Deep Driller 8 (DD8) - ABAN MS Cases/DD8/2015 FEB/DD8... · 2015. 2. 12. · DD8 HSE Case ABAN-DD8-HSE Case-Part 2 Part 2 – Facility and Operations Rev 5 Page 1 of 74 1. I N T R

Hard copies of documents are not controlled Document Owner: DD8 Rig Manager

ABAN Singapore Pte. Ltd.

Deep Driller 8 (DD8)

Jack-Up Mobile Offshore Drilling Unit

Health, Safety & Environment (HSE) Case

Part 2 - Facility and Operations

DD8 HSE Case ABAN-DD8-HSE Case-Part 2

Part 2 – Facility and Operations Rev 5 Revision Page

Revision Record

REV REVISION DESCRIPTION DATE

Draft Issued for rig crew review and input July 2010

Rev 0 Issued for ITS CLIENTS review and acceptance August 2010

Rev 1 Client comments incorporated August 2010

Rev 2 Gap Analysis against EDPMO MAH Regulations July 2013

Rev 3 Finalised to EDPMO – Safety Case Contents Matrix: Mobile Facility Dec 2013

Rev 4 Finalised to EDPMO – Safety Case Contents Matrix: Mobile Facility April 2014

Rev 5 Final Iteration- to EDPMO – Safety Case Contents Matrix: Mobile Facility May 2014

Document Control and Validity

The master copy of this HSE Case resides with ABAN Singapore Pte Ltd. under the custodianship of the QHSE Manager. Changes

to this document are subject to control as specified in Procedure ISM 1101.00 of ABAN Management System.

This document is valid for a maximum of four years after the last revision date. Notwithstanding this, it shall be revised as and when

necessary to reflect any significant changes to the Mobile Offshore Drilling Unit (MODU) or its Management System.

Document Approvals

By signing below, the following persons confirm that the contents of this HSE Case are valid for the subject Facility and Operations

described herein.

Copyright 2010

ABAN Singapore Pte Ltd.


Part 2 – Facility and Operations Rev 5 Content Page

TABLE OF CONTENTS

1. INTRODUCTION ............................................................................................................................................ 1 1.1 Reference Sources ...................................................................................................................... 1 1.2 Objective .................................................................................................................................... 1 1.3 DD8 Facility Overview – ........................................................................................................... 1

2. DD8 OPERATIONS- ........................................................................................................................................ 3 2.1 General Operations .................................................................................................................... 3 2.2 Afloat Operations (reference Section 2 of DD8 Marine Operation Manual) ............................. 3 2.3 Elevating and Operations when Elevated .................................................................................. 5

3. FACILITY DESCRIPTION AND OPERATIONAL LIMITS - .................................................................. 7 3.1 Unit overview description and history of operations - ............................................................... 7 3.2 Classification, Certificates, Rules and Regulations ................................................................... 9 3.3 Unit Particulars ........................................................................................................................ 11 3.4 Operational Limits ................................................................................................................... 12 3.5 Main Structure ......................................................................................................................... 13 3.6 Loading .................................................................................................................................... 16 3.7 Environmental Limitations ...................................................................................................... 18 3.8 Power Generation - .................................................................................................................. 19 3.9 Towing Arrangement and Limiting Conditions ....................................................................... 20 3.10 Anchors .................................................................................................................................... 20 3.11 Jacking System ........................................................................................................................ 21 3.12 Skidding Systems ..................................................................................................................... 21 3.13 Major Hoisting and Lifting Equipment .................................................................................... 22 3.14 Mud System ............................................................................................................................. 25 3.15 Blow Out Prevention Equipment ............................................................................................. 26 3.16 Heating, Ventilation and Air Conditioning .............................................................................. 28 3.17 Bilge System ............................................................................................................................ 30 3.18 Deck Drains System ................................................................................................................. 30 3.19 Fixed Fire Fighting Equipment ................................................................................................ 31 3.20 Life Saving Equipment ............................................................................................................ 32 3.21 Fire and Gas Detection Systems .............................................................................................. 33 3.22 Water Maker, Sewage Treatment and Environmental Protection ............................................ 34 3.23 Communication and Instrumentation ....................................................................................... 35 3.24 Hazardous Areas, Inventory..................................................................................................... 37

4. HSE CRITICAL ELEMENTS AND PERFORMANCE STANDARDS ................................................... 39 4.1 Safety Critical Equipment Overview ....................................................................................... 39 4.2 Development and Content of SCE Performance Standards ..................................................... 39 4.3 DD8 Safety Critical Equipment (SCE) .................................................................................... 39 4.4 DD8 / Combined Operations (Drilling and Production) .......................................................... 72

5. HSE-CRITICAL FEATURES ....................................................................................................................... 73

6. TEMPORARY REFUGE ............................................................................................................................... 74

7. HSE-CRITICAL PROCEDURES AND TASKS ......................................................................................... 75 7.1 Safety Critical Procedure (Operations Procedures) ................................................................. 75 7.2 Rig-specific Procedures ........................................................................................................... 77 7.3 Maintenance Tasks .................................................................................................................. 77 7.4 Emergency Procedures and Incident Investigation Procedures ............................................... 78 7.5 Engineering Management / MODU Modification ................................................................... 78

8. REFERENCES ............................................................................................................................................... 80

Attachment A – DD8 Certification Survey Status List (example)

Attachment B – ABAN SHORE-BASE EMERGENCY RESPONSE MANUAL, BRUNEI


Part 2 – Facility and Operations Rev 5 Page 1 of 74

1 . I N T R O D U C T I O N

Deep Driller 8 (DD8) HSE Case documents the systems in place for managing Health, Safety and

Environment (HSE) Hazards and Threats, and for recovering from accidents if they occur, during

normal operation of ABAN DD8 Jack-Up Drilling Rig. This Part 2 of the DD8 HSE Case describes

the drilling unit in terms of its structure, capacities, facilities, safety systems and normal operating

envelope.

1.1 Reference Sources

The bulk of information provided in this Part of DD8 HSE Case, is taken from the drilling

unit’s Marine Operation Manual (Ref. 1), IADC Equipment List (Ref. 2), rig drawings (Ref. 3)

and a 3rd

party rig survey during July 2010 (Ref. 4).

It is important to note and understand that the data provided in this Part 2 of DD8 HSE Case

is provided only in order to support and assist in illustrating the case for safety of DD8. The

data is not definitive and may not be the latest: reference must be made to the latest revisions

of the above documents (Refs. 1, 2, 3, 4) for definitive values of all DD8 limits and

specifications.

1.2 Objective

The purpose of describing the facility within the HSE Case is to demonstrate suitability and

capability of the drilling unit to safely fulfil expectations of planned operations, i.e. to

demonstrate the drilling unit's fitness for purpose. Information concerning the facility’s design,

equipment, and systems is provided, with additional detail for those equipment and systems

that are categorized as HSE-Critical.

1.3 DD8 Facility Overview –

DD8 is a non-propelled, 5th

generation KFELS Super B Class self-elevating independent leg

Mobile Offshore Drilling Unit (MODU), capable of drilling high temperature / high pressure

(HT/HP) oil and gas wells up to 35,000ft deep in water depths of 350ft. DD8 is registered

under the Singapore administration and classed by the American Bureau of Shipping (ABS).

Construction of DD8 was completed in the 3rd

Quarter of 2008, by Keppel FELS Ltd in

Singapore with delivery to the current (2010) owner-operator, ABAN Singapore Pte Ltd. The

triangular shaped welded steel hull is normally supported on the ocean floor by three

independent, triangular truss type legs fitted with spud can footings. The legs are elevated and

lowered independently by means of an opposed pinion, electric rack and pinion jacking system.

DD8 can safely accommodate up to 120 persons - this being the drilling unit’s POB limit, for

which it is equipped with beds and full lifesaving equipment in accordance with the

requirements of the classification society (ABS) and relevant regulatory bodies (e.g. SOLAS).

The internal volume of the hull consists of ballast and storage tanks, engine (generator) room,

compressor room, pump rooms, various machine spaces, workshops and storage spaces.

An Aluminium helideck located at the fwd end of the drilling unit is designed and built to

Class, Regulatory, IMO and CAP 437 rules to accommodate a Sikorsky S-61N or S-92 or

equivalent helicopter.

Within the confines of the Living Quarters (LQ), located on the main deck level are the crew

change rooms, laundries, gymnasium and sickbay. The second level (01 Level) of the LQ

consists of crew accommodation. The third level (02 Level) accommodates the galley, mess

room, TV room and reading room, along with the 4 external lifeboat stations. The fourth level

(03 Level) of the LQ includes the radio room, jacking control room, Offshore Installation



Manager’s (OIM) office, conference room, helicopter briefing room and additional offices and

cabins. The emergency generator module, Fast Rescue Craft, Personnel Basket (FROG)

landing area and various antennae are located on the roof of the quarters.

Aft of the Living Quarters, the cantilever is located on two longitudinal beams, each 30ft off

center-line, allowing for skidding of the cantilever fore and aft. The drilling package is located

at the aft end of the cantilever on transverse beams - allowing for transverse skidding of the

drill floor.

The international nature of ABAN is reflected in the national cross section of those persons

manning the unit. In an effort to secure the best personnel, capable of meeting the expectations

of the company, ABAN recruits personnel from all corners of the globe to draw from the best

the world has to offer in drilling and work over operations.

Unit name : DEEP DRILLER 8

Rig type : Self-Elevating,

Cantilever, Independent Leg,

Jack-Up Mobile Offshore

Drilling Unit, Skid-Off

Capability

Unit / design / shape : KFELS

Super B Class Independent

Cantilevered Triangular Jack-Up

Unit flag : Singapore

Unit classification : American

Bureau of Shipping, A1 Self-

Elevating Drilling Unit, CDS

(2001 Rules)

IMO Certification : Yes

- Which code version : Code for

the Construction and Equipment

of Mobile Offshore Drilling

Units, 1989 with 1991

Amendments

Year of construction : Under

construction – Q1 2009

Construction yard : Keppel FELS

Limited, Singapore



2 . D D 8 O P E R A T I O N S -

DD8 MODU is designed to safely and reliably drill, construct, test and work-over offshore oil &

gas wells, both in open water and on existing production platforms and well jackets. Its primary

designed operations are divided into General Operations, Operations when Afloat, and Operations

when Elevated (‘jacked up’, on location), as detailed in the Marine Operation Manual (Ref. 1) and

briefly described below. Note that operational limits are listed in Section 3.4.

2.1 General Operations

2.1.1 Safe Accommodation of Personnel

DD8 is designed to safely and comfortably accommodate up to 120 persons offshore,

including the core rig operation and drilling crew, client personnel and 3rd

party service

providers (see Part 3 of this HSE Case for details of people and organisation). To this end

the drilling unit operates like a self-contained ‘flotel’, with its fully equipped air-conditioned

living quarters, on board electrical power generation, potable water-making systems, food

storage, preparation and consumption facilities, sewage and waste disposal systems. The rig

is also equipped with extensive internal and external communications equipment and full life

saving equipment for 120 persons, as required by the SOLAS convention (Ref. 5).

Personnel can access and egress the drilling unit normally via helicopter or crane-lifted

personnel baskets (the ‘FROG’ system being the default for DD8). In emergencies, davit

launched life boats, overboard ladders and leg ladders provide additional means of access and

egress to the MODU.

2.1.2 Integrity Maintenance

DD8 is equipped with mechanical and electrical workshops, machine tools, hand tools and

stores for paints, consumable materials and spare parts. All basic topside maintenance can

therefore be carried out on board / at sea.

Docking of the drilling unit is generally only necessary for detailed inspections of the hull

and lower parts of the legs / spud cans (e.g. 5-yearly dry dock Class inspections), and for

structural modifications as may be required from time to time for specific assignments.

2.2 Afloat Operations (reference Section 2 of DD8 Marine Operation Manual)

DD8 is not designed to drill when floating. Operations in this mode are limited to rig moves,

which are split into 2 categories, as briefly described below. Full instructions for these

operations can be found in Section 2 of DD8

Marine Operation Manual (Ref. 1).

DD8 does not have a propulsion system, so it

must be towed between locations by suitable tug

boats (‘wet tow’) or else lifted onto a marine

transport vessel (‘dry tow’). The latter (dry tow)

is a special case, normally limited to long

distance ocean transits and not applicable for in

field moves.

The rig’s main wet towing chains and wires run

from the forward main deck, below the helideck.



2.2.1 Field Transit

Field transit shall be considered a change in location, which required no more than 12 hours

voyage to a protected location or to a location at which the drilling unit could be elevated.

This may be a move of longer duration than 12 hours, provided that at no point during the

voyage, the drilling unit is more than 6 hours from a safe location or from a location where it

may be elevated. For field transit of extended duration, accurate weather forecast with

updates at intervals not exceeding 6 hours are required.

For installed leg length of 486ft:

Wind velocity 70.00 knots

Tip if can at hull baseline 0.00ft

KG Allowable at 16ft draft – spud cans free loading / buoyant 101.08ft / 98.62ft

Load Line Draft 16.00ft

2.2.2 Ocean Transit

Ocean transit shall be considered long moves not meeting the conditions for field transit or

short moves in areas where the weather cannot be accurately predicted.

For installed leg length of 300ft:

Wind velocity 100.00 knots

Tip if can at hull baseline 0.00ft

KG Allowable at 16ft draft – spud cans free loading / buoyant 101.08ft / 98.62ft

Load Line Draft 16.00ft

2.2.3 Moving into a fixed platform

When DD8 reaches its approximate location, it can be anchored at a safe distance before

moving into its final (drilling) position using its 4 main anchor winches and, when necessary

as a precaution, dragging its spud cans along the seabed after ‘soft pinning’.

DD8 fwd stbd anchor and anchor winch

The exact position and orientation of DD8 is measured using the drilling unit’s navigation

systems, and its position relative to fixed platforms is verified by use of a simple laser

distance monitoring tool. Once the correctness of this final position is verified, the drilling

unit commences pre-loading in preparation for elevating (see below).



2.3 Elevating and Operations when Elevated

DD8 is designed to carry out its primary function of drilling wells when it is elevated off the

sea floor on its 3 legs. Instructions for elevating the MODU (‘Jacking up’) are contained in

Section 3 of the Marine Operation Manual , whilst operations when elevated are described,

together with limits and instructions, in Section 4 of the Marine Operation Manual (Ref. 1).

2.3.1 Preparing for drilling

After moving into position, DD8 pre-loads in accordance with the requirements of its Marine

Operation Manual , to settle its legs into the seabed and to verify that the seabed can safely

support the drilling unit’s weight when jacked up.

After jacking up (elevating) to its required elevation, the cantilever is extended out and

‘rigging-up’ for the drilling work is carried out.

2.3.2 Drilling and other well intervention operations

The primary business operations that DD8 conducts may be summarized as:

Drill and secure Wells – this involves:

o Drill floor & Derrick activities, including making up drill strings, handling down-

hole equipment, installing and testing the diverter and BOP, tripping drill pipe and

BHA’s, preparing and cementing casing / liners in hole and performing leak-off

tests, circulating out kicks, carrying out stuck pipe activities and fishing activities.

o Maintaining control over formation pressure, calculating pressures / volumes,

preparing and maintaining drilling fluids, including kill mud, curing losses.

o Well logging activities, using the drill string or wire line.

o Securing cuttings samples and cores.

o Testing the Well (third party) - drill stem tests, production tests.

Well Completion, including:

o Installing completion equipment in Well

o Perforating the Well (third party) with wire line guns or with tubing conveyed guns

o Displacing the Well

Well work over activities, e.g.:

o Pulling old tubing

o Replacing down hole equipment

o Well Stimulation

o Milling (chemical / mechanical cuts)

o Cementing repairs

o Plug and Abandon wells -

o Seal perforations

o Set cement plugs

o Cut and remove casing

Construction support activities:

o Conductor driving



o Heavy lifting

o Mechanical workshop activities

o Utilities supply

o Temporary storage / lay-down of construction materials and equipment.

Refer to Section 3.4 for DD8 operational limits.



3 . F A C I L I T Y D E S C R I P T I O N A N D O P E R A T I O N A L L I M I T S -

This section describes the physical attributes, equipment and operating limitations of DD8. It

includes the class, rules and regulations applicable to DD8 as well as the history of unit operations.

None of the information presented herein is intended to replace that of the source documents, i.e.

References 1, 2, 3, 4 - which remain the source of definitive data and information for DD8.

3.1 Unit overview description and history of operations -

DD8 is a non-propelled, 5th

generation KFELS Super B Class self-elevating independent leg

Mobile Offshore Drilling Unit (MODU). This type of drilling unit is commonly referred to as

a Jack-Up Drilling Rig.

Construction of DD8 was completed in the 3rd

quarter

of 2008 at the Keppel FELS Shipyard Pte. Ltd,

Singapore, for its initial owner,

Deep Driller Invest Pte Ltd. The MODU was

thereafter transferred to its current Owner/Operator,

ABAN Singapore Pte Ltd. – a wholly owned

subsidiary of ABAN Offshore Ltd (AOL). The

original intended DD8 Operator - Premium Drilling

Inc. of Houston, Texas U.S.A, was dissolved around

the time of completion of DD8. For more information

on the history of AOL and its subsidiaries, reference

may be made to

http://www.ABANoffshore.com/aboutus.aspx.

DD8’s first assignment was to India, on contract to

Hindustan Oil Exploration Co. for a two-well contract

in PY-1 Gas Field in the Cauvery basin about 100

miles south of Madras in the Bay of Bengal.

DD8 is inspected and certified by the American

Bureau of Shipping (ABS), a classification society recognized by the Flag State of the

Singapore under whose flag the MODU is registered.

