Safety In Drilling Manual

Shell International Exploration & Production B.V.

Drilling

EP 95-0210

HSE MANUAL

Revision 0 16 October 1995 jh 0202/2000

Contents

EP HSE Manual Amendment Record Sheet Section Number:

EP 95-0210

Section Title:

Drilling

Rev

Chapter Nos.

Description to amendment

All

Original hard copy and CD-ROM issue

Amended by

dd/mm/yy

No. 0

Date

EP 95-0210 Revision 0 16 October 1995

16/10/95

EPO/61

ii

Contents

3.6.5 Incident reporting........................35

Contents

3.6.6 Incident follow-up........................36

1

3.7 Audit...................................... ............37

1.1 Objectives....................... ....................1

3.8 Review......................... .....................39

1.2 Background.................................... .....1

4 Preparation

2 Overview

3

4.1 Site Preparations - Land...................44

2.1 Scope of the Document......................3

4.1.1 Locations.....................................44

2.2 Relationship Between the Chapters....3

4.1.2 Road vehicles and mobile plant. .45

1 Introduction

3 Drilling HSE Management System 5 3.1 Leadership and Commitment..............5

44

4.1.3 Camp sites..................................46

4.2 Preparation Offshore........................48 4.2.1 Location preparation offshore.....48

3.2 Policy and Strategic Objectives..........6

4.2.2 Structural integrity of jack-ups.....48

3.3 Organisation, Responsibilities, Resources, Standards and Documents............................... ........8

4.2.3 Precontract assessment of semisubmersibles and drill ships. .50

3.3.1 Organisational structure and responsibilities.........................8

4.3 Materials Procurement......................52

3.3.2 Management representative(s). . .10

4.3.1 Hazard data.............................. ...52

3.3.3 Resources...................................10

4.3.2 Inspection....................................52

3.3.4 Competence................................11

4.3.3 Stacking and storage..................52

3.3.5 Contractors..................................15

4.4 Transportation of Materials and Equipment................................. .....52

3.3.6 Communication...........................18 3.3.7 Documentation and its control.....19

3.4 Hazards and Effects Management Process............................. .............21

4.2.4 Tender assisted operations..........51

4.4.1 Road transport.............................52 4.4.2 Sea transport...............................53 4.4.3 Air transport.................................53

3.5 Planning and Procedures.................22

4.4.4 Rig moving on land.....................53

3.5.1 General.......................................22

4.4.5 Rig moving offshore....................54

3.5.2 Asset integrity..............................24

5 Equipment

3.5.3 Procedures and work instructions ..............................................24

5.1 Maintenance.....................................56

3.5.4 Management of change..............27 3.5.5 Contingency and emergency planning............................... ..28

3.6 Implementation and Monitoring.........31 3.6.1 Activities and tasks......................31 3.6.2 Monitoring...................................31 3.6.3 Records.......................................35 3.6.4 Non-compliance and corrective action....................................35

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5.2 Hazardous Zones............................. .56 5.2.1 Hazardous zone classification.....56 5.2.2 Operation of diesel engines in hazardous zones...................56 5.2.3 Electrical safety in hazardous zones................................ .....57

5.3 Personal Protective Equipment.........57 5.4 Drilling Equipment................... ..........58 5.4.1 Drawworks safety........................58

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HSE Manual EP 95-0210 Drilling 5.4.2 Pulsation dampeners..................58

6.1.2 Taking tubulars on site.................69

5.4.3 Relief valves...............................59

6.1.3 Transferring tubulars to the rig floor ..............................................70

5.5 Derricks and Masts...........................59 5.5.1 Erection equipment.....................59

6.1.4 Rigging up and running casing....71

5.5.2 Derrick and mast inspection........59

6.1.5 Making up or laying down tubulars, e.g. drill collars......................72

5.5.3 Derrick loading............................59

6.1.6 Elevators and slips......................72

5.5.4 Foundations................................59

6.1.7 Drill floor operations....................73

5.5.5 Masts....................................... ....59 5.5.6 Guy lines.....................................60

6.2 Handling of Chemicals and Gas Cylinders......................... ...............75

5.5.7 Escape line and slide..................60

6.2.1 Handling of harmful chemicals....75

5.5.8 Crown protection.........................60

6.2.2 Storing and handling of gas cylinders................................76

5.5.9 Deadline anchor/weight indicator 60 5.5.10 Stabbing board..........................61

5.6 Lifting Equipment..............................61 5.6.1 General.......................................61 5.6.2 Inspection - general.....................62

6.3 Crane Operations............................. .77 6.3.1 Safe operating principles............77 6.3.2 Heavy lifts...................................77

6.4 Pressure Testing...............................78 6.4.1 General.......................................78

5.6.3 Inspection of wire rope slings, hooks, shackles and winches 62

6.5 Hydrogen Sulphide (H2S).................78

5.6.4 Elevators.....................................63

6.5.1 General.......................................78

5.6.5 Crown block and travelling block 64

6.5.2 Planning for H2S.........................79

5.6.6 Wire ropes................................ ...64

6.5.3 Equipment...................................79

5.6.7 Catlines and catheads.................65

6.5.4 Monitoring...................................80

5.6.8 Man riding winches.....................65

6.5.5 Alarm systems (H2S detection)...81

5.7 Blowout Preventers (BOP)................65

6.5.6 Personal protective equipment. . .82

5.7.1 Recommendations specific to subsea BOPs........................66

6.5.7 Additional safety equipment........82

5.7.2 Shear rams................................ ..66 5.7.3 Hydraulic bolt tensioning equipment.............................66

6.5.8 Well control.................................83 6.5.9 Personnel training.......................83 6.5.10 H2S drills.............................. .....84 6.5.11 Personnel..................................84

5.7.4 Store keeping and spare part control...................................66

6.6 Occupational Health and Safety.......85

5.7.5 BOP control system....................67

6.6.1 Housekeeping.............................85

5.8 Steel Hoses (Chiksan and Coflexip). 67

6.6.2 Noise control...............................85

5.8.1 Standardisation of HP unions......67

6.6.3 Contractors' occupational health. 85

5.8.2 Restrictions on use......................67

6.7 Permit-to-work............................. ......86

69

6.8 Environmental Hazards.....................87

6.1 Tubulars Handling.............................69

6.8.1 Noise...........................................87

6.1.1 Certification and testing..............69

6.8.2 Environmental auditing...............88

6 Operations

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6.8.3 Waste management....................88

7 Associated Activities

89

7.1 Electric Wireline Operations.............89 7.1.1 Responsibilities...........................89 7.1.2 Rigging up...................................89 7.1.3 Logging operations......................90 7.1.4 Pressure control..........................90 7.1.5 Storage and working with explosives.............................90 7.1.6 Safety procedures in use of explosives.............................91 7.1.7 Radio transmissions....................92 7.1.8 Systems impervious to stray electrical currents..................93 7.1.9 Tubing Conveyed Perforating (TCP) systems......................94 7.1.10 Storage and use of radioactive sources..................................95 7.1.11 Fishing............................... ........96

7.2 Well Testing....................................... 97 7.2.1 General.......................................97 7.2.2 Fracturing....................................98 7.2.3 Acidising......................................99

7.7.3 Responsibilities.........................109

7.8 Helicopter Operations.....................110 7.8.1 Training................................... ...110

APPENDIX I Policies

112

APPENDIX II Responsibilities of Key Staff 114 APPENDIX III Land Rig Move Plan

120

APPENDIX IV Classification of Hazardous Areas 122 APPENDIX V Operation of Diesel Engines in Hazardous Areas 126 Abbreviations

130

Glossary

132

References

134

Index

138

7.2.4 Cryogenic operations..................99

7.3 Coiled Tubing Operations...............101 7.4 Concurrent Operations................... .102 7.4.1 General.....................................102 7.4.2 Procedures................................103 7.4.3 Supervision...............................104 7.4.4 Specific requirements...............104 7.4.5 Wireline activities (slickline and electric logging)...................106

7.5 Wireline Operations (Slickline)........107 7.6 Diving/ROV Operations...................107 7.6.1 Special precautions...................107 7.6.2 Restrictions...............................108

7.7 Standby Vessels.............................108 7.7.1 General requirements...............108 7.7.2 Duties........................................109

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1 Introduction

1

INTRODUCTION

1.1

Objectives

This document is a development of EP 55000-34 'Safety in Drilling' revised in July 1991 which it now supersedes. It is aimed at both Company and contractor staff involved in drilling operations. It is intended to: • identify health, safety and environmental hazards in the drilling operation and provides guidance on how risks can be reduced • provide guidance on drilling HSE related issues • describe how to develop the essential core of a HSE Management System (HSE MS) appropriate to drilling operations • enable an assessment to be made of a contractor's approach to HSE which will assist in the contractor selection process and facilitate better control of HSE in the drilling operation.

1.2

Background

Activities on drilling sites and rigs present potential major hazards to health, safety and the environment. This is exacerbated by the diversity of the personnel involved resulting from the use of contractors and subcontractors and the international nature of the business. Despite our best endeavours accidents still occur, people are injured, the environment may be damaged and Company assets put at risk. The basic cause of accidents can be frequently identified as a lack of effective planning or a failure to train personnel to achieve competence. The recognition of all the potential hazards of a drilling operation during the planning stage is essential so that they can be eliminated or at least controlled. Similarly, attention shall be paid to the programme for training personnel to a standard which enables them to perform competently the requirements of their job function and duties.

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2 Overview

2

OVERVIEW

2.1

Scope of the Document

This document addresses HSE aspects of the business process activity 'Drilling and Well Operations' as defined in the Shell Exploration and Production Business Model, the EPBM (Ref. 1). The HSE Management System (HSE MS) for a drilling operation has effectively the same components as the overall system for the Opco which are described in EP 95-0100 and other referenced parts of Volume 1. This section describes many of the requirements of an HSE MS as they relate to a drilling operation. The remaining chapters provide guidance on drilling HSE related issues that might be encountered and may be useful in the development of hazard registers associated with an HSE Case. It is not the objective of this document to provide comprehensive guidance on the development of an HSE Case. A great deal of guidance is provided, however, on the management of hazards. Much of this advice is a distillation of experience gained by many knowledgeable staff over a long period.

2.2

Relationship Between the Chapters

The following chapters of this document are shown in Figure 2.1 indicating their hierarchy. Figure 2.1

Relationship between the chapters

DRILLING HSE SYSTEM MANAGEMENT Chapter 3

Preparation

Equipment

Operations

Associated Activities

Chapter 4

Chapter 5

Chapter 6

Chapter 7

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Preparation This chapter provides guidance on HSE requirements associated with site preparation, materials procurement, transportation to site, and moving the rig.

Equipment Hazardous zone policies are detailed, and the background to personal protective equipment requirements. A good deal of information is provided on hardware. Drilling equipment is primarily under the control of the contractor but the Company Supervisor shall be aware of the HSE related matters in order to verify that proper control is being exercised.

Operations This chapter covers the HSE aspects of executing the drilling operation.

Associated activities The operation of drilling a well entails the use of other services such as wireline logging and well testing services. This chapter gives guidance on the hazards associated with such operations and on the responsibilities of the drilling department when such activities are taking place.

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3 Drilling HSE Management System

3

DRILLING HSE MANAGEMENT SYSTEM

The text draws in part on work carried out in Opcos and single string ventures and consequently reflects the views of a wide variety of staff in a number of areas. It also incorporates work by the Safety Management System team in SIEP, with the intent that it is compatible, in a drilling engineering specific way, with guidance documentation provided in EP 95-0310. In essence, an HSE Management System is a reflection of the objectives of an enterprise and the manner in which these objectives are to be met as laid down by its senior management. Achievement of the hazard management objectives will be realised through the setting up of an organisation in which responsibility is assigned and to which resources are provided. The standards and procedures through which the objectives will be met are defined by those with the necessary expertise. The implementation of standards is monitored through performance indicators and assured through periodic audits. Such audits are reviewed by management who may initiate system changes to facilitate improvement. The system is additionally made live through loops which feedback improvements and corrections at all stages. The system incorporates the eleven elements of enhanced safety management (ESM) and increases their effectiveness through the structured improvement process. The quality management structure and the ESM relationship is illustrated in Figure 3.1. Figure 3.1

HSE Management System and ESM relationship HSE Management System

ESM Principles Visible senior management commitment Sound HSE policy Line responsibility for HSE Competent HSE Advisers High, well understood HSE standards Effective HSE training

Leadership and Commitment Policy and Strategic Objectives Organisation, Responsibilities Resources, Standards & Doc. Hazards and Effects Management

Realistic HSE targets and objectives

Effective motivation and communication Techniques for measuring HSE performance Thorough incident investigation and follow up Audit of HSE standards and practices

Planning & Procedures

Corrective Action

Implementation

Monitoring

Audit

Review

Corrective Action & Improvement Corrective Action & Improvement

In this chapter it is intended to provide guidance on how Drilling Engineering Departments should structure their HSE MS in a way which is fully compatible with Group guidance. Drilling Engineers will then be in a better position to assess the completeness and compatibility of a contractor's HSE MS and also the rig HSE Case which defines the controls that assure safety in a drilling operations project.

3.1

Leadership and Commitment

The foundation of an HSE MS is leadership and commitment from the top management of the Company, and its readiness to provide adequate resources for HSE matters.

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HSE Manual EP 95-0210 Drilling Particular attention is drawn to the importance of senior management providing a visible expression of commitment. Failure to do so will undermine the credibility of HSE policy and objectives. Demonstrations of commitment to the HSE MS at different management levels include, amongst others: • allocating the necessary resources, such as time and money, on HSE matters • setting a personal example in day-to-day work • putting HSE matters high on the agenda of meetings, from the Board downwards • being actively involved in HSE activities and reviews, at both local and remote sites • communicating the importance of HSE considerations in business decisions • recognition of performance when objectives and targets are achieved • encouragement of employees' suggestions for measures to improve HSE performance • participation in internally driven and externally driven initiatives. Management leadership is also necessary to promote a Company culture conducive to good HSE performance, in which the HSE MS can function effectively. Senior management can foster active involvement of employees and contractors in improving HSE performance by encouraging a culture of belief, motivation, participation and commitment: • Belief in the Company's will to improve its HSE performance - essential in particular to open, blamefree incident reporting, and in general to effective HSE MS implementation. • Motivation to improve personal HSE performance - based on awareness and understanding, and positive recognition to reinforce desirable attitudes and behaviours. • Participation of staff at all levels - through seeking their views and involvement in HSE MS development, and energetically pursuing suggestions for improvement. • Commitment of staff at all levels is essential if the HSE MS is to be fully effective, and should follow from firm belief, personal motivation and active participation.

3.2

Policy and Strategic Objectives

This chapter gives guidance on the content of a Health, Safety and Environmental (HSE) policy and the objectives such a policy is intent upon fulfilling. Within Opcos, departmental policies are derived from the corporate document, which is itself invariably based on Group guidelines, though adapted to take account of specific area needs. Consequently, a good deal of commonality is seen between them. Likewise, contractors follow the same general principles. Figure I.1 shows the Group policy guidelines on health, safety and the environment as endorsed by the committee of managing directors in June 1991. Likewise, contractors are required to support policies which advise that the health and safety of all persons on the installation or worksite, and all others who may be affected by its activities, together with the protection of the environment: • are of prime importance to the contractor who will seek to maintain the highest practically achievable standards in respect of these • have equal status with the other primary business objectives • are line management responsibilities which form an integral part of the duties of all supervisors.

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3 Drilling HSE Management System The policy shall also confirm that the contractor will ensure that employees have the required skills and support to meet this commitment, by providing, where necessary, appropriate training and opportunities to gain competence. It shall also state that: • the contractor promotes active participation of all in its employ in the establishment and observance of measures to safeguard their health and safety at work and to protect the environment • it expects its subcontractors to work to similar high standards and achieve comparable performance. To assure the above, it is necessary to perform an HSE assessment at the precontract stage. This may take the form of a questionnaire in the tender document, but will increasingly take the form of reviewing the contractor's HSE Case for the installation or operation. This and other aspects of HSE in the management of contractors is fully described in EP 95-0100 HSE Management Systems and EP 95-0110 Management of Contractor HSE. The objectives which underpin the health, safety and environmental protection policy can typically be summarised as follows: • to prevent all workplace injuries, by encouraging active workforce participation in all aspects of safety including participation in the hazard management process • to provide a safe and healthy workplace • to eliminate environmentally damaging discharges and emissions through the implementation and monitoring of an effective waste management programme • to comply with all statutory obligations, through the fulfilment of management responsibilities • to provide properly engineered and well maintained facilities • to work with external agencies such as certifying authorities to promote improvements • to ensure all employees are competent to fulfil their duties • to prevent use of alcohol or abuse of substances on location • to prevent vehicle accidents. Increasingly, companies and contractors are developing substance abuse policies. A model Company policy statement, taken from Group guidelines on the subject, is shown in Figure I.2. Industry guidelines are described in 'Substance Abuse Management Strategies' (Ref. 2).

HSE sensitive positions Within the policy on substance abuse, reference is made to safety and environmentally sensitive positions which in the context of well operations include: • all Company and contractor line managers and office based supervisors with operational responsibility • field based staff including Company, contractors' and subcontractors' employees. The success of a substance abuse policy depends on the commitment and leadership of management. For the purpose of the policy, management is treated in the same manner as those employees holding safety and environmentally sensitive positions.

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HSE Manual EP 95-0210 Drilling

3.3

Organisation, Responsibilities, Resources, Standards and Documents

The responsibility for all well operations aspects of exploration, appraisal and development drilling, and workover operations, lies with the Drilling Engineering group which also sponsors and manages all drilling and most associated contracts. The responsibility for health, safety and the environment in the well operations process is vested in the Head of Drilling Engineering. In practical terms, elements of this responsibility are delegated through the line. Operations, in this sense, cover the complete process from planning, through execution, to review and improvement. Thus, for instance, the writer of the drilling programme is responsible for the accuracy and completeness of that programme in the same way as a Driller is responsible for the safe execution of drill floor operations. Well drilling operations consist of the following main activities in most Opcos: Plan well operations

Drilling Engineering staff need to be involved in the earliest phases of planning. The contribution made to feasibility studies and evaluating development options can lead to significant cost and HSE benefits. Other areas of planning include: • the preparation of the short term drilling sequence on the basis of the exploration, appraisal, development or workover portfolio • acquiring the necessary services • planning for the transport of equipment and personnel.

Prepare for well operations

Prepare a well design and detailed drilling programme or workover programme covering contingencies and emergency procedures and obtain required internal and external approvals. Order all necessary materials and complete site preparation.

Execute well operations

Secure adjacent wells and facilities as required. Move in, rig up, drill and complete or workover wells according to programme, rig down and move or demobilise as appropriate.

Report and analyse

Prepare an end of well report which will enable an in-depth analysis of the operation. Apart from being an important record, the report will facilitate cost and HSE improvements in later wells.

3.3.1

Organisational structure and responsibilities

The Company shall define, document and communicate, with the aid of organisational diagrams where appropriate, the responsibilities, authorities, accountabilities and interrelations necessary to implement the HSE MS. These shall include those of all personnel who manage, supervise and/or monitor HSE-critical activities. Refer to EP 95-0100 HSE Management Systems, Chapter 3 for further advice on organisational structure. Guidance on individual responsibilities for key staff, both Company and drilling contractor, is given in Appendix II. Any inconsistency between Company and contractor HSE MS shall be resolved prior to commencement of operations. The conduct of operations in a manner which takes full account of the health and safety of personnel, protection of the environment and local culture and circumstances is the responsibility of all involved,

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3 Drilling HSE Management System with each layer of supervision being responsible for their subordinates in accordance with the principle of line responsibility.

Contractor responsibilities The main contractor is responsible for: • implementing a management system directed at providing a safe worksite • implementing an on-site HSE programme • providing for the safety of contractor and subcontractor personnel • controlling work and health conditions at the rig site • training contractor personnel to ensure safe operations • providing contractor personnel with necessary protective and safety equipment and appropriate training in the use of such equipment • ensuring that all contractor and subcontractor furnished machinery and equipment is fit for purpose and properly maintained • developing on-site emergency contingency plans for major scenarios such as blowout fire/explosion, toxic material release, man-overboard, stability control, heavy weather, etc • liaising with the Company in the development of plans for emergencies which require the intervention of outside resources • complying with all applicable laws and regulations • complying with Company HSE guidelines, policies, procedures.

Company responsibilities The Company is responsible for: • verifying that contractors' HSE policies, standards, and procedures are acceptable to the Company and conform with applicable laws and regulations • verifying that contractor's HSE programme is accomplishing the desired HSE objectives • reporting any hazards to appropriate contractor supervisors when situations exist where safety has been compromised and following up to ensure that appropriate action has been taken to correct the situation • requiring the Company's subcontractor's personnel to observe the rig contractor's HSE programme and co-ordinating activities between rig contractor and Company subcontractor personnel to avoid conflicts • identifying responsibility for third party equipment maintenance and operability and ensuring that such responsibilities are discharged • emergency contingency plans requiring co-ordination of third party groups. Such plans will include responses to oil spills, rig evacuation, etc • monitoring contractor and Company personnel HSE performance and assisting in the implementation of improvement initiatives.

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HSE Manual EP 95-0210 Drilling

Role of HSE department In areas where operations are supported by an HSE department, responsibilities assumed should include the following: Operational HSE • Advise on the development and testing of contingency plans and drills • Advise on governmental HSE regulatory requirements and liaise with governmental agencies as required to ensure that regulations are workable • Assist in the investigation and analysis of accidents and incidents, and in the preparation of reports. Responsibility for this, however, remains with the line supervisor • Disseminate information, data and experiences related to HSE in operations • Participate in formal HSE audits and inspections • Develop standards and specifications for safety and protective equipment • Advise on hazards associated with chemicals and other materials produced, or likely to be used in the operations, and advise on exposure limits • Advise on HSE clauses, and their implementation, in drilling related contracts • Advise on noise limits and other areas of occupational health • Liaise with contractor's HSE adviser to assure consistency of advice • Review risk analysis and hazard assessment of drilling and well test programmes. • Advise on and assist in the development of standards and practices that will protect the environment • Liaise with governmental agencies to ensure timely advice of regulatory requirements and compatibility of operations with those requirements. HSE training • Assist in the identification of HSE training needs • Develop and conduct specialist HSE training as required • Assist in on-the-job HSE training programmes • Provide HSE awareness material, and training aids • Contribute to HSE meetings • Arrange defensive driving training • Maintain a record of HSE related courses attended by drilling staff and notify refresher requirements. In some areas this responsibility is retained by the line department.

3.3.2

Management representative(s)

See EP 95-0100 HSE Management Systems.

3.3.3

Resources

The changing roles of both Company and contractor staff with the advent of integrated engineering and incentive contracting strategies need to be addressed in the planning stages of operations. The decision making process shall be agreed prior to start-up and both the numbers and calibre of contractors' staff

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3 Drilling HSE Management System shall be commensurate with the demands and objectives of the job. HSE audits and operations reviews have frequently found that the demands on the contractor's Toolpusher have been underestimated. Responsibilities should be agreed and matched by levels of authority. Staff should not be held responsible for areas where they do not exercise control. In this respect, job descriptions for supervisory staff enables both numbers and competencies to be defined in the contract rather than being modified on an ad-hoc basis after commencement. A clear job description will also assist in facilitating a smooth transition with respect to the changing role of the Company Drilling Supervisor.

