Marketing Presentation – R4 2009Page 1 SKDP N-Class Jack-Up Unit Drilling/Production N-Class Harsh...

Marketing Presentation – R4 2009

SKDP N-Class Jack-Up UnitDrilling/Production

N-Class Harsh Environment Jack-up Drilling/Production

N-Class Harsh Environment Jack-up Drilling/Production


Company Background

Rig Concept and Design

Operations Management

QHSE

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SKDP CLASS-N JACK-UP UNIT SKDP CLASS-N JACK-UP UNIT

TABLE OF CONTENT

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SKDP established September 2006 and located in Kristiansand, Norway.

31% owned by Skeie Technology AS, 12% by Wideluck Enterprises and 57% by external investors (Post financial restructuring in July 2009).

Signed contract for design and construction of three KFELS Class N Jack-up Unit with delivery in 3Q and 4Q 2010, and 2Q 2011.

OTC listed in Oslo.

Operational Management: Skeie Rig Management.

COMPANY BACKGROUND COMPANY BACKGROUND

COMPANY INTRODUCTION – SKEIE DRILLING & PRODUCTION


Skeie Technology AS

SKDP

SKDP1 SKDP2 SKDP3

Skeie RigManagement AS

(ex Offshore Production Services AS)

Norsupply AS

Pier Offshore Management

Services AS

OSM Consultants AS

Business Management Agreement

Head Management

Agreement

Sub Management

Agreement

Supervision Agreement

Sub Supervision Agreement


COMPANY SET-UP



KEY COMPANY STRUCTURE

Skeie Drilling & Production ASA

(Kristiansand, Norway)

SKDP Project Management/Project Supervision Group

(Kristiansand, Norway; KFELS Shipyard, Singapore; Sub-Contractor Manufacturer

Yards)

Skeie Rig ManagementGroup (Onshore)

(Trondheim, Norway + Local Base Office)

KFELS Shipyard Singapore(Engineering / Construction)

Rig Offshore Organisation

Sub-Contractor Manufacturer Yards

(Engineering / Construction)



SKDP – PROJECT ORGANISATION

SKDP OPERATIONWilly TørhaugDag Eggan

MARKETING & SALES

Stein Eggan

Oil Company

HSE ADVISORDag Eggan

QA/HSEJan Brataas

TECHNICAL MANAGER

Helge Skeie

PURCHASEJens Ugland

DOC.CONTR./SEC.Beate Austefjord

STRUCTUREArne Tønnessen

MARINE/ACCOM.Arnt Henriksen

HULLArnt Henriksen

JACKING SYSTEMMorgan Tønnessen

MACH.SYSTEMSStein Anderssen

MACHINERYStein Anderssen

POWER SYSTEMHalvor Flatland

COMMUN. / INSTR.Keesoon Woon

El./INSTR.Halvor Flatland

DRILLING EQUIPYngve Kristiansen

MUD SYSTEMKnut Bakke

PIPINGTBN

DRILLINGTrond Standal

SITE MANAGERMark Aitken

SITE TEAM

Vetco Aibel AS

PRODUCTION

OSM Offshore AS

FSO

SKDP PROJECT TEAMTom Mikkelsen

Skeie Drilling & ProductionTomas Norrby


FORMAL HANDOVERDELIVERY ACCEPTANCE

PROJECT GROUPPROJECT GROUP

Supervise the engineering, construction, documentation and delivery of the Rig:

Fully commissioned

Documented

Certified (Flag State and Class)

Ready for Operations

OPERATIONS GROUPOPERATIONS GROUP

Prepare Operational Documentation

Prepare Maintenance Procedures

Prepare Acceptance Criteria

Assist Project and Verify Operability

• System by system

• Area by area

Accept and Operate

Coastal Authority Certification (PSA)

Client Interface

COMPANY BACKGROUND COMPANY BACKGROUND PROJECT INTERFACE – RESPONSIBILITY AND MANDATE


Company Background



QHSE

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Self-Elevating Drilling Unit (KFELS Class N)

Harsh Environment North Sea and Canadian waters

High pressure/high temperature deep well GoM

Extended reach and transverse skidding of Drill Floor

Combined drilling & production facilities

10 wells tie back or sub sea completion with production module installed

Subsea well completion with HP riser and dry BOP over large subsea template – 75 ft long x 66 ft wide

Large Subsea X-mas tree (45 mt) handling through Cantilever hatch 5x6m

Operations in 122 meters water depths. Optional 131 meters with 30 ft. leg extension.

Drilling depth up to 35,000ft (10,667M) Set Back.

Derrick 1100 tons.

Triangular hull with three (3) triangular truss legs each fitted with a spud can with tip at its lower end. The triangular hull is 264 ft. (80.46M) long, 289 ft. (88.09M) wide, and 35 ft. (10.67M) deep at the side.

LQ designed to accommodate 120 persons.

Helicopter deck designed for Sikorsky 61N and S92 helicopter.

RIG CONCEPT AND DESIGN RIG CONCEPT AND DESIGN

SPECIFICATIONS FOR DRILLING AND PRODUCTION OPERATIONS



CONSTRUCTION WORK KEPPEL FELS, SINGAPORE



COMBINED DRILLING AND PRODUCTION OPERATIONS

The Cantilever and Drill Floor can be repositioned 26ft (7.92M) to the Port side of the Vessel, to allow space for installation of a future production process module.

LimitsArea: 12,918 sq ft (1,200M2) Height: 52.5ft (16M)



COMBINED DRILLING / PRODUCTION UNIT WITH STORAGE TANK


Drill Floor located on the substructure above the cantilever.

Cantilever capable of being skidded fore and aft with center line (primary Cantilever position) of rotary up to 75 ft (22.86m) aft of sternIt can be relocated 26 (7,92m) ft to port (secondary Cantilever position)

The Drill Floor can be skidded 20 ft (6.1m) port and starboard of the Cantilever centerline both in primary position and in secondary position

Max operation envelop over a pre-

installed Jacket/Wellhead Platform:75 ft aft of Transom, 20 ft to starboard of hull centerline and 46 ft to port of hull centerline.