The published ‘Main Dimensions / Technical Description’ of DD8 are as follows (Ref. 2):

Light ship (kips): 28,284 Estimated

Displacement at load line (kips): 34,341 Estimated

Draft at load line (deepest) (ft): 16

Overall length of unit (inc. Helideck) (ft): 310

Hull length (ft): 246

Hull depth (ft): 25

Overall length of unit (inc. Helideck) (ft): 310

Number of legs/length no /(ft): 3 x 486

Leg length available below hull (ft): 429 (with 5 ft reserve)

Type of leg : Triangular Structural Truss Cross Section,

Three Chord Leg Structure

DD8 in Keppel Fells shipyard, 2008

http://www.abanoffshore.com/aboutus.aspx



Plan and Elevation drawings of DD8 are provided below/next page given

Leg spacing (centre to centre):

- Transverse (ft) : 142

- Longitudinal (ft) : 129

Independent leg or mat: Independent Leg

Spud Cans: 3

Spud can diameter/bearing area (ft)/(ft2): 52 / 2,123 per Spud Can

Spud can height (ft): 15 ft + 4 ft can tip

Spud can jetting system yes/no: Yes

- Bottom jets yes/no: Yes, 12

- Top jets yes/no: Yes, 12

Water supply from mud pumps yes/no: Yes – manifold flex hose

Pressure psi: 1440 max

Cantilever or slot: Cantilever

Skid-off yes/no: Yes

Cantilever envelope:

- Drilling envelope (ft)/(ft): 15 ft Centre line (P&S) either side

- Reach aft of transom, from/to ft/ft: 20 / 70 from aft end

- Transverse, port/stbd ft/ft : 15 / 15

Max cantilever load(Combined hook +

rotary + setback) (kips):

2,700 on Centerline at 30 ft. extension

Max rotary load kips: 2,000

Max setback load kips: 1,210

Accommodation for maximum number

personnel no.:

Min of POB

The Rig design life time:

120

20

30 years subject to regular Class

approvals.



3.1.1 Plan Elevation drawing of DD8

DD8 Stbd Elevation View

3.2 Classification, Certificates, Rules and Regulations

3.2.1 Classification Society

The Vessel and its equipment, were built and surveyed during construction in accordance

with the American Bureau of Shipping (ABS) “Rules for Building and Classing Offshore

Mobile Drilling Units”, 2006, including all amendments to these Rules up until the date that

the Builder applied to ABS to class the Vessel. Upon completion, the Vessel bears the

following ABS class notation: A1 SELF-ELEVATING DRILLING UNIT, CDS.

Re-certification surveys are carried out regularly, covering all critical aspects of the drilling

unit structure and equipment. The frequency of these surveys varies between 1 year and 5

years, according to the system being certified – see Attachment A for a list of ABS surveys

and corresponding frequencies for DD8.

3.2.2 Insurance Society

ABAN has appointed GLND (Germanischer Lloyd Noble Denton as its Marine Warranty

Surveyor who are directly involved in our marine rig moves and based on their approvals

only the Rig is moved.



3.2.3 Regulatory Bodies

The drilling unit is designed to meet the following Regulatory Bodies’ Requirements and

International Conventions and Codes:

`The International Maritime Organization (IMO) “Code for the Construction of Mobile

Offshore Drilling Units” 1989 Resolution A. 649(16) (generally known as the 1989 IMO

MODU Code) with 1991 Amendments

The International Convention for the Safety of Life at Sea (SOLAS) 1974, 1978 Protocol

including amendments of 1981, 1983,1988, 1989, 1990, and consolidated version 2001

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 plus amendments

International Convention for the Prevention of Collision at Sea 1972, including

Amendments of 1981, 1987 and 1989

The International Convention of Tonnage Measurement of Ships 1969

UK Civil Aviation Authority, CAP 437 for Helicopter Deck Design only

IEEE Standard No. 45, “Recommended Practice for Electrical Installations on Shipboard

1983”

Singapore Merchants Shipping Regulation, 1997

International Telecommunications and Radio Regulations

ABS Requirements for Compliance with Cranes

“Codes of Noise Levels Onboard Ships” IMO Resolution A. 468(XII).

3.2.4 Certificates

All certificates and statement of fact covering the approval and indicating compliance with

the regulations, as listed in sections 3.2.1 and 3.2.3, are listed below. These include the Class

Certificate, Builder’s Certificate and the IMO Certificate.

All certifications are current and valid at the time of this writing.

Builder’s Certificate

International Tonnage Certificate (1969)

Mobile Offshore Unit Safety Construction Certificate

Mobile Offshore Unit Safety Equipment Certificate

Mobile Offshore Unit Safety Radio Certificate

Mobile Offshore Unit Load Line Certificate

De-ratting of Fumigation Exception Certificate

Navigation Lights Certificate

Classification Certificate for Hull and Machinery

International Oil Pollution Prevention Certificate (IOPP)



Individual Certificates and Data Books (where necessary), for all equipment, components

and systems, which Class and Authorities require of a Drilling Unit

Authority Register of Cargo Gear for all cranes and lifting appliances, other than the

Derrick

MODU Code Certificate (ABS)

Documentation of all stores and loose inventory, including spare parts and consumables.

See also the example survey status report from ABS, included as Attachment A to this Part of

the HSE Case.

3.3 Unit Particulars

Name of Vessel: Deep Driller 8 (DD8)

I.M.O. Number: 8769080

Call Sign: 9V7568

Type of Vessel: Mobile Offshore Drilling Unit (Jack-Up)

Date of shipyard delivery: 2009

Gross Tonnage: 10,200 T

Port of Registry: Singapore

Flag: Singapore

Owner: ABAN Offshore Limited (AOL)

No: 8 & 9, Vikas Centre

S.V.Road, Santa Cruz (W)

Mumbai - 400 054

Phone : 91-22-26616016 / 26615905

Operator: ABAN Singapore Pte. Ltd.

No.6, Temasek Boulevard,

#28-01 to 05, Suntec Tower Four,

Singapore 038986.

(Phone: +65 – 65001300 to 9)

Fax: +65 - 62948540



3.4 Operational Limits

The published operational limits of DD8 are as follows (Ref. 2):

OPERATIONAL CAPABILITIES

Max designed water depth capability (ft): 350

Outfitted max water depth capability (ft): 350

Normal min water depth capability (ft): 30

Drilling depth capability (rated) (ft): 35,000

Leg (spud can) below hull in transit (ft): 0

Max leg length permitted in tow:

- Ocean tow (wet) (ft): 300

-Ocean tow (dry) (ft): 486

- Field tow (ft): 486

Number of tugs for field tow no.: 3, Per Marine Surveyor’s Requirement

Associated min bollard pull per tug lt: Per Marine Surveyor’s Requirement

Anti-roll system yes/no: No

Maximum preload reaction per leg (kips): 15,450

Bearing pressure at max preload (lb/ft2): 10,140



3.5 Main Structure

3.5.1 Hull & Legs

The rig consists of a modified triangular hull with three triangular truss legs; each fitted with

a spud can at the lower end. The welded steel hull is 246ft long, 218ft wide and 25ft in

depth, having a load line displacement of 34,341kips.

The three legs are spaced with the forward leg on the center line of the vessel and the two aft

legs 129ft aft of the forward leg and 71ft outboard of the vessel center line. The spud cans,

which form the lower part of the legs, are circular having a diameter of 52.42ft.

The total leg length, including spud can, is 486ft. Cathodic protection is provided by

sacrificial anodes on the legs and spud cans.

Thrusters yes/no: No

VARIABLE LOAD (VL) CAPACITY

Transit VL capacity (kips): 5,000 (inclusive of set back load)

Drilling VL capacity (kips): 7,510

Survival VL capacity (kips): 5,510

Jacking VL capacity (kips): 5,000

Cantilever pipe rack capacity (kips): 800

ENVIRONMENTAL LIMITS

Transit:

- Max. wave height (ft): N/A

- Max. wave period (sec): 11

- Max. wind velocity knots: 70

- Max. current velocity knots: N/A

- Max. heave (ft): 12

- Max. pitch (single amplitude) degrees: 6 deg single amplitude, Per Marine

Operations Manual, Fig 2.14, and Critical

Motions

- Max. roll (single amplitude) degrees: 6 deg single amplitude

Working Water Depth (ft): 25- 350

Drilling:

- Air gap (below bottom main hull) (ft): 36

- Max. wave height (ft): 40

- Max. wave period (sec): 14

- Max. wind velocity (knots): 70

- Max. current velocity (knots): 1.0 Surface

- Penetration Assumed (ft): 17.5

Survival:

- Air gap (below bottom main hull) (ft): 50

- Max. wave height (ft): 48

- Max. wave period (sec): 14.0

- Max. wind velocity (knots): 100

- Max. current velocity (knots): 1.0 Surface

- Penetration Assumed (ft): 17.5

Working Water Depth (ft): 250



3.5.2 Cantilever Substructure

The cantilever beams, sub base and sub structure are welded structures. The cantilever sits

on two longitudinal steel beams 30ft either side of the centerline. Hydraulic skidding units

allow the rotary table to extend a maximum distance of 70ft aft of the stern when elevated.

The beams are supported at the transom on load bearing pads. This allows the cantilever to

be moved easily and yet provides vertical support at the optimum location while drilling.

The sub base is attached to the upper flanges of the cantilever beams. The sub base includes

two transverse beams, which support the drill floor and derrick. Hydraulic cylinders

facilitate transverse skidding of the substructure, drill floor and derrick 15ft port or 15ft to

starboard of the transverse beam centerline.


Maximum Dist. Of Center of Well over Aft Shell at Fr. 38

(Transom)

21.34 m (70.00 ft)

Center to Center of Cantilever Beams 18.29 m (60.00 ft)

Height of Bottom of Cantilever above Vessel Baseline 8.17 m (26.79 ft)

Height of Substructure (above Main Deck at C.L.) 9.66 m (31.70 ft)

Height of Pipe Rack Deck (above Main Deck at C.L.) 8.62 m (28.27 ft)

Length of Pipe Rack Deck 20.41 m (66.97 ft)

Width of Pipe Rack Deck 19.20 m (63.00 ft)

Travel Fore and Aft 27.58 m (90.50 ft)

3.5.3 Drill Floor


Length 20.81 m (68.29 ft)

Breadth 13.56 m (44.50 ft)

Height above main deck at C.L. 11.70 m (38.40 ft)

Derrick Base 10.97 m x10.97 m (36 ft x 36 ft)

Travel Port and Stbd either side of C.L. 4.57 m (15.00 ft)

3.5.4 Living Quarters (Accommodation Unit)

DD8 Living Quarters (LQ) is a 3-storey integrated steel Accommodation Unit with 3 wings

(Port, Starboard and Aft), containing all the facilities of a small hotel as well as command

and control functions for the entire rig. It is designed to accommodate up to 120 persons

offshore. It is located at the forward end of the main deck of DD8. The aft external walls

and those of critical internal rooms such as the Radio and Jacking Control room, are A60-

rated. The four levels are known as Main Deck, 01 Level, 02 Level, and 03 Level. All four

levels are accessible externally (via external walkways around the LQ) and internally (via

internal stairwells).

Main Deck

Port side consists of laundry, change room, sick bay and coffee room.

Starboard side consists of laundry, change Room, women’s change room and gymnasium.

01 Level

Port side consists of two man accommodation units. Aft is AHU and internal stairwell to all

levels. Forward is external stairwell to all levels.



Starboard side consists of Two Man Accommodation Units. Aft is AHU and internal

stairwell to all levels. Forward is external stairwell to all levels.

02 Level

Port Side consists of two man accommodation units. Aft is internal stairwell to all levels and

AHU, movie room, dish wash room and galley and CG Locker. Forward is external stairwell

to all levels. Two lifeboats are outside, accessible from Forward and Aft.

Starboard side consists of two man accommodation units. Aft is internal stairwell to all

levels and AHU, Linen Locker, Chiller, Freezer, Reading Room and CG locker. Forward is

external stairwell to all levels. Two lifeboats are outside, accessible from Forward and Aft.

The mess room is Aft and central.

03 Level

Port side consists of two man accommodation units, 5-one man accommodation units and the

OIM cabin. Aft is internal stairwell to all levels and AHU, and offices and OIM Office.

Forward is external stairwell to all levels and access to Helideck.

Starboard side consists of two man accommodation units, 3-one man accommodation units

and company man cabin. Aft is internal stairwell to all levels and AHU, company man

office, radio and tracking room and equipment room. Forward is external stairwell to all

levels, two offices, training Room, conference room, Helideck waiting room and access to

Helideck.

04 Level (Roof)

Roof space is a restricted access area, with

ventilation inlets/outlets, communications systems,

UPS batteries storage, laydown spaces and:

Starboard Side - Emergency Generator Room

(Module, accessible only externally).

Aft - Fast Rescue Boat.

Port side - FROG laydown area



3.5.5 Helideck

The platform of the helicopter deck is designed and built to Class, Regulatory, IMO and CAP

437 to accommodate the Sikorsky S-61N helicopter or S-92 or equivalent. The helideck

polygon structure with included circle has a diameter of 22.2m (72.83ft). Additional

information about the Helideck can be found in the Marine Operations Manual.

The ABS refuelling arrangement, consisting of storage, pumping, dispensing and filtering

systems is isolated and not in use and as such does not pose a hazard.

3.6 Loading

Limiting design loads for DD8 are stipulated in Section 1.6 of the Marine Operation Manual,

from which the following figures are replicated.

3.6.1 Design Deck Loads

Pipe Racks 2,636 kg/m2 (540 lbs/ft

2)

Main Deck (Outside Pipe Rack) 2,075 kg/m2 (425 lbs/ft

2)

Drill floor (Working Areas) 1,953 kg/m2 (400 lbs/ft

2)

Drill floor (Set Back Load) 550 tons (1,210 kips)

Helideck 9,253kg + 205 kg/m2

20,400 lbs + 42 lbs/ft2

Quarters Deck 459 kg/m2 (94 lbs/ft

2)

House Top 459 kg/m2 (94 lbs/ft

2)

Mud Pits 8,299 kg/m2 (1,700 lbs/ft

2)

Machinery Spaces 1,328 kg/m2 (272 lbs/ft

2)

Top of Mud Process Area 928 kg/m2 (190 lbs/ft

2)

Sack Stores 2636 kg/m2 (540 lbs/ft

2)

House top access ways 459 kg/m2 (94 lbs/ft

2)

Pipe Rack Beam (Cantilever) 7440 kg/m2 (5000 lbs/ft

2)

3.6.2 Cantilever Drilling Loads

The cantilever and associated structural components will accept a maximum combined total

drilling load of 2,700 kips (1,223 Tons) within the maximum individual component load

limits shown below:

Setback Load 550 tons (1,210 kips)

DD8 Helideck – viewed from LQ Roof DD8 Helideck – viewed from Crew Boat



Rotary Load 907 tons (2,000 kips)

Hook Load 907 tons (2,000 kips)

Cantilever Skimmer Tank 4.5 tons (10 kips)

3.6.3 Cantilever Pipe Rack Deck Load

The Cantilever Pipe rack Deck load limit in drilling position is 800kips. The LCG of this

800kips load is to be a minimum of 69ft forward of well center. The Cantilever Pipe rack

Deck load limit under towing conditions is also 800kips.

3.6.4 Conductor Tension Drilling Load

The conductor tension drilling load of 500kips (227 tons) is supported by the conductor

platform which is not part of the cantilever drilling load. It is located at 20ft aft of transom.

3.6.5 Bulk Storage

‘P’ Tank (Cement) 3 x 58 m3 (2,049 ft

3)

‘P’ Tank (Mud) 2 x 58 m3 (2,049 ft

3)

‘P’ Tank (Gel) 2 x 58 m3 (2,049 ft

3)

Sack Storage Room 5,000 sacks

3.6.6 Liquid Capacities

Lube Oil 11 m3 / 383 ft

3 / 68 bbl

Base Oil 248 m3 / 8,762 ft

3 / 1,561 bbl

Fuel Oil 532 m3 / 18,777 ft

3 / 3,345 bbl

Dirty Oil 8 m3 / 294 ft

3 / 52 bbl

Separator Tank 5 m3 / 179 ft

3 / 32 bbl

Potable Water 326 m3 / 11,525 ft

3 / 2,053 bbl

Drill Water 3,457 m3 / 122,094 ft

3 / 21,746 bbl

Preload (Sea Water) 11,222 m3

/ 396,305 ft3

/ 70,586 bbl

Mud/Slugging Pits 853 m3 / 30,116 ft

3 / 5,364 bbl

Brine 161 m3 / 5,699 ft

3 / 1,051 bbl

(Tank tables are to be found in Appendix B of the Marine Operation Manual)

3.6.7 Pre Load

Pre load is the ballast weight required, to be added to, the variable load to simulate spud cans

reaction to maximum wind and wave conditions. Preloading the Unit tests the soil to the

vertical leg load that would be imposed by the design storm survival condition. Preloading is

required at each location prior to elevating the hull to the desired working air gap.

Required information concerning lightship, variable loads, etc. is to be found in the Marine

Operations Manual. This information along with variable (VCG), longitudinal (LCG) and

transverse (TCG) centre of gravity is necessary to determine the preloading for any particular

location.

The values of pre load requirements for the range of water depths are given in Section 3 of

the Marine Operations Manual.



3.7 Environmental Limitations

3.7.1 Environmental Effects Under Tow

The angle of roll and/or pitch should not exceed those that are shown on the Critical Motion

Curve as defined in section 2.14 of the Marine Operations Manual.

In the event these limits are approached, the tow course and/or speed must be altered as

necessary to keep the Drilling unit’s motions from exceeding the limit.

3.7.2 Environmental Effects when Raising / Lowering the Hull

The hull can only be raised or lowered during relatively calm weather conditions.

Wave height Not to exceed 5ft

Wind Speed Not to exceed 24knots

Current (at surface) Not to exceed 0.5knots

Current (at seabed) 0

Unit Motion (pitch or roll) 0.5 degrees

Allowable sea-bed slope (Soft surface) No limitations

Allowable sea bed slope (Hard Surface) 4 degrees

Seabed Load Bearing Capacity 6.54 kips/ft2 to 26.95 kips/ft

2

3.7.3 Environmental Limitations Elevated

The drilling unit is expected to be lowered, or raised only during relatively calm weather

conditions. The environmental criteria to which this drilling unit has been designed are

detailed below.

Exceeding these environmental limitations will jeopardize the safety of all personnel aboard

and put the drilling unit itself in danger and potentially in harms’ way.

It is the duty of the Rig OIM to ensure that operations remain within the environmental

parameters necessary for safe operations. At any point that environmental parameters for

normal drilling operations are exceeded or environmental conditions are deteriorating to a

point that they will be exceeded, it is the duty of the Rig OIM to take precautions by

suspending normal operations preparing to take precautionary measures as outlined in the

“Storm Survival Mode”.