3.3.4

Competence

General All staff shall be competent to discharge the responsibilities of their jobs or be in the process of gaining such competence in a supervised manner. Work roles that are key to the HSE management of the operation shall only be performed by those persons who can discharge their responsibilities safely and effectively. The contractor's Base Manager is responsible for ensuring that all HSE critical activities are covered by standards of competence and an assessment scheme to assure continuing competence is in place. He shall fulfil this requirement in accordance with corporately defined standards. The contractor's Rig Superintendent is responsible for ensuring that all personnel on the rig (other than those undergoing training who will be under direct supervision) are competent to carry out tasks without risk to the health and safety of themselves and others. The contractor's capability to provide competent staff is assessed during the prequalification appraisal stage of the contract process and by continuous assessment throughout the course of the contract. Company management is responsible for the provision of personnel who are competent to perform their defined roles and will monitor continuing competence through the formal annual performance appraisal review.

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HSE Manual EP 95-0210 Drilling

Qualifications

Contracts should define the qualifications of staff holding key HSE and operational responsibilities. Where such responsibilities include the control of significant hazards, the qualifications shall include a tested practical element (e.g. for a Driller, the possession of a well control certificate which includes a successful simulator exercise endorsement, for a Barge Engineer skills in ballasting and rig stability). Increasingly, the demands of senior rig supervisory jobs require skills not formerly required of contractor's staff. Contracts should explicitly state the scope of senior job positions and verify that incumbents are qualified to hold them.

Training Safety training should be based on competence requirements, and take into account development plans. The effectiveness of training will need to be assessed through observation and drills. The Company Drilling Supervisor on contractor rigs has an important role to play in verifying that contractors fulfil their obligations in the above. Some specific requirements are suggested below. • The contractor's Rig Superintendent and the Company Drilling Supervisor have undertaken technical and managerial training in accordance with local legislation and contractual requirements. All supervisory personnel have undergone a programme of training and assessment in dealing with emergency situations, supplemented by a programme of drills and exercises on the installation • All persons involved in permit-to-work procedures are trained, satisfactorily examined and authorised for the specific worksite. • Job specific safety training shall be provided for all personnel in safety critical roles • Everyone working at the site shall have attended an induction briefing covering key HSE procedures and, where necessary, survival training • Specialist emergency response training shall be carried out for all personnel with specific duties (e.g. fire team training, H2S training, etc). This subject is further discussed in 6.5.9, also in EP 95-0260 Logistics.

Specific training requirements A system shall be set up by each Company to verify that any person proceeding to the rig possesses the necessary certification as dictated by local circumstances. Outline guidance is given below. Offshore survival

Persons working offshore shall have a valid offshore survival course certificate in accordance with Company regulations. The nature of the course will depend upon the area of operation but classroom instruction should include: • methods of escape from a rig • use of lifeboats • use of lifejackets and survival suits • boarding helicopters • escape from a helicopter

There should additionally be practical training in lifeboat handling, life raft

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3 Drilling HSE Management System

deployment, and underwater escape from helicopters. Specialist training

Persons who have a specific responsibility (e.g. fire team, helideck crew) shall have a valid certificate of completion of the appropriate course. In addition to the rig medic, there should be at least one other trained firstaider on shift at all times. These personnel should be involved in regular drills, under the supervision of the medic, to maintain the necessary competence. Training should also be given to staff who on occasion have to assume responsibilities normally undertaken by others. Particular attention should be paid to areas normally covered by service contractors whose equipment and materials may arrive before the personnel. An example here is the competence requirements to assure the proper storage of explosives and radioactive sources.

Pressure control

Certain key personnel on the drilling unit shall hold a valid certificate of examination from a recognised pressure control course. These personnel are: • Company Drilling Supervisor • Well Site Drilling Engineer • Contractor's Rig Superintendent • Toolpushers • Drillers • Assistant Drillers • Subsea Engineers The exam shall have been passed at supervisor level by all except the Drillers and Assistant Drillers. Where subsea wellheads are being used the above listed personnel shall have a subsea endorsement. Where drilling contracts stipulate the requirement for volumetric stripping equipment, supervisory staff of both the Company and drilling contractor shall be trained in the technique.

High pressure/high temperature operations

When HP/HT operations are being planned it is recommended that key Company and contractor personnel attend a course specifically relating to well pressure control requirements for drilling these wells.

Hydrogen sulphide

When the possible occurrence of hydrogen sulphide is identified a specific H2S training programme shall be undertaken. See 6.5.9 for details.

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Induction training Employee induction programme

Every contractor shall have an induction programme for new rig employees. This programme shall be carried out regardless of prior experience to ensure awareness of current standards and practices. In addition to emphasising the responsibilities employees have for their own safety, they shall be instructed on work procedures, safe practices, the station bill and any emergency responsibility associated with their position on the station bill, and the use of personal protective equipment. Guidelines should be in place for key contractor personnel to observe the new employee's work performance until they are satisfied that the employee can fill the position in a safe and effective manner. The induction programme shall also provide service contractor personnel and Company visitors information and instruction commensurate with their duties and length of stay.

Visitors and new crew members induction (offshore)

Newly arriving visitors and crew members shall be met by a responsible person designated by the OIM who shall update the POB list, assign muster points and allocate lifeboat stations. The OIM or his appointee shall then perform a general safety briefing. This briefing shall cover essential safety and survival features of the drilling unit plus general safety practices, rules and procedures. It will at least cover the following: • alarm signals and how to respond • lifeboat stations and location of survival equipment • escape routes and signs • information about the main hazards (e.g. fire/explosions, falling into sea, gas/oil under pressure, dangerous work areas, H2S presence, etc) • issue and use of H2S escape mask (where appropriate) • use of breathing apparatus • use of cascade system • smoking regulations • drugs/alcohol/weapons policy • restrictions on photography (i.e. permit needed) • protective clothing requirements • safe handling of chemicals • personal safety awareness and requirement to report any hazards observed • supervisors' responsibilities for their area's personnel • permit-to-work system • requirement for visitors to be accompanied and guided • requirement to report before leaving, so that POB list can be updated.

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For those personnel unfamiliar with the drilling unit or its operations, and who will be staying onboard to work or who will be staying onboard overnight, a brief trip around the installation should be arranged. The trip should cover: • lifeboats, life rafts and survival equipment • restricted areas • escape routes • emergency telephones • rig office • radio office • sick bay • alarm systems and procedures. An induction booklet is useful both for detailing the above information and for reference. Visitors and new crew members induction (onshore)

Appropriate parts of the above requirements relating to offshore operations also apply to land operations. Of particular concern here is mustering procedures, which are complicated by the ease of access to land rigs and the distribution of staff between rig and camp. There should be no free access to rig sites. A reporting procedure should be in place which tracks the movement of personnel. A 'T-card' system to aid tracking and facilitate the rapid identification of missing personnel is a good method of achieving accurate mustering.

Experience

Previous relevant experience is an important factor in accepting the nomination of contractor's personnel for key positions. The required level of experience will vary with the seniority of the position and shall be determined prior to contract. Any subsequent substitution of personnel by the contractor shall be subjected to the same criteria.

3.3.5

Contractors

Contractor selection requirements Prior to inviting tenders, it is essential to establish or update the requirements for the services needed to carry out the work programme. All offshore rigs have an operating envelope which determines the limits of operation. This operating envelope takes into account water depths, environmental conditions and operating loads. It is therefore important to determine these parameters prior to inviting rig tenders. The importance of preliminary well planning to determine drilling unit specifications cannot be overstressed if the appropriate rig requirements are to be stated in the tender documents. The application of the Hazards and Effects Management Process during the planning stage is important to help identify such requirements.

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HSE Manual EP 95-0210 Drilling Health and environmental issues should also be addressed here, for instance: • the requirements for 'no negative impact' discharge • the limiting of noise to below levels known to cause hearing loss • the provision of mud storage, mixing and treatment systems that minimise the exposure of staff to safety and health hazards • the provision of adequate recreational facilities, etc It is important to ensure that the rigs being bid enjoy staff continuity. This will ensure that operations do not start at the bottom of the learning curve. Where a 'mothballed' rig is being contracted, contractor supervisory staff assigned to it should at least have previous experience on a similar unit. Where possible a straightforward 'shake down' well should be programmed for a newly contracted rig prior to it engaging in more technically difficult and challenging work such as high pressure/high temperature drilling. Agreement should be sought from Tender Boards to enable proven good performance to be a selection criteria. Reference should be made to EP 95-0110 Management of Contractor HSE.

Review of contractor's HSE MS/HSE Case During the contractor selection process, when a short list has been made, it will be appropriate to undertake a review of the contractor's HSE Management System and, where applicable, HSE Case for the drilling unit. The contractor's HSE MS should contain in detail: • contractor's management system as it applies to safety • a breakdown of all safety critical activities • a list of all the documents and standards relevant to the HSE MS • a remedial action plan which will address any deficiencies found in the process of documenting the HSE MS. Since the HSE MS is a 'living' document the last element above is particularly subject to change. The HSE Case for the drilling unit shall contain: • information about the operation of the unit and restrictions should safety systems be inhibited or incapacitated • a description of all the identified hazards, their analysis, and the means by which they are to be controlled • details of the HSE Management System as it applies to the unit • details of the remedial action plan for rectifying deficiencies identified in the preparation of the HSE Case and any subsequent reviews • a statement that the rig is safe to operate as the hazards have been evaluated and measures have been taken to reduce the risks to a level where effective control can be demonstrated.

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3 Drilling HSE Management System Performance monitoring, audit programmes and HSE Case reviews are all vehicles by which HSE Case deficiencies may be identified. Where such deficiencies are assessed by management as necessitating remedial action, the strategy described in 3.7 should be followed.

Reporting relationships A combined organogram which integrates the individual Company and contractor organograms is a clear way to depict the reporting relationships between the various parties. Once established, it is important not to circumvent the agreed reporting route other than in a previously documented manner such as, perhaps, the Emergency Procedures. This can often prove difficult in practice due, for instance, to drilling contractors being unable to get telecommunications licences from the host government. Proper planning may not overcome such difficulties, but it will allow the procedures and organograms to reflect the realities of the situation rather than being in conflict with practice.

Subcontractor HSE All service and subcontracting companies and their staff are required to work to similar consistent high HSE standards, and achieve comparable levels of HSE performance as the drilling contractor. They will be assessed accordingly. Monitoring of subcontractor's HSE performance is continuous and integral with the monitoring of the drilling contractor's own performance. Service and subcontractor employees who work at the site are exposed to risk, both as a consequence of the potential hazards of the site and from specific work activity performed. They should be advised of significant location hazards identified in the risk assessment or hazard register, how these are controlled or mitigated, and the emergency procedures and muster arrangements. All new employees shall attend a HSE induction course prior to commencement of work. Contractor should specify training, competence and experience requirements for each specified position, together with the responsibility of the contractor for fulfilling and maintaining such requirements. Contract holders are responsible for these specifications and for verifying that the contractor meets this obligation. Line supervision has the responsibility for monitoring work performance. On large, long term contracts, service and subcontractors are required to provide strategies which identify the methods for assessing staff competence, determining training needs, and defining the system for maintaining the currency of training and competence. Given the principle that the drilling contractor's senior site representative is responsible for safety on the rig, other line supervisors, including Company staff, shall report to him on safety issues. Service and subcontractor staff shall also fall under his authority in this respect. The face that they may report to the Company Drilling Supervisor, as the contract holder, on technical performance matters does not undermine this principle. The proper exercise of the drilling contractor's authority and responsibility requires that he includes service and subcontractor facilities in his inspections and ensures that they maintain high HSE standards. When the Company is the contract holder, their representative also has responsibilities in this respect and should ensure that high personnel and equipment standards are maintained. Joint inspections of service contractor operations will both demonstrate the common cause held by the Company and the drilling contractor, and improve the drilling contractor's understanding of hazards associated with operations where he has traditionally had little involvement.

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HSE Manual EP 95-0210 Drilling The Company shall make clear to all their service contractors that they endorse the drilling contractor's authority on HSE matters and shall uphold disciplinary measures taken for HSE transgressions. In integrated engineering contracts where the drilling contractor is not the lead contractor, the most senior person on site shall be ultimately responsible for on-site HSE, in line with the principle described above. If this person does not have a drilling operations background, particular care will need to be taken to ensure that he is equipped to handle all facets of his responsibility, and that the line structure on site is such that he is properly supported. Detailed guidance on contractor HSE is given in EP 95-0110 Management of Contractor HSE.

3.3.6

Communication

Daily on-site co-ordination meetings are an effective forum for eliminating unwanted simultaneous operations and minimising disruption to operations. Access to information is particularly vital to staff with a planning function, the corollary of this being that they should be able to influence decisions being made. The advent of integrated engineering services should improve information flow, but care needs to be taken that contractors who are not part of the integrated engineering services package are included in this flow. It is vital that staff at the rig site and in base offices have a common understanding of ongoing operations and that the quality of information is not compromised through any filtering process. To this end daily reporting should be a joint effort with both Company and contractor line supervisors being present at both ends when operational (including HSE) information is being communicated and decisions being made. At meetings between contractor and Company management, HSE issues should always be on the agenda. The rig HSE committee should meet (preferably weekly) and be attended by the contractor's Rig Manager who will provide a communications link between site meetings and management meetings. HSE meetings are held to: • stimulate a two-way communication between staff and personnel which is relevant and constructive • monitor and promote HSE consciousness • report upon unsafe conditions or practices and their correction • generate suggestions on how to improve HSE performance at all levels. Regularly scheduled HSE meetings are required. These meetings and any specially convened meetings should be led by appropriate line supervisors. They should ideally be conducted in the language of personnel in attendance, though necessity might dictate the involvement of an interpreter. HSE meetings should have a structured form with the provision of HSE themes and suitable support material. They should be action oriented, relevant and should encourage participation. A base supervisor should be a regular attendee and report between HSE meetings held in the field and at the base office. They should include a review of any recent incident and HSE procedures implemented to prevent its recurrence. Every individual shall attend a HSE meeting at least once per crew cycle. Rig site weekly meetings should not be protracted to the point where attendees lose interest. Crews should be given the opportunity to provide input to the agenda. Each meeting should be documented, and the minutes should include a listing of those in attendance, topics covered and any HSE concerns raised. Minutes should be copied to the Company Drilling Supervisor and posted on notice boards in relevant languages.

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3 Drilling HSE Management System Of critical importance is the resolution of recommended actions. Explanations should be promptly given should recommendations be considered inappropriate or unnecessary. Agreed recommendations shall be followed-up, with actions being monitored, closed-out and assessed for fulfilling the desired aim. Pre-job, or 'toolbox' meetings, are particularly effective and recommended for the purpose of discussing HSE concerns specific to a particular job. Such meetings should be attended by all those involved, including service contractors. Refer to the document 'Guidelines for Single String Venture Drilling Operations' (Ref. 3) for a typical HSE meeting structure.

3.3.7

Documentation and its control

Scope of standards Standards lie at the heart of an HSE Management System and can be divided into four groups: Management standards

Set the framework in which the Company operates and deals with corporate policies, objectives, accountabilities and controls.

Engineering, equipment and material standards

Set the standards by which equipment and materials are procured and by which the control of change is effectively managed.

Working standards

Set down the way in which day to day work is carried out, monitored and inspected. They include work procedures and particularly those which relate to HSE critical activities.

Competence standards

Describe the competencies needed in a variety of Company and contractor work roles and how competency is assessed.

Standards are set to: • secure technical integrity • define quality and performance requirements • standardise materials, equipment and documentation • define working procedures • transfer knowledge. Standards provide a means by which performance can be measured and evaluated, and enable corrective action to be identified and executed. So far as possible, internationally recognised external standards should be used, as this is the best way of achieving consistency through the Group and throughout the industry.

Implementing standards The management process includes: • The auditing of contractor rigs, contractor management and, where appropriate, the rig HSE Case, to ensure these conform with Company standards and operational safety objectives.

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HSE Manual EP 95-0210 Drilling • Preparing the drilling programme and associated documentation, which shall contain information such as: – environmental factors for both rig and location – well data and objectives – well design including casing programme design criteria (for instance H2S), kick tolerance, drilling fluids, well evaluation requirements, well steering requirements (well path, targets and potential hazards), equipment requirements, BOP requirements, reference documentation and standards, well testing requirements and completion, suspension or abandonment requirements • agreeing with contractor's Rig Managers a HSE Plan and the monitoring of performance against this • reviewing incidents with Rig Managers and agreeing and implementing preventive measures • defining authority levels • defining and implementing auditable change control procedures • progressing waste management programmes • promoting workforce involvement in HSE. All parties involved in the well operations process exercise their responsibilities and attain their safety objectives by managing the activities described in the drilling contract. They will invariably have their own HSE Management Systems, which will be documented either in a Safety Policy and Procedures Manual, or increasingly, in their rig specific HSE Case. Provided these systems meet the Company's requirement for quality and completeness, it is recommended that they be followed. The contractor's understanding, commitment and compliance with their own system will be stronger than one imposed upon them. Further, the contractor's knowledge and experience should be utilised during well planning and programming stages. Contract documents shall include the necessary obligations relating to health, safety and protection of the environment.

Control of standards The Head of Drilling Engineering is responsible for the specification, maintenance and monitoring of appropriate standards and for specifying their scope and application. Any planned deviation from Group standards shall be approved at Group level and documented. Reference should be made in this chapter to the standards and reference material to which the Drilling Engineering department conducts its business. Appropriate, controlled documents should be available on all rigs and in the base offices of Company and contractors. Company standards should be reviewed and updated in line with changing technology and practices. Amendments shall be approved by the Head of Drilling Engineering.

HSE Case control, documentation and revision The contractor's Base Manager, as the designated 'Asset Owner' of the drilling installation is responsible for maintaining the currency of the HSE Case and for ensuring that any changes that may be proposed are confirmed at the appropriate level and are developed in conjunction with the workforce.

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3 Drilling HSE Management System Any change occurring to either the organisation described and its responsibilities, the management controls or the installation hardware, will be evaluated to assess the implication of such change on the HSE Case and the conclusions documented. In the event of any proposed modifications of a substantial nature which constitute material revision, irrespective of whether such modifications may decrease current levels of risk, then such proposals will need to be justified in a revised HSE Case. This will incorporate the proposed revision and be submitted for Company approval prior to implementation. Examples of modifications to the management system, the structure of the rig or to plant and equipment which could impact safety and which would normally merit a revised HSE Case submission are: • changes of operatorship, ownership or the contracting out of the management function • significant changes in the rig's organisational structure or staff numbers not already allowed for in the HSE Case • as a result of an unsatisfactory audit of the HSE Management System leading to significant changes or remedial work. This refers to the system itself rather than the effectiveness of implementation • the conclusions of an investigation into an incident where the actual or potential consequences were significant, which recommend significant changes to the HSE MS or facility design • the introduction of any major new activities on the rig or in connection with it not already considered in the HSE Case • major extensions in the scope or volume of work associated with activities not considered in the HSE Case • modifications to the rig, or the programme of work it is required to undertake, which has or may have a major impact on safety • if the rig is to be working alongside or above another installation, a bridging document shall be produced.

3.4

Hazards and Effects Management Process

The Hazards and Effects Management Process (HEMP) has four steps: • systematic identification of hazards • assessment of the significance of hazards • implementation of suitable hazard controls • planning for recovery in the event of loss of control The process is applied by asking a series of questions of each activity. This document lists the drilling activities in sequence although the Drilling Engineer shall ensure that the list includes all activities which are likely to occur during the operation being considered. Refer to EP 95-0300 and EP 95-0310 for further details. The questions which shall be addressed are: • have hazards been identified in the process of carrying out this activity? • are the results of the hazard occurring of consequence? (i.e. is there a risk of injury or loss?) • are hazards being controlled in any way whilst the activity is being carried out? • is it necessary to plan for recovery or emergency response in the event of the hazard being released?

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HSE Manual EP 95-0210 Drilling If the answer to any of these questions is positive the activity is then regarded as safety critical. These activities will then need to be addressed at a level which assures effective control. The involvement of staff working with the hazards is important, if the controls developed are to be effective.

3.5

Planning and Procedures

3.5.1

General

For the planning phase of an operation to be effective it should concern itself with the prevention of incidents through the elimination or control of hazards and the mitigation of consequences should the hazardous event occur. It follows that a process needs to be followed to systematically identify and assess hazards and develop the controls to manage those which cannot be eliminated. This can be achieved by: • use of Group or locally developed policies, standards and procedures • making a scouting visit to assess the situation on the ground • study of legislation and supporting approved codes of practice (where these are available) • a thorough analysis of the particular operation (see 3.4) • a study of accident, incident and ill health data from previous operations. For the drilling phase of a new venture, such data may be available from the seismic acquisition phase Other narrative in this chapter considers the HSE considerations in the well planning process.

Planning the operation Experience has shown that HSE performance can be optimised through a structured planning process which incorporates: • comprehensive operational pre-planning incorporating HSE measures to manage identified hazards. Those exposed should be subjected to the latter three phases of the Hazards and Effects Management Process as described in 3.4 • verification of equipment safety standards before operation start-up • verifying that an effective HSE Management System is in place before start-up • an HSE management training programme aimed at senior line management (Company and contractor) and direct supervisors. This training would include such topics as Job Hazard Analysis, Unsafe Act Auditing (UAA), Safety Training Observation Programme (STOP), waste management and an understanding of the factors which affect behaviour • detailed documented HSE and contingency planning specific to the drilling campaign prior to operational start-up • regular combined Company and contractor management team audits and inspections according to a planned schedule and focusing on HSE management • establishment of and adherence to transport management system. Effective planning is essential for all aspects of the business, with plans based upon known and researched information, and reasoned assumptions. In established Companies, much of the known information is

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3 Drilling HSE Management System based upon experience. Plans for sustained improvement is contained in the Drilling Engineering Department's HSE Plan. This plan is prepared annually as part of the Company's total HSE Plan and its implementation is reviewed periodically by the Company's Management HSE Committee. The plan sets out the department HSE objectives and the methods by which it will achieve them, lays down a time scale for implementation, identifies action parties and establishes a review process, both to monitor implementation and to modify the plan according to needs. The HSE Plan is developed from such things as: • requirements carried over from the previous year's plan • audit and inspection findings • incident findings • new corporate initiatives • accident investigation findings • Tripod incident analysis, Tripod-DELTA implementation • HSE suggestions from the workforce • management review action items.

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HSE targets

It is essential to set HSE targets that are accepted by management and employees as achievable. Typically, a progressively reducing target is set, which in the long term will lead to accident free performance. Realistic targets can only be set after assessing the scope of work for the period under review and allocating tasks to manage such work. The only way to reach a HSE target is to manage effectively risks which threaten its achievement. Effective management demands that hazards and their controls shall, so far as possible, be addressed in the planning process. Staff reports shall include HSE-related targets or tasks against which performance can be measured. These should be cascaded down from department and Company targets. Performance improvements should not be 'demanded' without giving individuals the tools to do the job, such as training and proper equipment. It shall be verified that drilling contractors and lead service contractors commit themselves and their subcontractors to a programme that enables staff to achieve the performance standards aimed for.

Site selection

The Exploration Department or Development sections of Petroleum Engineering will determine the sub-surface target of the well to be drilled and sometimes also the well trajectory to reach the target. This should be challenged if proposed site conditions so dictate. Aside from considerations such as access, topography, submarine cables obstructions, etc the hazard of shallow gas and seabed or soil conditions shall be taken into account. Shallow seismic run at the time of site surveying will give a good (but not infallible) indication of shallow gas in the area. Where practicable, drilling locations shall not be sited where there is a risk of encountering shallow gas. Where this is not practicable, additional measures to assure the safety of the operation shall be taken. Procedures to be followed are referred to in 'Shallow Gas Procedure Guidance Manual' (Ref. 4). Likewise, shallow seismic will give indications of the competence of the seabed to support a jack-up rig or anchor a floating vessel. Soil boring may be required to assess this. For insurance purposes, drilling contractors require the agreement of a warranty surveyor, acting on behalf of the rig insurers, before siting an offshore drilling unit on location. See 4.2.1 for details of offshore location preparation.