The Cantilever and Drill Floor can be repositioned 26ft (7.92M) to the Port side of the Vessel, to allow space for installation of a future Production Process Module. 12,918ft2 (1,200m2) in area and 52.5ft (16m) maximum in height.

With the cantilever/drill floor in offset position with 10 wells tie back (1500 ton tension)

Row no. 1 - 5 wells 12 ft aft of transom

Row no. 2 - 5 wells 20 ft aft of transom

With cantilever in secondary position and no production module installed a total of 12,918 square ft (1200 square m) free main deck area is available in one common space. (Page 16)





CANTILEVER FOOTPRINTS



DESIGN OPERATING CONDITIONS – STANDARD DRILLING MODE

Design Operating Conditions Design Storm Survival Conditions Parameter Imperial SI

Leg Length 596.0 ft 182 m

Water Depth 430.0 ft 131 m

Maximum Wave Height 68.0 ft 20.72 m

Corresponding Wave Period 15 sec 15 sec

Maximum Wind Velocity (1-minute average)

70.0 knots 36.01 m/sec

Current at Surface 1.940 knots 1.00 m/sec

Current at Mid-Depth 0.486 knots 0.25 m/sec

Current at Seabed 0.486 knots 0.25 m/sec

Air Gap 69.0 ft 21.03 m

Penetration 10.0 ft 3.05 m

Weights:

- Elevated Hull Lightship Weight* 34,800 kips 15,785 MT

- Maximum Combined Drilling Load**

3,000 kips 1,361 MT

- Maximum Variable Load (Including Combined Drilling Load)

10,000 kips 4,535 MT

- Total Elevated Load*** 44,800 kips 20,320 MT

Parameter Imperial SI

Leg Length 596.0 ft 182 m

Water Depth 430.0 ft 131 m

Maximum Wave Height 90.22 ft 27.5 m

Corresponding Wave Period 17.4 sec 17.4 sec

Maximum Wind Velocity (1-minute average)

88.31 knots 45.4 m/sec

Current at Surface 2.624 knots 1.35 m/sec

Current at Mid-Depth 1.128 knots 0.58 m/sec

Current at Seabed 1.011 knots 0.52 m/sec

Air Gap 69.0 ft 21.03 m

Penetration 10.0 ft 3.05 m

Weights:

- Elevated Hull Lightship Weight* 34,800 kips 15,785 MT

- Maximum Combined Drilling Load**

700 kips 318 MT

- Maximum Variable Load (Including Combined Drilling Load)

7,000 kips 3,175 MT

- Total Elevated Load*** 41,800 kips 18,959 MT


Source: Company, ODS Petrodata

MSC CJ70-X150A 1)

DNV492

40,000

291/336/38

673

90

15,000

46,793

15,7234,600

1 000 tons/2x1150 HP3

14,4845,200120

RIG DESIGN Keppel N-Class MSC CJ70-X150A MSC CJ62-S120Class DNV DNV DNV

Operating water depth (ft) 400 (430) 492 380

Drilling depts (ft) 35,000 30,000 30,000

Hull size (ft) (LxBxD) 264/289/35 291/336/38 256/296/35

Leg length (ft) 598 673 541

Cantilever outreach (ft) 75 90 60

BOP (psi rating) 15,000 15,000 15,000

Mud Pumps 3 (space for 4) 4 3Liquid mud capacity (bbls) 6,600 6,793 5,400Bulk mud capacity (bbls) 15,892 15,723 14,027Drawworks (hp) 4,600 4,600 3,000Top Drive 1 000 tons/2x1150 HP 750 tons/1150 HP 750 tons/2x1150 HPCranes 3 3 3Main Power(hp) 13,050 14,484 6,880Variable Deck Load (st) 4,535 4,600 3,693Accomodation 120 120 115

1) Enhanced version of the existing CJ-70 design with increased drilling depth, increased variable deck load and 1000 t top drive.


TECHNICAL COMPARISON WITH PEERS


SKDP Units Typical Premium Unit (1)

Typical Premium Unit (2)

Typical 116-C Typical L-780

Design N-Class (KFELS) MOD V B

(KFELS)

Pacific Class (BM) LeTourneau 116-

C

F & G - L-780

Mod II

Delivered 2010 2006 to 2009 2006 to 2009 1979 1982

Operating Water Depth 500 ft + (1) 350 ft 375 ft 350 ft 300 ft

Leg Length 598 ft 480 ft 506 ft 477 ft 340 ft

Hull Size (L/B/D) 264/289/35 ft 234/208/25 ft 240/224/28 ft 243/201/26 ft 180/175/25 ft

Drilling depth 35,000 ft 30,000 ft 30,000 ft 25,000 ft 20,000 ft

Cantilever Outreach Transverse Envelope

75 ft66 ft

70 ft40 ft

70 ft40 ft

47 ft24 ft

40 ft25 ft

BOP Stack 18 ¾” - 15,000 psi 18 ¾” - 10,000 psi 18 ¾” - 15,000 psi 13 5/8” - 10,000 psi 13 5/8” - 10,000 psi

Mud Pumps 3 x 2,200 hp(space for 4)

3 x 2,200 hp 3 x 2,200 hp 3 x 1,600 hp 3 x 1,600 hp

Liquid mud cap. 6,600 bbls 3,500 bbls 4,100 bbls 1,500 bbls 2,100 bbls

Bulk capacity 15,900 cuft 11,100 cuft 11,300 cuft 8,160 cuft 8,000 cuft

Draw works 4,600 hp 3,000 hp 3,000 hp 3,000 hp 2,000 hp

Top Drive - Rating 1,000 T 750 T 750 T 750 T 500 T

Variable Load (Drilling) 5,000 T 3,750 T 3,750 T 3,900 T 2,400 T

Main Power 13,050 hp 9,275 hp 10,750 hp 6,600 hp 4,950 hp

Accommodation 120 110 115 106 98

(1) Depending on actual location criteria and leg extensions


TECHNICAL COMPARISON OUTSIDE NORTH SEA



OPTIMISED DRILLING EQUIPMENT

Derrick model SSBN 1100-40X40X180

Crown block/Traveling block 1100 sh. Tons 72” diameter 2” groves.