3.7.4 Storm Survival Condition

Water Depth (ft) 350

Maximum Wave Height (ft) 48.0

Corresponding Wave Period (sec) 14.0

Maximum Wind Velocity (knots) (one-minute average) 100.0

Current – Surface (knots) (profile piece-wise linear) 1.0

Air gap (ft) 50.0

Penetration (ft) 17.5

Total Elevated Load (kips) 25329

(See section 4.4 of the Marine Operations Manual “Storm Survival Mode”



3.7.5 Normal Drilling Condition

Water Depth (ft) 350

Maximum Wave Height (ft) 40.0

Corresponding Wave Period (sec) 14.0

Maximum Wind Velocity (knots) (one-minute average) 70.0

Current – Surface (knots) (profile piece-wise linear) 1.0

Air gap (ft) 36.0

Penetration (ft) 17.5

Total Elevated Load (kips) 27329

(See notes for environment A Marine Operations Manual-1.18)

(See section 4.3 of the Marine Operations Manual “Normal Drilling Mode”)

3.8 Power Generation -

3.8.1 Prime Movers

Five Diesel Wartsilla, model 6L26A2, radiator cooled engines, 2151hp @ 900 rpm, driving

Leroy Somer LSA56VL8R/8P AC generators, located in the engine room aft of the

machinery deck.

3.8.2 Emergency Power

One Diesel Caterpillar, Model 3412 TA, 830hp @ 830 rpm, diesel electric set driving a 480

volt, AC generator having an emergency electrical power distribution panel with interlocks to

the main distribution panel. The Emergency Generator Room is located on the Starboard

roof of the Accommodation Unit.

3.8.3 Rig Air Compressors / Receivers

Two Cold-Start Sperre HL2/77 air compressors rated at

16.5 ft3/min capacity and 435psi.

Three medium pressure (Rig Air) Quincy QSI-500-

AVA3296 single stage rotary screw compressors rated at

494 ft3/min and 110 psi, connected to 1 Ultra Air /

LFE1600-DNS04 Air Dryer, with rated capacity of 1488 ft3/min.

One Low Pressure Quincy QSI-500 single stage rotary screw compressor rated 494

ft3/min and 110psi regulated down to 60psi, connected to 2 Ultra Air / LFE800-DNS13

Air Dryers with rated capacity of 550ft3/min.\

One 240 ft3, 125psi rated

Air Receiver located in the Auxiliary Machine Room,

Starboard Aft.

DD8 Main Engines / Generator Sets and Diesel Fuel piping

Rig Air compressor (Typ)



One 120 ft3, 125psi rated Air Receiver located on the Drill Floor.

One 120 ft3, 60psi rated Air Receiver located in the Auxiliary Machine Room,

Starboard Aft.

3.9 Towing Arrangement and Limiting Conditions

3.9.1 Towing Equipment

Tow gear consists of two 165st towing bits, with Fairleads in line with towing bits. The

towing bridle consists of a 3” chain linked to a 2 ½” wire rope fish plate to a 2 ½” tow line

and a hook up system. The rating of the tow gear is 85MT, with a spare bridle kept on board.

One FA5-16XMK1GPV winch rated at 5MT is used to manoeuvre the Towing Bridle.

The towing arrangement drawing is to be located in Appendix D of the Marine Operation

Manual, drawing # M102-20. As a conceptual drawing only, all towing arrangements must

be verified by the tow master / owner prior to the commencement of any tow.

3.9.2 Preparation for Towing

All towing activities are to be planned; the planning of a tow must be done considering the

following checks;

Stability for the loading condition and / or tow mode

Securing of water tight closures

Sea fastening

Safety gear and lifesaving equipment

Unit has readied for tow according to requirements of Marine Operation Manual

Approval of tow plan by a qualified marine surveyor which is to include;

Tow route

Towing procedures

Weather forecasting

Suitability of Tug(s)

Potential alterations to routing as contingency

Identification of ports or sheltered areas en route

Arrangements for progress reporting

Only after all approvals and procedures have been secured and accomplished should the tow

be allowed to commence.

3.10 Anchors

4-five tons fluted anchors are provided in total, two on the bow (one on the port side one on

the starboard side), and two aft (port and starboard). Each anchor has its own dedicated

electrically powered winch, a Brohl 400Kn with 2500ft of 1½” wire rope with breaking

strength of 1190 Kn.



3.11 Jacking System

The rig jacking system is for elevating and lowering the drilling unit and

is a KFELS rack and pinion model elevating system. The system

consists of a central console, three Motor Control Centers (MCCs), three

local consoles with nine jacking assemblies each or 36 rack & pinion

type jacking units.

The jacking control house is located on the 4th

level (03 Level) of the

quarters in the combined Radio Room and Jacking Control House.

3.11.1 Jack Ratings

Jacks or Pinions - 36

Normal Jacking - 1000 kips

Pre Load Jacking - 1300 kips

Static Holding - 1869 kips

Jacking Speed - 1.5 ft/min

Allowable Motion - 0.5 degrees (single amplitude)

For further details refer to Section 3 of the Marine Operation Manual.

3.11.2 Self Positioning Fixation System

DD8 is equipped with an ABS approved, hydraulically activated fixation system with

hydraulic power supplied by individual HPUs at each leg.

3.12 Skidding Systems

DD8 skidding systems are those systems used to move the

cantilever beams relative to the hull, and the drill floor relative

to the cantilever beams.

The cantilever is intended to be stored on the main hull and

extended aft to a maximum of 70ft over the vessel transom

during operation (Section 3.”Elevated Operation” of the

Marine Operation Manual). The drill floor can be skidded a

distance of 15ft port or starboard of the vessel centre.

A hydraulic skidding system is installed on port and starboard

sides of the cantilever to enable it to be extended from stored

location to operation position and withdrawn from operation

position to stored location.

The cantilever skidding system is comprised of:

Two pumps located on the Main deck.

Four hydraulic cylinders

Skidding control console located on the main deck portside.

The rate of travel for the cantilever skidding system is 1.5ft / min.

The drill floor skidding system is comprised of,

Cantilever jacking system,

looking Aft

Cantilever jacking system,

looking Fwd



Two hydraulic cylinders installed on the forward and aft sides of the drill

Each cylinder is fitted with reversible locking claws

Hydraulic power pack located above the drill floor

A control console located on the Aft side, outside and below the drill floor.

The rate of travel for the drill floor skidding system is also 1.5ft / min.

3.13 Major Hoisting and Lifting Equipment

3.13.1 Deck Cranes

Quantity - 3 (Port Forward, Port Aft and Starboard)

Manufacture - Favelle Favco

Model - Model 7.5/10k

Lifting Speed - Variable

Boom - 120 ft

Lifting Capacities - 10.9 tonnes at max radius

For complete details on the controls, maintenance and operation of the

cranes, refer to the crane operation and maintenance manual. This

manual is the required reading for the crane operating crew and all

personnel involved in crane maintenance.

3.13.2 Derrick

The derrick (NOV SSBN-1060/36-36-170X) has a

base of 36ft x 36ft, a water table (crown) size of 17ft

x 16ft. The travelling assembly is strung up with 2”

OD main hoisting wire on a NOV Hydralift HB-N 8

sheaves on travelling block set up rated at 1060 st.

3.13.3 Derrick Capacity Ratings and Equipment

The derrick is designed to accommodate a setback

load of 550 tons (1,210 kips).

Static Hook Capacity: on 16 part reeving = 2,000

kips

The Derrick is designed to withstand loads and reactions from the following equipment

located and operating within it:

Guide Rails with Top Drive and Retractable Dolly

Crown Block Assembly

Bridge Racker Crane

Derrickman’s Cabin

Fingerboard

Racking board

Casing Stabbing Basket

Manual Racking winches (Qty: 2)

Fwd Port Crane

View looking directly up the Derrick



Stand-building System incl. Guide Frame, Upper and Lower Guide Arm

Rig Tong Counterweight Systems incl. Wire assemblies

Bug Blowers

Sheaves and Snatch Blocks for the utility lines

Derrickman’s Escape Station

HVAC unit.

The Derrick is designed and manufactured to accommodate simultaneous drilling and stand-

building operations.

The fingerboard is approximately 79ft above the drill floor and is equipped to set back

approximately 20,000ft of tubulars as indicted below:

Drill Pipe

57/8 inches OD, S-135, Range 2, XT57 tool joints, 7 inches OD x 4.25" ID, 26.3 ppf

nominal.

Drill collars

Six, 9½" OD x 3" ID, spiral drill collars, Eighteen (18) 8½" OD x 213

/16" ID spiral drill

collars, Eighteen (18) 7" OD x 213

/16" ID, spiral drill collars.

Heavy-Wall drill pipe

Thirty, 57/8" Heavy Weight drill pipe, XT57 tool joints.

3.13.4 Drawworks

The NOV AC electric powered single speed gear driven (SSGD), electrically powered

drawworks located on the drill floor is for the lifting and handling of the drilling equipment.

It is powered by four General Electric GEB22A2 AC motors with continuous ratings of

1,150 HP, 600VAC and 1120A per motor.

For further information, refer to the following:

a) Drwg No. G007-01 General Arrangement – Drill Floor and Pipe Rack Plan.

b) National Oilwell Varco (NOV) Operational and Maintenance Manual for SSGD 4600-

57-82-1015 Drawworks. This manual gives drawings, diagrams, instructions and

operational limits.

3.13.5 Top Drive

Manufacture - National Oilwell

Model - HPS 1000-2E-AC-KT

Motor Rating - 1,150 hp (2 motors)

Capacity - 1,000 short tons

Max. Continuous Torque - 78,450 ft-lbs

Max. Breakout Torque - 115,000 ft-lbs

Max. Makeup Torque - 115,000 ft-lbs

Max. Speed - 280 rpm

Quantity - 1 Top Drive (landed on Drill Floor)



The Hydralift Power Swivel (HPS) system is the top drive system used to rotate and make up

the drill pipe and bottom-hole assembly components. Primary components of the top drive

system include:

Drive System

Rotary Swivel

Pipe Handler System

Control System

Auxiliary System.

The HPS package provides rotating power to the rotary drive, allowing tripping, circulating,

rotating and running casing.

Refer to Top Drive Drilling System Service Manual for detailed specifications and operating

limits.

3.13.6 BOP Handling Hoists

Two JD Neuhaus / JDN-EH50 BOP Handling Chain Hoists are located above the cellar

deck area in the cantilever. Their function is to manoeuvre the BOP stack between the BOP

storage area on the cellar deck port side and the conductor casing at the well center line.

The chain hoists are designed to pneumatically lift, transport and position a BOP stack from

the BOP storage area to the conductor tension platform. Each trolley has a safe working

load of 60MT each.

The trolley hoists are limited to movements within the Cellar Deck area only. The hoists are

only operable when the drilling unit is in the jacked up drilling condition: chain hoists must

be stowed and secured in the storage position at all other times.

3.13.7 Pneumatic Winches

DD8 has a total of nine various types of pneumatic winches for general lifting, handling and

hoisting of personnel. Each is purpose built for the functions intended. Personnel hoists are

dedicated for that purpose only and are fitted with the necessary features of personnel

hoisting devices.

Qty Location Purpose Model Rating

1 Main Deck Towing Bridle FA5-16XMK1GPV 5MT

2 Sub-base Texas Deck Lifting FA2.5MR24MK1G

DP

2.3MT

2 Cellar Deck Utility FA5-16XMK1GPV 5MT

1 Cellar Deck Man Rider FA150KGMR12-1-

E

150kg

3 Drill Floor Stand Building FA5-16XMK1GPV 5MT

1 Drill Floor Personnel Hoisting FA150KGMR12-1-

E/

150kg

1 Pipe Rack Deck Utility FA2.5-8XMK1GPV 2.3MT

2 Monkeyboard Racking Pipe LS2-600R-L-E 600kg

(For compressed air pressure ratings, safe working loads and operational limits. Refer to

the relevant OEM Service Manuals kept onboard DD8).



3.14 Mud System

3.14.1 Pumps

High Pressure Mud Pumps

Three National Oilwell 14-P-220, Triplex GE 752 mud pumps. Continuous power rating

per motor is 1,150 HP. Max working pressure 7,500psi.

Mud Mixing Pumps

2 HALCO 2500 Supreme, centrifugal 6 x 8 x 14, 10”-14” Impeller pumps. Output capacity

1200 GPM (US). RPM 1800. Power Output 100HP.

2 HALCO 2500 Supreme centrifugal 6 x 8 x 14, 10”-14” Brine Transfer Pumps. Output

capacity 400 GPM (US). Power Output 30HP.

1 HALCO 2500 Supreme centrifugal 6 x 8 x 14, 10”-14” Base

Oil Transfer Pumps. Output capacity 400 GPM (US). Power

Output 20HP.

Mud Charging Pumps

3 HALCO 2500 Supreme centrifugal 6 x 8 x 14, 10”-14”

Output capacity 1200 GPM (US). RPM 1800. Power Output

100HP.

Desander Pump

1 each. 3 x10” Cones. NOV DSN-3V-10CX. Nominal flow rate of 1,200 GPM. 100 HP

Drive Motor.

Desilter Pump

1 each. 16 x4” Cones. NOV DSL-16GG-5CTX. Nominal flow rate of 1,200 GPM. 100 HP

Drive Motor.

Degasser Pump

2 Derrick Vacu Flo 1200. Nominal flow rate of 1,200 GPM. 100 HP Dedicated 6 x 8 x 14

centrifugal Feed Pump. Vacuum Pump, Ingersol Rand /V255/5 HP.

Trip Tank Pumps

2 each 4 x3 x 13. 400GPM. 25 HP HALCO 2500 Supreme Pump.

3.14.2 Mud Processing Equipment

Mud Cleaner

One NOV MC380 Orbital mud cleaner connected to HALCO 2500 Supreme Centrifugal 6 x

8 x 14 with a 10-14” impeller, rated at 100HP and 1200 US gpm feed pump.

Gumbo System



2 x National Oilwell Model GM250-VS-PPS, dual gumbo conveyor, stainless steel chain

with ¼” opening. Nominal Flow Rate (Total) 2,000GPM.

Shale Shakers

Primary

Quantity 4. . Manufacture: NOV brandt VSM-300 + 1 National Oilwell Varco

DLMS380as mud cleaner. Linear Motion. Nominal Flow Rate 500GPM each.

Gumbo

Quantity 2. National Oilwell Varco GM250-VS-PPL. Dual Gumbo Master. Nominal

Flow Rate, 2,000 GPM.

Mud Agitators

Four Lightning 17L-11, 14.8 HP, at pit #1 and #6

Twelve Lightning 17L-7.5, 10 HP two each pit #2, #3, #4, #5, #7 and #8

Three Lightning 15L-4, 5.4 HP one each at slug pit, pre-mix #1 and pre-mix #2

Mud Mixing

Two each mud mixing hoppers NOV DP-10-150-L, with 1200 US gpm 100hp motors.

19 Mud Guns. Model MGB 3LP12. 95 US gpm through ¾” nozzle.

Two Barite hi rate mixer, NOV DP15 200-400, 120 tons / hr located at pit #3 and #4

3.15 Blow Out Prevention Equipment

3.15.1 Diverter

One 47” maximum bore ABB Vetco Gray, KFDJ, 500psi fixed diverter system complete

with spools, overshots and running tools. Two 16” diameter outlets are located on each side

of the housing with lines extended outboard to the port and starboard sides of the drilling

unit, as well as two 4” flowlines with a pressure rating of 500psi. One 16” flow line is

directed to the mud process area with 16” diameter ball valves, hydraulically controlled,

rated to 500psi, are installed in both overboard lines and the mud return flow line.

There are stand-alone Cameron/EPH Diverter Control Panels located in the Drillers Control

Room and the Rig Manager’s office.

3.15.2 BOP Stack

NOTE: All appropriate components are H2S rated.

BOP Stack– One Annular Hydril- GX type , 5000 psi with 10 K bottom flange and 5K top.

One Hydril –MPL dual compact 13-5/8” dual ram BOP with 10 K top and bottom Flange

conn.

One Hydril –MPL single ram BOP 13-5/8” BOP with 10K top and Bottom conn.

Available Rams (Installed and Spare):



Two set 5 7/8” pipe rams

One set blind-shear rams

One set VBR 3 1/2” to 5”

One set VBR 5’ to 5 7/8”

One set Casing Ram 9 5/8”

One set Casing Ram 13 3/8”

One set Casing Ram 7”

3.15.3 Choke and Kill Valves

One each manual 3 1/16”, 15,000psi Cameron FLS gate valve and one each hydraulically

activated 3 1/16”, 15,000psi Cameron FLS gate valve are fitted to both the choke and kill

outlets. All valves with studded BX-154 grooves. Steel wrapped, flexible, 3” ID, 15,000psi

76ft WP hoses connect to fixed piping to the choke and kill manifold.

3.15.4 Choke and Kill Manifold

One 3 1/16” x 15,000psi choke and kill manifold complete with

two hydraulically operated chokes and two manual adjustable

chokes. There are two 76ft Coflexip flexible Choke and Kill

Lines rated 15,000psi that are connected to the BOP manifold

via BX-164 Hub Connections. The control panel is located in

the Driller’s control room.

3.15.5 Mud Gas Separator

One Technics Offshore Engineering 05065 or equivalent, Vertical

Mud/Gas Separator (Poor-Boy De-gasser) 30’ in height x 48” in diameter

with a 10” ID vent line extending 10 ft above the derrick A-frame. A U-

tube and siphon breaker is provided. A snuffing system is provided for

the vent line. The Mud Seal height is 19.5 ft.

3.15.6 BOP Control System

Accumulator Unit

Cameron BOP and Diverter Control /system

manufactured to API RP53 requirements, is located on

the Port Cantilever, inboard side below cantilever rack.

Total of 900 US Gallon accumulator capacity without

pre-charge. Working Pressure is 3,000psi, and has two

regulators, a Manual-MKR and an Annular-MKR.

Accumulator Hydraulic Pumps

Two electric driven Cameron 75hp. Flow rate 40 US GPM. Operating Pressure 3,000psi.

The Primary Accumulator Control Panel, a Cameron 2186215-24, is located on the

Cantilever BOP Portside.

The Remote Control Panels, type Cameron SK-2, are located, one in the Drillers Control

Room and one in the OIM Office.