3.5.2

Asset integrity

See EP 95-0100 HSE Management Systems.

3.5.3

Procedures and work instructions

Permit-to-work A permit-to-work system shall be in place which includes procedures for non-routine and critical operations such as hot work, heavy lifts, electrical work, confined space entry and the handling of radioactive materials and explosives. On contracted drilling units working in isolation, the contractor's procedures should be adopted with any necessary changes. They shall define the individuals responsible

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3 Drilling HSE Management System for authorisation, for verifying specified controls are in place and for co-ordination of the system. The permit shall include space for restrictions and controls to be applied while the specified work is being undertaken. When a permit is issued, all relevant personnel shall be informed when the work has started and when it is completed. Planned work which requires a permit shall be discussed at the daily rig site co-ordination meeting. Refer to 6.7 for further discussion.

Concurrent operations Concurrent operations (also referred to as simultaneous operations) pose problems which demand high levels of co-ordination to control effectively. Detailed hazard identification and risk assessment are required during the planning phase of such an operation. Such assessments will invariably lead to a manual of permitted operations (MOPO) which will define which operations are permitted to be conducted simultaneously and which are not. Refer to 7.4 for further details.

Adverse weather procedures Many Opcos are working in areas where operations are adversely affected from time to time by environmental conditions. It is vital in these circumstances for the Company to develop its own adverse weather policy and procedures suited to the local circumstances. The procedures shall not only address actions on the rig but also outside support requirements. Before commencing any contract with a mobile offshore unit, the responsibility for decision making in the event of heavy weather, or the forecast of heavy weather, shall be clearly defined and known to involved parties.

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Definition

Adverse weather is defined as environmental conditions which may affect the safety of the operation, equipment, and/or personnel if precautions are not taken to protect against the hazard. Adverse weather will include, severe sea conditions, high wind, ice, icebergs, poor visibility, snow, lightning, torrential rain potentially leading to flooding and sandstorms.

Forecasting

Essential to the ability to take timely action to counter the adverse weather is an accurate weather forecasting service. This service may be supplied on contract either from a local source, if one exists, or from an international weather forecasting service. A good local service will be in a better position to provide short term forecasts which are important for predicting localised storm conditions. Assistance to the forecasting service can be provided by passing regular weather reports from the site of operations. This in turn should improve the accuracy of forecasting. The development and movement of adverse weather systems shall be closely monitored such that appropriate preparations are made in a timely manner. In some areas prone to heavy weather, a sector system, whereby progressive action is taken as a storm approaches, shall be developed.

Developing a procedure

A procedure shall state the actions to be taken at site to ensure a safe system of working during the period of adverse weather and the conditions under which the operations must be suspended. The procedure shall take into account the nature of the work and set limits for certain operations such as running a BOP stack, running casing or the use of cranes. This will need to be developed in conjunction with the contractor.

Operations planning

Some activities carried out on the rig once commenced should be completed without interruption, examples are the running of a BOP stack or running casing. It is important that the weather forecast is noted on the work instructions. Similarly, when adverse weather is forecast which will affect operations, adequate time must be allowed to take defensive action. Limits on crane operations in respect of wind speed and rig motion must be taken into account. Contingency plans shall also be drawn up, particularly offshore, for occasions when it may be prudent to reduce the number of personnel on board, reduce the variable deck load, and adjust the draft of the drilling unit. The contractor's operating manuals will indicate what action needs to be taken in this respect.

Safety during heavy weather

The development of an adverse weather policy for an offshore mobile drilling unit is governed by four major considerations • minimise risk to personnel • minimise storm damage to the drilling installation • minimise storm damage to the conductor, riser, wellhead, and other exposed equipment • minimise possibility of pollution by ensuring integrity of the well Each type of drilling installation has its own criteria for reacting to a given

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storm condition. To a large extent the continued operation of a rig depends upon its design and equipment characteristics. Allowable operating conditions should be detailed in the operations manual.

There are three phases in safety planning during heavy weather when using a floating drilling installation: Phase I

Stop drilling operations, make the well safe, hang off drill string and make preparations for disconnecting.

Phase II

Disconnect the Marine Riser, which may involve: a)

Controlled disconnection

b)

Emergency disconnection

c) Move the rig away from the wellhead and orient it to a heading which minimises weather affects on stability. In some cases towing the rig out of the path of the storm may be necessary Note: As well as minimising the effects of the weather on the vessel, this is intended to avoid the possibility of the Lower Marine Riser Package (LMRP), or in shallow water the pontoons, hitting the top of the BOP stack due to rig heave. If an emergency disconnect has taken place, the direction in which the rig is moved away should take account of the water depth to ensure that the LMRP does not hit the seabed. Phase III

3.5.4

Evacuate personnel from the drilling vessel

Management of change

The effective control of change, be it to personnel, hardware or procedures, is key to assuring the ongoing integrity of the operation. The change of personnel relates largely to issues of competence and will involve both an assessment of competence and, where necessary, training followed by a handover period. The change of personnel should be controlled to minimise the disruption caused by loss of continuity. In making hardware changes the integrity of the original design shall be ensured with respect to equipment and the fitness for purpose assured with respect to additions. This requires that appropriate expertise is applied to the change. For instance, the modification of a piece of equipment shall require a review by a suitably qualified 'in-house' engineer, and often need the approval of the equipment manufacturer. A procedure shall be in place which assures that all hardware changes are approved at the appropriate level before being implemented. This may involve external parties such as classification societies. Changes to programmes and procedures shall be agreed at the level of original approval and involve the input of those affected by the change. All changes shall be assessed to ensure that they do not inadvertently introduce other hazards. Changes and their consequences shall be documented and disseminated to ensure all involved are fully aware both of the change and its implications. Such documentation will also provide an audit trail. Major changes may require an amendment of the HSE Case.

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3.5.5

Contingency and emergency planning

In preparing for an operation a plan shall be put in place which will detail the methods of recovering from any incident, on the drilling unit or attendant services, which causes injury or poses a threat to the health and safety of personnel or the environment. The recommended contents of the Company's Emergency Procedures document are given below as is a list of the hazards which may need to be addressed. It is the responsibility of the person in charge (generally the contractor Toolpusher on a land rig or Offshore Installation Manager [OIM] on an offshore rig) to ensure that the emergency response facilities and materials as specified in the contractor's Emergency Procedures are available and fit for purpose at all times. Emergency response procedures shall address the action to be taken on the drilling unit and the responsible persons in the event of an emergency. It is also essential to identify alternative individuals to assume key duties should normal incumbents be incapacitated. Station Bills shall be posted detailing the action to be taken by all personnel in emergency situations. Co-ordination between the contractor's and the Company's Emergency Procedures is required to avoid conflict of actions. This applies primarily in the base offices where support services (helicopter, medical back-up, notification to official organisations, etc) will be arranged. In principle, the contractor should take the lead on the rig in combating the emergency. For contract and resource reasons, the Company will normally co-ordinate logistics, liaise with outside agencies and otherwise provide intervention needs. The Base Manager of the main contractor and other relevant contractors should always be included in emergency control teams. The co-ordinating link between rig and base office will normally be the Company Drilling Supervisor on the rig. These arrangements shall be documented and signed by both contractor and Company. An emergency exercise shall be performed to test the procedures prior to commencement of the operation. Further drills and exercises shall be performed, particularly during the early stages of a contract, to verify that the roles and responsibilities of all staff (on all shifts) are understood and effectively discharged.

Opco emergency procedures Documented emergency procedures shall be in place before operations commence. The document shall detail the responsibilities of Company personnel both on the rig and in the base office in the event of an incident. In addition the principal responsibilities of the drilling contractor's Rig Superintendent shall be stated with regard to co-ordination with the Company Drilling Supervisor. The action to be taken by Company base office staff with regard to support services (e.g. helicopters) and notifications (e.g. coast guard, hospital government) shall be detailed for each type of incident. When documents are normally stored electronically, hard copies of key procedures should be available and the storage system should be connected to an uninterruptable power supply. As appropriate to the operation, the document may include procedures for: • injury/illness requiring medevac to hospital • injury/illness requiring medevac out of country • fatal accident/illness • road accident requiring medevac • vehicle overdue

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3 Drilling HSE Management System • loss of aircraft • fuel/chemical spillage • hydrocarbon spill • extreme weather conditions • fire and abandonment • loss of well control • H2S release • radioactive source/explosives incident • security breakdown • bomb scare. EP 95-0316 Emergency Response provides guidance.

Oil spill contingency plan A plan shall be prepared for combating and cleaning up of oil spills. Reference should be made to current corporate guidance available through HSE departments. The service may well be provided by a contractor who will have clean-up equipment and his own procedures for its operation. Company procedures shall detail the notifications necessary and provision of other contracted services (e.g. supply vessels) and materials dependent on the scale of the spill.

Relief well plan It is advisable, and in some areas a requirement, to prepare a relief well contingency plan. Of prime importance is having adequate data on the path of the problem well. The plan, which will be site specific, should consider: • blowout contingency team organisation • acquisition of third party expertise • sourcing of a drilling unit • provision of a high volume water supply • evacuation plan for nearby population • sourcing of materials (casing, mud, bits, wellheads, etc) • safe siting of a rig for relief well drilling • directional services • possible kill methods.

Well control The latest version of the 'Pressure Control Manual for Drilling and Workover Operations' (Ref. 5) shall be used.

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H2S procedures Each Company shall prepare its own procedures based on local conditions and incidence of the gas. Refer to 6.5 for further discussion on the subject.

Shallow gas The document 'Shallow Gas Procedures Guidance Manual' (Ref. 4) shall be used by the Company as the basis for establishing a procedure for dealing with shallow gas.

Drills and exercises Effective drills address three important objectives which are: • to demonstrate the crew's ability to respond to a wide range of emergencies. Drills improve and develop crew confidence and identify those areas where further attention is needed • to train the crew in both individual proficiency and team work necessary to handle anticipated rigspecific emergencies • to test the emergency equipment. An effective drill programme should cover: • a description of the drill, including list of participants • realism in the drill • frequency of drills • a means of disseminating the results of drills to supervisors • topics identified during past drills which need improvement • an objective evaluation of the drill highlighting both areas of success and areas requiring improvement. Drills should be based upon realistic criteria and carried out, so far as possible, as though the emergency existed. They shall not, however, expose personnel to unwarranted risk. The following drills shall be carried out at each drilling installation: • kick/pit drills • fire drills • drills in the use of breathing apparatus • hydrogen sulphide drills (if applicable) • stretcher drills (e.g. from the rig floor) • muster and abandonment drills • medevac exercises. The frequency of the drills should be established in the annual HSE Plan, but should be sufficiently frequent to assure the competence of all staff. All drills, whether onshore or offshore, shall include contact being made with base to verify the effectiveness of communications. This shall periodically include the requirement for duty staff to contact the rig to confirm their contactability.

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3 Drilling HSE Management System A timed log of events should be kept by supervisors acting as observers. These logs should be consolidated into a drill report and used for the debrief, and for disseminating information on corrective actions to staff. A copy of the report shall be sent to the base offices of both the drilling contractor and the Company. Supervisory visits should occasionally include the observation of a drill.

3.6

Implementation and Monitoring

3.6.1

Activities and tasks

See EP 95-0100 HSE Management Systems.

3.6.2

Monitoring

This chapter discusses various arrangements that are employed to monitor the implementation of the health, safety and environmental policy at the installation. Performance monitoring and review will be a key element of the HSE Plan and the part which facilitates enhancement of the plan's quality by highlighting areas for improvement. The HSE performance can be assessed against the criteria considered below.

Occupational health Performance in relation to occupational health is measured against Company standards which shall at least meet legal requirements and in any event ensure the prevention of adverse health effects due to working conditions. Occupational health issues in drilling operations shall include the safe handling of chemicals, the use of oil-based muds (OBM), the use of radioactive substances, exposure to H2S, ergonomic issues, protection against the elements and noise control. All of the above should be dealt with through the Hazards and Effects Management Process. Performance indicators can be derived through the analysis of medical referrals. A typical analysis at a drilling location would be the frequency of skin rashes which may reflect on work practices and compliance with protective equipment requirements. Another longer term indicator would be the number of persons showing evidence of hearing loss. The analysis of some of these indicators will need the support of specialist services.

Safety monitoring The measurement of performance in relation to safety is based on such things as injury statistics, the incident potential matrix, TRIPOD DELTA sensing exercises, unsafe act auditing, feedback from drills and exercises and feedback from audits and inspections.

Environmental protection A waste management programme shall be part of the HSE Plan and be aimed at achieving short and long term reductions in the volume and toxicity of waste generated. Within drilling operations, reductions can be achieved by such things as slim hole drilling (SHD) and the substitution of chemical products, e.g. using water based mud instead of OBM.

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HSE Manual EP 95-0210 Drilling SHD offers onshore the additional and substantial advantage of reducing the location footprint, minimising road construction and upgrade work, reducing overall drilling associated costs and disturbance of the environment. Reference should be made to 'Making the Most of Drilling Waste Management' (Ref. 6).

Review The review process will address the meeting of targets documented in the annual HSE Plan. It will also address the success of implementing the action items arising out of all activities which produce recommendations, such as HSE meetings, inspections and incident investigations. Individual HSE performance targets, normally developed during the annual staff reporting cycle, should also be assessed and, where necessary, further action to achieve attainment agreed. Reviews shall also be carried out on all contracts against the contractor's HSE Plan. The reviews should be jointly held and any remedial action jointly agreed.

Performance indicators The measure of HSE performance can be obtained by the use of suitable indices which will: • provide a consistent method for collecting and communicating data on incidents • show by comparison the effectiveness of the HSE management programme, both within the Company and with other companies • enable an assessment to be made of a contractor's HSE performance relative to the industry • indicate whether an operation is being managed well or whether management is driven by events. For performance monitoring to be useful it is essential that all incidents are reported. Appropriate measures to assure this shall be put in place. Performance criteria with respect to Lost Time Injuries (LTIs) and Total Recordable Case Frequency (TRCF) are set at the beginning of each year and detailed in the HSE Plan. Some proactive indicators would be produced by: • monitoring compliance with the plan • monitoring compliance with corrective action requirements arising as a result of HSE meetings, audits, etc • monitoring changes in the drilling sequence which may have a significant impact upon effective planning. Trends indicated by periodically auditing against predetermined criteria, such as those provided by the International Loss Control Institute (ILCI), are being used by some drilling contractors. The Company and contractor should assess and record the potential outcome of all incidents (including near misses) as a means of reviewing them in terms of 'what might have been the consequences'. Results are presented on an incident potential matrix. Incident report action items together with action parties and completion dates are recorded on the rig HSE information data base and monitored on a regular basis. Tripod-DELTA may be used as a proactive human factors diagnostic tool for assessing the resistance of a rig to accidents and for identifying those problem areas which, if not attended to, are most likely to cause accidents in the future. Rig inspections are also used to measure performance. This is achieved using a programme of inspections, against predetermined standards and improvement targets. These inspections are carried out both

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3 Drilling HSE Management System internally, by rig supervisors and members of the workforce, and externally by base management representatives of the Company, the drilling contractor and services contractors. An example of such an inspection is that made by the site supervisors. This inspection is conducted by both contractor and Company personnel against a check list and progressively covers all areas of the installation including service contractor facilities. Each inspection report is reviewed by the base line managers so that appropriate resources can be made available, and any corrective action requirements be given the priority required. For further information on the subject of performance indicators refer to 'Guide for Safety Performance Reporting' (Ref. 7).

Line management HSE inspections A frequent observation made during SIEP-led drilling technical HSE audits is that line management visits lack focus and therefore effectiveness. To get the most out of the effort put into rig inspections in general and line management inspections in particular, it is essential that a structured approach is taken. The following three paragraphs suggest an appropriate structure and give guidance on how to develop it. One of the objectives is to minimise extra administration and to reduce the seemingly never ending job lists which act as demotivators to both Company and drilling contractor site staff. The three elements of the inspection are: • planning • execution • feedback/close out. Planning

Inspections made shortly after start-up will place the main emphasis on verifying the effective close out of deficiencies, particularly those associated with HSE management, identified in the pre-start-up audit. The focus will change as the drilling project progresses. The importance of hardware inspections should not be underestimated. Appropriate and well maintained hardware is essential for the safe conduct of operations and such inspections are also essential to allow a reasoned judgement to be made on such things as: • the effectiveness of the preventive maintenance system • the competence of personnel to perform their duties • the ability of staff to handle their workload An inspection made during non-routine operations may well focus on the permit-to-work system and the effectiveness of communications, such as briefings and tool box talks, to assure that staff remain aware of, and in control of, the overall operation. One made during routine operations may focus on hoisting equipment, to verify the effectiveness of on-site audit and inspection. Electrical safety may be addressed, to verify that hazardous zone requirements are fulfilled and that staff are not

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exposed to electric shocks. Expert assistance should be called on to inspect areas in which the manager lacks expertise. This is particularly important to give assurance that accidents do not arise out of lack of knowledge of the inherent hazards. The key point is to have a particular HSE objective in mind. The main thrust of the inspection, with respect to HSE, is to ascertain the effectiveness of the systems and where necessary make recommendations for improvements, rather than to focus on the operational 'nuts and bolts'. Execution

All Companies perform rig inspections, with many doing it to a regular schedule. It is generally a multi-purpose visit, addressing a wide variety of issues. The more effective ones include a briefing/discussion with all relevant supervisors covering the highlights of the previous period and a look ahead. It is helpful if supervisory visits are made jointly by Company and contractor representatives and that they hold a joint meeting with their senior site representatives to ensure that a common approach is agreed for follow up action. There will always be a place for a rig walkabout, but it should not distract from the planned objective. Hardware deficiencies should be looked at in terms of the management system in place to identify and rectify them, rather than merely noting it on a job list for rectification. This is not to minimise the importance of rectification, more to ensure that all deficiencies will be systematically identified and their root causes addressed to prevent similar ones recurring.

Feedback/close out

For supervisory visits to be both useful and credible, there needs to be a process which feeds back the results of the inspection and closes out any remedial action requirements. This will require a degree of documentation. The written report of the inspection should be concise and should be passed to the rig promptly. Action items, action parties and completion targets should be given. Since the success of an operation is dependent upon team effort, the feedback should be given to all relevant staff after having identified action parties with the agreement of senior site supervisors. The emphasis should always be on agreed action items as this will increase commitment to successful resolution. So long as the overall objective is not compromised, give and take should be used to obtain such commitment. Follow up shall be monitored regularly and this may best be done during subsequent visits. Should an agreed remedial action prove not to be feasible, this should be openly discussed and agreement reached on possible alternatives. Clearly, all remedial actions shall be closed out in a time frame commensurate with their importance. The document 'Management Safety Inspections' (Ref. 8) gives valuable guidance on this subject.

Unsafe act auditing Experience has shown that a high proportion of accidents result from an unsafe act by an individual. The reason for the unsafe act may well be a reflection on the individual's training or the pressures under which

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3 Drilling HSE Management System he is working rather than negligence. Whatever the reason, there is a need to be proactive in removing the basic causes of accidents and to carry out an audit of any unsafe acts which still occur. The objectives of auditing unsafe acts are: • to reduce the potential for accidents • to reaffirm and improve the accepted standards of safety • to improve communication and understanding • to improve the cultural attitude toward safety. The process of unsafe act auditing is fully described in 'Unsafe Act Auditing' (Ref. 9). Many Shell Companies and contractors have adapted the technique to suit their mode of operation and the culture of the host country. The objectives, however, remain the same.

3.6.3

Records

See EP 95-0100 HSE Management Systems.

3.6.4

Non-compliance and corrective action

See EP 95-0100 HSE Management Systems.

3.6.5

Incident reporting

Objectives and principles The objectives of an incident investigation and reporting system are: • to investigate all hazardous and potentially hazardous incidents at a level, depth and speed appropriate to their seriousness • after determining root causes, to take appropriate action to prevent the recurrence of the incident or similar incidents • to communicate the findings of incident investigations, the conclusions reached and recommendations made to all appropriate personnel. This includes contractors and service companies and, where appropriate, dissemination on a Group wide basis. • to identify trends in a timely fashion and target areas of particular concern • to contribute a database to assist engineering design. EP 95-0100 HSE Management System Chapter 6 and the document 'Incident Investigation and Analysis Guide' (Ref. 10) are useful references. For investigation purposes, with the exception of a fatality or a serious lost time injury, the level and depth of the investigation should be based on the incident's potential rather than the actual consequences. The document 'Incident Potential Matrix' (Ref. 11) provides guidance. The Company Drilling Supervisor at drilling locations shall assist in assessing the potential of all incidents occurring on site and should verify the adequacy of their investigation. This will require that he takes part in the investigation of incidents which fall into an area of the incident potential matrix that has been defined as requiring Company participation in the investigation.

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HSE Manual EP 95-0210 Drilling Except where the seriousness of an incident dictates otherwise, the drilling contractor should lead the investigation and Company base management verify that corrective actions are appropriate and sufficient. Responsibility for follow-up action shall be identified. Any changes in procedures, rules, equipment replacement, etc which arise as a result of the investigation, shall be documented in the report and shall be discussed during appropriate HSE meetings.

Incident reporting procedure In a stand alone drilling operation, the drilling contractor's senior site representative is responsible for HSE on the rig and all incidents shall be reported to him. Together with the Company's senior representative, he should assign each incident with a code derived from an incident potential matrix. This code will determine the seniority of staff taking part in an investigation and the depth to which the incident needs to be investigated. Clearly, a degree of common sense needs to be applied if staff are to be motivated to report all incidents, including near misses. Fear of the investigative and administrative workload should not inhibit staff from making such reports. This may initially result in lower potential incidents merely being logged. If a recurring trend is noted further investigation may well be warranted to eliminate underlying causes. As performance improves, the 'goal posts' can be narrowed to address lower potential incidents. It is essential that the senior supervisors are appraised of all incidents so that they can assess potential and decide necessary corrective action to be taken. Equally importantly, they can ensure that relevant information is disseminated to others who may benefit from the knowledge. Detailed guidance on incident reporting and investigation is given in the documents 'Accident Investigation' (Ref. 12) and 'Guide for Safety Performance Reporting' (Ref. 7). A reporting procedure might the take the following form for non-critical incidents: 1.

The drilling contractor Toolpusher leads the on-site investigation into the incident and prepares the report which includes remedial action requirements. The Company Drilling Supervisor takes part in the investigation and countersigns report as accurate and sufficient.

2.

The report is sent to drilling contractor Rig Manager who adds his comments and signs his agreement to the recommendations. He can also recommend further investigations if necessary at this point, perhaps with a higher level team.

3.

The report is sent to relevant Company Senior Drilling Engineer (Rig Superintendent) who adds his comments and signs the report. He can also recommend further investigation

4.

The report is then sent to the contract holder (Head of Drilling Engineering) who follows the process previously described.

5.

Parallel with this process the HSE Department will review the report as received from the rig and provide any input they may have to the Company Senior Drilling Engineer.

6.

A copy of the finalised report is returned to the rig for implementation of the agreed remedial actions.

While the above describes auditable, procedural aspects of the incident reporting process, normally communication channels keep relevant issues alive while this is ongoing.