Top Drive Model HPS 1000-2E-AC-KT Torque 78450 ft. Lbs. continious

Retractable Dolly for Top Drive

Drawworks 1100 sh. Ton 16 lines 4XAC GE motors with regenerative braking + disc brakes for parking and emergency brake

1000 sh Ton Rotary support table 49 ½”, Max 15 rpm / 45000 ft.Lbs. at 5 rpm.




Dead line anchor 160 kip. Floor mounted Rotary slip

Dual Hydraulic catheads with commen control panel

Pipe Racker 10 ton lifting capacity. Parallel racking of 90 ft stand. Off line Stand building capability for DP, DC and Casing.

Fingerboard: 35.000 ft racking capacity. DP- 273 st. of 5 7/8” and 108 st. of 6 5/8”, 10 st. of 9 ½” DC, 22 st. of Casing 9 5/8” or 14 st. of Casing 13 3/8”

Belly Board for 190 stands locking latch for each pipe slot.

Stabbing basket/work basket 250kg swl.




Drillers Cabin elevated 2 m with 2 chairs and Cyberbase operation stations.

Catwalk machine with remote control from DCR or Drill floor and tail in /out arm for transport of DP, DC and Casing up to 36” OD to rotary, separate pull back winch on Catwalk structure

Drill floor Manipulator Arm with remote control from DCR or Drill floor for DF handling and tail in operations of large tubular

Pipe handling crane Working radius 25 m. SWL 5.5 Mt.

3 x 5t utility winches with remote control, installed in Derrick level at level 4

1 x Derrick Man rider winch with remote control, installed in Derrick level at level 4

Iron Roughneck type Wellquip (JIM)



WELL CONTROL EQUIPMENT

Surface 18 ¾” BOP Shaffer 18-15M

- 1ea spherical 10 K

- 1 ea pipe Ram 15 K

- 1ea. Shear Ram 15 K with Booster for max shearing capacity

- 2ea. Pipe Ram 15 K

- 2ea.3 1/16” 15 M type DB valve Hydraulic operated

- 2ea 3” 15 M type B valve manually operated

Koomy Hydraulic Power Unit

- Remote control of HPU functions from Drillers panel and Tool Pushers panel

- Emergency remote operating panel located in central control room

- 3000 psi. working pressure

- Accumulator capacity to meet API 16D and PSA requirements




Choke & Kill Manifold 15 K

- 2ea Remote operated chokes from Drillers Cabin

- 2ea. Manual operated choke

1ea. Poor boy degasser 12” went line to top of derrick and 20’’ U-tube

2ea. Swaco CD 1400 degasser with blower

Vetco KFDJ-500 Diverter System

Equipped with 20’ “U-Tube” for HPHT NORSOK D-001



EQUIPMENT IN CANTILEVER

BOP Overhead Crane with 2x75 T SWL The two hoist beams are split to operate 75 T of each side of the well centre. For lifting of the BOP or sub sea X-mas Tree, the 2 hoists beams run simultaneously.

2 x120 t BOP skid to handle BOP or X-Mas tree from landing area to BOP Crane working area, or onto BOP 130 t trolley

1 x Cellar deck opening 130 t BOP trolley with 60 ½” opening through

1 x Cellar deck transverse moving and telescopic work basket

1 x Cellar deck Man rider winch with remote control, installed in cantilever

2 x 5 t utility winches with remote control in Cellar deck

Conductor Tensioning System 318 MT capacity fold down conductor tensioning platform (centre 20 feet aft of hull)

Riser Tensioning System 318 MT capacity – 4 cylinders installed below Drill floor

BOP tensioning system 140 MT capacity – 4 cylinders installed below Drill floor



MUD CIRCULATING SYSTEM

3 x Mud HP pumps 7500 psi. Model NO 14-P-120. 2200 HP/2 GE AC motors and Centrifugal pumps arranged for charging.

5 x VSM 300 dual deck Shale Shakers.

2 x centrifugal mixing pumps arranged with manifold for simultaneous mixing in active pits and reserve pits

Power and piping provided to delegated place for Centrifuge.



MUD PIT CAPACITIES

Length Width Tank Height Height at Usable Volume Usable Volume Allowance Net Volume

in mm in mm in mm in mm in3 m3 bbl % m3

Mud Pit No.1 216,0 5486 180,0 4572 197 5004 186 4724 7231680 118,5 745 5,0 112,6

Mud Pit No.2 216,0 5486 180,0 4572 197 5004 186 4724 7231680 118,5 745 5,0 112,6

Mud Pit No.3 216,0 5486 180,0 4572 197 5004 186 4724 7231680 118,5 745 5,0 112,6

Mud Pit No.4 216,0 5486 180,0 4572 197 5004 186 4724 7231680 118,5 745 5,0 112,6

Mud Pit No.5 288,0 7315 180,0 4572 197 5004 186 4724 9642240 158,0 994 5,0 150,1

Mud Pit No.6 288,0 7315 180,0 4572 197 5004 186 4724 9642240 158,0 994 5,0 150,1

Mud Pit No.7 288,0 7315 138,0 3505 197 5004 186 4724 7392384 121,1 762 5,0 115,1

Mud Pit No.8 288,0 7315 138,0 3505 197 5004 186 4724 7392384 121,1 762 5,0 115,1

Slug Pit 96,0 2438 84,0 2134 197 5004 186 4724 1499904 24,6 155 5,0 23,4

Pre-Mix 96,0 2438 84,0 2134 197 5004 186 4724 1499904 24,6 155 5,0 23,4

Pill Pit 96,0 2438 84,0 2134 197 5004 186 4724 1499904 24,6 155 5,0 23,4

Total 1106,1 6957 1050,8



BULK TANKS (P TANKS)

Five (5) mud tanks each of 1875 cu ft (50 m3) and four (4) cement tanks each of 1875 cu ft, (50 m3).

Operating pressure of 60 psi and bulk material specific gravity 2.163.

Mud additive system with skid mounted sack cutting unit, big bag unit, liquid additive skid, high rate mixer, HP mud share unit, density control unit and caustic mixing unit.