Poor-boy degasser



3.15.7 BOP Test Unit

A storage and test stump is provided for the 13-5/8” BOP stack.

A Haskel Portable Test Air Driven Fluid Pump Unit is provided; with a pressure rating of

15,000psi equipped with chart recorder and 30ft hose rated at 20,000psi.

3.16 Heating, Ventilation and Air Conditioning

3.16.1 Heating

DD8 is designed for a minimum ambient temperature of -10 °C (14 °F).

Electric duct-mounted heaters are installed at the outlet of air handling units providing heat

to the accommodation spaces, main store and mechanical/electrical workshops.

3.16.2 Ventilation

DD8 is ventilated utilizing mechanical and natural means. Spaces requiring in excess of

1,400 Cubic Feet / Minute (CFM) ventilation air are served by mechanical supply and

exhaust fans.

Ventilation fans are in general adjustable pitch axial flow types. All fans have oversized

motors accommodating 10% overload. Ventilation ducts for machinery spaces and

accommodation areas are fitted with volume control dampers to adjust the amount of

airflow.

Accommodations spaces requiring less than 1,400 CFM are ventilated using natural

aspiration assisted by mechanical fans. Spaces served by natural aspiration with fan assist

include:

Galley

Stairwells (port and starboard)

Toilets

Galley

Laundry Room

Change Rooms

Sick Bay

The table below indicates ventilation arrangements for spaces requiring both supply and

exhaust fans providing an excess of 1,400 CFM air exchange.

Space # Supply #Exhaust Considerations

Engine Room 2 2 Automatic dampers for CO2 release

Sack Storage Room 1 2 No special considerations

Mud Pump Room 2 2 DC motor blower exhaust, independent

Mud Lab 0 1 Within pump room machine space

Mud Pit Room 2 2 50pa neg. pressure maintained

Auxiliary Rooms 1 1 No special considerations

Emerg. Generator 1 0 Not in operation

Supply Fans

Exhaust Fans



Space # Supply #Exhaust Considerations

0 1 In operation – Engine exhaust fan

Automatic dampers for CO2 release

Emerg. Generator

switchboard room

1 1 For extraction of heat from switchboard

CO2 Room 0 1 No special considerations

Paint Locker 0 1 Natural supply + CO2 manual dampers

Mud Process Area 0 1 Shakers have vented hoods

Drill Floor 2 0 Bug blowers to provide cooling air to drill floor

personnel

3.16.3 Fire Dampers

Air conditioning ducts passing through A0 or A60 class boundaries are equipped with fire

dampers complying with regulatory requirements. Dampers are activated automatically by a

thermal fuse. The fire links are closed collectively when the quarter’s ventilation

emergency shutdown is activated.

The process of initiating a Quarter Ventilation Shutdown will be manually at the ESD

system, which will in turn lead to the corresponding closure of all dampers in the living

quarter. However, when the CO2 system in the galley is activated, the fire dampers at the

boundary of the galley will shut automatically to isolate the galley space from the rest of the

other unaffected boundary.

3.16.4 Air Conditioning

The air conditioning system for accommodation spaces is a refrigerant direct expansion type

and consists of seven AHU-01 to AHU-07 air handling units, using R407C refrigerant,

distributed over the three levels of the living quarters. An independent condensing unit

located on the roof of the quarter’s serves each air-handling unit. Ventilation fans are

installed in the quarters to exhaust air from the galley and sanitary spaces and to supply

fresh air to Galley and Stairs Port and STBD.

The table below indicates locations and capacities of all AHU on board:

Unit Location Cooling Capacity

AHU-01 Quarters 01 Level Starboard. 30 tons

AHU-02 Quarters 01 Level Port 36 tons

AHU-03 Quarters 02 Level Starboard 18.5 tons

AHU-04 Quarters 02 Level Port 19 tons

AHU-05 Quarters 03 Deck Galley 11 tons

AHU-06 Quarters 03 Deck Starboard 21.5 tons

AHU-07 Quarters 03 Deck Port 16 tons

AHU-08 Electrical/Mechanical Workshop 6 tons

AHU-09 Main Storage Room 10 tons

AHU-10A PCR Room Portside 20 tons

AHU-10B SCR Room Starboard 20 tons

AHU-11A Local electrical room 25 tons



Unit Location Cooling Capacity

AHU-11B Local electrical room 25 tons

AHU-12 Mud Lab 1.15 tons

3.16.5 Refrigeration

The refrigeration system consists of two fan coil units using R404A refrigerant, located one

in each of the chiller and freezer rooms, and two condenser units, mounted on a single skid

located on the roof of the quarters. Each condensing unit has 100% capacity of the system.

The fan coil unit in the chiller room can maintain the temperature in the chiller room at +2

°C / 35 °F. The fan coil unit in the freezer room can maintain the temperature in the freezer

room at –23.3 °C / -10 °F.

3.17 Bilge System

The bilge system serves two different areas, namely port and starboard side. DD8 is equipped

with a centrifugal pump and an air-operated diaphragm pump to serve each area. In normal

conditions, each side must be served by its own pumps. If necessary, the pumps can take

suction from the opposite side manifolds via a cross-over link.

The drilling unit has two ABB M2QA180M4A bilge pumps, with a 550 US gpm capacity

each. It also has two Wilden T20 Diaphragm Pumps each with a 225 US gpm capacity.

All suctions are taken from bilge sumps. They are manifolded and located in the Aft auxiliary

machine rooms port and starboard. Discharge From the system is routed to the bilge holding

tank, mud contaminated tank, overboard to the starboard aft leg well or MARPOL discharge

connection at loading stations.

Coaming Drains from the machinery areas (except mud pump room and mud hopper area) are

led into the bilge sumps. The oily water separator will take suction from the bilge holding

tank and drain holding tank (SW preload tank 18-C). Regular maintenance of oily water

separator shall be carried out accordingly to the maker’s instruction manual. In order to

provide redundancy during maintenance, two oily water separators, each of 10m3/hr are

provided.

Coaming Drains from mud pump room and mud hopper area are directly led into mud

contaminated drain tank. The bilge pumps will take suction from mud pump room bilge sump

and discharge to mud contaminated drain tank. An air-operated diaphragm pump will take

suction from the mud contaminated drain tank and discharge to bilge connections at loading

stations.

The oil discharged from the oily water separator is piped to the dirty oil tank while the clean

water is piped overboard to the port aft leg well (the threshold limit for discharge being

15ppm OIW as per MARPOL requirements).

Dirty oil tank is discharged to MARPOL connection at loading station for transport ashore via

direct discharge to a supply boat or via transportable tanks.

3.18 Deck Drains System

Deck drainage is divided into three areas including,



Mud Processing deck and shakers – drainage leads to drain sumps on Main Deck and then

to mud containment tank

Main Deck – drainage leads overboard to starboard aft leg well or diverted to pre-load

tank 18C

Cantilever and Drill floor – drainage leads to separation tank starboard aft of cantilever

Drainage can be routed to a skimmer tank, a holding tank or discharged overboard,

depending on the conditions at the time of drainage. Water from the skimmer tank can be

routed to the oily water separator.

3.19 Fixed Fire Fighting Equipment

There are several fixed fire-fighting systems on DD8, including water deluge / spray, foam

and CO2.

3.19.1 Fire water ringmain

DD8 is equipped with a firewater ringmain, fitted with

manual isolation valves and supplied by two Allweiler

NIM80-400/02 Centrifugal vertical fire pumps rated at 500

US gpm, situated in the aft machinery room. The ringmain

supplies hose stations around the MODU including in the

Accommodation unit, and a water deluge system on the Drill

Floor. The firewater main system interfaces with the

foam/deluge system by means of a crossover valve.

3.19.2 Deluge System

The drilling unit is equipped with a deluge system for drill floor area, cellar deck around

BOP equipment, below drill floor and water spray curtain at both side of side shell. Two

monitors are installed at opposite sides of the well testing area. Fixed nozzles are installed

for drill floor and cellar deck area. Water Spray curtain with fixed nozzles are installed at

both side shell for protection of aft portside and starboard side.

The deluge water supply is from the foam/deluge pump located at starboard forward

machinery room during elevated condition and supply taken from fire water main during

afloat condition.

3.19.3 Foam System

The drilling unit is equipped with a foam system for helideck protection. Two monitors and

two foam hoses are installed at the opposite sides of the helideck, to cater for any direction

of wind. The AFFF foam tank and injector pump are located on the helideck aft access

platform (ref. DD8 drawing P119).

3.19.4 CO2 System

The places protected by the CO2 flooding system, and their points of activation are as

follows (Ref. DD8 drawings P-124,5,6):

Engine Room (Local + CO2 Room Main Deck)

Galley (Galley Entrance)

Electrical Room (Local + CO2 Room Main Deck)

Paint Locker (External Paint Locker)

Emergency Generator Room (External Emergency Generator Room)

Firewater pump (above) and Firemain isolation

valve long handle (right)



3.19.5 Galley Hood Fixed System

A fixed R102 fire extinguishing system is installed in the Galley Hoods over the range,

griddle and deep fat fryer. The system is activated by a manual/remote activation panel

located in the vicinity of the Galley Hood.

3.19.6 Fire Fighting Equipment

Fire hose stations, portable extinguishers, and firemen’s outfits are strategically located

throughout the drilling unit in such a manner as to conform to the International Maritime

Organization Fire Safety Systems Code and the IMO MODU code 2001 consolidated

version.

See table below for list of Portable Fire Extinguishers and other Fire Fighting Equipment:

Portable Fire Extinguishers

CO2 5Kg 8

CO2 6.7Kg 1

CO2 9Kg 2

Dry Chemical Powder 22.5kg 2

Dry Chemical Powder 6Kg 47

Foam 45L 1

Other Fire Fighting Equipment

Fire Hose Stations c/w spanner, nozzle, rack 44

Fire Blankets 1

Fireman’s Outfit 9

(For placement of all Fire fighting equipment and complete listing of accessories see Marine

Operations Manual, Fire Control and Safety Plans)

3.20 Life Saving Equipment

DD8 lifesaving equipment compliment conforms to the requirements of the International

Maritime Organization Life Saving Appliance Code (LAS Code):

Helicopter Rescue Equipment Boxes 3 (Equipped as per CAP 437)

Norsafe Jiangyin JN80F Launched Lifeboats 4 x 60 (2 Port, 2 Stbd)

Inflatable Life Rafts 6 x 20 (3 Port and 3 Stbd)

Ring Buoys of various descriptions 10 strategically placed

Fast Rescue Boat (6 persons capacity) 1 (stored on roof of Accommodation,

launched by the crane)

Personal floatation devices 242 (122 in Accommodation and 120 at

lifeboat stations)

(For placement of all Life Saving Equipment and complete listing of accessories see Marine

Operations Manual, Fire Control and Safety Plans)



3.21 Fire and Gas Detection Systems

The Fire and Gas Detection System on board the DD8 is separated into two divisions in the

overall fire and gas system.

(a) A gas detection panel which controls the H2S and combustible gas detectors and

integrated directly into the Vessel Management System (VMS).

(b) An auto-safe fire panel which controls smoke detectors, manual call points, heat detectors

and flame detectors. System information is displayed locally on the main fire panel and

also relayed to the VMS system.

The fire and gas detection system panel is located in the Control

Room. Two gas repeater panels to repeat alarm status in the one

in the OIM Office, one in the Drillers Cabin on the Drill floor,

one in the Engine Room and one in the Mud Room. There are

VMS HMI’s in strategic locations throughout the drilling unit.

3.21.1 Main Fire Control Panel

In normal operating conditions, the main fire control panel in the radio room will display

system status, date and time.

The panel has a system over view facility whereby all components, circuit loops and devices

which compose the fire detection system are continuously monitored.

3.21.2 Combustible Gas and Toxic Gas (H2S) Detection

DD8 is equipped with a combustible and H2S gas detection system with sensors located at;

Shale Shakers

Mud Pits

Bell Nipple

Other locations as per regulatory body requirements.

LOCATION H2S LEL

Living Quarters Ventilation System Yes Yes

Bell Nipple Yes Yes

Drill Floor Yes Yes

Shale Shaker Yes Yes

Mud Tanks Yes Yes

FRC, Typical Lifeboat & Typical Life Raft & Life Ring

Typical DD8 Gas

Detector



3.21.3 Smoke and Heat Detection

DD8 is equipped with a smoke and fire detection system that provides

fire detection coverage for all machine spaces and smoke detection

coverage for all cabins and other required spaces. The control console

is located in the Barge Engineers office. The system is in compliance

with regulatory bodies.

(For numbers and placement of smoke and fire detection sensors see Marine Operations

Manual Drawing # J-134)

3.21.4 Visual / Audible Alarm Locations

Audible and visual alarm comprising the general alarm/Abandon platform alarm/PA with

red beacon flashing lights, fire/PA with red beacon flashing lights, toxic gas alarm/PA with

blue beacon flashing lights, and combustible gas alarm/PA with amber beacon flashing

lights are located in the following areas:

Driller’s Console

Engine Room

Mud Pits Room

Living Quarters (audible only)

Central Area (audible only).

3.22 Water Maker, Sewage Treatment and Environmental Protection

3.22.1 Water Makers

One Alfa Laval, Model D-PU-36-

C100, rated at 12,000 US gpd, waste

heat type and one Haten Boer Water

GSW3 UV sterilizer. One reverse

osmosis unit.

3.22.2 Sewage Treatment Plant

The on board sewage treatment plant is of type Hamworthy ST

type which is a Biological Unit in compliance with MARPOL

73/78.

3.22.3 Bilge Pumps

The drilling unit has two ABB M2QA180M4A bilge pumps, with a 550 US gpm capacity

each. It also has two Wilden T20 Diaphragm Pumps with a 225 US gpm capacity. The bilge

water passes through the oily water separator.

3.22.4 Waste Collection System

Drill floor, rotary and drawworks are fitted with drip pans. The mouse hole and cantilever

pipe deck are piped to a skimmer tank and the oily water separator. Deck drains have been

addressed previously.

3.22.5 Oily Water Separator

Two Aquanautic RWO SKIS 10 coalescing system type, with a nominal capability of 22 US

gpm each. The limit for water discharge is 15ppm OIW as per MARPOL requirements

Typical DD8 Audio-Visual

Alarms

Typical DD8 Smoke Detector

DD8 RO Water Maker



3.22.6 Garbage Disposal

The galley is equipped with one IMO certified Hobart F03-150 certified

food waste disposal unit.

3.22.7 Garbage Compaction

DD8 is equipped with one Max International MAX40 EX.

3.23 Communication and Instrumentation

3.23.1 Drilling Instrumentation at Driller’s Position

One NOV CYBERBASE full drilling instrumentation and data acquisition system. Also

available to the driller are:

Weight indicator

Standpipe pressure gauges

Choke manifold pressure gauges

Rotary instrumentation

Tachometer

Torque indicator

Top Drive Instrumentation

Tachometer

Torque indicator

Pump Stoke Counters

Tong Torque Indicator

Pit volume totalizer

Mud flow indicator

Trip tank indicator

Automatic driller

Remote choke control unit

Crown clearance indicator

One drilling parameter recorder unit with displays and recorders in driller’s control room,

Rig Manager’s office and Operator’s office.

The six parameter measured are Standpipe pressure, string weight, weight on bit, pump

strokes per minute, torque and RPM.

Instrumentation at Choke Manifold includes one Standpipe pressure gauge; two choke

manifold pressure gauges and two transmitters to the CYBERBASE system.

Instrumentation at Standpipe consists of two Standpipe power choke pressure gauges and

two transmitters.

Deviation equipment consists of one NOV Go-devil deviation recorder, a slick line unit and

an electric Wire Line unit located on Main Deck.

DD8 Garbage

compactor



3.23.2 Communications Equipment (GMDSS)

Rig telephone system consists of three (3) types

o 15 x Motel SX2000 type with 21 additional indoor outlets (Accommodation block)

o 17 x Gaitronics Commander type weather proof (Outside on Main Deck)

o 14 x Gaitronics AUTELDAC4 Explosion proof (Hazardous areas)

Public Announcement (PA) System (2 stations plus all telephones)

Four hand held VHF radios satisfying GMDSS

Furuno/Fellom INMARSAT C Satellite Communication System

VHF survival radios for each lifeboat

NavTex Receiver

One MF/HF Single Side Band Transceiver (equipped with DSC controller and watch

keeping receiver)

Two VHF Marine Transceivers (battery powered and one is equipped with DSC

controller and watch receiver)

One VHF Aircraft Transceiver

One portable VHF Aircraft Transceiver

One helicopter Beacon Transceiver

One Emergency Positioning Indicating Radio Beacon (EPIRB)

Six Radar Transponders (one in each life boat and 2 in the radio room)

Approximately 6 VHF handheld radios.

3.23.3 Navigation Equipment

Running lights

Aircraft warning lights on top of Legs, Cranes and Derrick

Helicopter perimeter lights

Foghorn

Navigation and obstruction lights

All meet regulatory body requirements. The MODU also has an Inmarsat C GPS.

3.23.4 Instrumentation

Meteorological instrumentation for measurement of;

Atmospheric pressure

Atmospheric temperature

Wind speed and direction

Wave height

Tide

Humidity

Wave profile



3.24 Hazardous Areas, Inventory

Hazardous Material Storage

Arrangements have been made on the Installation to store hazardous materials.

The capacity of hazardous chemicals is kept to a minimum and a system of segregation is

used to ensure that the contamination of non-hazardous chemicals is avoided.

Storage areas are as follows:

Deck Deck store on Main Deck

Catering Dry store and linen lockers

Mud Engineer Chemicals for his lab are held within the mud lab.

Mud chemicals stored in the sack room.

Mechanics Mechanical workshop. COSHH locker.

Cementers Chemicals stored in the sack room and Main Deck

Painters Paint locker situated on the main deck

Stores Warehouse

Drill Crew Sack Room

Electricians Electrical workshop. COSHH locker.

3.24.1 Hazardous Materials Location and Protection

The following hazardous materials are provided with dedicated storage areas and are

segregated and have appropriate degrees of protection against fire or other hazard.

Radioactive Substances Radioactive containers are stored on Port Bow Side. The containers are stored in a specially

designed container on a quick release platform.