3.6.6

Incident follow-up

See EP 95-0100 HSE Management Systems.

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3 Drilling HSE Management System

3.7

Audit

Technical HSE audits assess the effectiveness of the controls in place to manage HSE aspects of activities. As proper HSE management is a quality inherent in the way the Company conducts its operations, it is essential that the audit team has members familiar with the process being audited. It is also important to be able to make an objective assessment. This makes it desirable that the team includes members without direct responsibility for the operation. In small Companies and ventures, this may not be possible. The HSE Management System shall contain reference to: • the relevant audit policy and procedure • the way actions recommended by an audit are agreed, put into effect and followed-up • the means by which lessons learned from such audits are communicated laterally within and outside the organisation in order that actions arising out of key learning points can be applied elsewhere. Operations associated with the installation shall be subject to a programme of audits under the Company and contractor audit plan. This subject is addressed below.

General It is a requirement that drilling contractors and associated service contractors have an effective system in place for managing HSE. The assessment and approval of this system shall be part of the tender evaluation process. So long as major contractors apply corporate requirements to their world-wide operations, the work load for performing this task should diminish quickly with time. The HSE department should have the expertise to assist with this task. The effectiveness of the system cannot be assessed, of course, until the unit has been manned up for operations. This implies that ideally, a HSE management audit should be carried out while the rig is working for another operator, such that deficiencies can be rectified prior to the start of contract. Where this is possible, and the system is found to be effective, assurance should be gained from the contractor that staffing, at least at the supervisory level, will not be significantly changed without prior agreement. Where agreement from the previous operator cannot be gained, or where the rig is being mobilised from a stacked condition, assurance should be gained from the drilling contractor that supervisory staff are familiar with the requirements of the HSE Management System. This shall then be assessed upon start-up of operations. When properly structured, the Company's assessment of the contractor's HSE Management System also provides a useful insight into how effectively the contractor manages other aspects of his business.

Schedule The following offers advice on a suitable schedule of audits and inspections of drilling operations.

New venture Characterised by small Shell team with limited manpower, and a high reliance on contractor resources. Pre-Tender

Meeting with contractors selected to bid to advise on Shell HSE requirements.

Precontract

Pre-selection inspection of rig and associated equipment generally by third party consultants.

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Environmental impact assessment of the drilling site and means of access. Pre-Start-up

Audit by Company and main contractor management to verify that an HSE MS is in place which enables the achievement of venture HSE objectives.

Start up

SIEP-led HSE audit shortly after spud.

Weekly

Inspection by Company and contractor senior supervisors.

Other

Inspections by a member of the management team (frequency depending on overall management field visit programme but at least monthly).

Small Opco Characterised by limited manpower and by discontinuous drilling operations which may lead to loss of expertise between drilling campaigns. Pre-Tender

Meeting with contractors selected to bid to advise on Shell HSE requirements.

Precontract

Pre-selection inspection of rig and associated equipment generally by third party consultants. Environmental impact assessment of the drilling site and means of access.

Pre-Start-up

Audit by Company and main contractor management to verify that an HSE MS is in place which enables the achievement of venture HSE objectives.

Start up

SIEP plus Opco safety audit shortly after spud.

Weekly

Inspection by Opco senior supervisors.

Quarterly

Review of audit follow up progress. Copy to be sent to SIEP.

Yearly

By a team of local Company and contractor management.

Other

Inspections by a member of the management team (frequency depending on overall management field visit programme but at least quarterly).

Audits generally include service company, transport, supply and associated field engineering activity.

The audit process The objectives of HSE audits are: • to keep Company management informed of the health and integrity of all the Company's activities by monitoring, on a periodic basis and in a systematic manner, the HSE management system in order to assess its effectiveness • to assist line management to identify HSE shortcomings • to assist line management to identify remedies • to ensure that remedies are carried out through effective follow-up procedures. HSE audits should form part of the annual HSE Plan and in some larger Companies will be part of an integrated audit plan. Staff should be keenly aware of the difference between audits and inspections. The

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3 Drilling HSE Management System audit process is one of verifying the effectiveness of HSE management and is not a detailed hardware inspection. It is particularly important to emphasise to all concerned that a drilling audit is not simply an audit of the drilling contractor. It will cover all aspects of the drilling operation including those aspects controlled or managed by the drilling contractor, the Company and service contractors. Audit frequency is somewhat dependent upon the length of contract but a start-up audit is particularly valuable as it emphasises the HSE principles upon which the operation is founded. As with all other aspects of the business, audits need to be planned and team members prepared, such that the scope of work is effectively covered. In this planning stage the expertise requirements is identified and will dictate the audit team make-up. The main elements of the audit include: • reviewing documentation, including necessary certificates • interviewing staff both in the base offices, field offices and on the rig • inspecting equipment • comparing work practices with documented procedures. External audits are led by an experienced SIEP technical auditor, generally with wide drilling operations experience. They should include representatives of both Company and drilling contractor line staff. Team members should be of a seniority which empowers them to agree to the main findings. So long as findings are based on objective evidence, agreement should not be difficult to reach. An internal management HSE audit should be conducted once a year by a team typically consisting of the contractor's Area Manager, contractor Local Manager, the Company Senior Drilling Engineer and Company's HSE Adviser. The audit should be similarly structured to that of an externally led audit and review the application of the system in place to manage HSE issues as well as other organisational and hardware issues. The implementation of HSE Cases should aid the auditing process by more clearly focusing on the management of hazards associated with the operation. Copies of previous inspection records should be kept on the rig to document findings noted during earlier inspections and follow-up action taken to correct the problem. It is important that the audit report is a balanced document giving credit where credit is due and not just highlighting deficiencies. A review should be carried out near the end of a contract to assess the effectiveness of HSE management throughout the contract period. Performance trends should be identified and an end of contract note written to use as an input into any future tender exercise in which the contractor is involved. SIEP will provide a guidance package for the audit of drilling operations upon request.

3.8

Review

This subject is divided into three parts and describes the corrective action process for audit recommendations, HSE Case recommendations and HSE Management System remedial action recommendations.

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39

HSE Manual EP 95-0210 Drilling A monitoring system should be instituted to track completion of action items in the indicated time frame.

Audit action recommendations Where the auditee cannot agree a recommended action item a variation should be documented which describes the proposed alternative which will achieve the same objective or alternatively the reasons why the recommended action has been rejected. The audit should be closed out with a listing of the status of action items.

HSE Case remedial actions Remedial actions from the preparation of HSE Cases may arise as follows: • deviations from agreed standards identified in preparing the HSE Case • actions arising out of studies used to assess hazards • actions arising as a result of creating standards the need for which has not previously been recognised • actions arising out of changes to the HSE Case prompted by significant changes to the installation or the operations it is conducting. Actions should be agreed, a party responsible for implementation nominated, a completion date fixed and a progress monitoring system put into place.

HSE MS remedial action The definition and documentation of the HSE MS may well lead to weaknesses being identified and remedial action items being recommended. The HSE MS itself will be subjected to an ongoing review process which will lead to further corrective action plans. The plans shall show action parties and realistic completion dates.

Monitoring system For each recommendation, action parties and completion estimates are established and entered onto the Remedial Action Plan. The status of all action items are reported at regular intervals to a review committee of senior managers in order that progress is effectively monitored and expedited as necessary. It is logical that a common system should be set up to monitor the implementation of action items arising out of all four of the subjects discussed. The HSE department, when properly staffed, should be the guardian of such a system, though responsibility remains with the line who should follow up and keep the system guardian regularly appraised of status.

Review and improvement The management review and improvement process consists of three main parts: • the development and maintenance of HSE Plans cascaded from the corporate to the departmental level • the review process by which the effectiveness of the HSE Plans, HSE MS and HSE Cases is determined • the improvement strategy through which the product of the review process is implemented.

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3 Drilling HSE Management System

Development, maintenance and review of HSE Plans The Company shall produce an annual HSE Plan. This is normally prepared by the HSE department with significant input from line departments to assure completeness of coverage and the setting of realistic targets. It is reviewed and endorsed by the Managing Director. Its purpose is to: • create an understanding of the corporate HSE policy and give it a common direction • focus on key elements of HSE management, with the objective of systematically removing the basic causes of loss, by means of ongoing reviews of HSE systems and performance. From this corporate document will be generated an Operations HSE Plan and subsequently a Drilling Engineering HSE Plan. These plans will for a large part be a development of the previous years plan, but may also include new ideas and procedures brought in from outside. Staff new to the area can have an important role to play in this respect. The targets set out in plans shall be monitored for achievement by periodic review. The plan should remain a living document with amendments initiated when benefits to performance can be seen. The implementation of the plan is a line responsibility and line supervisors should be allotted HSE tasks and targets based on the plan's requirements. The achievement of such targets should also be part of the annual performance assessment process.

Improvement strategy Company

The Company's improvement strategy should be set against the outcome of the review process and the long term targets of zero accidents and zero negative discharges to the environment. To this end five year reducing targets should be set and performance reviewed periodically to monitor achievements and identify actions for further improvements. As performance improves, the 'goal posts' tend to narrow and new strategies are required to continue the improvement trend. The drilling contractors have a particularly valuable role to play here as they have been exposed to ideas from outside the Company which may well offer fresh insights. The annual plans are developed with all of the above in mind so that lessons learned are incorporated into successive year's plans. The HSE MS is reviewed periodically (approximately every three years) and a revision and improvement programme developed based upon: • examination of performance indicators to see where HSE MS improvements are necessary • review of audits and incident reports to identify areas where enhancing the HSE MS will facilitate performance improvement • reviewing the adequacy of the HSE MS documentation. For the HSE MS to achieve its desired objective it is vital that staff at all levels understand its aims and their role in its effective implementation. The system therefore needs to be transparent and 'user friendly'.

Contractor

The contractor HSE improvement strategy, likewise, is set against the long term targets of zero accidents, zero negative impact to health and zero negative discharges to the environment. To this

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end, reducing targets are set for the occurrence of recordable accidents by the contractor Base Manager. These are reviewed annually. The improvement strategy is based on the identification of key corporate HSE issues periodically, and addressing them in the rig HSE Plan by a series of actions. The issues will continue to be addressed in annual plans until conditions have been improved as far as reasonably practicable.

The rig HSE Plan is developed with the above in mind and the lessons learned from each year's operations are reflected in next year's plan and programmes. Both the HSE Management System and health, safety and environmental performance are subject of a number of formal reviews: • the Company Operations/Drilling Manager monitors HSE programme progress and reports status at the Company's quarterly HSE management overview committee meeting • the contractor Base Manager reviews and summarises the overall health, safety and environmental performance for the installation in his monthly report • HSE performance is discussed at the installation HSE meetings giving the opportunity for comment and feedback. Where such reviews identify concerns or trends which merit immediate attention, appropriate action is initiated.

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4

PREPARATION

4.1

Site Preparations - Land

4.1.1

Locations

Siting Wells should be located at least the height of the mast away from public roads, railways, public works, houses or other public places. Safe distances from any radio transmitters need to be established so that the use of explosives and detonators may proceed without danger of external activation. Where this is not the case, enforceable control procedures shall be established, or detonating systems not affected by stray electrical currents should be used. Sites close to overhead and underground power lines should also be avoided. Not only do they pose a threat to the safe use of explosives, but also to the safe operation of cranes and other equipment that can potentially come into contact with them. All practicable means shall be taken to minimise or avoid detrimental effects on the surrounding environment by virtue of the construction of the location or the operation of the drilling rig. For specific sites, advice should be requested from the HSE Department.

Size The site should be sized to contain all equipment and buildings, storage, workshops, etc using distances between various rig components in line with existing rules and regulations for the area of operation and the hazardous area drawing of the drilling rig. Within the above constraints, it shall be sized to minimise environmental impact.

Sources of ignition Naked lights, unprotected electrical equipment, smoking and all other sources of ignition shall be prohibited on all drilling/well sites. When internal combustion engines are permanently used within a hazardous area they shall be protected. Petrol driven engines are not to be permitted on the worksite. See 5.2.2 and Appendix V for further details.

Flares and flare pits Flare pits and extremities of flare lines should be located at least 90 m from railways, roads, public works, processing units or tanks. They should be at least 30 m from a well, gas/oil separator, site drainage or other possible source of ignitable vapours.

Warning and other notices Warning notices stating restrictions applicable to unauthorised persons, vehicle access, naked lights, smoking and other hazards should be prominently displayed. Notices should also be displayed indicating where firefighting equipment, personal protective equipment, breathing apparatus, and first-aid equipment are stored. Escape routes shall be indicated where appropriate. All signs and notices shall be written in languages understandable to all site personnel. The induction process shall bring the hazards of the site, and the rules of the site, to the attention of staff.

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4 Preparation

Telecommunications Telecommunications equipment such as telephones, radios and talk-back systems located in hazardous areas shall be suitable for Zone 1 application. Instances have occurred where radios operated in the SCR cabin and the Driller's control cabin have interfered with SCR systems. Radios should not be operated in these areas unless it is determined that the SCR system is not affected by to the electromagnetic radiation generated by them.

Drainage Drilling sites and camps should have an adequate drainage system so that potentially harmful effluents are contained and can be carried clear of the site to a point where they are unlikely to cause harm. Means shall be provided to trap any escape of oil before it can leave the site. Drains and bunds should be sized so that they can contain two to three times the maximum storm rainfall expected over a two-hour period, plus the liquid inventory they are designed to contain. Surface drains should be adequately graded and kept debris free to ensure quick disposal of their contents. Waste oil from pumps or other machinery should be trapped, collected and disposed of properly.

Sewage and waste Arrangements shall be made for the provision of septic pits and the proper discharge of sewage. Waste should be collected and contained in specially supplied waste skips on site or burnt at the site. Metallic waste should be collected and disposed of at locations approved by the local authority. Mud chemicals used should be of low potential toxicity and mud disposed of in a responsible manner.

Excavation Excavation work shall be carried out under the permit-to-work system and in such a manner that the collapse of side walls is precluded. Measures shall be taken to prevent persons and livestock from accidentally falling into an excavation. They should be properly illuminated at night.

Site access Only authorised persons shall be admitted to a drilling site. This may need to be enforced by enclosing the whole or parts of a site. Openings in enclosures should be permitted only under authority, and after adequate steps have been taken to control entry and exit. Approved personal protective equipment shall be worn when visiting or working on a drilling rig or on a well servicing hoist.

4.1.2

Road vehicles and mobile plant

Only protected diesel engines conforming to 'Recommendations for the Protection of Diesel Engines Operating in Hazardous Areas' (Ref. 13) shall be used within hazardous Zones 1 and 2 (see Appendix IV). Any exceptions shall be strictly controlled through the application of the permit-to-work system. Road vehicles shall not be permitted to enter or operate in a hazardous zone, except by special permits which will take into account necessary precautions to ensure no flammable vapours will be present during the duration of the work in the area. Vehicles should not be parked within the location perimeter. Adequate parking facilities will need to be provided outside the location. Before entering a location, vehicle drivers should report to the site supervisor for instructions. On location vehicle speeds shall be limited to walking pace.

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4.1.3

Camp sites

In remote operating areas where there is no acceptable local accommodation, it is necessary to provide camp facilities to house operations staff, crews and other contractor personnel. Provided below are topics directly associated with drilling camp construction, layout and operation, which technical HSE audits highlight as requiring particular attention. Access control at the camp site should provide immediate information for newcomers or visitors to inform them: • where to park their vehicles • where to report their arrival and nature of business • who will brief newcomers/visitors on site rules, hazards and emergency response in case of alarm. The person often designated the above duties is the camp boss or the medic.

Fuel storage Fuel storage shall be segregated away from the general accommodation area and adequately marked with hazard signs and cautionary notices (e.g. 'no smoking'). Fuel tanks should be bunded and situated on the low side of the location so that fluid run-off will be directed away.

Explosives and radioactive sources Explosives and radioactive sources, together with any other hazardous substances, shall not be kept at the camp site, but in defined and separate areas at the rig site. This restriction relates to security as well as health and safety aspects of hazardous substance storage.

Waste disposal pits Waste disposal pits shall be situated a minimum of 30 m from the accommodation area so that full hygiene control can be exercised without risk to persons using the camp facilities.

Potable water Potable water shall be regularly checked for possible contamination and, if stored in tanks, shall be chemically treated to prevent growth of potentially harmful organisms. Where tests indicate that water supply is unsuitable for human consumption, bottled water from a reliable source shall be provided.

Food storage Food storage, handling, preparation and messing facilities shall be controlled by regular inspections. Such inspections shall be made at least weekly by the medic and camp boss. The quality of these inspections should be periodically verified by contractor management and specialists. The medic/medical officer shall be responsible for verification of adequate health checks for catering staff, particularly those engaged in food handling.

Fire extinguishers Fire extinguishers shall be provided for all accommodation units including kitchens, mess room, recreation rooms, clinic and radio room (if applicable). Further fire fighting facilities shall be provided around fuel tanks, vehicle parking areas and the camp generator.

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4 Preparation

Fire drills Fire drills in the camp site shall be held at least during every crew work cycle and shall involve all personnel at the camp site, including subcontractors, visitors and catering personnel. Required response to the general and fire alarm(s) shall be known by all personnel on site. Drills held in the camp must be reported, and deficiencies which are noted shall be corrected. They should be co-ordinated with muster drills at the rig site so that the adequacy of the system which accounts for the whereabouts of personnel can be checked.

Electrical systems Electrical systems in the camp shall comply with a recognised standard. All lighting, heating and accommodation power circuits shall be fully protected by all or a combination of the following: • miniature circuit breaker (MCB), with thermal magnetic over-current release • fuses • overload trip switches • 30 mA earth leakage circuit breaker (ELCB) Full earthing shall be provided, verified and documented. An earthed system is considered acceptable for temporary purposes, if the resistance between ground and any part of the earth system is maximum 160 ohms and the system is protected with a 300 mA residual current operated circuit breaker (RCCB). Note: 160 ohms is derived from Re *I < U where: - Re is the earth electrode resistance, - I is the maximum leakage current (300 mA as specified in DEP 33.64.10.10 -

Appendix 5)

- U is the safe touch voltage (50 VAC maximum). An earth resistance of much less than 160 ohms, typically 4 ohms, can usually be obtained easily with two or more electrodes. Any type of conducting material should prove sufficient for the electrodes, though copper is preferred. The opportunity should be taken to place earth electrodes around the camp, especially in the vicinity of major electrical loads. Power distribution cables shall be UV protected if strung above ground and if buried shall be contained in a marked conduit, otherwise armoured cable shall be used. It is recommended that following the arrival of a camp to a new area or venture, a full inspection of the electrical generation and distribution system is carried out by a specialist, so that adequate protection, earthing and operating standards can be verified. Audits have indicated a high incidence of potentially dangerous electrical systems in seismic and drilling camps. This topic therefore deserves particular attention.

Access around the camp Walkways connecting the mess room(s) accommodation units with ablution facilities should be kept clean, clear of obstructions and where possible dry. Lighting around camp facilities shall be such that the ground can be seen clearly at all times during the hours of darkness. Similarly emergency response equipment shall be kept in well illuminated positions. Muster areas shall be clearly indicated and illuminated.

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Medical facilities The clinic is the usual base for the medic and is normally situated at the camp site. In case of emergency call-out it is essential that adequate means of communication exist between camp site and rig. Transportation for the medic shall also be available 24 hours per day, as shall a vehicle suitable for carrying a patient on a stretcher from the rig site to the clinic. In remote areas the provision of a helipad should be considered. Where this is not a viable proposition, the provision of a doctor and facilities to stabilise and treat patients during the period needed to evacuate, should be considered.

Security In areas where security risks are an identified hazard, advice, either from the local authorities or from Group security advisers, should be sought.

4.2

Preparation Offshore

4.2.1

Location preparation offshore

Information is required about meteorological and oceanographic data of the area in which drilling will take place to establish the type of rig most suitable for the economic completion of the drilling programme. Seismic surveys provide data concerning water depth, sea bed topography and soil conditions and in the majority of cases will provide sufficient information to indicate the probable presence or absence of shallow gas (see 3.5.1, 'Site selection'). Such information is considered adequate for operations with vessels such as drillships and semi-submersibles. Bottom supported rigs (jack ups) require a more detailed location investigation which may include seabed coring and sampling to establish data on leg penetration and the adequacy of the surface strata to support the vessel and avoid punch through.

4.2.2

Structural integrity of jack-ups

Site specific assessment The Group position is described in the report 'Marine Safety of Mobile Offshore Units' (Ref. 14). In accordance with this, it is Shell practice to perform a site specific assessment for each jack-up prior to contract award and for each location thereafter where conditions significantly differ. The primary objective of the assessment is to ensure a level of structural reliability of the jack-up in elevated condition, which is comparable with fixed platforms. The verification of the structural adequacy of a jack-up involves three key activities: • site specific structural analysis • condition assessment • condition monitoring. The first two activities (structural analysis and condition assessment) shall be completed before award of contract and/or prior to mobilisation. Condition monitoring should preferably be the continuation of contractor's normal practice, but shall commence at least at mobilisation and should continue until completion of the operations.

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4 Preparation

Site specific structural analysis The site specific structural analysis aims to check that the jack-up theoretical strength, based on assumptions regarding the condition of the jack-up structure, conforms to SIEP criteria. The SIEP practice for site specific structural analysis of jack-ups is described in the document 'Practice for the Site Specific Assessment of Jack-up Units' (Ref. 15) and in a similar report which has been made available to drilling contractors. The practice provides guidance on the recommended analysis procedures and acceptance criteria. It addresses the key failure modes of a jack-up in elevated condition such as overturning stability, structural failure (leg strength, pinion/rack chock overload) and foundation failure. The site specific analysis may be carried out in-house or by a consultant, but shall be carried out in accordance with the above referenced document. Required data include jack-up structural data (usually obtained from the drilling contractor during tendering) and site specific data including water depth, 50year return period storm wind, wave and current, seabed, and soils data. Some of the same information will also be used to assess overall safety conditions such as seabed hazards (e.g. old footprints, pipelines, etc), drilling hazards, or presence of shallow gas.

Condition assessment and monitoring The condition assessment is to validate the analysis results by confirming that the actual condition of the jack-up structure is in line with the assumptions made in the site specific structural analysis. If significant differences should be detected then a re-analysis may be required. Condition monitoring aims to provide early warning of any significant reduction in the jack-ups structural integrity during the operations with the jack-up. Monitoring may be of special importance if the jack-up will be used for a long period; typically more than one year, be it on one or more than one location. The engineering requirements and scope of work for jack-up condition assessment and condition monitoring are summarised in the document 'Jack-up Structure Condition Assessment and Condition Monitoring' (Ref. 16) This information has also been published in 1991 as SPE/IADC paper number 21979 'SIEP Practice for Site Specific Structural Fitness for Purpose Assessment of Jack-up Rigs' (Ref. 17) and therefore is available to drilling contractors. In general terms condition assessment (and subsequent condition monitoring) should address certification, general condition of the structure, the condition of leg-hull interface, leg spud can connection and aspects of the spud can foundation. Confirmation is needed that there is no structural damage, that topside weight is in accordance with operations manual and that level of corrosion and marine growth do not exceed prescribed limits. Signs of deterioration, such as major mechanical damage (from accidents; local overload), existing fatigue cracks and severe corrosion are relevant and shall be recorded for future reference. It is noted that significant deterioration of components which are not essential for the ultimate strength of the jack-up may not be of importance when deciding if a jack-up structure is acceptable. Existing inspection/maintenance records held by the drilling contractor should be the primary source of information. Additional data may be obtained from a general visual inspection, which is usually carried out in conjunction with the drilling, marine, aviation and HSE audits. In some cases, there may be a requirement for an additional detailed inspection by a third party consultant. These inspection/monitoring activities should be carried out by the contractor and verified by Shell. It should be recognised that the contractor is responsible for maintaining his unit at a minimum acceptable level as specified in the contract and as required to remain in class. Condition monitoring by Shell may inadvertently take on the assumption of liabilities assigned to the contractor in the contract and should be avoided.