TANK CAPACITY

Tank Capacity: Total capacity

Fuel oil (3 tanks) 880 m3

Base oil tank 330 m3

Brine oil (2 tanks) 782 m3

Mud pit 1050 m3

Mud contaminated tank 10 m3

Drillwater (2+8 tanks) 6094 m3

Fresh water (2 tanks) 831 m3



DECK LOAD PLAN

• Canteliver Pipe Rack (800 kips) 363 ton 2637 kg/m2

• Total setback area (1200 kips) 544 ton• Drillfloor working area 1953 kg/m2

• Drawworks house top 459 kg/m2

• Main deck (outside pipe rack) 2075 kg/m2

• Pipe rack (Main Deck) 2637 kg/m2

• IWO Production module 3330 kg/m2

• Quarters deck & plan 459 kg/m2

• Loading platform 1318 kg/m2

• Emergency Generator room 459 kg/m2

• Helideck is designed for Sikorsky S61 and S92 Helicopters in accordance with CAP 437



RIG CRANES

1 ea. Electro hydraulic driven Deck crane starboard aft.Certified for Zone 1, compliance with PSA/NMD regulation. SWL 50 Mt @ 36 m SWL 38,1 Mt. @ 46m

2 ea. Diesel engines driven Deck cranes port side and starboardCompliance with PSA/NMD regulations.1 off SWL 50 Mt @ 36 m / SWL 38,1 Mt @ 46m1 off SWL 50 Mt @ 20 m / SWL 14,5 Mt @ 46m



WELL TESTING PROVISIONS AND AREAS

Well Testing Area assigned starboard aft between aft leg and cantilever (area approx 7,5 x 9,0 meters)

Two burner booms will be installed on each side

Piping System

1 off 4" line, 10.000psi (1700 bar), HP line from DF to well test area

1 off 6” line, 1500 psi (260 bar), gas line from well test to each burner boom

1 off 4” line, 1500 psi (260 bar), oil line from well test to each burner boom

1 off 4” line, cooling water line to each burner boom

1 off rig air line each burner boom


• Space provision on main deck for Production Process and Utility Module

• Fire Water/Deluge System interface to future Process Module;To provide sufficient fire water and deluge capacity for both rig and process module systems, the following arrangements is provided for:

Rig fire ring main to accommodate the full fire water flow based on total required flow rate of 1800 m3/h Provide additional guides on legs for three future raw water pumps based on two guide pipes per leg. Accommodate space for addition self contained future fire water "containers" that also has a generator

included to drive the dedicated raw water/seawell pumps for each fire pump unit. There will be space for 3 containers each drawing from a separate leg and tying into the firewater ring main.

Connection points in the fire water ring main for supply and off take of firewater Space for future piping to fire water pump containers

• Structural strength; The hull reinforcements are based on a weight of Production Process and Utility Module of maximum wet weight of 3,500 MT. The Weight of the Utility Module of 1500 MT and Process Module of 2000 MT were used to define the supports. If there are any changes of the Production Module weights, distribution and the Support foot print position, a re-assessment of the hull support interface will be required.

• Cooling water supply to production plant;

Guides provided for the three additional future raw water pumps for cooling water based on two guide pipes per leg. A seawater cooling line of 20” is installed and based on 2000m3/hr flow rate.


PROCESS MODULE FACILITATION - KEY ARRANGEMENTS DONE


• Rig strengthening for Wellhead Platform for the Production Risers;The hull is designed to support the risers and wellhead platform at the transom. The wellhead platform connection to the transom will be provided at four locations vertically on both sides of the wellhead platform in way of the eight connections. Pin connections are assumed Reinforcement is based on 1500 tonnes Risers load and 300 tonnes Wellhead self-weight.

• Arrangements for Drilling Rig ESD system to communicate with the Process Module ESD system;Rig ESD comes with provision to transfer 20 signals via hard wire to Process ESD systems including cabling work. ESD panel is be expandable.

• Control Room Integration for Process Module;Four (4) cable tray of 600mm width, 200m length is catered for instrument cables coming from the process plant to the Central Control Room.

• Space/facility arrangements for Emergency Switchboard Power for Production Unit (e.g. lighting etc.) based on PROD (N) Requirements;A 100kW Power feeder from Emergency Switchboard for Process Module is provided.

• Compressed Air/Instrument Air supply to Production Module area using existing rig air system/compressors; One 3” service outlet with shut off valve is provided for next to the future Process Module.

• Communications System – PA/GA;Rig PA/GA is provided with following speakers, telephones and stations.

– PA/GA Speakers ea 10

– Telephones ea 6

– General Alarm Stations ea 10


KEY ARRANGEMENTS DONE


• Fuel oil supply to process area;A 2” service outlet with shut off valve is provided next to the future Process Module.

• Arrangement for service utilities in process area – 230 V / 480V;3 X 230 V outlets and 3 X 480V outlets taken off from the nearest power panel next to the future Process Module are provided.

• Arrangements for Fresh/Sea Water supply to process area;2” FW & SW service outlet with shut off valve are provided next to the future Process Module.

• Starboard aft crane is certified for use in Hazardous Area Zone 1 (i.e. over and next to the future Process Module).


KEY ARRANGEMENTS DONE


• The process system is generic designed for two types of concepts:– Oil fields which require a one stage separation of liquid and gas before export to an existing oil processing

plant.– Oil fields which require a two stage separation to stabilize the oil for export to an oil tanker.

• The topside process facility is divided into different module areas:

Process Module:– Production Manifold– Oil Separation– Gas Compression– Water Injection– Produced Water Treatment– Chemical Injection– Fuel Gas System– Seawater Filtration

Utility Module:– Power Generation– Heating Medium– Nitrogen Generation

• Flare KO / Closed Drain Drum Skid– Flare/Closed Drain System

• Flare Tower


DESIGN BASIS


Medium Capacity (1) Unit

Oil Production 30 000 BPD

Total Liquid Production

50 000 BPD

Water Production

20 000 BPD

Water Injection 20 000 BPD

Total Gas Production

50 000 MSCFD

N-Class facility


BASIC PROCESS CAPACITIES

1) Subject field specific evaluation



OVERFALL PRELIMINARY TOP VIEW


Subsea storage tank (steel / concrete)

FSO

Offloading to shuttle tanker


OIL STORAGE AND EXPORT SOLUTIONS


Company Background



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• Skeie Rig Management AS (SRM) established in Trondheim in 2008 as a wholly owned SKDP subsidiary.