Shipment of radioactive material offshore is the responsibility of the third party company

providing this material. Responsibility for compliance with the requirements regarding the

handling and use of radioactive material offshore rests with the OIM.

The OIM, as the responsible person for ionising radiation, liaises with the qualified radiation

protection supervisor from the third party company using the radioactive source. Names and

addresses of persons responsible for radiological safety, contactable for advice in case of an

incident, are kept on board the MODU.

Operations requiring the use of such material are controlled through the PTW system. All

radioactive material is removed from the MODU prior to a rig move.

An inventory of all radioactive sources on the Installation, together with a record of the

radioactive materials shipment manifests, is maintained by the Barge Engineer.



Explosive Materials Explosives containers must be placed on top of accommodation Port Bow side. The

containers must be placed on a quick release table to make it possible to dump them in the sea

if needed.

The OIM, as the responsible person for explosives, holds and controls the keys to the

explosives container and liaises with the supervisor from the third party company which uses

the explosives. Records of the explosives inventory are maintained on board.

The use of explosive materials is controlled under the Work Permit system. All explosives are

removed from the MODU prior to a rig move.

An inventory of all explosive materials on the Installation, together with a record of the

explosive materials shipment manifests, is maintained by the Barge Engineer.

Heli-Fuel – Not in use at this moment Heli-fuel (jet fuel) is delivered to the MODU by supply boats in purpose-built, certified transit

fuel tanks and stored, once on the MODU, on a purpose-built platform which is cantilevered

out away from the MODU and which has the capacity to facilitate the storage of two tanks.

The platform for these transit tanks is fitted with a hydraulically operated jettison system for

rapid disposal of the tanks in an emergency. The area is foam deluge protected. The heli-fuel

is transferred from the transit tanks directly to the helicopters. Empty transit tanks are shipped

ashore as soon as possible.



4 . H S E C R I T I C A L E L E M E N T S A N D P E R F O R M A N C E S T A N D A R D S

4.1 Safety Critical Equipment Overview

The DD8 Hazards and Effects Management Process (HEMP – as described in Part 4 of this

HSE Case) has resulted in a register of Major Accident Hazards and potential Major Accident

Events for DD8, together with Critical Risk Controls. Physical items and systems that are

critical to controlling the risk of MAH are termed ‘Safety-Critical Elements’ (SCE –

comprising equipment, structures and computer systems), whilst activities that are critical to

controlling the risk of MAH are termed ‘Safety-Critical Activities’ (SCA). The

appropriateness of the design, construction and installation of all DD8 SCE is validated by

compliance with, and certification to, the various rules, regulations and standards that form part

of Class and other compliance certifications of the drilling unit. Any new or changed Safety-

Critical Elements that are not covered by Class or other existing DD8 certification are validated

separately as part of campaign planning and preparation.

Identified SCE for DD8, together with associated Performance Standards are listed below,

whilst the SCA are listed in Part 3 of this Case.

4.2 Development and Content of SCE Performance Standards

Performance Standards (PS) have been developed, as part of the HEMP process described in

Part 4 of this HSE Case, for DD8 SCE and SCA, including the following PS parameters for

DD8 SCE:

a) Critical Function(s)

b) Specifications

c) Standard(s) governing design & construction

d) Availability and Survivability requirements

e) Responsible Parties (for ensuring that the SCE is present and properly maintained)

f) Means of Verification

g) Interdependency (what other equipment or systems does the SCE depend upon?).

Compliance with these standards of performance ensures that the SCE fulfil their safety-critical

role in maintaining the risk of MAH to ALARP. Any deviations fall under the general policy

and procedure for the Company Management of Change – requiring formal approval (see Part

3, Section 4.4).

4.3 DD8 Safety Critical Equipment (SCE)

The following is a list of the agreed SCE and associated Performance Standards for DD8 where

it is clearly stated in table below on the reliability and suitability of the SCEs.

The Reliability of the SCE’s is such that for the active systems that needs to perform critical

functions in response to a MAE. and for other systems that which monitor the status of other

systems like alarms etc. the performance standard criteria for reliability can be expressed in

terms of Probability of Failure on Demand ( PFD ) , Safety Integrity Level ( SIL ) or Mean

Time between Failure ( MTBF ) . The frequency and results of tests is such that the Reliability

target (set during the design phase) is confirmed both by the Rig Staff during their maintenance

and by the relevant class authorities during the annual, bi annual and 5 yearly certifications.

Suitability: these SCE’s are all designed according to the prevalent standards as per the rules

and regulations (latest) at the time of producing the rig which include all the certifications of all



the materials used in the manufacture of the components, and that it confirms to all the rules

and regulations and approved by the relevant authorities.

All the below mentioned SCE are maintained by our staff who follow our maintenance policies

as dictated by the AMOS system and audited in-house cross visit teams and in addition

checked by the OEM depending on the 5 yearly maintenance schedule and also verified

independently by the attending Class Surveyor (ABS) to ensure that these SCE are reliable and

suitable for the jobs they are intended to do.

DD8 HSE Case ABAN-DD8-HSE Case-P2


DD8 Safety-Critical Equipment Register

No. Equipment

Name or

Title

Suitability

Criticality

Functionality.

Specifications Governing

Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

1. Hull including

watertight

bulkheads

To safely support

and accommodate

DD8 POB,

facilities,

structures

equipment,

systems,

materials, and all

activities thereon,

when floating and

when elevated

(jacked up). Must

remain rigid,

stable and not

susceptible to

flooding or when

in float mode, loss

of buoyancy.

Single, welded, triangular shaped

steel Hull measuring 74.98m(l) ×

66.45m(w) × 7.79m(h), equipped

with 3 truss-type triangular legs,

each fitted with spud can footing.

Designed and constructed in

accordance IMO & ABS MODU

Code requirements, coatings: surface

preparation with primer and topcoat

according to Keppel “Coating

Specification.” Designed to operate

in water up to 106m (350ft) carrying

plant, equipment and materials for

drilling wells down to 35,000 feet,

and capable of accommodating up to

120 personnel with full SOLAS-

compliant LSA.

IMO Code for the

Construction and

Equipment for

Mobile Offshore

Drilling Units

(1989 IMO MODU

Code with

Amendments) and

ABS MODU Class

*A1

100 % Available, Able

to operate in salt-water

environment and

survive waves up to

15m height and winds

up to 100 knots speed.

Barge Engineer,

supported by

Maintenance

Department

ABS Class

certification,

annual surveys

and five-year

surveys and

dry-docking

survey every 3

years.

Reliability

Monthly PMS

inspection in

Amos.

Re-check every

rig move on

Legs, watertight

doors.

2. Legs, Spud

Cans and

Jacking

System

To safely support

the loads from the

Hull and various

structures when

elevated and the

drilling

operations. It is

must remain rigid,

with limited

flexibility, but

enough to

withstand the

environment

3 triangular-structural, truss cross-

section, jacking legs at 486ft in

length with spud cans. Cans measure

13.85m(d) × 5.79m(h) and have

jetting systems (12 on top and 12 on

bottom). Designed and constructed

in accordance with IMO & ABS

MODU Code requirements, coating.

Legs are elevated and lowered by

means of an opposed-pinion

electrically powered rack and pinion

jacking system constructed by

KEFLS and rated at a total of 36,000

1989 IMO MODU

Code with

Amendments and

ABS MODU Class

*A1

100 % Available, able

to operate in salt-water

environment and

survive wind speeds of

up to 100.

Barge Engineer,

supported by

Maintenance

Department

ABS Class

certification,

annual surveys

and five-year

surveys and

dry-docking

survey every 3

years.

Reliability

NDT on the

legs conduct

after Rig Move

Hull, Jacking

motors




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

kips. and Visual

inspection the

Jacking System

3. Topsides

structures

including

accommodatio

n, stairways,

elevated

walkways and

platforms,

cantilever

Provide adequate

living quarters for

rig workers, safe

access to

equipment and

escape

routes/muster

points. Must

remain safe and in

good condition

Accommodation block provides

living quarters for 120 personnel (55

two person rooms, and 10 single

person rooms), galley, washing

facilities, offices, a gym, recreation

room, prayer room, changes room,

and library and mess room. Contains

air conditioning system, rig

manager’s office, and electrical room

also. Lifeboats are situated outside

on level 3, port and starboard (2

each). The emergency generator is

situated on the roof. External

stairwells lead between all floors and

the main deck. The forward

stairwells lead to the helideck.

ABS MODU Class

*A1

100 % Available, Able

to operate in salt water

environment and

survive waves up to

15m height and winds

up to 100 knots speed,

providing adequate

shelter for personnel

inside. Made from

flame-resistant

materials and has

multiple escape route in

event of emergency.

Barge Engineer,

Bosun &

Catering

Department

supported by

Maintenance

Department

ABS Class

certification,

routine

housekeeping

by Catering

Department, ,

annual surveys

and five-year

surveys and

dry-docking

survey every 3

years.

Reliability

Amos PMS

weekly on lift

boats

Hull

4. Helideck

(S61N or S-92

or equivalent)

To provide

support for

helicopters (S61N

or S-92 or

equivalent)

landing and taking

off from the rig.

Octagonal deck located at fwd end of

rig measuring 22.2m in diameter

with Included circle and with three

escape stairs as per IMO MODU

Code. Suitable for S61N or S-92 or

equivalent. Design Deck Load of

9253kg + 205kg/m2.

CAP 437 and ABS

MODU Class *A1

Must survive offshore

environment and

loading from helicopter

landings including

impacts from hard

landings in bad

weather. Should

survive helicopter

Barge Engineer

& Bosun (HLO)

Pre-landing

checks,

integrity checks

against DROPS

on a scheduled

basis and dry-

docking survey

every 3 years.

Structural beams

& access ways,

helideck fire-

fighting systems,

external

communications

systems




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

crashes and fuel fires.

Reliability

Yearly Audit

conducted by

Client…

Daily

inspection by

the HLO and

conduct

checklist before

any of

helicopter

landing.

5. Derrick

Structure, sub-

structure and

cantilever.

Derrick to provide

main vertical

structure to

support the

hoisting system,

cantilever to

provide for the

full load and

skidding of

drilling set.

NOV Derrick, 170 ft high (below

crown) with 36 x 36 ft base and

water table size of 16 x 17 ft. Has a

static hook load of 2000 kips and

rated for 70 knots of wind with full

set back (550 MT). Substructure is a

KEFLS design. Drill floor measures

44.3 ft by 68.6 ft and has a setback

capacity during operations of 1,210

kips. 10ft windbreakers provided.

Skid-off cantilever rated at 2,700

kips on centreline at a 30ft extension.

Maximum rotary load of 2,000 kips.

ABS MODU Code

& API standards

Must be able to

withstand the extreme

loads required for

drilling operations, as

well as the extreme

environmental loads,

such corrosion, wind

speed (70 knots full

setback, 100 knots with

no set back)

Assistant

Driller,

Derrickhand,

Floorhand,

supported by

Maintenance

Department

Constant use of

derrick,

inspection and

maintenance of

equipment prior

to use and

annual surveys.

Reliability

Weekly Derrick

DROPs

inspections as

given in the

DROPs picture

Client platform

and capping

beams / grillage

and hoisting

equipment




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

book by third

party surveys.

6. Navigation /

Obstruction /

Aircraft

warning

lights, fog

horns

To annunciate the

drilling unit

position and

direction of

movement when

under tow.

Lights and foghorns provided in

accordance with Regulatory Body

requirements for “non-propelled,

self-elevating drilling unit.”

SOLAS,

COLREGS and

ABS MODU Class

*A1

Storms / bad weather /

heavy seas

Electrical

Maintenance

Personnel,

Barge Engineer

& Bosun

Navigation

lights tested

before every

transit and once

every 6 months.

Reliability

Obstruction

lights and Fog

Horn tested

weekly.

And also daily

visual check the

light up bulb

working before

dark.

Electric power

(with back up

from the

emergency

generator) for the

lights

7. Anchor

winches,

anchor wires

& lines,

anchors

To hold the

drilling rig with

tugs in position at

a platform during

jack-up.

Four Brohl 400 Kn model,

electrically driven anchor winches

with 5T Flipper Delta Anchors. 1.5”

x 2,500ft of wire rope with a

specified breaking strength of 1190

kN (Drum & dynamic brakes

capacity).

ABS MODU Rules

/ Class

requirements

Must survive metocean

loadings as per the

mooring analysis.

Barge Engineer

& Bosun,

supported by

Maintenance

Department

Annual survey.

Reliability

Weekly checks

and inspections

prior to usage.

Rig move




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

Testing and

check

accordance the

rig move check

lists before

8. Tow bridle +

forerunner and

associated

chain, delta

plates and

shackles

To connect the

drilling rig with

the tugboat when

in transit / under-

tow.

Towing gear consists of 2 towing

bits with fairleads, towing bridle

made of 3” chain connected to 2-½”

wire rope with an 85 MT handling

winch system.

ABS MODU Rules

/ Class

requirements

Must survive towing /

metocean loadings (in

excess of maximum

bollard pull of the tug

boat).

Barge Engineer

& Bosun,

supported by

Maintenance

Department

Annual survey.

Reliability

Monthly

inspections,

pre-tow checks

Tow boat

complete with

main tow wire +

shackle to connect

onto WA

forerunner.

Line throwing

gun (for back-up

tow line).

9. Draw works To provide

hoisting power

necessary to run

tubulars into and

out of the well

bore.

One NOV Model-SSGD-4600-57-

82-1015 Drawworks for 2” diameter

drill line, with standard equipment, 4

General Electric 22A2 AC Motors

rated at 4600HP and Crown Saver.

NOV Drilling Control and Data

Acquisitions System (DCDA) used.

API 7 & 8 Must be able to


loads required for

drilling operations.

Toolpusher,

Tourpusher and

Driller,

Derrickhand,

supported by

Maintenance

Department

Maintained and

serviced in

accordance with

NOV Ops and

Maintenance

Manual.

Reliability

Main generators

Crown Block

Derrick Structure

10. Drilling line

and clamp

To provide the

vertical lifting

required of

2” diameter x 7,500 ft

2 NOV (or equivalent) drill collar

safety clamps for 9¼” to 10½”.



loads required for

Toolpusher,

Tourpusher,

Assistant

Annual survey.

Drawworks

Deadline anchor




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

tubulars in and out

of the well bore.

drilling operations. Driller &

Driller. Reliability

Drilling line

Slipped & Cut

on a regular

program based

on Ton Miles.

Clamp

inspected each

time line is cut.

11. Crown Block To provide the

elevated sheaves

to work in

conjunction with

the travelling

block.

NOV CBE 7 x 72 (or equivalent)

Crown Block with seven 72”

diameter cluster sheaves, one 72”

diameter fastline sheave and one

fastline sheave grooved for 2”

diameter wireline. Rated for 1060

short tons.



loads required for

drilling operations.

Toolpusher,

Tourpusher and

Driller

Annual survey.

Reliability

Daily

inspections

conducted

Drawworks &

drill line

Derrick Structure

12. Deck Cranes To provide the

lifting capabilities

necessary for

loading and

offloading

equipment and

supplies, and

positioning

equipment on

decks.

Three Favelle Favco Pedestal Crane

Model 7.5/10K with 120ft booms

located starboard, port-aft and port-

fwd of the drilling unit. Maximum

lifting capacity of 10.9 tonnes at max

radius. Auxiliary hoists rated at 11

short tons. Prohibited from operation

during winds speeds above 40 knots.

API 2C & ABS

Guide for

Certification of

Cranes 1991

Must be able to survive

reasonable excess of

rated capacity loads

and extreme

environment

conditions.

Barge Engineer,

Crane

Operators &

Deck Pushers,

supported by

Maintenance

Department

Maintenance

and inspections

done in

accordance with

crane

operations and

maintenance

manuals. Load

test every 5

years and

inspected

Crane’s own

diesel engine and

hydraulic

operating system,

instrument air

from the drilling

unit system (to

start the crane

engine) and

electric supply for

lights etc. (but




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

annually by

ABS.

Reliability

Daily crane

inspection,

Motor oil

checks as

require in the

crane checklist.

Weekly PMS

Amos

critical for MAE

avoidance).

13. Winches For general

lifting, handling

and servicing of

utilities and

personnel.

6x FA5-16XMK1GPV @5MT, 2x

FA2.5MR24MK1GDP @2.3MT, 2x

FA150KGMR12-1-E @150kg, 1x

FA2.5-8XMK1GPV @2.3MT, 2x

LS2-600R-L-E @600kg.

LOLER & API 7K Must be able to

withstand reasonable

excess of rated safe

working loads, and rig

working environment.

Barge Engineer

& Maintenance

Department

Routine

maintenance

checks in

accordance with

equipment

manual and

prior to-use and

3rd party

inspections

every 6 months.

Reliability

Weekly PMS

Amos

Pre-Checks

before use.

Rig air supply for

winches, shivs in

the derrick and at

monkey board.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

14. Pad eyes,

sheaves, chain

hoists,

shackles,

slings, wire

rope, plate

clamps,

hooks,

spreader bars

To provide the

physical link

between the items

to be lifted and the

lifting device.

Constructed to approved standards

relating to specific item and shipped

with certification to recognised

approved certifying body such as

ABS or similar.

LOLER & API 8 &

9

Must be able to

withstand reasonable

overload and offshore

environment.

Barge Engineer

& Tour Pusher

supported by

Maintenance

Department

Six monthly

visual

inspections and

colour coding

Reliability

Daily / weekly

and pre-job

inspections

done by day

crew.

Lifting devices

such as winches

and cranes.

15. Transfer

Baskets

To support

personnel during

transfer by crane.

Transfer basket to

support equipment

during transfer by

crane.

3-person FROG Marine Transfer

capsule.

LOLER & API 2D Must be able to

withstand rated load +

overload due to shock

loading up to weather

limits.

Crane

Operators &

Barge Engineer

Recertification

every two

years.

Reliability

Inspection prior

to use and 3rd

party

inspections

every 6 months.

Crane and lifting

gear

16. Mud supply

system – mud

pumps and

To provide and

maintain an

appropriately

Three National Oilwell 14-P-220

1150HP Triplex Mud Pumps rated

@7,500psi maximum working

API (various

elements)

Must survive full range

of required mud

parameters –

Assistant

Driller, Mud

System

Reliability

Daily and

weekly

Main Electric

power, with back

up from a diesel-




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

lines weighted mud

column in the well

during all drilling,

well construction

and workover

activities.

pressure. 5-½” and 7” liners

available with 8” discharge/suction

line. Working pressure of 3500psi

and working flow rate of 822 US

GPM. RR type CX reset relief valve.