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Industry guideline and recommended practice A joint industry project to develop an industry practice for the site specific assessment of jack-ups is nearing completion. The work is carried out by the Industry Work Group with representatives from the complete spectrum of the offshore industry. SIEP (EPD/51) are representing Shell on this Work Group. The industry practice will consist of two documents, i.e. Guideline and Recommended Practice. The guideline titled 'Society of Naval Architects and Marine Engineers (SNAME) Technical and Research Bulletin 5-5' (Ref. 18) describes the philosophy for site specific assessment of jack-ups and is in complete agreement with Group practice. Currently the joint industry project is finalising the recommended practice which will contain the detailed engineering procedures and acceptance criteria. It is scheduled that this document will be published in May 1994.

4.2.3

Precontract assessment of semi-submersibles and drill ships

The SIEP position on the subject is described in 'Marine Safety of Mobile Offshore Units' (Ref. 14) and covers both semi-submersibles and drill ships. In accordance with this document, key features of the vessel should be assessed prior to contract to ensure that it has an adequate level of structural reliability to carry out the intended function at the selected location. The following aspects are important to the structural reliability of semi-submersibles and drill ships:

Stability and reserve buoyancy The vessel shall have adequate stability and reserve buoyancy to remain afloat and upright with its required payload in the anticipated environmental conditions, even after sustaining a certain amount of damage. It should be noted in this respect that damage stability requirements have become more stringent over time in response to accidents but older vessels are rarely forced to comply. The fact that a vessel is classified does not mean it meets the latest criteria. The stability characteristics of a vessel should be assessed in relation to the maximum intended loading condition.

Structural strength Most modern vessels are designed for world service and so are designed with adequate strength. However, some older semi-submersibles may only be suitable for mild environments. Degradation of design strength through corrosion, damage or fatigue cracking is the main structural threat to all semi-submersibles and drill ships and requires assessment.

Station keeping The station keeping performance of a vessel, by dynamic positioning or more usually an anchoring system, depends on the environmental conditions, the water depth and the soil conditions at the selected location. This should be assessed on a site specific basis although this need not be on a per well basis if the conditions over the whole area of a drilling campaign are considered together. Analysis of the anchoring pattern and assessment of the condition of the anchoring equipment are both required. The requirements for mooring of mobile units are given in the document 'Mooring Standards for Mobile Units' (Ref. 19).

Ballast control system The ballast control system is vital to the safe operation of semi-submersibles. Significant improvements have been made in systems of modern vessels but not all older vessels have been made to comply with

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4 Preparation these more stringent requirements. Ballast systems designed to the latest code requirements shall be stipulated in all new contracts. Most semi-submersibles and drill ships are classified with one of the major classification societies and, in conjunction with the vessel owner, they monitor the condition of the vessel in respect of the aspects mentioned above. These inspection/maintenance/repair records should be the primary source of information in assessing a vessel and shall be made available for inspection by Shell. Additional data can be obtained from a general visual inspection, which may be carried out in conjunction with the drilling, marine, aviation and HSE inspections, by an appropriate specialist. In some circumstances, for example if the vessel is old or the existing records are of a poor quality, there may be a need for a further more detailed inspection. The onus to provide a site specific anchoring analysis showing compliance with current codes, together with evidence of satisfactory stability characteristics, should be placed on the drilling contractor in consultation with the relevant classification society or certifying authority. Similarly, inspection, monitoring and repair activities to maintain the vessel at a safe and satisfactory standard are the responsibility of the contractor and so should be undertaken by the contractor in consultation with the classification society. Shell's primary role should be one of verification but may include independent inspections. The classification societies have standards which differ in some aspects between themselves and also change with time. Whilst there is a movement towards harmonisation of standards in the industry, this has not yet been achieved. Consequently SIEP may be consulted, if required, to advise on appropriate standards for the integrity assessment of semi-submersibles and drill ships. A draft procedures guide for the Safety and Integrity Assessment of MODUs is available from SIEP.

4.2.4

Tender assisted operations

Offshore tender drilling and workover operations are no longer limited to areas which are environmentally benign, i.e. minor expectation of prolonged periods of severe weather conditions. Tender assisted operations are also used in North Sea type environments albeit with semi submersible tenders. However, in all cases water depths should be compatible with feasible anchor cable length and required anchor patterns. Deck space and load capacity are limited. Vessel stability shall remain a controlled operating parameter. Emergency response plans in case of severe weather, platform fire and damage control in the event of a collision shall be in place. All tenders should have emergency anchor release capability which can be controlled from the Bargemaster's or Toolpusher's office. Before commencing operations on a new platform the anchor release mechanisms should be verified as functioning correctly. Similarly the remote platform/well shutdown function shall also be tested as well as the bridge/umbilical release system if used. The remote BOP control panel on the tender shall be tested as part of the normal BOP test routine. Other emergency functions commonly activated from the Bargemaster's or Toolpusher's office are the generator shutdown and the air fans to the generator and mud room areas of the barge. These should also be tested as part of fire drills. It is the responsibility of the OIM to ensure that at all times there are personnel available to launch and operate the lifeboats should the need arise for a general evacuation.

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4.3

Materials Procurement

4.3.1

Hazard data

Prior to the use of any material, particularly mud chemicals and cementing materials, Material Specification Data Sheets shall be obtained from the supplier and the product assessed for toxicity and the requirement for any special handling precautions. The medic shall be equipped to deal with injuries to personnel arising out of the use of all materials on site.

4.3.2

Inspection

The requirements for inspection of materials and equipment to be procured for an operation should be considered prior to ordering and the inspection programme clearly stated on the order. Shell Quality and Inspection Requirement (SQAIR) exists for many items of drilling equipment and materials and should be specified on purchase orders. Only genuine spare parts, purchased from original equipment manufacturers or their authorised agents, should be used for the maintenance or refurbishment of safety critical equipment.

4.3.3

Stacking and storage

Incorrect stacking of tubulars and sack materials is the cause of many accidents on site. Casing rack loading, particularly on land sites, shall be carefully considered to avoid subsidence and hence instability. Adequate strength dunnage and nailed-in chocks at the end of each row are important. The stacking and de-stacking of pallets in the correct manner should be planned and only pallets in good condition used. The operation of fork lift trucks shall be restricted to designated personnel who have demonstrated competence.

4.4

Transportation of Materials and Equipment

4.4.1

Road transport

A significantly high proportion of all accidents in EP operations, including drilling operations, are directly related to incidents involving vehicles. To address this problem, a strict journey management system should be implemented. Guidelines for developing such a system are published in EP 95-0260 Logistics. The following documents are useful references: • 'Road Safety Management' (Ref. 20) • 'Seat Belts' (Ref. 21). Required driving skills will depend on the local environment and may include considerations such as desert terrain, dust, ice, fog, water crossings, etc. It is recommended therefore that prior to commencing operations, all Company and contractor drivers should attend defensive driving courses addressing local hazards and on-road/off-road driving regulations and techniques. If subcontractors such as caterers, civil engineering contractors, etc are utilised, they should also be included in the training scheme as a contractual obligation.

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4 Preparation Compliance with Company driving rules shall be verified by the contract holder through spot checks and audits. Compliance checks should include: • review of maintenance practices • observation of speed limits • day/night driving limitations • the use of seat belts for front and rear seats • minimum hardware requirements in place, e.g. first aid box, fire extinguisher, roll bar, etc • radio communication system in good working order • installation of tachographs to monitor speed, etc • verification of driver qualification requirements • journey monitoring/logging • alarm conditions and emergency response plans.

4.4.2

Sea transport

The transport of materials and equipment by sea shall be carried out only by vessels specifically designed for the purpose. Safe unloading operations can only take place if the vessel has been correctly loaded. This is the responsibility of the Master. Responsibility for material transfer operations rest with the Barge Master on the rig and the Master on the vessel. With regard to the advisability to conduct such operations during adverse weather conditions, the Master's decision shall be final with respect to the safety of his vessel and crew.

4.4.3

Air transport

Aviation operations are audited and approved by Shell Aircraft Limited. Their advice should be sought on questions or problems relating to air transport. The carriage of goods by air is covered by air transport regulations and the final decision on whether any particular item will be carried rests with the helicopter pilot.

4.4.4

Rig moving on land

A detailed rig move plan shall be prepared by the drilling contractor which addresses personnel requirements, equipment requirements, responsibilities and contingency plans. In areas where contractors do not move their own rigs, responsibilities/accountabilities of Company transport services shall be defined prior to moving operations taking place. Adequate provisions shall be made for: • location/road surveys • rig-moving vehicles • craneage • fuel tankers • hazardous loads • fork lifts • personnel vehicles

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HSE Manual EP 95-0210 Drilling • repair facilities • supervisory staff • communication • emergency response • escorts. During rig moves, the drilling contractor should have a senior supervisor at both the old and new locations to ensure the safe loading and unloading of vehicles. These supervisors should be in radio contact with each other so that information on awkward loads or special handling precautions can be communicated. Road and load safety matters should be addressed and included in the drilling tender and contract documents. Police escorts may be required for traffic control. In populated areas there may be local rules and regulations which should be observed. Refer also to EP 95-0260 Logistics and Appendix III 'Land Rig Move Plan'. Following a rig move, a report should be made to provide an analysis of key aspects of the move.

4.4.5

Rig moving offshore

Prior to a rig move all participating parties, i.e. Company, drilling contractor, surveyors, vessel masters (if possible) and rig mover (towmaster) shall hold a meeting to discuss and agree on procedures, problems likely to be encountered, operational matters and responsibilities. A detailed rig move plan shall be prepared and should outline such aspects as: • move programme, contingency plan, responsibilities • weather forecast • sea bed survey • surveying method • rig position on new location • anchor pattern and test tension • pennant and chaser combinations • communications responsibilities • selection of anchor handling tugs. When moving on to producing facilities, well close-in and production shutdown requirements shall be discussed and agreed by production and drilling staff. Verification prior to move-on shall be via a documented handover procedure. During anchor handling operations, the crew on the deck of the rig and anchor handling vessels shall be kept to a minimum and crew members shall be positioned to minimise the risk of injury should there be an equipment failure. Failures of very heavy hooks and anchor pennant lines have resulted in fatalities. Hydraulic release mechanisms (shark jaws) should be used wherever possible instead of pelican hooks. Anchors shall be laid in such a way as to avoid any possibility of damaging pipelines or any subsea equipment either during anchoring or subsequent operations.

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4 Preparation Following a rig move, a report should be made to provide an analysis of all aspects of the move, a log of events including weather conditions and a list of recommendations on procedures and equipment performance. The rig mover should note any matter that could lead to a safer and improved method of work. Refer also to report 'Offshore Rig Move and Anchor Handling Operations' (Ref. 22) and EP 95-0260 Logistics.

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5

EQUIPMENT

5.1

Maintenance

It is in the interest of safety and the prevention of time loss to ensure that all the equipment is properly maintained. Spare parts for equipment essential for the safe operation of the rig shall be carried by the drilling contractor. The contractor shall give an undertaking to use the original equipment manufacturer's spare parts or those from a supplier approved by the manufacturer. Following commencement of the contract, the effectiveness of the contractor's programme for preventive maintenance of the rig equipment should be evaluated by selective verification. When precontract audits are performed on rigs (generally by third party consultants), the effectiveness of the preventive maintenance system (PMS) should be part of the scope of work. All items of equipment in the rig's asset register shall be included in the PMS.

5.2

Hazardous Zones

5.2.1

Hazardous zone classification

Hazardous zone classification is aimed at reducing the risk of fire or explosion by keeping ignition sources out of areas where combustible gas release or accumulation of gas is possible. Such areas include the wellhead, wellhead cellar, bell nipple and mud treatment systems. Various systems of hazardous area classification exist. The system adopted and recommended by SIEP is 'Area Classification Code for Petroleum Installations' (Ref. 23). This Institute of Petroleum (IP) code should be taken as the basis for ignition control criteria used in rig selection, equipment specification and hazardous zone dimensions. Some essential elements of the code are presented in Appendix IV. Another system of hazardous zone classification is based on 'Classification of Areas for Electrical Installations at Drilling Rigs and Production Facilities on Land and/or Marine Fixed and Mobile Platforms' (Ref. 24) and is largely applied in areas closely associated with the USA. Its main drawback is that the system allows potential sources of ignition closer to the wellhead, bell nipple and active mud system. This system should only be adopted if it can be shown that conversion to comply with the IP code would involve expenditure not justified by the risk reduction achieved.

5.2.2

Operation of diesel engines in hazardous zones

The Shell standard reference used for operating diesel engines in hazardous zones is contained in the 'Recommendations for the Protection of Diesel Engines Operating in Hazardous Areas' (Ref. 13) published on behalf of the Institute of Petroleum. The recommendations contained in this document were formulated to provide for the protection of diesel engines when used in potentially hazardous zones within the petroleum and petrochemical industries. Details are provided in Appendix V.

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5 Equipment

5.2.3

Electrical safety in hazardous zones

There are many different systems of electrical equipment classification and certification. For the purpose of uniformity and standardisation the European (CENELEC), UK (BSI) and international (IEC) are used as the main references for electrical equipment specifications for use in hazardous zones. Electrical equipment for use in hazardous zones shall be selected in accordance with the following criteria: • the type of protection shall be compatible with the hazardous zone classification • the surface temperatures of the apparatus shall be lower than the ignition temperature of the gas and vapours that will be encountered • the apparatus construction shall be able to withstand the environmental conditions.

5.3

Personal Protective Equipment

The selection of Personal Protective Equipment (PPE) takes account of risks to health based on knowledge of the hazard and assessment of the exposure which can be, for example: • direct, a projectile or sharp or abrasive object • chemical, an irritant, carcinogen or sensitiser • physical, noise, radiation, temperature extremes, vibration, electrical or light • biological, fungal. The hazard may be in the form of gas, vapour, mist, dust, fumes, liquid, solid, high or low temperature, radiation or under pressure. Based on the hazard and risks, consideration is required concerning the degree of protection needed for special situations. The following general rules will apply to all rigs: • all persons shall wear safety headgear, footwear and eye protection outside the accommodation (offshore) or on the rig site (land) • anyone working over the side of an offshore rig shall wear a life vest • anyone working more than 6 ft (2 m) above a floor level shall wear a safety belt firmly anchored above them to check a fall. In addition special equipment such as breathing apparatus shall be required for firefighting and in toxic atmospheres (e.g. H2S). Full details for the selection of PPE are contained in 'Personal Protective Equipment Guide' (Ref. 25). The requirement for the provision of breathing apparatus for use in atmospheres containing H2S are given in 6.5.

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5.4

Drilling Equipment

5.4.1

Drawworks safety

Accidents still occur from guards not being replaced after repairs or maintenance of drawworks and rotary table gears. All necessary guards shall be replaced after completion of maintenance work. All drawworks shall be fitted with a secondary braking device (e.g. eddy current or hydromatic). Drawworks fitted with an eddy current brake (e.g. Elmagco) should have an auxiliary powered back-up supply in the event of a main power failure. An emergency stop device shall be provided for the drawworks, within easy reach of the Driller. This device shall be tested regularly. There shall always be a sufficient number of wraps of hoisting line remaining on the drum to eliminate any strain being transmitted directly to the fastening device. The minimum wraps for a given drawworks is given in the manufacturer's operating manual. The installation of a top drive will require additional wraps. Past incidents involving brake handle and brake linkage failure indicate the need for a rigorous inspection schedule, including NDT, of the main drawworks brake. Main brake failures have also occurred due to the failure of the brake cooling system. Fitting a flow sensor and temperature alarm to the cooling water return line is recommended. As a minimum, loss of cooling water pressure should be indicated by an audio-visual alarm on the Driller's console. A low level alarm on the cooling water tank is recommended.

5.4.2

Pulsation dampeners

Charging of pulsation dampeners - high pressure discharge Safety precautions peculiar to this job: • a permit-to-work should be used for this operation • ensure charging gas is nitrogen, if necessary by using a portable analyser • nitrogen bottles are painted in a distinctive colour scheme that makes identification positive. The body of the bottle should be grey with the top and shoulders painted black • a pressure regulator shall be installed on the bottle • clear vicinity of non-involved personnel before charging • follow the recommended instructions from the pulsation dampener manufacturer.

Charging of pulsation dampeners - low pressure mud pump suction Pulsation dampeners on the suction side of mud pumps are rarely used and generally considered unnecessary when a charging pump is incorporated in the system. If they are used the following points should be noted: • never use high pressure nitrogen, or any other compressed gas to charge a suction (low pressure) dampener unit. A foot pump is preferred • isolate the pump and mud suction system • use a permit-to-work for this operation • ensure that the low pressure mud suction relief valve is set open

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5 Equipment • follow pulsation dampener manufacturer's instructions for charging the dampener unit.

5.4.3

Relief valves

The high pressure mud pump discharge piping is protected by means of high pressure relief valves. The discharge lines should be a minimum of 3" diameter, constructed from high pressure pipe and slope downwards to facilitate drainage. Screwed valves should be phased out and replaced with a flanged type.

5.5

Derricks and Masts

5.5.1

Erection equipment

Winches, gin poles and other erection equipment, together with wire ropes, shall be re-certified on a six monthly basis and visually inspected prior to use. A record shall be kept of the inspections. Ensure that the loads are within the safe working load of the slings and other equipment in use.

5.5.2

Derrick and mast inspection

Derricks and masts shall be thoroughly inspected after erection and before lowering to verify that no members are distorted and all bolts are tightly in place and equipped with suitable lock washers. This inspection should ensure that no member has been installed in a manner that will impair the safety of the derrick. Telescoping masts shall be inspected to verify that all the locking devices are in place before transferring the load from the raising system. During inspection use should be made of the 'Report of Visual Field Inspection of Derrick or Mast and Substructure' (Ref. 26).

5.5.3

Derrick loading

Eccentric loading of a derrick should be avoided. If, because of unequal settling of derrick corners, the centre of the water table when drilling with rotary tools, does not line up with the centre of the well, the condition should be corrected by inserting shims at the low corners of the derrick. A crown block shall never be shifted off centre to correct for derrick misalignment unless such movement is small and due care is taken to determine the effect it will have in reducing the safe working load of the derrick. Eccentric application of loads reduces the rating of the derrick and may ultimately result in derrick failure. To balance further derrick and mast loading, the dead line and fast line should be on opposing sides.

5.5.4

Foundations

The bearing capacity of all soils decreases as the moisture content increases. Proper drainage should be provided and the foundation inspected after heavy rains to ensure that derrick corners have not settled unequally, thereby causing the derrick to be out of plumb. Civil engineering advice should always be sought and matting or concrete pads will generally be used.

5.5.5

Masts

Written procedures shall be provided and enforced by the contractor when raising or lowering a mast. The type of weight indicator used shall indicate the correct number of lines strung to the block. Lock pins, or other locking devices for holding the upper sections of a telescopic mast in place, shall be inspected to ensure that they are seated before any additional work on the structure if performed. Any

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HSE Manual EP 95-0210 Drilling alteration to the securing pins or positive locking mechanisms shall be made only after authorisation by the manufacturer and application of change control procedures. No other work should be performed underneath the derrick while it is being erected or dismantled, or under the mast while it is being raised or lowered. The cellar should be completely covered during these operations. Wells within the mast radius shall be closed-in and isolated prior to mast raising or lowering operations.

5.5.6

Guy lines

Guy lines shall be used to support the mast as recommended by the manufacturer. The strength of the guy lines and auxiliary equipment shall be in accordance with the manufacturer's specification. If guying requirements are not mentioned in the operating procedures or are not known, the mast should be guyed according to 'Specification for Drilling and Well Servicing Structures' (Ref. 27). Guy lines shall never be used for aligning the mast. Guy lines shall never be removed during operations and shall be subjected to the same inspection procedures as other wire rope devices.

5.5.7

Escape line and slide

On each operating rig a derrickman's escape line shall be provided, with one end secured to the derrick or mast near the derrickman's platform and the other end anchored at a point one mast length away from the well bore, in a clear area, where a derrickman can make a safe landing by way of the line. (If possible the line should be strung-out into the prevailing wind).

5.5.8

Crown protection

Every rig shall have a crown-o-matic or other similar emergency stop device to prevent hoisting the travelling block against the crown block. If timber blocks are used as shock absorbing devices, ensure that they are secured in such a way that impact does not dislodge them. There exists a real hazard to the Driller from the rapid downward movement of the brake handle when the crown safety device is activated. Jumper bars to prevent drilling line from jumping out of the crown sheaves shall be installed so that no section more than 100° of arc is unprotected.

5.5.9

Deadline anchor/weight indicator

Deadline anchors for hoisting lines shall be constructed and installed (bolted/welded) such that their strength equals or exceeds the working strength of the hoisting line. Avoid systems which rely on bolts in tension, the system should be designed such that a bolt failure does not result in the anchor flying. Regular checks for cracks and significant corrosion shall be made to ascertain proper functioning and structural integrity of the equipment. Precontract and major inspections shall include detailed inspection of the anchor assembly. Failure of the welding of the drilling deadline anchor has occurred during jarring operations. Critical welds or other securing devices shall be regularly inspected. A weight indicator shall be installed on every drilling and workover rig and it shall be maintained such that it registers an accurate indication of the hook load suspended (within 5 per cent at maximum hook load). The weight indicator shall be checked regularly for calibration by comparing its reading with the

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5 Equipment calculated drill pipe or tubing string weight. The load cell gap should be checked every shift. A closed load cell will not indicate additional loading.

5.5.10 Stabbing board Prior to running casing or any other job requiring the stabbing board, it shall be inspected and tested to ensure safe operation. The following points should be checked or observed: • a safety harness, attached to a derrick member above the stabber, shall be worn on the stabbing board at all times • inspect hoisting system • inspect safety stops • check emergency brake system • ensure no loose objects are left on the board • never test stabbing board during other drill floor operations • good communication (visual) is required at all times between Driller and stabber. The stabbing board shall be regarded, for the purpose of inspection and testing, as lifting equipment. It shall be subjected to the same rigorous inspection and certification process as other hoisting equipment, with particular attention to its man riding function. Stabbing boards shall have a positive mechanical locking device in case of hoist failure. Friction devices alone are not acceptable. Stabbing boards shall be included in the rig's preventive maintenance procedures. Controls of the stabbing board winch shall be fail-safe and of the dead-man type of action. Any maintenance work done on the stabbing board shall be concluded by a complete system function test to verify that all controls work correctly. The function testing should be done under the permit-to-work system. Some rigs are equipped with a so called 'cherry picker' which is a mechanised pipe handling tool. This and other types of mechanised systems shall be included in the preventive maintenance procedures and be additionally subjected to pre-job safety checks.