• SRM will be responsible for all rig operations after delivery from yard.

• Key onshore and offshore management positions and section leaders already recruited.

• Pre-operations activities ongoing– Training and competency development

programs under development– QHSE management systems established.– Maintenance systems.– Logistics (spare parts)

OPERATIONS MANAGEMENTOPERATIONS MANAGEMENT

OPERATIONS MANAGEMENT STRUCTURE


Operations Manager(SKDP Units)

SKEIE DRILLING & PRODUCTIONCEO/PresidentTomas Norrby

OPERATIONS MANAGEMENT OPERATIONS MANAGEMENT SKEIE RIG MANAGEMENT – RECRUITMENT AS PER SEPTEMBER 2009

E&I ManagerBjørn Lilleeide

Marine ManagerTBD

Drilling ManagerTBD

Maintenance ManagerTerje Lindrupsen

Personnel Co-ordinator *Kirsti Jenssen

Accounting/Payroll Manager*Ann-Karin-Dullum

Drilling Eq. SpecialistKristian Skagemo

Administration/Doc. Control Randi Damstuen

Technical Support Manager TBD

Supply/Purchasing ManagerStephen Knight

QHSE Manager TBD

* This function may support several units depending on the area of Operations as reflected in Base Organisation structure.

Process Manager(As Applicable)

SKEIE RIG MANAGEMENTManaging Director

Stein Eggan

Business Dev./ MarketingStein Eggan

Human Resources ManagerGeir Bjørsvik

Office Administration ManagerRandi Damstuen

Chief Operating OfficerWilly Tørhaug

QHSE DirectorDag Eggan

Finance/Accounting ManagerHeidi Fornes

IT SupportFrank Ådnevik (Enitro)

OWNER / CONTRACT HOLDER

OPERATIONS MANAGEMENT COMPANY

OPERATIONS BASE ORGANISATION

SKDP Rig No. 1Rig Manager

Odd Magnar Johnsen

Ass. Rig Manager(PENDING CONTRACT)

QHSE AdvisorTBD

Supply/PurchasingJohn Larsen

Personal Co-ordinator *

TBD

Technical SuperintendentPer Revheim

Technical Limit Co-ordinator(PENDING CONTRACT)

Rig Accountant *TBD


TBN


Håvard Skagen

Rig Offshore OrganisationOIM

Org. Structure as for Rig No. 1 Org. Structure as for Rig No. 1


Offshore Installation Manager (OIM)Atle Fjørtoft (01.02.09)

Rasmus B. Larsen (01.12.08)

Stability Section LeaderDrilling Sect. Leader (Toolpusher)Kim V. Sørensen (01.12.08)

Rig Operations SuperintendentPeder Andreasen

Kjell Arne Orvik (01.02.09)

Admin.

Medic

Camp Boss

Safety Officer

1+(1) x Storekeeper*

1+(1) x Driller*

2 x Assistant Driller

2 x Derrickman

2 x Pumpman

6 x Roughneck

TourpusherAlaln Hay (01.12.08)

Ole Villefrance (01.12.08)

OPERATIONS MANAGEMENT OPERATIONS MANAGEMENT UNIT OFFSHORE ORGANISATION – AS PER JAN 2009

Stability S.L. II

Permanent Crew Onboard - # 25

Drilling Mode Crew – # 14

Total Crew No. Drilling/Production Mode - # 52

ProcessSection Leader

2 x Process CCR Op.

4 x Process Operator

Production Mode Crew - # 7

Pending Activity Crew – # 6

* Number in brackets (#) indicates additional number for full Drilling or combined Drilling/Production mode activity.

2 x Crane Operator

2+(2) x Roustabouts*

2 x Ass. Crane Operator

Technical Section LeaderBjørn Glørstad (01.01.09)

Henrik Birnbaum (01.12.08)

Ass. Tech. Sect. Leader

Engine Room Op.

Hydraulic Engineer

Rig Mechanic

Motorman

Welder

Electrician

Electrician

Lead E & I Engineer


Company Background



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QHSE MANAGEMENT SYSTEM FRAMEWORKQHSE MANAGEMENT SYSTEM FRAMEWORK

SKDP QHSE POLICY


QHSE MANAGEMENT SYSTEM FRAMEWORK QHSE MANAGEMENT SYSTEM FRAMEWORK

QHSE MANAGEMENT SYSTEM OVERVIEW


QHSE Management System Key Management System Elements

ELEMENT ADRESSING

Leadership, communication and commitment

Top-down-top commitment and company culture essential to the success of the system. Employee participation is a key factor.

Policy and strategic objectives

Corporate intentions, principles of action and aspirations with respect to all aspects of the operations

Organisation, resources and documentation

Organisation and qualifications of people, allocation of responsibility and resources and documentation of sound QHSE performance and Service Quality

Evaluation and risk management

Identification and evaluation of risks, for activities, products and services, and development of risk reducing measures/barriers

Planning Planning the conduct of the work activities, including planning for changes and emergency response

Implementation and monitoring

Performance and monitoring of activities, and how corrective action is to be taken when necessary

Auditing and reviewing Periodic assessments of system performance, effectiveness and fundamental suitability as basis for continuous improvement


INTEGRATED QHSE MANAGEMET SYSTEM MODEL



SUPPORTING CONTROLLING DOCUMENTATION

1) Unit specific “as built” documentation, including P&ID’s, drawings, design philosophies, vendor documentation etc., is not included in the listing of Unit Specific Documentation.

2) Reference is also made to procedure SKDP-QHSE-PRO-001.