Five Halco 2500 Supreme Pumps (2

for mixing 3 for charging) with

output of 1200 US GPM.

Three Halco 2500 Supreme Transfer

Pumps 4x3x13 Centrifugal with

output of 400 US GPM.

Hoses rated at least at maximum

working pressure of high-pressure

mud system.

compositions,

pressures, flow rates.

Operator,

Pumphand &

Maintenance

Department.

inspections

conducted by

the day crew.

powered unit.

17. Mud Flow

Sensor, PVT

system, trip

tank

instrumentatio

n

To provide the

driller with real-

time monitoring

of mud flow and

volumes, during

drilling, tripping

and running

casings or

completions.

National Oilwell Varco /

CYBERBASE - Full drilling

instrumentation and data acquisition

system.

API (various

elements)

Must survive

fluctuations in mud

parameters up to alarm

points. Must survive all

types of mud and

potential contamination

from reservoir fluids.

Mud System

Operator,

Electrical/

Electronic

Maintenance

Personnel &

Driller

Reliability

Constant

monitoring and

weekly

inspections

done by the day

crew.

Electric power,

with back-up by

an Uninterruptible

Power Supply

provides power to

Mud and drill

watch systems in

the case of a

power failure.

18. Casing and

Cement: exact

specifications

come from the

client and

differ from

To keep formation

fluids in the well

bore at all zones

above and/or

below the

reservoir.

Data unavailable, as exact

specifications come from the client

and differ from well to well, but must

be suitable for the worst case

reservoir fluid properties and

mechanical loading from weight of

Applicable API

standards / RPs and

client procedures

Must survive down-

hole environment, full

pore pressure &

temperature, and

weight loads.

Client and

cementing

service

contractors are

also responsible

parties.

Measurements

and numbering

of casing by

Client Rep.

Casing and

Cement are

dependent on

each other. Both

are dependent on

casing/cementing

program by the




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

well to well material above etc. Tour Pushers &

Drillers for

implementation

and challenges

to client well

design.

client and

cementing service

contractors.

Toolpusher,

Tourpusher &

Driller all review

the well program

and any changes

on a daily basis,

to help identify

any problems of

hazards

associated with

the design.

Remedial Action

= formalize this in

the HSEMS

19. Annular

BOP(s)

To close the well

bore annulus on

all sizes and types

of tubular.

One Hydril GX 13-5/8” size

5,000psi Annular Blowout Preventer.

Top 5K and Bottom 10K.

API 16

(Certificate of

conformation every

5 years)

Must be able to

withstand annular

pressure exerted by the

formation (up to its

rated working

pressure).

Toolpusher,

Driller and

Hydraulic

Technician,

supported by

Maintenance

Department

All the BOP

components are

leak tested prior

to use on each

well, and any

leaking

components are

changed out

according to the

Vendor

Procedures. 3rd

party certified

pressure tests

every three

Accumulator




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

years.

Reliability

20. Ram type

BOP(s)

To shut in the well

on pre-determined

sizes of tubulars,

or open hole, and

to shear tubulars.

One Hydril single and one Hydril

Dual ram 13 5/8” size, 10,000psi

working pressure, with 10 K top and

bottom flange Connections. Manual

Ram Locks and H2S service.

Available Rams –

2 sets Pipe Rams 57/8”

1 set Blind-Shear Rams

1 set VBR or Flex Packer 3 ½” to 5”

1 set VBR or Flex Packer 5” to 57/8”

1 Casing Ram 133/8”

1 Casing Ram 95/8”

1 Casing Ram 7”

API 16 (Certificate

of conformation

every 5 years)

Must be able to

withstand well bore

pressure exerted by the

formation (up to its

rated working

pressure). Must be able

to shear tubulars.

Toolpusher,

Driller and

Hydraulic

Technician,

supported by

Maintenance

Department

All the BOP

components are

leak tested prior

to use on each

well, and any

leaking

components are

changed out

according to the

Vendor

Procedures. 3rd

party certified

pressure tests

every three

years.

Reliability

Accumulator




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

21. IBOPs To prevent

formation fluids

exiting through

the drill string.

One Vetco Gray (or equivalent) Top

Drive upper IBOP, remotely

operated. Outside diameter 71/8” and

minimum inside diameter 3”, with

X-57 Box/Pin connection type and

working pressure of 15.000psi.

API 16 Must be able to

withstand potential

shut-in drill pipe

pressure and all well

bore fluids / drilling

mud.

Toolpusher,

Tourpusher and

Driller

supported by

Maintenance

Department

Tested regularly

and either

repaired or

replaced with a

serviced

standby unit.

Reliability

TDS power

supply (for the

TDS IBOP), and

manual

intervention for

the Tripping

Safety Valve.

22. Choke

manifold and

control panel

To control

formation

pressure while

circulating out

kick/well bore

influx.

One Control Flow Choke Manifold

31/16”, 15,000psi with two WOM

FEM (or equivalent) manually gear

operated Adjustable Chokes and two

WOM WCR 501 Power Chokes.

Flexible Choke and Kill Lines to

BOP manifold, two Corflexip with

BX-164 connections and inner

diameter of 3”, rated at 15,000psi,

length 76’.

Power Choke/Dual Choke Control

System remote control panel situated

in driller’s Control room.

API 16 Must be available at all

times when drilling,

tripping and running

casings or completions.

Must be able to

withstand backpressure

and flow rates and

pressures exerted

during well kill

operations.

Toolpusher and

Drilling

Department

supported by

Maintenance

Department

Unit is tested on

a regular basis

with the BOP

tests. Any

leaking

components are

either repaired

and retested or

changed out

with spare

remanufactured

units.

Reliability

Rig air supply

23. Accumulator

and BOP

Control Panel

To provide

necessary

hydraulic pressure

and control for

Accumulator Unit consists of one

Cameron (or equivalent) BOP and

Diverter control system, located

inboard side Port cantilever below

API 16 & API RP-

53 requirements,

3rd edition, Mar

1997

Must be available at all

times that there exists a

potential for formation

fluids influx into the

Toolpusher,

Tourpusher and

Driller

supported by

Reliability

Daily

monitoring.

None




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

operation of the

blowout

preventers.

pipe rack. Rated for working

pressure of 3,000psi. Reservoir

capacity of 825 US gal, and total

accumulated capacity (w/o

precharge) 900 US gal. Control

manifold type BOP valve and

Diverter with elctro/pneumatic

interface. Regulator type Manual

MKR and Annular AKR.

Two Cameron type Accumulator

Hydraulic Pumps producing 40 US

GPM at 3,000psi. Operable off

emergency generator.

Primary Control Panel Cameron

2186215-24 type located Port

Cantilever below pipe rack, controls

all annular BOPs, Ram BOPs,

Diverter system, Kill and Choke line

valves. Warning lights for

accumulator pressure, reservoir level

and rig air, as well as system

pressure regulator, annular pressure

regulator and flow meter.

Remote control panels Cameron SK-

2 type situated in Driller’s Control

room and rig Manager’s Office.

well bore, and most

especially during

periods of circulation

and tripping activities.

Typically the mud

loggers will have an

independent mud

monitoring system to

reduce reliance on a

single system.

Must survive loss of

main power and marine

environment.

Maintenance

Department

24. Diverter (and

lines)

To safely divert

shallow gas from

the drilling unit

while drilling top-

Fixed ABB Vetco Gray KFDJ

diverter BOP. Max bore 47”, inner

diameter of insert packer 27½” to

17¾” (10 diverter assemblies).

API 16 Well cannot be

constructed without it.

Multiple concentric

casings allow for some

Toolpusher,

Tourpusher and

Driller

supported by

3rd

party

certified

pressure tests

every three

Accumulator




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

hole section. Working pressure of 500psi. Two

diverter outlets of 16” nominal

diameter.

Flow lines; 1 ABB Vetco Gray

Hydraulic Operated Ball Mud Return

and 2 Overboard all rated at 500psi.

Cameron Hydraulic/ Electric/

Pneumatic Control Panel situated on

Port Cantilever, inboard side below

cantilever pipe rack. Remote control

panels in Driller’s Control Room and

Rig Manager’s Office.

loss of integrity

without blowout.


high velocity flow of

formation gas and

debris for long enough

to delete a shallow gas

pocket.

Maintenance

Department

years.

Reliability

Tested on a

regular basis

with the BOP

tests.

25. Fuel

containment

systems

To contain fuel in

storage and in

engine injection

lines and in

refuelling lines

Fuel Oil storage situated in hull

structure (Tanks 10P, 10S, 14P &

14S). Capacity for 3,344 bbl (532

m3).

Fuel Oil Day Tank provided with

drain valves.

Two diesel-fuel hoses 70’ long, 3”

diameter Brazen light with Everite

3” connectors.

ABS and IMO

MODU regulations

Must be available

during all periods when

the well is susceptible

to loss of control after

top-hole section.

Must survive engine

room environment and

fuel type / pressure.

Mechanic Central

monitoring

alarm system

and tank

sounding.

Reliability

Weekly Amos

PMS and

inspection

N/A




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

26. Pressure

vessels &

Pressure

Relief Valves

Vessels must

contain pressure.

PRVs must relieve

any excess

pressure beyond

vessel design

pressure.

Four Barite/Bentonite Thames type

Silos. Capacity 2400 ft3 located on

main deck forward. Rated at 60psi

with Crosby Griss / JOS-E-15-J

relief valve, 2” x 3” size with set

pressure of 62psi.

Three Thames VC 3500 Cement

Silos capacity 2048 ft3 located main

deck forward. Rated at 60psi with

Crosby Griss / JOS-E-15-J relief

valve, 2” x 3” size with set pressure

of 62psi.

Two Surge Tanks for

barite/bentonite. SM type 703 ft

capacities. Working pressure of

60psi.

Section 4/2 of the

ABS Rules for

Building and

Classing Steel

Vessels

Must be available

during all periods when

the well is susceptible

to loss of control after

top-hole section.

Must survive rated

pressures and rig /

marine environment.

Barge Engineer

& Mechanic

Weekly checks

and central

monitoring

alarm system.

Reliability

Weekly PMS

and inspection

None




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

27. Gas/smoke/

heat detection

systems

Fire & Gas

Panel

To provide

forewarning of the

unplanned release

of toxic /

flammable gas

and presence of

fire before

concentration and

/ or intensity

achieves critical

levels in

designated areas

of the drilling

unit.

The F&G panel

provides a means

of monitoring

location of gas,

smoke and heat

sources on board

the rig and on the

Derrick.

H2S Monitoring system Marshal

5704 type. Sample points at bell

nipple, drill floor, shale shaker, mud

tanks and ventilation system. Alarms

in driller’s control room, Engine

Room, Mud Room, living quarters

and central areas. Separate from

general alarm. Central control panel

situated in Control Room.

Combustible Gas Monitoring system

Seiger/System 57 type. PPM sensors

located at Bell nipple, drill floor,

shale shakers mud tanks and

ventilation system. Alarms in

driller’s console, Engine room, Mud

room, Living Quarters and central

areas. Tied to general alarm. Central

Control panel situated in Radio and

Jacking Control room.

Fire/smoke detection system Thorn /

Termex 220 (or equivalent) type,

providing for smoke, heat and flame

detection in the Accommodation

Unit and PA alarm across the drilling

unit. Central Control Panel situated

in the Radio and Jacking Control

Room.

ABS and IMO

MODU

requirements,

SOLAS, and

UKOOA guidelines

EHS05 - 1995

Must be available

whenever drilling.

Detectors must survive

gas/smoke/heat

concentrations up the

alarm point.

All system components

must survive marine

environment.

Detectors must

annunciate their own

failure.

Electrical /

Electronic

Maintenance

Personnel

Maintenance,

testing &

calibration

according to

manufacturer’s

manuals. Self-

fault detecting.

Reliability

Weekly PMS

and inspection

Dependent upon

emergency power

supply (including

UPS).




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

28. Emergency

Response

Alarms,

Engine

alarms, bilge

water alarms,

PVT Gain/loss

alarm, Flow

alarm,

Monitoring

alarms

systems, etc.

To provide rig

personnel with

early warning of

potential unsafe

situations and

requirement to

respond.

Crane alarm (audible and visual)

warns of crane instability.

Watertight Door monitoring and

indication (provided locally and in

control room).

Trip tank Alarm alerts control panel.

Pit Volume loss/gain alarm (audible

and visual).

Mud Flow high/low alarm (audible

and visual).

Central Monitoring Alarm System

monitors Air Receivers, Raw Water

Tower Ring Main, Fuel Oil Day

Tank, Main Transformers, Engines,

Water Maker, Oily Water Separator,

Sewage Treatment Unit, Potable

Water, Bilge Level, Lube Oil Tank,

Drill Water, Dirty Oil Tank, Bilge

Holding Tank, Mud Contaminated

Tank, Engine Starting Air Receiver,

Mud Pit / Mud Pump Room pressure

and Bulk Air Compressor. Central

Alarm Panel located in the

Mechanical Workshop.

General alarm alerts personnel of

any potentially dangerous situation

for various emergencies via PA

system. Can be activated from

Control room and drill floor.

ABS & Class Must be available at all

times while drilling,

with very high

reliability.

Must survive long

enough when exposed

to the hazard or

accident that it is

annunciating, to alert

personnel.

Electrical /

Electronic

Maintenance

Personnel,

Mechanic,

Toolpusher and

Barge Engineer

Function tested

and calibrated

according to

manufacturer’s

recommendatio

ns and manual.

Self-fault

detecting.

Reliability

Weekly PMS

and inspection

Power generation

but:

Fire system has

24V battery

backup, Engines

run from dual 24

Volt supply

(redundancy),

Alarm System

24V backup

through fire

system. UPS

through

Gaitronics

interfaced to

broadcast alarms.

Bilge water

alarms on 24V

backup supply.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

29. EX/IS

equipment

within all

Hazardous

Areas

To function

without causing

ignition of

flammable

releases.

Hazardous zone areas are defined in

accordance to the ABS & IMO

MODU Code requirements.

(Reference is to be made to drawings

C033-E100.01 & 02).

See Hazardous Area Plan Drawings.

Classified in accordance with the

applicable Regulatory Body

requirements.

ABS MODU Code /

API RP502, NEC

Articles 500, 501,

502 and 503

Must survive marine

environment and

engulfment in

hydrocarbon gas /

vapours.

Electrical

Maintenance

Personnel

Reliability

Inspections and

repairs carried

out weekly. IEC

Standards used.

Weekly PMS

and inspection

None

Remedial Action

= complete WA

HAC drawings

30. Poor boy

degasser and

shakers

degasser

(including

vent)

To separate

entrained gas from

drilling mud and

vent the gas to a

safe place

Technics Offshore Engineering

05065 (or equivalent) Gas/Mud

Separator. 30 ft long with outside

diameter of 48”. Primary discharge

location 10 ft above derrick A-frame.

Not tied to burner system. Vacuum

breaker and pressure gauge.

Calculated gas throughput 30 mmscf.

Two Derrick Vacu Flo 1200 (or

equivalent) degassers. Rated

capacity of 1200 US GPM. HALCO

(or equivalent) 2500 Supreme Feed

Pump. Ingersoll rand V255/5 HP

Vaccum Pump.

Section 4/2 of the

ABS Rules for

Building and

Classing Steel

Vessels

Required for main

power generation and

for refuelling. Must be

reliable in terms of not

leaking.

Must survive flow of

drilling mud and

released gases

Mud System

Operator,

Pumphand,

Derrickhand &

Driller

3rd party

checks every 6

months.

Reliability

Monitoring,

Gas Alarms,

weekly

inspections &

Weekly PMS in

Amos

None

31. (Mud Pits)

Ventilation

systems

To prevent build-

up of flammable

vapours in the

mud pits room.

Compartments served by two Hison

(or equivalent) supply and two

exhaust fans. Negative pressure of at

least 50 Pa is maintained against

neighbouring Mud Pump Room. All

ABS and IMO

MODU regulations

Must be available

whenever the tank is

pressured or receiving

pressure. Target

reliability = 100%

Maintenance

Department

Room pressure

differential loss

monitoring.

Electric power

(with back-up

from emergency

generator)




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

fans have oversized motors to cater

for 10% overloads. Must survive flow of

air and gas (without

being an ignition

source).

Reliability

Weekly PMS in

Amos

32. VHF Portable

radios,

Helicopter

VHF,

Inmarsat, SSB

Marine radio,

Intercom

system,

EPIRB,

antennas,

transceivers

To provide

internal and

external

communication

capabilities to and

from the drilling

unit, especially

during

emergencies.

Provisions sufficient to address full

internal rig communication through

PA system and handheld devices and

all relevant Marine and Air channels.

Meets Regulatory Body

requirements.

ABS MODU Rules

/ Class

requirements

Most must survive

major accident events,

as they will be required

for effective emergency

response. Also, must

survive environmental

and rig working

conditions found

offshore.

Barge Engineer

and Radio

Operator,

supported by

Electrical

Maintenance

Personnel

Reliability

Weekly PMS

Manning of

radio room 24/7

and function

tested as part of

weekly drills.

Emergency power

/ UPS and/or

individual device

batteries.

33. Emergency

Generator,

Switchboard

To provide

emergency power

supplies &

lighting to

essential areas and

systems of the

drilling unit.

One Caterpillar 3412 TA Engine

with a maximum output of 830HP

powering a Stamford Newage

HCM534F2 (or equivalent)

generator, creating 500kW at 480V.

480VAC Emergency switchboard

208/120VAC Emergency Lighting

Switchboard distributes

208/120VAC 3 phase power to

emergency lighting and other power

panels.

ABS MODU Rules

/ Class

requirements

Any unavailability

must be covered by

PTW controls.

Reliability in

accordance with the

manufacturer’s

specifications and

maintenance routines.

Needs to survive all

credible major accident

events, as far as

practicable and for as

long as emergency

power is required.

Maintenance

Department Reliability

Tested and

inspected at

least once each

week through

operation under

load for a

minimum of

two hours.

No

interdependency




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

34. Emergency

Shut Down

(onboard

ESD) systems

To shut down,

Hull Ventilation,

Main Generator,

Emergency

Generator &

Quarters HVAC.

