below TJ for handling gas in riser
(Option for future managed pressure
drilling option)

 Diverter and surface capabilities
 Choke and standpipe manifolds
 IBOP devices.
 Subsea BOP. (service, track history.)
 Surface BOP
 No and placement of rams.
 Choke and kill lines
 Instrumentation and control
 Competencies.
BOP systems

Blow Out Prevention Equipment
• Diverter and surface capabilities
• Choke and standpipe manifolds
• IBOP devices.
• Subsea BOP.
• Service, track history.
• No and placement of rams.
• Choke and kill lines
• Instrumentation and control
• Competencies.

Deepwater BOP stack

Deepwater Sub Sea BOP
 15,000psi 18 ¾” Multiplex BOP stack
 6 rams
 Three 4 ½” – 7” VBR
 Two blind/shear
 One casing shear ram
 10K annular’s
 Combination annular lower flex joint
 Temperature and pressure probes and gas
bleed v/v installed under annular.

Subsea BOP Stack issues
 External pressure loading
may exceed capability of
BOP equipment due to
 Total loss returns in wellbore
& riser
 Gas in riser unloading
 Removal and venting of
trapped gas
 During completions
 During production testing
 IADC supplement 3.1.4.13

S.S. BOP controls considerations
 Closing times, working pressures
 ROV intervention
 Accumulator / closing fluid requirements
 Automatic sequencing
 Redundancy vs. simplicity
 Instrumentation & controls
 Back up systems

Control system selection
Water Depth
0 – 2,000 ft
2,000 – 4,000 ft
Above 4,000 ft
Control System
Conventional Hydraulic
System Operated from
Surface
Deepwater Hydraulic Pod
Deepwater
Electro – Hydraulic Pod

SSBOP MUX control system
 Central control unit
 Data logging system
 Driller & Toolpushers
control panels
 Diverter control
 Electro-hydraulic back
up system

Why SBOP?
 Cost
 Optimize drilling operation
 Extends envelope of
existing rigs
 Reduce non productive
time
 Simpler well control

Relative Capabilities of Conventional Subsea BOP's vs Surface BOP's
Day Rate
Operating Water Depth
Dynamically Positioned Capability
Moored Capability
Metocean Conditions
Maximum Closed in PressureTubing Diameter
Hydrogen Sulphide
omplete as a Producer
Production Testing
Riser Fatigue Life
Subsea Capabilities
Surface BOP Now
High
Low
10,000ft
6,800ft
Yes
Not Yet
Canada
SE Asia
15,000psi
Yes
With Caution

Casing & Cementing
 Casing
 Handling, running
 Bulk systems
 Mud & cement
 Cement standpipe
 Cementing equipment
 Cementing operations

45
Cementing Pumps and Mixers
Higher capacity pump
and improved mixer
Cement-mud pump
combination

3rd Party Items
 Optimize equipment layouts for
all field development activities
 3rd Party Equipment (Drlg &
Completion)
 Alliance for most services
 Workshop/reviews with focal points
 Optimize interfaces; Identify
improvement areas (HSE, efficiency)
 Well Test equipment: Power Well
Services
 ROV interface - Oceaneering
 Subsea Trees, Accessories and
Subsea Facility Installation
 Equipment dimensions; Layouts;
Sequences
 3D Animation of rig/Deployment
sequences

Key work areas (3)
 Tensioning and
compensating systems
 Station keeping and marine
systems
 Deck loadings, materials
and logistics management
 To be covered in following
presentation

Questions?

Deepwater rig &amp; equipment selection

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