Corporate & Area Base Level Unit Specific Level 1)

QHSE MANAGEMENT SYSTEM MANUALQHSE MANAGEMENT SYSTEM MANUALQHSE MANAGEMENT SYSTEM MANUALQHSE MANAGEMENT SYSTEM MANUAL

QHSE MANAGEMENT PROCEDURES MANUALQHSE MANAGEMENT PROCEDURES MANUALQHSE MANAGEMENT PROCEDURES MANUALQHSE MANAGEMENT PROCEDURES MANUAL

ONSHORE CONTINGENCY MANUALONSHORE CONTINGENCY MANUAL(3(3rdrd Line Strategic Management) Line Strategic Management)

ONSHORE CONTINGENCY MANUALONSHORE CONTINGENCY MANUAL(3(3rdrd Line Strategic Management) Line Strategic Management)

UNIT SAFETY BOOKLETUNIT SAFETY BOOKLETUNIT SAFETY BOOKLETUNIT SAFETY BOOKLET

YEARLY HES PROGRAM FOR THE UNITYEARLY HES PROGRAM FOR THE UNITYEARLY HES PROGRAM FOR THE UNITYEARLY HES PROGRAM FOR THE UNIT

Above Corporate Documentation will also apply for local Company Entities including Branch- and Base Offices with local adjustments as required in the QHSE Management Procedures Manual and Onshore Contingency Manual.

Above Corporate Documentation will also apply for local Company Entities including Branch- and Base Offices with local adjustments as required in the QHSE Management Procedures Manual and Onshore Contingency Manual.

POTABLE WATER MANUALPOTABLE WATER MANUALPOTABLE WATER MANUALPOTABLE WATER MANUAL

UNIT TECHNICAL SPECIFICATION UNIT TECHNICAL SPECIFICATION UNIT TECHNICAL SPECIFICATION UNIT TECHNICAL SPECIFICATION

CONTRACT SPECIFIC QUALITY PLANSCONTRACT SPECIFIC QUALITY PLANS(OR BRIDGING DOCUMENT)(OR BRIDGING DOCUMENT)

CONTRACT SPECIFIC QUALITY PLANSCONTRACT SPECIFIC QUALITY PLANS(OR BRIDGING DOCUMENT)(OR BRIDGING DOCUMENT)

OPERATION MANUALS FOR THE UNITOPERATION MANUALS FOR THE UNIT(REF. SEPARATE SLIDE)(REF. SEPARATE SLIDE)

OPERATION MANUALS FOR THE UNITOPERATION MANUALS FOR THE UNIT(REF. SEPARATE SLIDE)(REF. SEPARATE SLIDE)

EMERGENCY PREPAREDNESS MANUALEMERGENCY PREPAREDNESS MANUALEMERGENCY PREPAREDNESS MANUALEMERGENCY PREPAREDNESS MANUAL

SOPEP MANUALSOPEP MANUALSOPEP MANUALSOPEP MANUAL

SHIP SECURITY PLANSHIP SECURITY PLANSHIP SECURITY PLANSHIP SECURITY PLAN

COASTAL STATE REGULATORY CERTIFICATIONCOASTAL STATE REGULATORY CERTIFICATIONAoC / UK Safety Case / CoF / US CG LoI AoC / UK Safety Case / CoF / US CG LoI

(including Key Risk / Working Environment Analysis)(including Key Risk / Working Environment Analysis)

COASTAL STATE REGULATORY CERTIFICATIONCOASTAL STATE REGULATORY CERTIFICATIONAoC / UK Safety Case / CoF / US CG LoI AoC / UK Safety Case / CoF / US CG LoI

(including Key Risk / Working Environment Analysis)(including Key Risk / Working Environment Analysis)

CORPORATE VISIONS AND POLICIESCORPORATE VISIONS AND POLICIESCORPORATE VISIONS AND POLICIESCORPORATE VISIONS AND POLICIES

COMPANY STANDARDSCOMPANY STANDARDSCOMPANY STANDARDSCOMPANY STANDARDS

COMPANY CORPORATE FORMSCOMPANY CORPORATE FORMSCOMPANY CORPORATE FORMSCOMPANY CORPORATE FORMS

MAINTENANCE MANAGEMENT MANUALMAINTENANCE MANAGEMENT MANUALMAINTENANCE MANAGEMENT MANUALMAINTENANCE MANAGEMENT MANUAL

PERSONNEL HANDBOOKPERSONNEL HANDBOOKPERSONNEL HANDBOOKPERSONNEL HANDBOOK

RIG MOVE MANUALRIG MOVE MANUALRIG MOVE MANUALRIG MOVE MANUAL

OCCUPATIONAL HEALTH & SAFETY SERVICESOCCUPATIONAL HEALTH & SAFETY SERVICESMANUALMANUAL

OCCUPATIONAL HEALTH & SAFETY SERVICESOCCUPATIONAL HEALTH & SAFETY SERVICESMANUALMANUAL


TABLE OF CONTENTTABLE OF CONTENT

PART 0PART 0

RIG DESCRIPTION

PART 0PART 0

RIG DESCRIPTION

PART 1PART 1

STABILITY BOOK

PART 1PART 1

STABILITY BOOK PART 2PART 2

RIG EQUIPMENT GUIDELINES & PROCEDURES

PART 2PART 2

RIG EQUIPMENT GUIDELINES & PROCEDURES

PART 3PART 3

DRAWINGS & DIAGRAMS

PART 3PART 3

DRAWINGS & DIAGRAMS

*) Specific manuals containing operational descriptions, instructions and procedures for the operations of the unit’s systems and equipment to be developed and implemented depending on the type of unit (e.g. drilling and/or production unit).

UNIT SPECIFIC QHSE DOCUMENTATION UNIT SPECIFIC QHSE DOCUMENTATION

RIG OPERATIONS MANUALS


Achilles accreditation (Joint Qualification System for the Offshore Industry) achieved for both Sevan Marine and Skeie Drilling & Production based on QHSE Management System framework developed by POMS.