5.6

Lifting Equipment

5.6.1

General

Of all the hardware subjected to inspection during audits, this is the area where most deficiencies are found. All deficiencies are the result of a lack of effective control systems. Below are listed groups of deficiencies with recommended controls. • improperly made slings and lifting devices • corroded loose lifting equipment • loose lifting equipment damaged by improper use • unidentified equipment • equipment not subjected to inspection • damaged equipment accepted for downrated use

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HSE Manual EP 95-0210 Drilling • improperly stored equipment • lack of effective preventive maintenance systems. Hoisting of heavy equipment, tools and tubulars is a major cause of injuries. Only experienced persons from the rig crews should be authorised to operate hoisting equipment. The use of 'home-made' lifting gear, unless properly engineered, designed, tested and certified and thereafter regularly inspected, shall be prohibited. All hoisting equipment shall be adequately guarded. Components used for lifting such as sheaves, hooks, shackles, wire slings, etc shall be marked with the safe working load (SWL). The safe working load for a system of interdependent equipment shall refer to the weakest component of the system, e.g. winches, wire, hooks, pulleys, etc. Lifting machinery such as cranes, fork lift trucks and gin pole trucks shall be appropriately inspected and certified for hoisting/lifting with a clearly displayed SWL. It is recommended that the Toolpusher maintains a list of authorised operators of hoisting machinery. The quality of inspections performed by junior staff should be verified on a selective basis by supervisors.

5.6.2

Inspection - general

Inspection of drilling lifting equipment is based in part on 'Specification for Drilling and Production Hoisting Equipment' (Ref. 28). • weekly routine visual inspection in assembled condition • thorough cleaning and visual inspection in assembled condition after every rig move or every month, whichever comes first • NDT inspection in disassembled condition of: – elevators, links, bails, lugs spider, slips, tongs every six months – Kelly, kelly-cock, kelly-spinner, and pin and box connections, every 12 months – crown block ,travelling block, hook and swivel, top drive, heave compensatory and deadline anchor every two years, depending on service conditions Whenever lifting equipment has been subjected to high dynamic loading, e.g. jarring or working stuck pipe, immediate inspection is required. This also applies to the derrick or mast after such operations. Particular emphasis should be given to the inspection of top drive equipment, in accordance with the manufacturers recommendations.

5.6.3

Inspection of wire rope slings, hooks, shackles and winches

Slings Slings should be tested and tagged on a six monthly basis and marked with SWL and inspection date. They shall be visually inspected by a competent member of staff before all lifting operations. Slings shall be rejected when there is: • severe deformation - where strands are severely kinked or the core is protruding • severe wear - wear of high points of the sling caused by dragging the sling across decks contributes to early broken wires. A sling which has wires worn to half normal diameter on high points should be replaced

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5 Equipment • termination damage • severe corrosion (be aware of the possibility of internal corrosion) • no SWL indicated or last inspection date/colour code missing.

Hooks and shackles • Check that the SWL is adequate for the lifts • Use only hooks and shackles marked with the SWL • Check shackle and pin for excessive wear: – make sure that the pin is free, but not loose in the tapped hole. Secure pins with wire to prevent them vibrating free – threads of the pin should be undamaged and without appreciable wear • Never replace the pin of a shackle with a bolt. Shackle pins are made of high alloy steel, heat treated for optimum strength and are a tolerance fit. Bolts may not be to the same standard and could fail • Check shackle and pin for distortion • Check alignment of the pin holes; the untapped hole should not be too large.

Winches • Check condition of wire - look for kinks, broken wires, flat spots, visible core, etc Ensure that wire runs freely in the mast • Check condition of eye - a thimble should be used. Check condition, spacing and correct installation of bulldog clips • Check condition and operation of brake - brake rims and bands shall be in good condition and the linkage operating freely. Avoid bands becoming contaminated with oil or mud or water • Check hook and safety catch are in good condition and the swivel is operating freely • Perform MPI inspections on winch pedestals and securing mechanisms (bolts or welds) at six monthly intervals • Winches with a free wheeling device should not be used • The safe working load of the wire and the winch securing mechanism shall be greater than the maximum winch pull (stall at overload).

5.6.4

Elevators

Use on the correct size and type for the pipe being run. Physically check by using a joint of pipe for the correct lift profile of the elevators. Inspect latch, hinge pin and body for any defects. For single joint elevators ensure latch has a retaining split pin in good condition and of the correct size, securely attached to the elevator body. Check that shackles are not worn and that nuts have retaining pins - see notes on shackles. Check pick-up strops for damage and make sure swivel is in good condition - see notes on wire rope slings.

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5.6.5

Crown block and travelling block

Regularly check the following points: • that the crown block is securely bolted with clamps onto the water table, complete with shaft end clamps to prevent the sheaves from rotating loose from their bearings • that jumper bars are fitted over the sheaves • that wooden sleepers are secured to the underside of the crown and are undamaged. The retention method shall be such that impact by the travelling block does not dislodge them • that there are no loose items at the crown block or travelling block and the water table is clean • that compensatory chain guards on the travelling block are properly fastened with safety straps (if applicable).

5.6.6

Wire ropes

Safety factor Safety factor is the ratio between the nominal strength of wire rope and the calculated load. Field operations indicate that the following safety factors should be used. Minimum safety factor Sand line

3.0

Rotary drilling line

3.5

Mast raising and lowering line

2.5

Hoisting services other than rotary drilling

3.0

Rotary drilling line while running casing

2.5

Drilling line whilst pulling on stuck pipe

2.5

When a wire rope is operated close to its minimum safety factor, operating personnel should exercise care to minimise shock, impact and acceleration or deceleration of loads.

Drilling line When slipping or cutting the drilling line, the following points relating to this operation should be considered: • the operation should preferably be carried out when the bit is inside the casing, near shoe depth on the trip in. This is to ensure that the maximum amount of pipe is in the hole, should the well start to flow. At this stage the well has been observed stable during most of the trip • slipping the block line shall never be carried out during any of the following conditions: – drill pipe out of hole on a non-cased well – drill pipe is in open hole • a kelly cock in the open position shall be installed • before starting, the drill floor shall be cleared of all personnel not associated with the operation • safety harnesses shall be worn by persons working on the travelling block

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5 Equipment • during slipping use the dead line anchor brake. While cutting the line, the travelling block shall be hung off or otherwise secured • slipping and cutting operations shall always be supervised by the Driller on shift. Close inspection by the Driller of end clamps on the fast line and dead line anchor clamp equipment is mandatory. There shall be no delegation of this task to staff of lesser experience and responsibility. The drilling line should be subjected to a systematic slip and cut programme. After this operation, the crown-o-matic shall be reset and tested. The recommended slip/cut procedures are given in the Driller's Handbook issued by SIEP Training Division (HRTH/5) to all drilling staff.

5.6.7

Catlines and catheads

Catheads shall not be used as winches as the SWL of the lifting rope cannot be accurately assessed or easily controlled. Derrick-floor mounted air winches should be used.

5.6.8

Man riding winches

Winches used for the transportation of personnel shall be equipped with an automatic fail safe brake and have non-rotating wire rope in good condition installed. Certification of the winch for man riding is required and the winch shall be so marked. Man riding winches are used to move personnel to otherwise inaccessible places both above and below the rotary table. Any other operation which may interfere with the movement of the winch, i.e. hoisting or rotating, shall be discontinued until the operation involving the use of the winch is completed. The winch shall be under the control of a fully competent member of the crew instructed on the correct procedures to be followed and the safety precautions to be observed. When using a bosun's chair, a safety belt shall be worn and attached to the winch wire at a level independent of the chair. Good communication is required at all time. This may require the use of radios and the placement of an observer in a position where the safety of the operation can be effectively monitored. (e.g. at the monkey board level where the height of the operation effects the judgement of the winch operator). Non-routine operations shall be carried out under the permit-to-work system. Routine operations can be classified as follows: • work in general up to 2 m (6 ft) above rig floor • work on kelly and swivel, when set back in its scabbard • installation of circulation head for casing, liners, etc • upper kelly cock operation below 12 m (40 ft) • operations associated with wireline lubricators All other operations are non-routine and will require a work permit.

5.7

Blowout Preventers (BOP)

Blowout prevention equipment shall be installed, tested and operated in line with the latest version of the 'Pressure Control Manual for Drilling and Workover Operations' (Ref. 5).

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HSE Manual EP 95-0210 Drilling The BOP stack in use shall be pressure tested initially before drilling out of the casing shoe and thereafter weekly. Should a sequence of successful tests indicate that greater confidence can be placed in the stack and control equipment, then the testing interval can be extended up to a maximum of two weeks. Water, not mud, shall be used for testing BOP stacks. All pipe fittings, valves and unions placed on or connected to blowout prevention equipment, well casings, casing head housing, drill pipe or tubing shall have a working pressure rating at least equivalent to that of the component to which it is fitted. Drilling or workover operations shall not proceed until blowout prevention equipment is found to be serviceable by visual inspection and appropriate pressure testing. Suitable lifting equipment to handle BOPs is essential. Bridge crane, overhead crane or lifting rings with cable attachments shall be properly designed and functional. Working platforms should be built around the BOP stack. Safety lines, safety nets and work vests shall be used as appropriate during BOP handling. For any operation it is recommended: • to verify that records of maintenance, both scheduled and unscheduled, are kept in a BOP history file • to ensure that the manufacturer's BOP operating manual is followed and no alterations are made to the BOP equipment without written approval from the manufacturer • to ensure that only original manufacturer's spares are used on BOPs.

5.7.1

Recommendations specific to subsea BOPs

All drilling units with a subsea stack should have a Subsea Engineer who is responsible for maintenance, etc. He should also be in possession of a current well control certificate. When failure of the BOP equipment or its control system is detected, operations shall cease for repairs. When using ROVs to assist with BOP operation, confirm that the ROV is fully functional before the job starts and that all personnel involved are fully briefed on job requirements.

5.7.2

Shear rams

Shear rams on surface BOP stacks shall be able to shear the tubular section of all drill pipe in use with an operating pressure of 21,000 kPa (3000 psi) at expected well close-in pressure. It should be verified that installed piston sizes and operating pressures are adequate for the forces required.

5.7.3

Hydraulic bolt tensioning equipment

In the past this equipment has caused some serious accidents. The manufacturer's instruction regarding safe operation should be strictly followed. No alteration should be made to this equipment without the consent of the manufacturer.

5.7.4

Store keeping and spare part control

Store keepers should organise receipt and use of spare parts on the basis of 'first in - first out'. This is particularly important for rubber seals and packers, where ageing is likely to cause material deterioration. Seals and packers should be stored under conditions recommended by the manufacturer. The use of air conditioned store rooms for rubber goods is recommended.

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5 Equipment

5.7.5

BOP control system

BOP control systems shall be installed, tested and operated according with the 'Pressure Control Manual for Drilling and Workover Operations' (Ref. 5). In addition to the instrumentation to indicate the availability of air pressure and fluid pressure, the following safety features should be considered for the control systems: • a relief valve installed • accumulator low-pressure alarm • reservoir low-level alarm • air-driven hydraulic fluid charge pumps • electric-driven hydraulic pump to be connected to the emergency generator • fail safe regulators • manifold pressure is consistent with ram closing force requirements at anticipated maximum surface pressure (high pressure wells) • accumulator capacity at elevated manifold pressures still meets requirements • fire resistant hydraulic control hoses and control fluid • appropriate location of remote operating panels • redundant functions plugged off • hydraulic control hose are tested to the rated pressure of the unit (i.e. by-pass is opened).

5.8

Steel Hoses (Chiksan and Coflexip)

5.8.1

Standardisation of HP unions

Steel long-sweep hoses (Chiksans) or flexible armoured hoses (Coflexip) are often used for cementing, fracturing, acidising, testing and for kill lines. The 'Weco' type hammer unions for connecting these hoses can be mismatched particularly the 2" and 3" 602, 1002 and 1502 series. To avoid this it has been repeatedly recommended to standardise on series 1502 (15,000 psi) couplings. Chiksans and lines used for potential high pressure applications shall be snubbed and anchored. Chiksan hoses shall not be used for operations where reciprocation under pressure is required as they are not designed for this purpose. All such equipment of 2'' diameter and above, which is used for service above 13,800 kPa (2000 psi), shall have unions of welded or integral construction (see 6.4). The use of equipment with metal to metal seals is recommended.

5.8.2

Restrictions on use

Never use a Chiksan in combination with any rotating operation. Chiksans shall remain static when under pressure. The connection of the union to the pipe shall be of welded or integral construction. For service where reciprocation or rotation is planned, appropriately rated hoses should be used with a swivel type circulating head.

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6 Operations

6

OPERATIONS

6.1

Tubulars Handling

This paragraph considers the safety of the process of moving tubulars on the rig and the operations of making up, breaking down and tripping a drill string. The running of casing is also discussed. Prior to every usage, tubulars handling equipment should be cleaned and inspected, generally by the Assistant Driller, to ensure serviceability. Refer to 5.6 for details.

6.1.1

Certification and testing

All lifting equipment shall be certified. This applies to air winch lines, chains, hooks, swivels, shackles, elevators, slings, links, single joint elevators, slings or swivels attached to single joint elevators, pulleys, sheaves, blocks, lifting eyes, chain hoists, overhead cranes, etc. Threaded lifting subs/plugs/buttons/caps used for handling drill collars shall be manufactured from suitable material. In general, will have the same properties as drill collars and conform with 'Rotary Drilling Equipment' (Ref. 29) They are considered to be items of lifting gear and shall therefore be subjected to the same inspection schedule as other items of loose lifting equipment.

6.1.2

Taking tubulars on site

The following points should be taken into account: • check that the pipe rack area is clear of obstructions and ready to accept the tubulars in the correct order • ensure that an experienced banksman is positioned so that the crane operator can see him and the load at the same time • take care when removing bulldog retaining clips from transit slings: remove the clip with the crane taking the strain then stand clear as the crane relaxes its load, before removing transit slings • beware of joints that have not fallen into line • if using 'Pelican' hooks to sort out individual joints, ensure that the hooks are inserted into the pin and box end of the same joint. Inserting one hook into the pin of one joint and the other hook into the box of another can cause personnel to be trapped when the crane lifts • in the advent of adverse weather, ensure that racked pipe is adequately secured • ensure that any cleaning of box and pin ends will not create a hazard while handling. Keep footing clean and secure, and any high pressure cleaning away from the handling crew • walking on top of tubulars should be discouraged at all times, and forbidden unless the upper rows of pipe are fully choked and secured in position • use tag lines to steer and steady the load • make sure the maximum weight to be lifted is accurately known • separate rows of tubulars with dunnage. Retaining posts shall be in place offshore and end stops securely fixed in place on land locations. Bear in mind the load bearing capacity of the soil when racking pipe at surface locations.

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Pipe bundles All bundles shall be lifted and transported horizontally, supported at each end. Lifting bundles (and/or suspending them) from one end only is prohibited. The most widely used method is with a crane and wire rope slings on each end of the bundle, secured with bulldog clips. An alternative method, when an 'outline' is in use between a drilling tender and a jacket, is to suspend the bundle with two wire rope slings and raise or lower with an air winch. When using a forklift truck, be aware of maximum load rating to avoid overturning forces being applied. When transporting pipe with a forklift, a securing device shall be used to prevent the pipe rolling off the forks.

Drill collars Drill collars size 6.25" and smaller should be bundled in groups of not more than three. All other sizes of drill collar should be handled by crane one at a time. Two slings should be used, one at each end and the drill collar(s) will be lifted horizontally. Tag lines should be used to steer and steady the load. Extreme care needs to be taken in removing the bundling slings to avoid trapping feet or hands

6.1.3

Transferring tubulars to the rig floor

Drill pipe For manual handling of singles of drill pipe, use a lifting cap with a shackle installed in the eye or bail, or use an appropriate single joint elevator under the tool joint box.

Drill collars All sizes (9.5"/ 8.25"/ 7.25"/ 6.25"/ 4.75") can be picked up by crane using a two-point lifting sling keeping joints horizontal and presenting them to the derrick floor where they can be taken over with a full strength elevator, either a centre latch DP elevator when a lifting sub is used, or a side door elevator when a lifting plug is used. Remember that the lifting sub/plug should first be torqued-up before the drill collar is added to the drilling assembly and subsequently the full assembly is lifted out of the slips and run in the hole. This requires that the single should first be set in the mouse hole for torquing up. Small sizes (6.25" to 4.75") can also be picked up using a suitably rated air winch, either attached to a lifting cap with a shackle, or using an appropriate single joint elevator under the shoulder of a lifting sub/plug/button. Do not use two winches to pick up heavy drill collars. If one winch is inadvertently slacked off, the rating of the other may well be exceeded. In many cases, drill collars are provided with elevator recesses at the box-end (normally squareshouldered). In this case, either a full strength or a single joint elevator should be used on these recesses, but ensure that the recess shoulders are indeed square and do not impose loads on the elevator latch. They should also be dimensionally checked periodically to ensure that they have not become worn below the diameter at which they can be adequately supported by an elevator.

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6 Operations

Casing For picking up singles of casing, use a single joint elevator. For certain types of casing (e.g. flush washover pipe) it is necessary to use lifting nipples. Alternatively casing joints can be presented to the derrick floor suspended horizontally from a crane with a two-point lifting sling, and then be taken over using either a single joint elevator or a full strength side door casing elevator. If quick release pin protectors are not being used, verify that steel pin and box protectors are properly installed. Improperly installed protectors may drop off during transit to the rig floor and frequently become cross threaded and difficult to remove.

Tubing Same as casing, though small size tubing joints or externally flush pipe (such as blast joints) can also be picked up by an appropriate single joint or full strength elevator under the shoulder of a lifting button.

Conductor Conductor joints are normally presented to the derrick floor whilst horizontally suspended from a crane with a two-point lifting sling, and then picked up by a purpose built full-strength elevator (e.g. a MACK elevator) either under the shoulder of a coupling, or under pre-installed pad eyes. Short conductor strings (depending on their weight) can be picked up by lifting slings suspended from the travelling block or hook, attached to a pair of pre-installed lifting pad eyes (welds to be checked for cracks).

Marine riser Marine riser joints are normally presented to the derrick floor while horizontally suspended from a crane with a two-point lifting sling, and then picked up by a full-strength elevator latched around a lifting sub (or nipple) which is part of the marine riser running tool. When handling the telescoping joint, ensure it is locked in the closed position.

6.1.4

Rigging up and running casing

Running casing safely is very much a team effort. High levels of awareness and communication are essential if the operation is to be carried out smoothly. Hold a pre-shift safety meeting to ensure that all personnel are aware of the operation to be carried out and of their duties. Do not compromise on safety. During the early stages of running, allow the team to get into the swing of the operation before increasing the pace. Points to be highlighted at the safety meeting are: • awareness - be aware of what is happening around you. Look out for yourself and other crew members • communication - know your own job and that of others. If unsure, ask. Do not let dangerous situations develop, tell the Driller immediately • do not block the Driller's view - the Driller must be able to see everything that is happening on the drill floor and in particular the joint in the V-door • be careful where you stand - do not allow yourself to be trapped and crushed if the joint swings free. Select a position that allows an escape route

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HSE Manual EP 95-0210 Drilling • familiarise crews with the operation of any new tools.

Preparation • Ensure there is an adequate weather window to complete the job. • Ensure that slings and shackles are compatible and of a similar rating. • Secure shackle pins with wire. • Never use a transit strop for any purpose other than securing the load in transit. • When rigged up, take the time to double check lifting equipment. If in doubt, ask.

6.1.5

Making up or laying down tubulars, e.g. drill collars

The crew should be briefed on all aspects of the job, i.e. the intended method, the lifting equipment to be used and the duties of the individual crew members. Below are listed some basic safety points to bear in mind when carrying out this operation. Check the SWL of each sling. The SWL shall never be exceeded. The approximate weight of various sizes of drill collars (DCs) are given below for guidance. Size

Weight for 1 joint (9 m or 30 ft)

6.25"

1.25 tons

8.25"

2.5 tons

9.5"

3.5 tons

Allow for the angle of the wire when estimating the load. Note that when lifting or laying down DCs to or from the end of the catwalk using the deck winch and the V-door winch, the load on the V-door winch increases by approximately half as much again due to the angle of the wire. An 8.25" collar weighing approximately 2.5 tons, pulled to the end of the catwalk and suspended just above the catwalk will be exerting a load of approximately 3.75 tons on the V-door winch wire. Lifting caps shall be in good condition and hammered up tight. Lifting lugs on handling subs are for lifting the subs themselves and not for lifting tubulars. If the use of two winches or a crane with a winch cannot be avoided, clear communications between all parties involved is essential. Do not stand on the catwalk or the V-door stairs when tubulars are moving up or going down from the drill floor. Do not allow yourself to be trapped if the pipe breaks free; always have an escape route. When using the winch ensure the winch wire is spooled onto the drum properly. This will prevent the wire from being crushed and avoid shock loads when improperly spooled wire jumps free.

6.1.6

Elevators and slips

The elevator is a major cause of injuries on drilling rigs. They can be generally classified as follows: • caught between elevator and pipe

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6 Operations • caught in the closing mechanism • caught between elevator and other object • overstrain. Elevators should be maintained in accordance with 'Specification for Drilling and Production Hoisting Equipment (Ref. 28) and 'Hoisting Tool Inspection and Maintenance Procedures' (Ref. 30). Latches, latch springs, hinge pins and elevator shoulder should be inspected before use. Jarring with the elevator is potentially dangerous. Jarring should be carried out using the kelly. If possible, after removing the kelly spinner. Following any prolonged jarring operation, an inspection of the hoisting equipment shall be carried out. Manufacturers of top drive systems have documented procedures governing such inspections. Use the correct size and type of elevator for the items being handled. For drill pipe use only drill pipe elevators For picking up casing and tubing use single joint casing/tubing elevators. Never lower the first or subsequent joints in the hole with a single joint elevator.

6.1.7

Drill floor operations

Tongs A high proportion of accidents on the drill floor involve the use of tongs. Injuries result from being caught between tongs and being struck by swinging tongs. All tongs should be securely attached and anchored. Tong safety lines should be of sufficient length, preferably allowing a 90° breakout angle between the lines, but short enough to prevent over rotation of the tongs. The tong jaws including the dies should be inspected regularly for size and condition. Tongs shall be maintained and replaced well before they become worn to the point of being unsafe. Hinge pins should be secured by a nut which should itself be locked in place by a device such as a split pin. All tong counter balances and parts thereof shall be so restrained, guarded, or located as to prevent them falling or striking crew members if the suspension line breaks. Remember that suspension lines are classified as lifting devices and should be inspected, certified and colour coded in the same manner as slings. Their history should be recorded in the sling register. While changing tong/slip dies ensure that: • goggles are worn as hammer blows can cause splinters to develop • gloves are used • working area is clear and unaffected by other operations in progress. Back-up post failure has potentially serious consequences. A systematic approach to back-up post inspection and planned preventive maintenance is required which includes MPI inspections on a six monthly basis. They should also be included in the weekly/monthly drilling equipment inspection check list.

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Tripping Ensure that the crew is up to strength and individuals are aware of tasks to be carried out. A communication system should be operational between rig floor and monkey board. Note the following: • before starting a trip, ensure that the equipment required is in a serviceable condition • avoid using the rotary table to spin out pipes. Use a pipe spinner • never make up a connection with rotary table while using a tong as back-up, the shock loading could result in breaking of the back-up wire • never attempt to stab a single into the mouse hole when the Driller is lowering the travelling block • ensure the crown safety device is correctly installed and adjusted at the start of each tour and following drilling line slipping or cutting operations • monitoring of mud levels, flow checks and use of the trip tank should be part of the routine tripping procedures in and out of the hole • do not install wipers until, the Driller is satisfied with the hole condition. they act as obstructions to the visual checking of mud levels • while pipes are being moved from or to the rig floor the catwalk should be kept free of personnel • when hole conditions allow, pump a heavy pill to avoid pulling 'wet' pipe.