Independent from other alarm and

shutdown systems. ESD Stations

located in OIM Office and Driller’s

Cabin. ESD switches located drillers

control room, OIM/Rig Manager’s

office, main deck port/starboard

forward, radio control room and

emergency generator room. Only

designated battery systems will

remain operational after Shutdown.

ABS MODU Rules

/ Class

requirements

Must be available

whenever the PTB is

required

Must still be able to

effect shutdown when

engulfed in gas or

smoke.

Shutdown buttons must

survive external rig

conditions.

Electrical

Maintenance

Personnel

Certification

and annual

inspections.

Reliability

Weekly PMS

Amos

No

interdependency

35. Fire Dampers The seal

ventilation and

AC ducting to

prevent the

migration of gas,

smoke to other

areas of the

drilling unit, the

living quarters in

particular.

Fitted on air conditioning ducts

passing through A0 or A60 class

boundaries in compliance with

Regulatory Body requirements.

Activated automatically by thermal

fuse link or CO2 flooding (galley

area) and can be manually closed

through ESD system.

ABS MODU Rules

/ Class

requirements

Target availability and

reliability for the

system as a whole =

100%. Individual

alarms may be less

depending on amount

of redundancy.

Fire dampers should

survive the rating of the

bulkheads through

which they pass.

Barge Engineer

& Camp Boss

supported by

Maintenance

Department

Reliability

Function tested

weekly.

Power Generation

and distribution

systems:

Controlled

through fire panel

in Control room

with power from

emergency

generator set and

24 Volt backup.

36. Helideck

Foam system

For the purpose of

extinguishing

helicopter &

helifuel fires.

2 Unitor (or equivalent) Foam

monitors installed on Helideck. 50

USG AFFF Foam Concrete Stored.

CAP437 Must be available for

all helicopter refuelling

Must work under

helideck fire

conditions.

Barge Engineer

and Bosun

Full function

tests every 6

weeks.

Reliability

Weekly PMS in

Amos

Interdependent on

electric supply

from the

emergency

switchboard and

seawater mains as

back-up supply.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

37. Fixed fire

extinguishing

systems

For the purpose of

extinguishing

large Class B fires

in enclosed

spaces.

Engine room, Paint Locker,

Emergency Generator room,

Electrical room and Galley range

hood (exhaust duct) protected by

CO2 Flooding. Controlled from main

control panel and remotely from

entrance to areas. Central CO2 bank

located in the aft / port auxiliary

machinery room for Engine Room

protection. Provision of three sets of

CO2 release cabinets. Other areas

protected by single release cabinet.

Manual Water Deluge system

installed on Drill Floor.

ABS MODU Rules

/ Class

requirements

Required in all

hazardous zones.

IS/EX features target

reliability = 100%


long periods of system

inactivity, diffusers and

piping must be able to

withstand high

temperatures associated

with Class B fires in

enclosed spaces.

Barge Engineer

& Fire Team

members,

supported by

Mechanic

Tested and

inspected at

least once every

12 months by

the appropriate

Regulatory

body approval

methods.

Replaced as

required upon

expiry.

Reliability

PMS Month

inspection and

recorded tag

No

interdependency

other than the

charged bottled of

fire suppressant.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

38. Portable fire

extinguishers

Provide a highly

portable fire

fighting capability

for combating

small Class A and

B fires in all areas

of the drilling

unit.

Quantity (total) no: 71

CO2 – 8 x 5.0kg, 1 x 6.7kg, 2 x 9.0kg

Dry chemical – 47 x 6.0kg, 2 x

22.5kg

Foam – 1 x 45ltr

ABS MODU Rules

/ Class

requirements

Must be available

whenever drilling with

risk of gas in mud.

Target reliability =

100%.


offshore environment.

Barge Engineer

& Fire Team

Leaders

Tested and

inspected at

least once every

12 months by

the appropriate

Regulatory

body approval

methods.

Reliability

PMS Month

inspection and

recorded tag

No

interdependency

39. Fireman suits To provide

thermal protection

to personnel

engaged in fire

fighting activities.

Aluminized 6 oz Nomex Approach

Suits, with Moisture and Steam

Pouch in Back to accommodate

Breathing Apparatus, Barrier Liner,

Complete with Jacket.

Firemen’s Yellow Nomex Outer

shell Coat with Thermal Liner and

Vapour Barrier, 35” long.

Aluminized 8.5 oz Nomex Firemen’s

Coat Outer shell with Nomex

Aramid Batt quilted to Nomex

Facecloth Thermal liner and Comfort

Zone on E-89 Moisture Barrier, 35”

long.

SOLAS 74/81 Must be available

whenever drilling with

risk of gas in mud.


100% but gas sensors

would alert any

problem of gas build-

up in any case.


the temperatures of the

fires that are being

fought.

Barge Engineer

& Fire Team

Leaders

Reliability

Pre-use

inspection for

condition and

functionality.

Maintenance

According to

manufacturer’s

recommendatio

ns.

Inspection as

part of weekly

drill.

No

interdependency




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

40. Breathing

Apparatus

To provide safe

breathing air for

personnel engaged

in fire fighting

and search &

rescue activities.

Four Unipack (or equivalent)

Positive Pressure breathing

apparatus, each with approx. 30 min

of breathable air. Two situated below

Helideck, and two on the roof of the

LQ.

10 minute ELSA Escape Breathing

Apparatuses.

Ska-Pak 4.5 10/15 minute SCBAs

for Emergency Egress.

ABS MODU Class

and NFPA

Standards for

SCBA for FiFi /

NIOSH / SOLAS


the temperatures of the

fires that are being

fought, and rough

handling associated

with fire fighting

activities, search &

rescue activities.

Barge Engineer,

Toolpusher &

Fire Team

Leaders

Reliability

Monthly

inspections

No

interdependency,

other than

charged air bottles

(WA has a refill

compressor).




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

41. Firewater

pumps, ring

main and hose

stations

To provide fire

fighting and

cooling water in

all fire scenarios

that cannot be

dealt with by

portable

extinguishers or

CO2 flooding.

Main seawater supply pumped by

three model 12 EBM-3A pumps each

with capacity of 2200GPM mounted

on the legs.

Three S&N Seawater Pumps (or

equivalent) with a capacity of 52

bbl/min each @ 40-45psi and one

Halco (or equivalent) 2500 Supreme

with a capacity of 26-35 bbl/min @

30-17psi. Supplies sprinkler system

and water lines to burner booms.

Two vertical centrifugal pump

Allweiler NIM80-400/02 type with

500 US GPM output each, located in

aft machinery room.

Hydrants are positioned so that any

point be reached with a single hose

from two hydrants. There are 44

hydrants in total.

Hoses vary between 30 ft and 50 ft

in length. Max diameter is 1 ½” in

accommodation.

SOLAS & ABS

Class

Target availability and

reliability = 100% for

the overall function,

but there is redundancy

amongst individual

items.

Must be able to operate

under black out and

survive the offshore

(salt water)

environment.

Barge Engineer,

supported by

Maintenance

Department

Central

Monitoring

Alarm System.

Reliability

Visual and

Weekly PMS in

Amos

Main firewater

pumps dependent

on main electric

power.

Emergency

firewater pump is

powered from the

emergency

generator /

switchboard.

Water can be

drawn from the

drill water tanks if

necessary. All

down-stream

systems are

dependent on the

pumped water

supply.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

42. Medical

equipment &

supplies

To provide

frontline medical

treatment.

First Aid Kits, Blood borne

pathogens kits, Burn Kits, CPR Kits,

Drug Testing Kits, Dermatological

creams, foams and cleansers &

stretchers provided. As required by

Regulatory Body requirements.

Regional Medical

Guidelines and

Protocols (ABAN

QHSE, Health

Policies HLT

200.00 & HLT

230.00)

100% available for

treatment of injured or

sick personnel.

Medic Record keeping

by Medic.

Monthly

updates

submitted to

OIM on

controlled /

dangerous

drugs. Regular

inspection and

servicing of

first aid kits and

eyewash

stations.

Reliability

Weekly PMS

check on the

medical

equipments

No

interdependency

43. Lifeboats and

accessories

To transport

personnel away

from the drilling

unit in incidents

of major fire, or

loss of rig stability

or buoyancy.

Must be self-

contained.

Four Norsafe/Jiangyin JYN80F

lifeboats, 2 located on the port and 2

located on the starboard side. Each

lifeboat has a 60-person capacity

(200% POB capacity in total) and is

equipped with fire protection,

radio/SART, water spray and

compressed air system.

Food rations and pyrotechnics are

provided as per LSA code.

SOLAS (1974 +

amendments to-

date)

100% reliable when

required Must be able

to pass through burning

oil on water and dense

smoke. Must survive

submergence of rig.

Barge Engineer

supported by

Maintenance

Department

Reliability

Weekly PMS

on the lifeboat.

Inspected and

cleaned once a

week, fuel

change-out

annually,

rechargeable

batteries

Accessories are

taken to include

the lifeboat davit,

release

mechanisms.

Dependent on the

davit launching

safety systems.

(Electric power is

only required for




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

2recharged

weekly,

operability

tested weekly as

part of drills.

retrieval, not for

launching).

Also dependent

on fuel (Diesel

stored in onboard

tanks, amount to

meet Class

requirements).

44. Life rafts and

accessories

To transport

personnel away

from the drilling

unit in incidents

of major fire, or

loss of rig stability

or buoyancy,

when the TEMSC

are not available

for any reason e.g.

major

accommodation

fire. Must be self-

contained.

Six RFD (or equivalent) throw-over

inflatable survival life rafts. Each has

a capacity for 20 persons, and they

are located on the port and starboard

of the Main Deck.

SOLAS 74/83 &

ABS MODU Class

Target availability =

100% however,

maintenance of

ductwork will

determine actual

availability. Target

reliability = 100% It

must survive

submergence of rig.

Barge Engineer

supported by

Maintenance

Department

Annual

inspection and

servicing.

No

interdependency

(throw-over side)

45. Launching

systems for

lifeboats

To ensure the

lifeboats can be

lowered from

height in a

controlled manner

and released once

afloat.

Four standard davit-launching

systems with offload hooks.

SOLAS & ABS

MODU Class

Must be available

during all SIMOPS

with target reliability =

100%

Must be able to

‘survive’ full weight of

fully occupied lifeboat,

reasonable shock

Barge Engineer

supported by

Maintenance

Department

Launching

winch

equipment

inspected once

every 3 months.

Reliability

Lowering line,

shackle or hook

and lifting lugs

(electricity

required for

recovery).




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

loading and marine

environment. Weekly PMS

on the lifeboat

by test the

winch

46. Lifejackets To provide

emergency

personal floatation

for personnel in

the sea.

One lifejacket per person located in

LQ cabins and 120 located in

lifejacket boxes on lifeboat

platforms. Lifejackets are

SOLAS/MCA (UK) & CE approved.

SOLAS and ABS

MODU Class

Must be able to

function as personal

floatation until arrival

of rescue craft.

Barge Engineer

& Camp Boss Reliability

Weekly checks

and drills

No

interdependency

47. Helicopter

rescue gear

To provide

emergency

personnel with the

specialized

equipment to

effect rescue of

helicopter crash

victims on the

helideck.

Helideck rescue equipment includes:

Aircraft Axe, Large fireman’s rescue

axe, crowbar, heavy duty hacksaw

with spare blades, grapnel hook,

quick release knife, bolt croppers,

fireman’s outfit and CO2 lance. The

toolbox is located next to the

helideck.

CAP437 Available whenever a

helicopter is

approaching, on the

helideck or departing.

Reliability in

accordance with the

manufacturers’

specifications and

routine maintenance

activities.


Class B fire for the

duration of helicopter

rescue efforts.

Barge Engineer Reliability

Inspections

prior to each

helicopter

arrival.

No

interdependency

48. Fast rescue

boat

To provide a

means of

retrieving persons

from the sea.

One Norsafe / 15 Merlin (or

equivalent) FRC, stored on roof of

accommodation block. Equipped

with an inboard diesel engine.

SOLAS Availability must be

100% of the time and

locations in accordance

with rig Safety Plan.

Barge Engineer,

supported by

Maintenance

Department.

Tested once

every two

months in-line

with man

Only dependent

on fuel (petrol

stored in onboard

tanks, amount to




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

Reliability is according

to the manufacturers

maintenance and re-

certification

specifications.


launching on a

relatively rough sea

and retrieval by a crane

(in case weather

conditions do not allow

davit recovery).

overboard

drills. Annual

survey.

Reliability

Weekly PMS in

Amos

meet Class

requirements)

49. Derrick

escape device

To provide a

means of escape

for one person

from the

monkeyboard in

the derrick.

One derrick escape chute, type DH-

SALA P-100 (or equivalent).

Equipped with two SALA (or

equivalent) safety belts and Derrick

ladder safety lines.

One Rollgliss Derrick Emergency

Escape Device Vertical Descent,

Low Speed, w/115 Ft. of 3/16”

Stainless Steel Cable, w/Snap Hook,

Auto Retract.

One Rollgliss Derrick Emergency

Escape Device Sloped Descent,

w/200 Ft. of 3/16” Stainless Steel

Cable, w/Linkage, Braking Trolley

and Suspension Bars, High Speed.

OSHA 29 CFR

1926.501(a)(2) &

CSA Z259.2-99

Standard

Availability must be

100% of the time and

locations in accordance

with rig Safety Plan.

Reliability is according

to the manufacturers

specifications.

The device must be

able to survive and

extreme marine

environment.

Toolpusher and

Tourpusher

supported by

Maintenance

Department

Periodic

inspections and

tests.

Reliability

Also covered in

weekly

DROPS.

No

interdependency




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

50. Lifebuoys To provide

buoyancy for

personnel in the

sea, until rescued.

Ten strategically placed Canepa &

Campi / Ligure (or equivalent) Life

Ring Buoys.

Two have smoke systems that react

when in contact with seawater, and

eight have lights, of which four have

140 lifeline throwers.

SOLAS & Class

(LSA certificates)

To be available

whenever drilling is

on-going.


in marine environment

and being thrown

overboard. Line to

survive stress of

pulling the MOB back

in.

Barge Engineer Reliability

Weekly

inspections.

No

interdependency

51. Cold store for

DD8 food

supplies

To preserve food

in a safe condition

for subsequent

human

consumption.

Two R404a refrigerant fan coil units,

one in the chiller and one in the

freezer room and two condenser

units on the quarters roof. Capable of

maintaining chiller room at 2°C and

freezer room at –23.3°C.

Compliance with

BS EN 441

Target availability =

100%


100%

Suitable for offshore

environment.

Chief

Electrician

supported by

Maintenance

Department

Reliability

Daily use by

catering crew.

Main power

supplied through

emergency

generator

switchboard.

52. Potable water

maker,

sewage

treatment

To provide safe

potable water for

all POB.

One Alfa Laval, Model D-PU-36-

C100 (or equivalent) waste heat

Water Distiller rated at a maximum

capacity of 12,000 US GPD and a

Haten Boer Water / GSW3 (or

equivalent) UV Sterilizer.

EEC Machinery

Directive and EN

292-1/2 standards

Suitable for offshore

environment

Medic &

Maintenance

Department

Monthly

bacteria and

quarterly

mineral analysis

of the potable

water.

Reliability

Monthly water

sample test to

town done by

the clients

Seawater intake

must be free of

harmful products,

and particulates

etc. Main electric

supply required

for the water

maker.




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

53. Mast cameras

and derrick

anti-collision

system

To prevent

collision between

the travelling

blocks and other

equipment in the

derrick.

Three Sony FCB-IX45AP (or

equivalent) derrick mast cameras

located at fingerboard level on the

derrick with zoom and panning

capabilities, controlled from the

Drilling Station. Each Receiver pre-

installed in explosion proof

Enclosure complete with suitable

power supply.

Alternative anti-collision system

control speed of raising and lowering

blocks as preset limits are

approached.

API standards Must be able to

withstand offshore

environment

Driller &

Electrical

Maintenance

Department

Reliability

Daily

monitoring.

And part of

Monthly PMS

Main electrical

supply

54. Drains and

bilge system

To safely drain

and dispose of

leak and spill

liquids, rain water

and fire water.

To prevent build

up of pools of

flammable liquid.

To prevent rig

loss of stability

and buoyancy

Bilge system - refer to Section 3.17

Deck & drill floor drains systems -

refer to Section 3.18

Helideck drains system complying

with clause 7.2 of CAP 437

ABS MODU code

CAP 437

Vessel drain available

at all time

Helideck drain

available whenever

helicopter is present

and during helideck

fire fighting equipment

testing.

Barge Engineer

supported by

the mechanical

department

Reliability

Daily

monitoring.

Bilge pumps, Oily

water separators

55. Controls for

explosives

To prevent

accidental

detonation of

explosives, to

jettison explosives

Bunker with jettison system:

The explosives are stored in

specially designed protective

magazines (the bunker) mounted on

supporting skids that can be

ABS MODU code Available whenever

explosives are required

to use or stored

onboard

Barge Engineer ABS inspection

Reliability

Inspected by the

clients third

None




No. Equipment

Name or

Title

Suitability

Criticality

Functionality.


Standard(s)

Availability

& Survivability

Responsible

parties

Reliability

Means of

Verification

Interdependency

overboard in an

emergency

mechanically activated to jettison

magazines overboard.

party as the

explosives

belong to them.

56. Corrosion

protection

system

To prevent

corrosion of all

major structures

and tanks.

Sacrificial anodes located on the

spud can, legs, sea chests, pre-load

tanks

ABS MODU code

and IADC

Must be available at all

times except when the

rig is in dry dock

Barge Engineer

supported by

the mechanical

department

Annual

inspection

Reliability

Metering

reading and

PMS

None



4.4 DD8 / Combined Operations (Drilling and Production)

The following below is the list of SCE used during the combined operations on a platform, fire

extinguishers, and fire hoses, hose connection from the rig for deluge operations on the

platform, emergency instrumentation air and power from the rig.

25 men life raft and 25 lifejackets, T-card system to work on platform, VHF radios, PA system

for communications, Emergency lighting for the working area. Stand by boat provided by

client, Emergency shutdown systems, Gas detection system. Fire detection system but not

limited to. (Refer to CPRA of client).