Pre-qualification QHSE audit performed by StatoilHydro 4th June 2008 to assess operational set-up and management system framework against Statoil’s qualification requirements (NORSOK S-006) with only a few minor obeservations identified


QHSE MANAGEMENT SYSTEM ACCREDITATION


Designed, constructed, installed, operated and maintained in compliance with relevant and latest Norwegian Continental Shelf requirements as defined by the Petroleum Safety Authority Norway (PSA)

Compliance based on DNV class requirements, the requirements of the Norwegian Maritime Directorate (as applicable) and additional PSA requirements and will generally follow the recommendations as outlined in “Handbook for Application for Acknowledgement of Compliance”.

For Working Environment, NORSOK standard S-002 specifically applies as design specification.

Above Norwegian Coastal State requirements selected as basis to achieve equivalent or higher regulatory framework for world-wide operations including North Sea, Canada and US waters.


REGULATORY FRAMEWORK / CERTIFICATION


Det Norske Veritas (DNV) Classification with the following class notations:

1A1 Self Elevating Drilling Unit (N)

- Drill (N)

- HELDK-SH

- CRANE

Designed in accordance with the following DNV specifications:

– OSS-101 Rules for Classification of Offshore Drilling and Support Units

– OSS-201 Verification of Compliance with Norwegian Shelf Regulations




The vessel shall be registered in the Panama’ Ship Register and comply with the latest and relevant International Rules and Regulations for world-wide operations including:

Governing maritime regulations for the country the Unit is to be flagged to. The International Maritime Organization’s (IMO) “Code for the Construction of Mobile

Offshore Drilling Unit”, 1989 Resolution A.649(16) (generally known as the 1989 IMO MODU Code)

The International Convention for the Safety of Life at Sea (SOLAS) 1974, 1978 Protocol and later amendments where being referred by the IMO MODU Code only.

The International Convention for the Prevention of Marine Pollution from Ships 1973, 1978 Protocol and later amendments (MARPOL 73/78).

The International Convention on Load Lines 1966, 1988 Protocol. The International Convention of Tonnage Measurement of Ships 1969. International Convention for the Prevention of Collision at Sea. International Telecommunication Union ( ITU) Radio Regulations (1982) ILO 92 and ILO 133 SNAME T&R Bulletin 5-5A Site Specific Assessment of Mobile Jackup Units, May

1944/1977 is only for Site Specific Assessment and not applicable for the current assessment. When applicable, the Unit will have to be re-assessed base on the Specific Site environmental and soil conditions.




Handbook For Application For Acknowledgement of Compliance (AoC) as published by the Norwegian Shipowner’s Association Revision 03 dated July 1, 2006

Norwegian Helicopter Deck regulation BSL D-51 issued by the Norwegian Civil Aviation Authority (equal to Regulation of 22 December 1993 No. 1240 concerning helicopter decks on mobile offshore units (NMD)) and CAP 437 issued by UK Civil Aviation Authority. Where discrepancies are identified between BSL D-51 and CAP 437, BSL D-51 shall apply.

Regulation and guidelines for potable water system and potable water supply on offshore unit issued by Norwegian Institute for Public Health (NIPH) including :

NIPH “Guidelines for Sufficient, Safe and Good Potable Water Offshore” dated 19 December 2005. Regulation of 4 September 1987 No 860 concerning potable water system and potable water supply on mobile offshore units

Electrical standards: IEC standards and other relevant standards as defined within the AoC Handbook.

The Offshore Deck Cranes shall be designed, installed and tested in accordance with the specific requirements for Offshore Cranes as defined directly by the PSA regulations (not NMD) effective at time of signing of this Contract.




Concept Risk and Working Environment Studies performed (Workshop) in co-operation with DNV iaw. principles outlined in NORSOK Z-013 including;

Pre-screening Hazard Review

Detailed Hazard Review

Evacuation Review

Working Environment Review (LQ and Working Areas)

Environmental System design specification review (Zero Discharge)

Performed prior to Contract Agreement for construction, to verify feasibility of concept both against prevailing Regulatory Framework (Norwegian Continental Shelf), ALARP principle for Risk Mitigation and to identify any key cost drivers for the design, construction and operations of the unit.


CONCEPT RISK AND WORKING ENVIRONMENT STUDIES


Initial concept analysis summarized in Concept Analysis Report with specific actions for further follow-up both during the detailed design phase and throughout the phases of construction and into Operations, to ensure risk ALARP and meeting the intention of the specified Regulatory Framework.

Concept Analysis further concluded with assistance from DNV in separate reports for reference during the detailed design phases:

Concept Working Environment Review report

Concept Evacuation Study Report

Concept Risk Analysis Report

Concept Emergency Preparedness Review report

Environmental Design Specification (included in Technical Design Specification)


CONCEPT RISK AND WORKING ENVIRONMENT STUDIES


QHSE MANAGEMENT SYSTEM FRAMEWORKQHSE MANAGEMENT SYSTEM FRAMEWORKDESIGN/CONSTRUCTION RISK AND WORKING ENVIRONMENT STUDIES(As per principles outlined in NORSOK Z-013)

1. Quantitative Risk Assessment Studies

1.1 Concept Risk Analysis

1.2 Design Risk Assessment

1.3 Construction Risk Assessment

2. Evacuation analysis

2.1 Concept Evacuation Analysis

3. Emergency Preparedness Analysis

3.1 Concept Emergency Preparedness Analysis

3.2 Design Emergency Preparedness Analysis

3.3 Construction Emergency Preparedness Analysis



4a. FMEAs, Reliability and Vulnerability Studies – Vital Operating Systems

4a.1 Ballast System

4a.2 DP (Incl. Anchoring and Positioning)

4a.3 Electrical Power Supply

4a.4 Fuel Oil System

4a.5 Drilling System

4a.6 Open and Closed Drains

4a.7 Machinery Monitoring System

4a.8 Ventilation of Electronic Equipment

4a.9 Ventilation of Hazardous Areas

4b. FMEAs, Reliability and Vulnerability Studies – Safety and Emergency Systems

4b.1 Alarm Systems

4b.2 Emergency Communication Systems

4b.3 Well Control System

4b.4 ESD System

4b.5 Ventilation with Damper System

4b.6 Structural Safety Systems, fire partitions etc.