Make-up and break-out of assemblies Drill collars and other assembly components should be made-up at low speed. Chain tongs can be used for initial make-up, though hydraulic tongs or an iron roughneck should be considered to improve rig floor safety. Power tongs (hydraulic or air) should be equipped with a safety relief valve with a pressure setting not higher than the manufacturer's specification. Spinning chain shall never be used. Make-up torque values should be checked in the Driller's Handbook to ensure that only the correct torque loading is applied, taking into account the correct friction factor. The make-up sensators shall be maintained in good working order and final torque should be applied with a 900 angle between the tong arm and the make-up line. Crew members shall never stand behind tongs when assemblies or tubulars are made up or broken out. Once the strain is taken on the tongs when making or breaking a connection, the clutch shall not be engaged fully until the floor crew are at a safe distance from the tongs.

Working torque in a string Particular care should always be taken when applying torque or releasing it from the string. Keep the forces involved fully under control and keep the crew out of the potentially dangerous area. During back-off operations, slips are often used to transmit the required back-off torque. It is mandatory that slips are properly secured with a wire sling to prevent them from being thrown out of the rotary if the drill string jumps during this operation. Use the kelly or top drive whenever possible. Where height above the tool joint prevents the operation of the kelly through the rotary table, consider an initial blind back-off such that the kelly or top drive can be installed prior to attempting further releasing operations. Consider severing drill collars (at the stress relieving recess in the pin) as an alternative to backing them off.

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6 Operations

6.2

Handling of Chemicals and Gas Cylinders

6.2.1

Handling of harmful chemicals

Personnel required to handle or use hazardous chemicals shall be instructed regarding their safe handling, use and disposal. Personnel shall be made aware of the potential hazards and the required protective equipment. Hazardous chemicals shall be segregated from benign chemicals, and from each other as appropriate (e.g. fire hazards). The hazards should be indicated by signs posted on or near them. Attention shall be paid to the provision of adequate data on chemicals used in mud logging and mud engineering applications. All hazardous substances shall be stored in proper containers and properly labelled in languages understood by all on the rig site. The rig medic shall hold copies of all Material Specification Data Sheets (MSDS) and the clinic shall be equipped to neutralise the effects of skin contamination, swallowing or inhalation of harmful chemicals. Rubber gloves, goggles, protective apron or other protective equipment shall be worn as appropriate when handling chemicals that may irritate, be injurious to the skin, or harmful if ingested. In view of the similarity of atapulgite salt water gel to asbestos, the use of this mud additive is not permitted. Solid free or low solid completion brines such as zinc bromide, calcium bromide, calcium chloride, etc shall be handled with extreme care and only under supervision, as these chemicals may burn skin and damage eyes. Skin/barrier creams shall be used by personnel who actually come into contact with muds and brines. Prolonged use of coveralls contaminated with oil based muds should be avoided. Slicker suits shall be used for zinc and calcium bromide brines, in addition to goggles and gloves.

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6.2.2

Storing and handling of gas cylinders

Gases most commonly used in drilling operations are: Table 6.1

Gases used in drilling operations

Gas

Bottle colour

Valve thread

Oxygen

Black

R-hand

Acetylene

Maroon

L-hand

Hydrogen

Red

L-hand

Nitrogen

Grey + black top

R-hand

Air

Grey

R-hand

Valve outlets • Combustible gas cylinders are screwed left-hand (anti-clockwise to close) and non-combustible gas cylinders are screwed right-hand (clockwise to close) • Never open a valve more than three revolutions. One full turn is usually enough.

Transporting of gas cylinders • Never roll a cylinder. • Always shut the main cylinder valve before moving a cylinder on a trolley. • Do not use magnets or chain slings for lifting. A purpose-built basket, skid or container, subjected to lifting equipment certification and inspection requirements, shall be used.

Storage of gas cylinders • Cylinders should ideally be stored in the open, protected from sun and rain, and be raised off the ground. • Store cylinders upright if possible, and chained/roped in position. • Always store acetylene and propane upright to avoid the possibility of the gas in liquid form being discharged into the delivery hose. • Set cylinders in racks so that every bottle can be reached. Rotate stock. (first in - first out). • Keep cylinders away from electrical welding tools and sources of heat. • Other than cylinders in use, segregate oxygen from acetylene and other combustible gases by a distance of at least 7 m. • Do not use compressed gas stores for other products. • Know the regulations concerning storage of liquids and liquefied petroleum gases in area of operation. • Never oil or grease any part of cylinders or fittings. Keep cylinder and valves clean and dry.

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6 Operations

Using gas cylinders When there is any doubt about the quality control standards of gas suppliers the contents of bottles shall be checked before use. It is not unknown for combustible gases to be supplied in bottles colour coded for non-combustible gases. This applies particularly to the use of nitrogen to charge high pressure systems (e.g. pulsation dampeners). Portable analysers are available which indicate any Oxygen contamination. Failure to verify the purity of nitrogen has resulted in explosion and fatality. Oxygen shall never be used to fill, drive or purge any system.

6.3

Crane Operations

6.3.1

Safe operating principles

• Cranes shall only be operated by fully trained personnel who are authorised to use the equipment • Cranes shall only be operated when safety systems and instrumentation are in good working order and not inhibited • Crane drivers shall only be assisted by personnel who have received instruction as banksmen • The banksman shall check the security of loads and the slinging before signalling to the crane driver to commence the lift • Only the banksman is allowed to give hand or radio signals to the crane driver • The banksman shall always remain in sight of the crane driver and the load • Tag lines shall be attached to any load being moved on a semi-submersible, drillship and onto or off of a supply vessel. Tag lines shall also be attached to any load over 1 tonne weight and to any long loads such as bundles of drill pipe or casing. It is important to ensure that tag lines do not become caught • Due account shall be taken of weather conditions before making any lift especially heavy lifts or loads with a large sail area such as steel sheets • Crane operations shall cease and the boom shall be laid down when necessary to prevent obstruction to helicopters.

6.3.2

Heavy lifts

No specific weight is given as the threshold for what is considered a heavy lift. It is more a matter of considering what hazards exist and the potential consequences. Movement of the BOP stack on a production platform, for example, presents the hazard of damage to, and loss of containment of, wellhead, flowlines, pipework and vessels under pressure. Similar hazards exist when raising and lowering masts on land. The risk can be reduced by closing in the relevant wells and depressuring the lines and vessels. The operation of carrying out a heavy lift requires a work permit which will stipulate the appropriate precautions to be taken.

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6.4

Pressure Testing

6.4.1

General

• Ascertain the maximum working pressure rating of the weakest section to be tested, this determines the maximum test pressure which can be applied. Where possible avoid changes of specification (spec. breaks) in a connected system. Where spec. breaks occur in a closed system, appropriately set pressure relief devices shall be incorporated. • Pressure relief or limiting devices on the pump shall be verified as operational, at the appropriate pressure before the test begins. • Visually inspect all equipment to be tested prior to testing. • Cordon off work area, post 'DANGER' notices (if applicable). • Announce testing is to take place over the public address system (if applicable). • Never attempt to tighten, slacken or hammer any item under pressure. • All hose connections shall have a back-up jump chain or sling secured across them to restrain the hose in event of connection failure. • Chiksan runs shall be avoided where possible and otherwise properly secured. • All non-essential personnel shall be evacuated from the vicinity of equipment to be tested. • The potential energy level of compressed fluids shall be minimised by purging air/gases from the system. Also the volume to be tested should be kept to a practical minimum. Cup-type testers should be suspended from drilled-out plug-type testers. If for any reason the test tool is suspended on drill pipe, the tensile load applied shall be within its load rating. Prior to applying test pressures, ensure that no dummy components (e.g. thread protectors, corrosion caps) are still installed on the equipment. All wellhead connections, valves and fittings subject to pressures above 13,800 kPa (2000 psi) shall be flanged, clamped or welded. Though screwed line pipe is covered by an API code up to 34,500 kPa (5000 psi), past experienced of failures due to corrosion, fatigue and other factors, has resulted in the Group recommendation that they should not be used in applications above 13,800 kPa (2000 psi).

6.5

Hydrogen Sulphide (H2S)

6.5.1

General

During drilling and workover operations the consequences of leaks or kicks with sour gas or crude can be very serious. Personnel can be incapacitated by relatively low concentrations of H2S in a very short time and equipment can suffer catastrophic failure due to H2S embrittlement. Available literature should be studied before drawing up H2S procedures. Recommended references are: • 'Guidelines for Detection and Control of Hydrogen Sulphide During Drilling Operations' (Ref. 31) • 'Hydrogen Sulphide' (Ref. 32)

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6 Operations • 'Safe Drilling of Wells Containing Hydrogen Sulphide' (Ref. 33) • 'Contingency Plan for Drilling Sour Oil and/or Gas Wells' (Ref. 34) The video 'The Silent Sniper', available through SIEP, provides a powerful H2S awareness aid when training personnel.

6.5.2

Planning for H2S

A contingency plan shall be drawn up when H2S may be expected during well operations. The contingency plan should include: • procedures for the following conditions, including responsibilities and duties of personnel – pre-alarm condition – moderate danger to life – extreme danger to life. • designation of briefing areas • evacuation plan • authorities to be notified in case of emergency, by whom and at what stage • a list of emergency medical facilities including locations and/or addresses and telephone numbers. A study should be made of the geological and geographical features of the area, in order to predict the expected areas where H2S may be encountered or may accumulate. Information about the area and known field conditions, including temperatures, pressures, proposed well depth and H2S concentrations, should be obtained and taken into consideration. The drilling programme shall highlight this hazard and give details of controls and recovery measures in place. A mud programme should be drawn up which will cater for the pressures expected to be encountered, but should also include the use of an H2S scavenger and/or inhibitor to reduce the reaction of H2S on the drill string and related equipment. In the pre-spud meeting, the Company Drilling Supervisor should review the drilling programme with the drilling contractor and service contractors, outlining each party's responsibilities. All personnel shall be fully trained in the use of H2S-related equipment. Procedures should be in place 350 m above and/or one week prior to the anticipated encountering of a hydrogen sulphide zone. Be aware that H2S can arise from stagnant mud (sulphate reducing bacteria) and may be found in little used tanks and in casing annuli.

6.5.3

Equipment

Blowout preventer (BOP) equipment Blowout preventer equipment selected for H2S wells, including ancillary items such as the choke manifold, shall be of chemical composition, heat treatment, hardness and trim which complies with current metallurgical specifications defined by 'Blowout Prevention Equipment Systems for Drilling Wells' (Ref. 35). Kill and choke hoses shall be of a type suitable for this kind of service.

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Flange, bonnet cover, bolting and nut material Each of these intended for H2S use should meet requirements prescribed in 'Valves and Wellhead Equipment' (Ref. 36).

Vacuum degassers/atmospheric mud-gas separator (poor boy separator) The vacuum degasser should be capable of effectively removing gases containing H2S from the drilling fluid. The vent outlet on the vacuum degasser shall be extended so that the extracted gas can be routed to a remote area for flaring or connected into the atmospheric mud-gas separator line. A mud-gas separator used to extract gas containing H2S from drilling fluids should be tied into a vent line for burning, so as not to release the gas into the atmosphere close to the rig. This requires that the line terminates away from the rig and not at the top of the mast. Vent lines shall be sized so that the back pressure they impose upon the separator vessel does not cause the mud leg to be evacuated at designed operating conditions. Note that H2S is denser than air and if not flared will still pose a hazard in low lying areas. Experience has shown that weighted drilling fluids heavily contaminated with H2S cannot be successfully treated. Disposal of such contaminated fluids in suitable ventilated locations with appropriate hazard warnings is therefore required.

Flare lines Flare lines should be installed from the degasser, choke manifold, and mud-gas separator according to 'Safe Drilling of Wells Containing Hydrogen Sulphide' (Ref. 33). All flare lines should be equipped with the means for constant or automatic ignition.

Drill pipe Lower grades of drill pipe, or pipe made from steel with anti-corrosive properties, should be used in order to minimise hydrogen embrittlement of sulphide stress cracking. Means to minimise hydrogen embrittlement and sulphide stress cracking or drill pipe can also be found in 'Safe Drilling of Wells Containing Hydrogen Sulphide' (Ref. 33)

6.5.4

Monitoring

Each drilling facility shall have a fixed H2S monitoring and detection system that activates audible and visual warning alarms at a level of 10 ppm H2S in the air. It is recommended that this system should have emergency battery power back-up, capable of keeping the system operational for 12 hours without recharging. H2S detection heads require regular calibration to retain their accuracy. The equipment manufacturers instructions should be known and followed. Calibration checks shall be logged.

Fixed H2S monitoring systems Fixed systems shall have a central readout panel located in an area where it will be constantly monitored. Required locations for sensor heads: • bell nipple and/or diverter opening

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6 Operations • Driller's console • mud tanks • shale shaker • ventilation system of living quarters • wellhead cellar Suggested additional locations offshore: • lower hull pump or ballast room entered by hatchways located on main deck • mud pump room • barge engine room • poorly ventilated areas where personnel work.

Portable gas detection instruments Frequent inspections of all poorly ventilated areas should be made with a portable gas detection instrument. This instrument should be capable of reading a minimum of 10 ppm of H2S. Detection devices should be available for use by all personnel on site. Such devices shall be regularly checked and calibrated to provide a clear audible alarm at a level of 10 ppm in air. At least one portable instrument should be available for the detection of SO2. For equipment selection, refer to 'Guidelines for Detection and Control of Hydrogen Sulphide During Drilling Operations' (Ref. 31).

6.5.5

Alarm systems (H2S detection)

In order for rig personnel to act once H2S is encountered, warning devices shall be present at various stations on the drilling rig. The meaning of each warning signal shall be made known to all personnel on or around the work location. The audible warning should be a yelping-type electronic siren, in order to establish a universal H2S warning system, and be connected to the fixed H2S sensing system. Amber warning lights should be of a rotating or flashing type. All warning devices located in hazardous zones shall be appropriately rated. Because of potential language barriers and the possibility of misunderstanding by drilling crew personnel, everyone shall be trained and conditioned to react to the audible and visual alarm system. Personnel designated as 'essential' should move to assigned stations or job functions after having put on their breathing apparatus. Non-essential personnel shall, at the first warning, move to the pre-designated briefing areas after having put on their breathing apparatus. Warning lights on offshore rigs/platforms should be shielded from the outboard view so as not to be confused with navigational aids and lights.

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HSE Manual EP 95-0210 Drilling Location of H2S warning alarms, audible and visual: • Driller's console (audible and light) • engine room (audible and light) • mud room (audible) • living quarters (audible at each level) • central area of each structural level (audible and light) • control room.

6.5.6

Personal protective equipment

All personnel on a drilling location where H2S is anticipated shall have available to them a certified breathing apparatus. Individuals on site who are designated as essential personnel, if gas is detected, shall be provided with an apparatus that supplies air at positive pressure into a full face mask. Practicality will normally dictate the installation of a cascade system in these circumstances, as this will ensure the availability of a continuous source of breathable air. Personnel shall always have access to a portable supply of air, however, to cater for the eventuality that escape is necessary. The use of chemical cartridge respirators is prohibited for service in H2S environments in drilling operations. Refer to 'Hydrogen Sulphide' (Ref. 32) for further information. The storage locations of all protective breathing apparatus shall be such that the equipment can be quickly donned and is readily available to all personnel on and around the rig. Locations for breathing apparatus should include: • rig floor • derrick monkey boards • mud logging unit • shale shaker unit • pump rooms (mud and cement) • crew quarters • Toolpusher's and Company Drilling Supervisor's office • each designated briefing area • heliport • standby vessels.

6.5.7

Additional safety equipment

The following items should be available on the rig: • chalkboards and note pads or other communication aids • bullhorns • resuscitators

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6 Operations • wind indicators • bug blowers • hazard warning signs • first-aid kit • stretcher • blankets • eyewash station.

6.5.8

Well control

Tripping Every effort should be made to pull a dry drill string. If it is necessary to pull the string wet after penetration of H2S - bearing zones, increased monitoring of the working area should be provided and protective breathing apparatus should be on standby and if necessary worn. Breathing apparatus should be worn by personnel in the working area prior to circulating bottoms-up in case H2S is indicated in sufficient quantities to require the use of breathing apparatus.

Coring operations in H2S-bearing zones Breathing apparatus should be worn from 10 to 20 stands in advance of retrieving the core barrel and especially while the cores are being removed from the barrel. Cores to be transported should be sealed and marked indicating the presence of H2S. During the above operations, warning signs indicating 'DANGER - POISON GAS' shall be displayed in languages understood by all personnel on the rig. On land rigs, flags at the location entrance gate are to be used to indicate that a hazardous situation exists.

6.5.9

Personnel training

It is usual for a specialised contractor to be employed to install both a fixed (cascade) system and provide portable breathing apparatus. The same contractor, particularly on a land rig where the drilling contractor may not have a rig system installed, will also provide detection equipment. Maintenance, training and certification of personnel should be included in the package. Where mud logging services are contracted, H2S detection equipment should be specified in the contract. When drilling in an area where hydrogen sulphide gas might be encountered, training specific to the H2S hazard in the area shall be carried out. The following guidelines are recommended for the training of personnel. The H2S training programme shall be developed prior to the commencement of drilling operations and should include: • a new employee/visitor H2S induction training programme to be presented to all personnel arriving on site for the first time

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HSE Manual EP 95-0210 Drilling • general information and physiological response to H2S and SO2 exposure • the use of self contained breathing apparatus and emergency escape equipment • procedures for operating conditions: – pre-alarm condition – moderate danger to life – extreme danger to life • responsibilities and duties of personnel for each operating condition • search and rescue procedures with designated staff • briefing areas, or locations for assembly of personnel during extreme danger condition, should be designated. At least two briefing areas shall be established on each drilling facility. Of these two areas, the one upwind at any given time is the safe briefing area • evacuation plan • agencies to be notified in case of an emergency • a list of medical personnel and facilities, including addresses and telephone numbers.

6.5.10 H2S drills The contractor shall have a comprehensive H2S drill procedure in place which shall be agreed and practised prior to commencement of operations. After training is completed, drills for H2S emergency conditions shall be carried out once each week or more often if conditions warrant. Records will be kept of drills and personnel that participated. The purpose of the drill is to rehearse emergency response procedures and verify that all personnel on site know their duties according to the plan.

6.5.11 Personnel Physical examinations All employees who are to work on a well site, which may expose them to H2S, should receive a physical examination. This examination should address conditions associated with respiratory problems and hypertension. Any individual with facial hair (beard) that could interfere with a complete mask seal is not permitted to work in an H2S environment as equipment leakage could prove fatal.

Dentures Personnel wearing dentures, while working in an H2S atmosphere, should be advised that they are to be worn at all times while they are exposed to the hazard, including rest periods. Dentures should only be removed for cleaning purposes. If dentures are removed from the mouth, the face takes on a different configuration, and it is possible that breathing apparatus will no longer fit. This could prove fatal.

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6 Operations

6.6

Occupational Health and Safety

6.6.1

Housekeeping

A high standard of housekeeping is a necessary prerequisite for any drilling operation. The accumulation of rubbish should be prevented as it presents, fire, health and access hazards. The work area shall be kept free of obstructions to allow free movement of personnel and machinery. In particular the rig floor should be kept clean of any equipment which is not in use unless it is required for safety reasons (e.g. the inside BOP assembly). Stairways, ladders, ramps, walkways and platforms shall be kept free of objects or substances which may create a tripping or slipping hazard or hinder or prevent emergency egress of personnel, or access to emergency equipment.

6.6.2

Noise control

The Group have issued the publications 'Noise Guide' (Ref. 37) and 'Management Guidelines for Hearing Conservation' (Ref. 38). These contain recommendations for the implementation of a hearing conservation programme designed to suit the wide variety of Company activities world-wide. They provide guidelines and recommendations concerning protection and preventative measures to avoid permanent hearing loss from exposure to noise. The acceptable noise dose limit of 85 dB(A) is applicable for shift lengths of eight hours/day or more, 40 hours/week, or in case of occasional overtime work, provided the exposure time over one year does not exceed a total of 2000 hours. Local legislation may demand a lower limit in some areas. Levels in accommodation used for off-duty activities shall not exceed 70 dB(A). However, this level of noise can interfere with mental concentration and certainly with sleep. It is therefore recommended that noise levels in sleeping areas are below 45 dB(A). In practice, control of noise and the requirement for hearing protection can only be effective if a noise map of the worksite is prepared with all machinery running under normal operational load. From such a map, areas of noise over 85 dB(A) can be identified. Areas less frequently used, such as the cementing unit also need to be mapped. Once identified, high noise levels can be addressed in three ways listed in order of preference: • the use of better engineered equipment • the use of noise reduction techniques (sound insulation, mufflers, etc) • the use of hearing protection. Signs indicating noise hazards shall be posted and appropriate hearing protection equipment shall be freely available for all personnel working in the high noise area.

6.6.3

Contractors' occupational health

The following is guidance from Group Health Advisers for specifying to contractors the requirements of an occupational health programme. Details on specifics are available through HSE/2 in The Hague, often in the form of Shell Safety and Health Committee (SHC) documents. A complete list of HSE documents available is printed on the inside back cover of all such documents. Contractors should have an occupational health programme in place in accordance with legal requirements and Shell Company guidelines. Companies should ensure that the contractors' occupational health

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HSE Manual EP 95-0210 Drilling programmes are managed in a way that is compatible with Company standards by specifying these requirements in contractual arrangements and by regular monitoring and auditing the contractors' performance regarding occupational health. In general, contractors should apply the same principles as are contained in Shell's Occupational Health Management Guidelines with emphasis being given to the following aspects: • identification of all health hazards (covering health hazards at work, and those associated with life style and the environment • assessment of risk to health to determine the need for and type of control measures (e.g. engineering controls, work procedures, use of personal protective equipment, vaccination programmes and employee assistance programmes) • planning and implementation of control measures and preparation of in-house guidance on procedures, practices and programmes • informing, instructing and training of the workforce • health surveillance • record keeping • first-aid and medical emergency response procedures. Specific aspects to be addressed normally include: • infectious diseases (including tropical diseases) • dermatitis • general hygiene (food storage and preparation, potable water, sanitary facilities, accommodation) • noise and vibration • ionising radiation • ergonomics • lighting • life-style factors (e.g. use of alcohol and drugs, smoking). Each drilling contractor should appoint an occupational health focal point with the task to co-ordinate the implementation of the occupational health programme. Appropriate records should be held in order to be able to monitor the performance of the occupational health programme and to identify problem areas requiring more attention. Sufficient resources (expert advisers, facilities and budgets) shall be available to ensure that the implementation of the occupational health programme meets legal and Company standards.

6.7

Permit-to-work

The permit-to-work is a written document authorising persons to carry out a specific task, warning them of the possible dangers and spelling out precautions needed for the job to be done safely. It ensures that proper consideration is given to the risks and that they are dealt with prior to work commencing. The objectives are: • to ensure the proper authorisation of non-routine or hazardous work • to make clear to the person(s) carrying out the job the risks involved and precautions to be taken • to ensure that the person responsible for an area of the installation is aware of all work being done there

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6 Operations • to provide a record showing that the method of work and the precautions needed have been checked by the appropriate competent person. EP 95-0315 Guidelines on Permit to Work Systems provides recommendations on implementing a permitto-work system. All personnel shall have a good understanding of the permit system which should define: • the types of work requiring permits • documented procedure covering the permit system • clear definition of authority levels for permit issue and authorisation • checking of workplace conditions by the competent party • centralised holding and control of live permits • permit close-out system • permit handover mechanism • mechanism for checking effects of changed conditions on permit validity The permit-to-work is authorised by the senior person on site after he has assured himself that all necessary precautions have been taken and that all those working in the area on other duties are aware of the activity. Where simultaneous production and drilling operations are taking place the Company Drilling Supervisor shall be a signatory to the permit. Permits shall be revalidated at the beginning of each shift.