Please note that during any skidding operation, jacking operations or any heavy lift operations

and rig moves the combined operations or production operations are stopped and suitably bled

off



5 . H S E - C R I T I C A L F E A T U R E S

Aside from the HSE-Critical Elements listed above, DD8 has a number of features that are critical

to preventing and/or mitigating the risk of potential Major Accident Events for the drilling unit.

These HSE-Critical features include:

DD8 is designed, constructed and maintained, as evidenced by its certification, to the

highest appropriate international standards for its designed function of supporting offshore

petroleum development – ref. Section 3.2 above

DD8 is able to accommodate loads as specified in Section 3.6 above

DD8 is able to survive extreme weather / met ocean conditions as specified in Section 3.7

above

DD8 layout features maximum separation of the accommodation from the drill floor and

multiple escape routes from all areas (reference may be made to DD8 Fire & Safety

Drawing No. J134).

Temporary Refuge in the event of emergencies is effectively provided as described in

Section 6 below. The accommodation unit incorporates non-flammable materials.

The layout and provisions of emergency systems on-board DD8 enable the OIM and his

Senior crew members to maintain command and control throughout any reasonably

foreseeable emergency, including provision of temporary refuge for all POB pending

orderly evacuation - for all identified potential Major Accident Events (ref. Section 6

below).

Furthermore, DD8 is equipped with:

Comprehensive monitoring and automatic alarm systems, covering:

o stability of the MODU when afloat and when elevated

o water-tight doors open

o all drilling and well control parameters, including derrick loads, mud flows &

volumes, BOP and Diverter

o flammable & toxic gas detection

o smoke, heat, fire detection

Extensive on-board communications, audio-visual alarm systems and safety signage

throughout the drilling unit

Comprehensive fire protection and fire fighting systems including both passive (fire-rated

bulkheads and deck heads, non-sparking equipment to prevent ignition of leaks) and active

(including dry power, gaseous and water and foam based systems) throughout the drilling

unit

Comprehensive marine navigation and external communications systems

Lifesaving equipment for the entire maximum POB (in full compliance with SOLAS

regulations)

Multiple redundant alarm, command, control & communications facilities and multiple

redundant emergency evacuation systems.



6 . T E M P O R A R Y R E F U G E

DD8 was designed in accordance with ABS and IMO MODU rules (Refs. 6, 7); as such its design

does not include a formally designated Temporary Refuge (TR) of the type specified in Shell

DEM2 Process Safety Manual (Ref. 9). However, DD8 does have facilities that meet the intent of a

TR as originally set out in Cullen’s report into the Piper Alpha disaster (Ref. 8) and translated into

engineering requirements in Shell DEP 37.17.10.11 (Ref. 10), which defines a TR as “a place or

places where personnel will be adequately protected from relevant hazards while they remain on an

installation following a major incident, and from where they will have access to the

communications, monitoring and control equipment necessary to ensure their personal safety, and

from where, if necessary, safe and complete evacuation can be effected.” The places on DD8 that

meet these requirements comprise the Accommodation block and its external muster and evacuation

areas on each side and the helideck – as depicted below.

DD8 Accommodation (LQ) is located as far away as possible from the Drill Floor & Derrick, is

protected with A60 fire rated walls and closable ventilation dampers. It is equipped internally with

fully redundant command, control and communications systems. Outside on the walkways

TEMPSC lifeboats with capacity for 100% of the maximum POB each side are provided (200%

POB total capacity) and at main deck level liferafts are similarly provided for all personnel each

side of the LQ. The CAP 437 compliant helideck is located forward of, and shielded by the LQ.

As part of the HEMP work that underpins this HSE Case, DD8 TR requirements and provisions

have been assessed, qualitatively by the crew and separately by technical study, against all credible

Major Accident Events for the MODU. This TR assessment work resulted in a small number of

agreed remedial actions, including to provide active fire protection for the LQ walkways and

lifeboats – as documented in Part 4 (HEMP) and Part 5 (Action Plan) of this HSE Case.

DD8 ‘TR’ Areas:

Helideck for H2S emergencies

LQ external walkways / lifeboat

stations

LQ box for command & control

functions and for any scenarios

where the external areas on both

sides are deemed unsafe



7 . H S E - C R I T I C A L P R O C E D U R E S A N D T A S K S

The work of identifying and analysing potential Major Accident Events (MAE) for DD8, as

described in Part 4 of this HSE Case, resulted in the formal recognition that certain equipment,

structures, systems and activities of DD8 and its crew are critical to preventing, and/or mitigating

the risk of, MAE.

These HSE-Critical Elements (SCE) and Activities (SCA) are listed in Section 4 of this Part 2, DD8

HSE Case and in Part 3 respectively.

In order to ensure that all SCE and SCA are effectively maintained / carried out, written procedures

are included in DD8 management system and detailed maintenance tasks are set up in DD8

electronic Preventative Maintenance system (AMOS). Procedures and Tasks that relate to

maintaining SCE or carrying out SCA are, by definition, HSE-Critical.

In compliance with the EP 2005-0310 HSE Case model, HSE-Critical Procedures and Tasks for

assuring / maintaining DD8 SCE are presented here.

7.1 Safety Critical Procedure (Operations Procedures)

ABAN management system includes a Safe Operating Manual, a Marine Manual and a

Drilling Manual, which all together contain over 160 written operating procedures applicable

for DD8, many of which relate to one or more of the Major Accident Hazards defined for DD8

in Part 4 of this HSE Case.

These procedures given below are referred to depending on the rig operations, and are

reviewed accordingly.

Management and Review on the Safety Critical Procedure: is done depending on the operations

planned and are documented in the daily reports for well control and for Marine procedures as

an example: the location has to be approved by the Insurers who study the suitability of the

location with respect to the rig, pre rig move meetings are held and documented and signed off.

Which includes all the points mentioned below for the marine and to ensure that we operate it

as per the Marine Manual and the Tow Master , Insurance Rep and the Barge Master and OIM

ensure that it is followed. For the HSE Critical Task can be refer to Part 3 Section 4.3

If any change in the operation plan or client requirement an MOC is signed off.

The procedures cover:

‘Safe Operating Procedures’:

o Drilling, Drill Floor and Well Control activities

o Testing / Pressure testing equipment

o Hygiene, House Keeping, Storage and control of Perishable Materials

o Personnel and Cargo transfers

o Anchor handling, sea bed surveys, bunkering

Marine Procedures:

o Certification, regulations and surveys

o Rig moves, Location approvals, moving into fixed structures, mooring

o Stability calculations

o Vessels alongside, vessels in close proximity

o Weather forecasting



Drilling Procedures:

o Hand-overs, check lists and signals

o Derrick and Drill Floor operations – handling and maintaining equipment

o Drilling, well construction, completion and work over operations

o Wire line and coiled tubing operations

o Well Control activities.

7.1.1 Safety Critical Procedure – Identified: The process to manage/Document control system and review cycle validity period with process of retention

Safety Critical Procedures are identified.

The procedures cover: Process to manage Document control system

Review cycle

Validity period with

process of retention.

‘Safe operating Procedures’:

o Drilling, Drill Floor and Well

Control activities SOP,s , DSI, Client Well control Manual.

Aban Operating

procedures and Well control Manual

Review 5 yearly,

documents validity 5 years

, updated regularly . And change is done as per Aban

MOC procedures.

o Testing / Pressure testing

equipment

UT every year, Pressure testing every 14 days limited to a max of 21 days, two yearly inspections ,

Certification every 5 years.

Aban Well control Manual procedures. Client well

control Manual. Contract.

Pressure Test charts are kept for 3 years. COC of

the equipment is live

document updated every

change in any part of the

equipment.

o Hygiene, House Keeping,

Storage and control of Perishable Materials

Inspection of items when received, daily and weekly inspections by Medic and regular safety

meetings, yearly medical checkup of food handlers

.Maintenance of Chiller and Freezer as per AMOS.

AMOS PMS system.

Contractor Six Monthly

o Personnel and Cargo transfers

6 monthly lifting gear inspections , Crane

maintenance as per Aban PMS ( AMOS ). 5 yearly load tests as per Class requirement.

AMOS certification Schedule, BE monthly

reports and rig

Certification updates.

5 years and updated.

o Anchor handling, sea bed

surveys, bunkering

Rig move meeetings, at shore as well as rig with all parties like tow master, client tow master, insurance

surveyor , OIM and BE, pre rig move site

inspections and bore hole logs analysed and COA from insurance, adhering to bunkering procedures,

pre use checklists

Rig Move COA, Rig move meetings and procedures

signed off,

Every rig move. Rig move

documents are kept for 5 years on the rig and stored

and then sent to shore for

storage.

Marine Procedures:

o Certification, regulations and

surveys

inspections done 6 monthly / yearly /bi annualy and 5 yearly as per class ABS requirements to the satisfaction of the attending surveyor.

Certification master list on the rig managed by BE and kept at Spore with the Marine Manager

lifetime of the rig. Reviewed annually.

o Rig moves, Location

approvals, moving into fixed

structures, mooring

Rig move meetings, at shore as well as rig with all parties like tow master, client tow master, insurance surveyor , OIM and BE, pre rig move site inspections and bore hole logs analysed and COA from insurance,

rig move document, Reviewed every rig move and kept for 5 years.

o Stability calculations

daily and reported to all .soundings are given to BE, who puts in the figures and calculates the amount of variable is less than the allowed loading on each leg. ballast as required.

rig move calculation programme, stability programme

reviewed every day, and reviewed by marine manager and tow master and insurance prior to rig move including the preload programme, stored for atleast 5 years.



o Vessels alongside, vessels in

close proximity

Boats call the rig announcing the ETA with the

cargo as per the requirement and loading notes, tied

up to buoy and come close otherwise mostly DP

vessels are in use. station keeping and in close

contact with radio room and crane operator and BE. Stay upwind of dry bulk cargo transfer

Marine operating

procedures. Client Marine

procedures. Daily barge

reports file.

Radio room log book ,

showing call and tie up and

cargo start and end times,

yearly.

o Weather forecasting

daily basis received and if extreme weather is

forecasted sent by Aban Singapore marine

manager. Two sources are used one from Aban and one from Client for rig moves and extreme weather

like Fugro and Metaocean.

email and contracted and during the rig move two

independent forecasts are

checked for better clarity

Weekly / monthly records

kept .

Drilling Procedures:

o Hand-overs, check lists and

signals

driller and crew handovers, Checklists and audits,

PMS for the day, Drilling safety instructions.

Signals are used when necessary like navigation lights during moves

Barge Engr / OIM have the

reports as required. Rig document . 5 yearly.

o Derrick and Drill Floor

operations – handling and maintaining equipment

DSI for drillers signed off by OIM and DSV, and

then handed over to floor by Tool Pushers for operations. Handling equipment go for 6 monthly

inspection and daily use pre-checklist. Maintenance

is done as per AMOs schedules and when any breakdown happens.

Amos for equipment

maintenance. SOP and JRA

5 years

o Drilling, well construction,

completion and work over

operations

pre spud meetings, pre operation meetings, morning conference calls, AAR, end of well reports,

ABAN & Client Ops Manuals

5 years

o Wire line and coiled tubing operations

Pre job meetings, JRAs and pre tour meetings and

pre job meetings, regular hole fill up monitored.

TPW checked and pressure tested

Client manuals and standards.

5 years

o Well Control activities.

Regular drills are help, trip drill, strip drill, pit drills, equipment draw down tests and function tests

are done and if situation demands follow aban

procedures of shut in calculate pressures and kill well, always ensure two barriers in place for process

safety. divertor function tests and pressure tests

also.

Aban Well control manual

and client PCM,

every change in BOP , on installation and every 14

days , kept in files and also

5 yearly coc.

7.2 Rig-specific Procedures

In addition to the above corporate procedures, DD8 maintains a set of additional rig-specific

procedures and equipment operating and maintenance manuals. These address use and/or

maintenance of all equipment on-board including the HSE-Critical equipment listed in Section

4 above.

The full list of procedures is included in Part 3 of this HSE Case, and as such is not replicated

here.

7.3 Maintenance Tasks

DD8 uses the AMOS Preventative Maintenance (PM) System, as described in Reference 13.

HSE-Critical Maintenance Tasks set up within ABAN / DD8 AMOS cover maintenance of all

SCE listed in Section 4.3 above, as well as many SCA e.g. Drill Floor & Derrick inspections.

The full catalogue of DD8 maintenance tasks relating to SCA and SCA is extensive and is

therefore not reproduced here. However, an AMOS output report of all DD8 maintenance

tasks (running to over 200 pages of single line items) has been generated to demonstrate the

comprehensive coverage of DD8 maintenance requirements within the PM system, hyperlinked

here. Please also see Reference 13. Information within that listing is presented in the

following fields:

1. Component Number – this is a unique equipment identification number, of which the first

three digits represent the equipment group (e.g. 313 for well control equipment), followed

by another 3 digits that represent the type of equipment (e.g. 057 for electric motors),

followed by 2 more digits for the equipment sub group

2. Name of the equipment



3. Job Code – comprising a single letter that represents the job type (e.g. I for inspect, L for

lubricate) followed by a 3-didgit unique job identifier

4. Revision number (of the task as set up in AMOS)

5. Job Description – the task that is to be done on the equipment (based on OEM

recommendations and ABAN experience)

6. Frequency with which the job is (to be) done

7. Last Done – the date of the last performance of the job.

7.4 Emergency Procedures and Incident Investigation Procedures

These categories of procedures are HSE-Critical but do not contribute directly to maintaining

the SCE. As such, they are described (only) in the HSEMS section of Part 3 of this HSE Case,

not in this Part 2 Facility Description.

7.5 Engineering Management / MODU Modification

Since delivery in 2008, the ABAN DD8 has undergone no major modifications or upgrades.

Details of procedures and responsibilities are given in ISM 900.00 ABAN Management of

Change.

In terms of safety, quality and cost efficiency it is necessary to have a systematic approach to

the control of all elements affecting technical projects.

Controls shall ensure that the integrity of the operating unit is not adversely affected by any

technical modifications that correct inspection, maintenance, operating and verification

requirements are implemented and that pertaining documentation is updated accordingly.

Projects will be subject to the company management of change process. The proposed scope of

work is reviewed by suitably qualified personnel at Singapore Head office who shall involve

the supervisory personnel responsible the area of scope of work.

The OIM Manager is responsible for drilling and marine procedures and thus responsible for

changes and the implementation of change. Changes are carried out according to the Change

Procedure.

The approval authority is the Rig Manager .

Recommendations for change and corrective action arise from non-conformance reports and

specifically from accident investigations, emergency exercise reports and audits.

A report will identify the person responsible for corrective action who will prepare the request

and the change scope once the Rig Manager has determined whether existing procedures

should be revised or new ones initiated.

Changes may also be imposed by the regulatory authorities, Classification Society or the

Operator.

A change in procedures is considered to be complete when:

A written instruction has been issued and circulated to all staff concerned

When the change in procedures has been monitored and found to be effective

Tools utilised during the MOC procedure depending on the nature of the change include:

HAZID/ HAZOP etc;



Engineering change procedures;

Variation order;

Work guideline revision, training/ procedures matrix, competence assessments;

Permit to Work, HMO (Hazard Management Outline) Tool-box Talk, and SMART Card

Change in people.

Change in operation procedures.

Business and commercial risk assessments;

Document Control;

Communication from External Interested Parties; and,

Management Review.

The OIM has to verify that any change affecting the rig has been carried out. A schedule and

deadline are set to implementation of the changes.



8 . R E F E R E N C E S

1. Deep Driller 8 – KFELS Super B Class 246ft x 218ft x 25ft MODU Marine Operation

Manual, Keppel FELS Document no. B289-D017, Alt no. 1

2. Deep Driller 8 IADC Equipment List, Revision 1, December 2007

3. DD8 Drawings:

Title Drawing

number

Revision

indicator

Date

General Arrangement

Quarters Arrangement

(120 Men, Main DK & 1st Deck)

D006 3 15th Sept 2004

General Arrangement

Quarters Arrangement

(120 Men, 2nd

& 3rd

Deck)

D007 3 15th Sept 2004

Schematic & Arrangement

Hospital Call Alarm

E707 2 22nd

February 2005

General Arrangement

Outboard Profile

D001 3 15th Sept 2004

General Arrangement

Machinery Deck (5Ft Level)

D003 3 15th Sept 2004

General Arrangement

Machinery Deck (16Ft Level)

D004 3 15th Sept 2004

General Arrangement

Main Deck and Above

D005 3 15th Sept 2004

Machinery Arrangement

Deck Cranes

M102-10 2 23rd

Dec 2004

4. DD8 HSE Case Development 2010, DD8 Survey Report, Document No. PEWI-ABAN-DD8-

Survey-01, dated July 2010

5. International Convention for the Safety of Life at Sea (SOLAS), 1974, IMO

6. ABS MODU Code: ABS Rules for Building and Classing Mobile Offshore Drilling Units

7. IMO MODU Code A.6499(6): IMO Code for the Construction and Equipment of Mobile

Offshore Drilling Units

8. The Public Inquiry into the Piper Alpha Disaster, The Hon Lord Cullen, UK Department of

Energy, HMSO

9. Shell HSSE Control Framework PROCESS SAFETY MANUAL, DEM 2 – Process Safety

Basic Requirements, Version 2, December 2008

10. Shell Design Engineering Manual: Design of Offshore Temporary Refuges, DEP 37.17.10.11-

Gen., March 1994

11. Deep Driller 8 – Emergency Response Manual, Revision 1, April 2009, File Code ABAN –

DD8 – 001



12. ABAN Singapore Pte Ltd. Shipboard Oil Pollution Emergency Plan (SOPEP) for Mobile

Offshore Drilling Unit Deep Driller 8 as required by MARPOL 73/78, Annex 1 Regulation 37

13. AMOS Onboard User Guide for ABAN, prepared by SpecTec Asia Pacific Pte Ltd., Revision

1, September 2009

14. Component Jobs List: Deep Driller 8/Maintenance 8/5/2010 (PDF file generated by AMOS

and hyperlinked here to the master electronic copy of this Case document)


Part 2 – Facility and Operations Rev 5 Attachment A

Attachment A

DD8 Certification Survey Status List (example)


Part 2 – Facility and Operations Rev 5 A1

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Documents

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