4b.7 Fire Pump System and Fixed fire-extinguishing System

4b.8 Electrical Emergency Power Supply

4b.9 Evacuation System



5. Working Environment and Human Factors Studies

5.1 Kick off meeting and preparation

5.2 WE Program

5.3 Experience Transfer Analysis

5.4 Organisation and Manning Study

5.5 WE Area Limits (WEAL) and WE Area Chart (WEAC) Input

5.6 Arrangements/means of access

5.7 WE Analysis

5.8 Hazardous Chemicals review

5.9 WE Design Review

5.10 Human Factors in work systems

5.11 Psychosocial preconditions Study

5.12 Intermediate Status WE Inspections (fabrication phase)

5.13 As Built Status WE Inspections (commissioning phase) and Non-Conformity Reporting Input

5.14 Follow-up of vendors

5.15 Noise and vibration control

5.16 Constructability

5.17 Material Handling Study

5.18 Illumination study

5.19 Coarse Concept WE Design Review

5.20 Hazardous Chemicals risk assessment

5.21 Outdoor operations/cold stress – Wind Chill study

5.22 Human Factors in crane cabins (per crane cabin)



6. Other Studies

6.1a Helideck Studies – turbulence modelling

6.1b Helideck Studies – temperature gradient assessment

6.2 Lifeboat concept sensitivity

6.3 HSE Program

6.4 Performance Standards for Vital Operating Systems and Safety and Emergency Systems


RISK & WORKING ENVIRONMENT ASSESSMENTSNorwegian PSA Requirements (NORSOK Standard Z-013)

UK HSE Safety Case Reg’s + PFEER Regulations

RISK & WORKING ENVIRONMENT ASSESSMENTSNorwegian PSA Requirements (NORSOK Standard Z-013)

UK HSE Safety Case Reg’s + PFEER Regulations

Coarse Concept Safety EvaluationCoarse Concept Safety Evaluation

HAZID Review Layout ReviewHAZID Review Layout Review

High Level Risk Assessment(Including Fire & Explosion Risk Analysis)

High Level Risk Assessment(Including Fire & Explosion Risk Analysis)

UK Safety Case / Norwegian “AoC”/

Certificate of Fitness etc.

UK Safety Case / Norwegian “AoC”/

Certificate of Fitness etc.

Evacuation, Escape & Rescue (EER) Analysis

Frequency & Consequence of:• Blow-outs• HC leaks - mud system & well test• Ship collision• Dropped objects• Helicopter crash onboard• Fires & explosions• DP failure• Occupational accidents

Rig Design w/DALs

Risk Acceptance CriteriaQHSE Management System

Reliability & vulnerability Analysis (FMEA):• DP system• Emergency power• Ballast system• Fire water/sprinkler• Fire & Gas detection• Control & communication• BOP control system

Input to Operations Manuals/Em. Prep. Manual Input to Emergency Prep. Analysis

Input to Maintenance Criticality Analysis

Verify compliance with regulations Verify compliance with Company Risk Acceptance Criteria

Input to Operations Manuals/Em. Prep. Manual Input to Emergency Prep. Analysis

Input to Maintenance Criticality Analysis

Verify compliance with regulations Verify compliance with Company Risk Acceptance Criteria

Concept Noise & Vibration+ Lighting Evaluations

Concept Noise & Vibration+ Lighting Evaluations

Concept Working Environment Evaluation

Concept Working Environment Evaluation

Noise Prediction Design Study

Noise Prediction Design Study

Noise & Vibration Survey(Sea Trials/Operations)

Noise & Vibration Survey(Sea Trials/Operations)

Working Environment Area Charts

(Design standard requirements)


(Design standard requirements)

Working Environment Assessments vs.


Working Environment Assessments vs.


Lighting Survey(Sea Trials/Operations)

Lighting Survey(Sea Trials/Operations)

Air Quality Assessment (Sea Trials/Operations)

Air Quality Assessment (Sea Trials/Operations)

Ergonomic/MMI Assessment(Sea Trials/Operations)

Ergonomic/MMI Assessment(Sea Trials/Operations)

Final Working Environment Area Charts for rigFinal Working Environment Area Charts for rig

Concept Environmental Evaluation(Zero Discharge Compliance)

Concept Environmental Evaluation(Zero Discharge Compliance)

Lighting Prediction Design Study

Lighting Prediction Design Study

CONCEPT PHASE

DETAILED ENG. PHASE

OPERATIONS

Zero Discharge AssessmentZero Discharge Assessment

Environmental HAZOP Review

Environmental HAZOP Review

Quantitative Risk Analysis(QRA)

Quantitative Risk Analysis(QRA)

PFEER /Emergency Preparedness Analysis

PFEER /Emergency Preparedness Analysis

ISPS Ship Security Assessment + Ship Security PlanISPS Code Compliance

ISPS Ship Security Assessment + Ship Security PlanISPS Code Compliance



PERSONNEL TRAINING AND COMPETENCE SYSTEM

Qualification Requirements for all offshore positions defined and implemented for guidance and follow-up during recruitment and training process.

Training Matrix including both Regulatory Training (Certification and Safety), Vendor Training and In-House Training has been prepared for the new SKDP Jack-up units.

Specific Competency Development & Assurance Procedure for the SKDP Jack-up operations being prepared by Operations Personnel defining the Rig Specific Competency Development Program to be effective for the SKDP North Sea Operations. This includes development of in-house QHSE Management System training packages.

Separate Personnel & Competency Administration system OCS (Onsoft Computer Systems) has been installed and implemented, to provide detailed planning tool for the training and competency development activities and further the actual scheduling, execution and documentation of all training activities to be performed.


Skeie Drilling & Production ASA Skeie Rig Management AS

Tordenskjoldsgate 9 Havnegata 9, BrattøraP.O. Box 1218, Pirsenteret

4612 Kristiansand 7462 TrondheimNORWAY NORWAY

Telephone: + 47 38 04 19 40 +47 73 83 19 80Fax: + 47 38 04 19 41 +47 73 51 05 01

E-mail: [email protected] [email protected]

www.skeiedrilling.com

Marketing Presentation – R4 2009Page 1 SKDP N-Class Jack-Up Unit Drilling/Production N-Class Harsh...

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