6.8

Environmental Hazards

Group policy is to reduce, and ultimately to eliminate, emissions of substances which are harmful to the environment. The greatest impact drilling operations have on the environment relates to the discharge of mud and drilled cuttings. As part of the effort to minimise this impact extensive research is ongoing to find viable alternatives to oil based mud systems. Documents addressing environmental subjects include: • 'Environmental Management Guidelines' (Ref. 39) • 'EP Environmental Assessment Guide' (Ref. 40) • 'E&P Waste Management Guidelines' (Ref. 41) • 'Making the Most of Drilling Waste Management' (Ref. 6) • 'Environmental Auditing Guide' (Ref. 42)

6.8.1

Noise

When working in the vicinity of housing or other areas sensitive to noise levels below the threshold where hearing damage occurs, extra precautions will be necessary to reduce it to levels at which it ceases to be a significant nuisance. These levels will vary depending on location. The rig contracting strategy should include an assessment of the planned programme of work with respect to the environmental issues and define such things as noise limitations in the tender documents. Noise maps of rigs being bid should be requested.

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6.8.2

Environmental auditing

The 'Environmental Auditing Guide' (Ref. 42) sets out the necessary steps for carrying out an environmental audit, namely: • the preliminary collection of basic data about the site of operations and the operation itself • inspections and interviews at the site to extend, evaluate and verify information obtained • formulation of conclusions and recommendations.

6.8.3

Waste management

General aspects of waste management are described in 'E&P Waste Management Guidelines' (Ref. 41). 'Making the Most of Drilling Waste Management' (Ref. 6) has been prepared specifically to address drilling wastes, focusing on business issues associated with waste and the implementation of new techniques and technologies in waste management. A structured waste management strategy is important from a cost standpoint and for environmental protection. The elements of such a strategy are: • Reduction of waste through good operating practices, changes in technology and changes in products • Reuse by returning the material to the process in its original form • Recycling material for resource recovery or as a by-product • Recover by incineration and making use of the energy developed • Residue is the final resulting waste material which cannot be managed by any of the previous four methods and is either used as landfill, incinerated, diluted or concentrated, or stabilised physically, chemically or biologically. The strategy can be applied to drilling operations to deal more effectively with waste. The above referenced document (Ref. 6), which contains many recommended practices on drilling waste management should be used by the Company as a planning tool to develop an effective programme suited to the operation.

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7 Associated Activities

7

ASSOCIATED ACTIVITIES

7.1

Electric Wireline Operations

7.1.1

Responsibilities

The senior person on site, generally the drilling contractor Toolpusher on land rigs or OIM on offshore rigs, retains overall responsibility for all site activities. He shall be provided with an inventory of all explosives and radioactive sources on site, which shall be updated whenever changes take place. With respect to radioactive sources, he shall also be provided with storage details, which includes a diagram indicating the rate of radioactive emissions at the edge of the container and the distances, in all directions, at which the rate of emissions are measured at 1 micro-sievert/hr and 2.5 micro-sieverts/hr. See 7.1.10 for further details. Throughout wireline logging activity the Driller on shift remains responsible for overall safety on the rig floor and for maintaining primary pressure control over the well. Continuous monitoring of well fluid gains or losses during logging operations is his prime responsibility. Non-essential equipment such as bits, bottom hole assembly components, lifting plugs, etc shall be cleared from the drill floor area. Rotary tongs are to be secured away from the rotary area and cover plates are to be installed over the single hole, rotary bushings and any other open spaces. The rig floor is to be cleaned of mud, grease or other extraneous material. The Logging Engineer is responsible for ensuring that all wireline operations are performed to the technical and safety standards laid down by legislation, his employer and the Operator. He shall inform the senior person on site and the contract holder of any precautions that need to be taken to assure safe operations and of any eventuality which impacts upon safe operations.

7.1.2

Rigging up

When the Driller is entirely satisfied that the well is stable, and that the rig floor is cleared of non-essential material and equipment, the logging contractor can commence rigging up. It is essential that there is sufficient lighting available for the logging winch man to clearly see the drill floor area. In addition a two-way intercom shall be installed to enable good communication between the logging winch operator and the operators on the rig floor. The intercom shall be certified suitable for zone 1 hazardous area use. The upper and lower sheaves, together with other equipment suspended in the derrick, shall be considered as lifting equipment and shall therefore have the safe working load clearly marked on each item. Only certified slings, chains and shackles are to be used to secure the upper or lower pulleys. If the upper pulley is to be secured on the elevators, ensure that the elevator latch closes properly and that the swivel on the travelling block is locked. A secondary safety sling should be used at all times. The lower sheave is attached to a main substructure member by chain. The chain shall be in visibly good condition, less than three years old and a minimum of 5/8" diameter with a SWL of 22,000 lb. Such chains shall be tagged to clearly show the age and rating of the chain. The chain eye should be secured to the lower sheave shackle by a single chain which is attached to a main member of the rig substructure. If the fixing point is a pad-eye, then it shall have been welded by a coded welder and certified free from any defect. The pad-eye shall also be load certified and inspected (NDT) annually.

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HSE Manual EP 95-0210 Drilling The lower sheave shall be fitted with finger and spoke protectors. When the travelling block has been raised to position, ensure the brake is securely chained down. Ensure that the logging wire does not foul the derrick.

7.1.3

Logging operations

During logging operations, the number of drilling crew permitted on the rig floor should be kept to a minimum. Neither Logging Engineers nor crew are allowed to operate any of the drill floor machinery, nor should any logging crew be on the rig floor without the presence of a drilling contractor representative. It is the Driller's responsibility to operate the drawworks, fill-up pumps and BOP controls. The Driller shall monitor the status of the well and maintain adequate fill-up on the hole at all times. Crane operations shall not be conducted over or close to the logging cable.

7.1.4

Pressure control

The pressure rating of the wireline lubricator shall always be at least equal to the maximum anticipated surface pressure, plus an excess to cover such contingencies as squeeze killing or bullheading. It shall be tested to this pressure. It shall be of sufficient length to contain the tool length and preferably have a margin of one lubricator section to cover birds nesting of the cable. A guiding principle is that the possibility of a tool string straddling both the lubricator BOP and the master valves on the Christmas tree shall be precluded. A tool catcher shall be fitted immediately above the BOP and verified as functioning correctly. It shall not be used as a lifting device.

7.1.5

Storage and working with explosives

General All operations involving the use of explosives are to be performed under the permit-to-work system. Prior to starting work, a safety meeting shall be held to include as a minimum: • Driller and assistant on shift • Senior Toolpusher/Offshore Installation Manager • Logging Engineer • Well Site Drilling Engineer • Company Drilling Supervisor Work requiring the use of explosives shall be carried out only by authorised specialist personnel (usually the Logging Engineer). During the job, personnel working in proximity of the device shall be kept to a minimum. All other persons are to be excluded from the working area throughout the operation. A register of explosives shall be kept on site by both the Logging Engineer and the Person in Charge (usually the OIM offshore and contractor Toolpusher on shore).

Explosive storage The local laws and regulations governing the storage and handling of explosives shall be observed, however in all cases, explosives and detonators shall be transported and stored in separate containers.

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7 Associated Activities On land, buildings constructed to contain explosives shall be completely separated from living and work areas and well separated from other stores containing flammable material. For more complete coverage of this subject refer to EP 95-0200 Survey Operations.

Operating with explosives The general rules which shall be observed when using explosives are: • do not smoke, strike matches or use an open flame lighter in the vicinity of explosives. Use only electric flashlights • do not leave explosives where they may be exposed to flame, heat, spark or impact • do not expose explosives to direct sunlight • do not leave explosives where unauthorised persons can access them • do not handle or store explosives in the vicinity of flammable products, compressed air bottles or welding equipment • do not fight a fire in a building or vehicle containing explosives. Keep well clear until the fire is completely out • be aware that in some types of gun pressure can be trapped internally after firing. Surface disassembly controls should take this into consideration.

7.1.6

Safety procedures in use of explosives

Electrically activated firing systems Arming and disarming of guns is to be carried out by the Logging Engineer only. A senior supervisor, knowledgeable of radio silence procedures and charged with their enforcement shall be on duty at all times during a perforating operation. The following is a guide to the safety precautions which should be taken when operating with electrically fired perforating guns, charges and other explosively activated devices such as packers. 1.

Guards and warning signs shall be placed around the working area to prevent unauthorised access to the work area by personnel and vehicles.

2.

Unless using a detonating system which is impervious to stray electrical currents, guns shall not be armed while an electrical storm is in the vicinity, or forecast, during perforating operations.

3.

The logging unit is to be grounded to the rig, the rig grounded to the wellhead by grounding straps, and the source of any AC or DC voltage, which results in stray voltages in excess of 0.25V, shall be eliminated. Such sources of voltage include: – cathodic protection – electrical welding – non-destructive testing – top drive systems – static electricity – radio transmitters including microwave transmitters.

4.

Restrictions applied when running explosives shall also be applied during retrieval operations, even when positive indications of firing have been seen.

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7.1.7

Radio transmissions

During periods of radio silence, radio transmitters shall be switched off and, where possible, isolated. Radio beacons are to be turned off. Portable two way radios shall be collected, checked against the inventory kept by the radio operator, and locked away. All other potential sources of stray electrical currents such as cathodic protection systems and electric welding operations shall be shut down. The monitoring of radio receivers should continue as normal. On land, road signs are to be placed at a minimum distance of 150 m from the location, to prevent the access of vehicles possibly using mobile transmitting equipment (e.g. taxis). If the presence of large commercial transmitters pose a hazard, the Logging Engineer shall request computation of a safe field zone prior to undertaking any work with electrically detonated explosives. Emissions from high tension lines either carried by pylons or buried can constitute a radio frequency (RF) hazard. Offshore, the control of radio silence shall be maintained to a distance of not less than 500 m. Offshore vessels shall therefore be notified in adequate time to stand off from the location. The standby boat is required to maintain station at stand-off distance and warn any approaching shipping of radio silence requirements on the installation. Two hours before each gun run the Company Drilling Supervisor or Wellsite Drilling Engineer shall communicate to the base office the estimated time of commencing 'radio silence'. Actual times are to be advised by the installation radio operator. In some areas third parties such as the coast guard and the military authorities may have to be informed. The notification procedure should cover this. Helicopter flight control will also require sufficient notice to reschedule/divert flights so that aircraft do not arrive at the installation during radio silence. Offshore, the co-ordinator for the 'radio silence' procedure shall be the OIM. The Institute of the Makers of Explosives (IME) gives recommended minimum distances between 'shot point' and 'transmitter' as indicated in Table 7.1. The table is modified to give transmitting power in watts.

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7 Associated Activities

Table 7.1

Recommended minimum distances between shot point and transmitter

Transmitter power

Minimum distance

(W)

(m)

(ft)

0-250

150

500

250-1,000

300

1,000

1,000-10,000

750

2,500

10,000-50,000

1,500

5,000

50,000-100,000

2,300

7,500

(IME Publication 20 revised March 1971)

After isolation of all sources of stray current, the casing-to-rig voltage shall be observed by the Logging Engineer in the presence of the Drilling Supervisor or the Wellsite Drilling Engineer and verified less than 0.25 V (DC or AC). In the event that the observed voltage exceeds 0.25 V, all sources of electrical supply may have to be switched off. This may preclude such operations as perforating during the hours of darkness.

Relaxation when explosives are more than 75 m below ground or seabed When the explosive device is more than 75 m below seabed (or ground level), the potential hazard to personnel is greatly reduced, and relaxations can be permitted as follows: i)

To allow helicopter operations to continue, VHF air band communication between platform and aircraft may be established using either the fixed VHF air band transmitter or a portable air band set from the helideck. In addition, a UHF communications system may be used for internal rig operations provided no more than the base station and one hand portable are operational at any one time.

ii)

The use of a single, 1-watt hand portable VHF or UHF set (not less than 10 m from the logging cable) for communication outside the platform.

iii) In an emergency, if a 1-watt hand portable radio cannot raise the assistance required, use of one fixed VHF or UHF transmitter. It is emphasised that these relaxations (i, ii and iii) are only permitted when the explosive device is more than 75 m below ground or sea bed, and only one may be applied at any one time. Explosive backing-off operations are not subject to any restrictions once the gun is 75m below ground or sea bed since detonation is unlikely and would not result in any damage to personnel or property.

7.1.8

Systems impervious to stray electrical currents

In order to avoid the necessity for complete radio silence or electrical shutdown, new methods of detonation have been developed. The systems use the energy released when a capacitor, charged to a high voltage, is discharged through a thin conductor or foil to directly initiate high order detonation of secondary explosives. The design of these detonators is very similar to conventional detonators except that no primary explosive is used. These systems require a minimum voltage of 150 to 200V DC at the cable head to operate the tool and to produce the 2500 to 3000V DC to which the capacitor will be charged. This compares with 10V AC or DC required for standard detonators and 1V for high temperature detonators, which do not contain

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HSE Manual EP 95-0210 Drilling internal safety resistors. Testing of the systems has shown them to be incapable of unintentional initiation even when exposed to powerful electrical and magnetic fields. The early reliability of these tools is less than that of conventional detonators and there is a substantial additional cost per run. It is anticipated that with time, the additional costs will fall and the reliability will improve. Their use should be considered where radio silence is difficult or expensive to achieve. It should be stressed that when introducing such systems, a high level of awareness must be maintained regarding the precautions required in the use and handling of explosives, particularly in areas where conventional systems are also used, as operating procedures may be confused.

7.1.9

Tubing Conveyed Perforating (TCP) systems

There are several suppliers of TCP systems using a variety of detonating devices. Because explosives are involved, safety precautions shall remain as detailed under 7.1.6 and 7.1.7 above. The precautions specified by the manufacturer shall be fully understood and stipulated on the permit-towork. In addition, due to the need for close operational co-operation between the TCP contractor, drilling crew and rig supervisory staff, a full safety meeting prior to the operation is essential. Various methods for firing the detonator of a TCP gun have been developed to enable reliable firing of guns in wells with differing geometry, mechanical configuration, and borehole conditions. These can be grouped into four main types, which are: • drop bar actuated systems, in which a metal bar is dropped from surface and free falls under gravity to mechanically initiate the firing head • hydraulically fired systems, in which fluid pressure is applied from surface to tubing or annulus to fire the gun • electrically actuated systems, in which the current is sent from the surface via an electrical cable to fire the gun • electrically actuated systems, in which a detonator and shaped charge are lowered from surface on wireline to fire the gun. When planning a completion which includes a TCP gun the following safety aspects should be considered: 1.

The firing head should only be armed when the gun is in place below the rotary table. This often means a considerable extension above the explosive charge and may not be practicable.

2.

During assembly and arming of the gun all personnel shall be cleared from the area beneath the rotary table, around the riser and BOP stack. Warning signs shall be posted at all accessible deck levels to ensure that no personnel approach the wellhead area. No one is allowed to work above drill floor level. The above restrictions can be relaxed when the entire gun is below ground (or sea bed) level.

3.

There should be no possibility of the drop bar hanging up in any of the tubulars prior to detonation. Provision shall always be made for retrieval of the drop bar in case of doubt.

4.

TCP guns shall never be pulled to surface without first retrieving the detonating device (drop bar or battery pack).

5.

If it is not possible to verify that the TCP gun has fired and the firing head cannot be disarmed by retrieval as in 3), then there shall be provision for dropping the gun. Only disarmed guns are allowed to be pulled to surface.

6.

If the provisions for either dropping the gun or safe disarming of the gun cannot be met, then proper consideration should be given to perforating by conventional guns.

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7 Associated Activities 7.

Never trust or rely on self-deactivating TCP systems. They are intended to provide extra safety. Full precautions should be taken if a TCP gun has to be pulled.

7.1.10

Storage and use of radioactive sources

The storage, transport and use of radioactive source materials used for logging operations is governed by local regulations enforced by appropriate legislation. The basic rules to be applied when using ionising radiation are given in Publications Nos. 26 and 60 of the International Commission on Radiological Protection (ICRP). The Group publication 'Ionising Radiation Safety Guide' (Ref. 43) uses the recommendations of the ICRP as the main source of guidance. In essence personnel, other than those classified as radiological workers and subjected to special monitoring precautions, shall not be exposed to radioactive emissions in excess of 2.5 micro-sieverts/hr. Barriers shall be erected to prevent access to areas where this rate of emissions is exceeded, and the areas where the rate of emissions falls between 1 and 2.5 micro-sieverts/hr shall be designated as no stay and marked accordingly. All radioactive logging sources are housed in dedicated carrying shields. Carrying shields are to be clearly marked with the Transport Index (TI) number. Where dedicated transport containers are in use, the transport container shall be labelled with a TI equal to the sum of the source TIs contained therein. Upon arrival of radioactive source materials at the rig site, the source materials in their carrying shields shall be immediately transferred from the transport container to the logging contractor's source store. This task is only to be done by specifically authorised personnel, e.g. the Logging Engineer on site. In the absence of such authorised personnel, the transport container shall be placed in a segregated area away from personnel and chain barriers erected at a distance around the container determined by the Transport Index (TI) marked on the external surface of the transport container. Allowance shall be made for a possible requirement for barriers above and below the container where there are working or living areas in proximity to the storage area. Table 7.2

Approximate barrier distance from source container

Transport Index

Segregated Distance (m)

(TI - mrem/hr at 1m)

2.5mµv/hr

1

2.0

3

3.5

5

4.5

10

6.3

15

7.7

20

8.9

25

10.0

Note: Typical full complement of sources (density, neutron, calibration, etc)

The radiation dose rate at the periphery of the segregated area shall be less than 2.5 micro-sieverts per hour and where practically possible below 1.0 micro-sieverts per hour.

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HSE Manual EP 95-0210 Drilling Given the space limitations at offshore locations, the segregated areas may be difficult to achieve for transport containers. When this is the case, an authorised person shall be available to transfer sources into a suitable protected store upon receipt. A register of radioactive sources shall be kept on the rig to record: • Full details of all sources on site • Transport record of the source • Destination of dispatched sources. The register shall be kept by the Logging Engineer and the most senior person on site. The Logging Engineer is responsible for the supervision of all work involving ionising radiation. He shall ensure that exposure to such radiation is kept to a level which is as low as reasonably achievable. In addition the Engineer will check that all logging contractor personnel working near source materials wear both gamma and neutron personal dosimeters that are valid for the period of work involving ionising radiation. In any segregated or classified work area, with instantaneous dose rates in excess of 2.5 microsieverts per hour, the Logging Engineer will ensure that only authorised personnel are allowed in the area and then only within the framework of a written system of work procedures. Carrying shields are only to be removed from the designated store area under the direct instruction of the Logging Engineer. The carrying shields shall be transported to and from the designated store area by the shortest possible route and the route shall be kept away from rig personnel as far as possible. Moving of source materials is to be covered by a permit-to-work. Before handling any radioactive source the Logging Engineer shall ensure that all possible open floor areas are securely covered. In the working area the Logging Engineer shall ensure that adequate notices displaying the trefoil (three-leaf) symbol are in place. Access points are to be chained off to establish a controlled work area. The controlled work area shall be defined as where exposure of more than 2.5 micro-Sieverts per hour exists, albeit temporarily. The Driller's doghouse is exempt from the 'controlled work area' status for the reason of maintaining full surveillance on the well. However, during handling of the source by the Logging Engineer, the Driller should keep well clear of the radioactive source - the distance to be advised by the Logging Engineer. The Logging Engineer is the only person authorised to remove sources from their carrying shields. The Engineer shall endeavour to keep collimated (directional) sources pointing away from personnel on the rig. The transfer of sources between carrying shields and logging tool shall be completed in the shortest possible time.

7.1.11 Fishing A logging tool fishing operation is never routine. It is essential, therefore, that a pre-job safety meeting is held prior to embarking on a fishing job so that all involved are fully aware of the potential hazards of the operation. The prime objective of a fishing operation is the safe and complete recovery of the downhole tool. Good communication between the Company Drilling Supervisor, Well Site Drilling Engineer, Toolpusher, Logging Engineer, Driller and wireline winch operator is of utmost importance. Once a logging tool is stuck or lost in the hole decisions concerning fishing operations shall be agreed by the Company, not just the logging company and the drilling contractor. The logging company provides advice on how the tool might best be recovered and should be able to furnish the fishing tools required for

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7 Associated Activities the job. For stuck tools, the preferred fishing technique is the reverse cut and thread method. Breaking the weak point, prior to the logging tool being latched into the fishing overshot, shall never be the method used for fishing operations involving radioactive sources. To break the weak point, the cable clamp and travelling block shall be used. Never use the logging contractor's winch (the upper sheave becomes a high stress point and the cable is likely to break around the sheave). When attempting to fish a tool containing a radioactive source be it either wireline run or LWD, it is important to monitor mud returns to detect any possible increase in radioactivity. Detailed information on radiation safety can be found in 'Radiation Safety Manual for Well Logging Operations' (Ref. 44) as well as the previously referenced 'Ionising Radiation Safety Guide' (Ref. 43).

7.2

Well Testing

7.2.1

General

All equipment used in well testing shall be fully certified for the purpose intended. The document 'Area Classification Code for Petroleum Installations' (Ref. 23) shall be used to define hazardous zone requirements. The appropriate authorities shall be notified prior to any production testing, especially where it is performed near populated areas. The requirement for such notification is often defined by government legislation. After perforation, the opening of the well to unload the tubing contents and the initial flow through the separator shall be carried out in daylight. Thereafter the production test may continue during hours of darkness. Burners of the type that minimise oil drop out should be utilised. Noise should be monitored and hearing defenders issued as necessary (see 6.6.2 for further information). The production test (onshore/offshore) shall only be commenced under the following conditions: • all test facilities are fully pressure tested and checked • fire, H2S and abandon location drills are held • adequate weather window forecast • shipping and aircraft warned to stand clear during flaring • standby boat advised that this operation is to take place, and the action and precautions necessary until the operation is completed • verify that the wellhead and production valve ESD systems function correctly and that emergency shutdown activating buttons are manned in a safe area throughout the test whilst flowing formation fluids to surface • check that all Weco type hammer unions are properly matched and according to agreed standardised type. • a pre-job safety meeting has been held to discuss the test and ensure all personnel are aware of their responsibilities and any restrictions imposed.

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HSE Manual EP 95-0210 Drilling All hot work shall cease during the production test. Cranes shall not be used over or near wirelines, flowlines, separators, heater or choke manifold. Personnel not directly involved with the operation shall stay well clear of production lines. When methanol is used as an agent to prevent/dissolve hydrates, a supply of salt should be kept close by to spread on any spillage. This will produce a visible flame should the methanol be ignited. Cooling water hoses shall be laid out on the flare side. In the event that the ambient temperature drops significantly below zero, and icing problems are observed to be occurring as a result of the cooling spray, testing operations should be terminated, possibly being restarted using brine as a cooling fluid. Glycol/water mixture and low freezing point hydraulic fluids should be used in all critical lines/ systems. Aviation fuel tanks and all pressurised bottles shall be located away from radiant heat and cooled, if required. Lines from steam generators shall be clearly marked and guarded to prevent burning injuries. A close check shall be kept on the casing/tubing annulus pressure. If this pressure increases it should be bled off (noting the volume and type of fluid bled off) and the annulus pressure checked for the rate of build-up. If the annulus pressure cannot be bled off the well shall be squeeze killed or reverse killed, depending on circumstances. Gas explosion meters, hydrogen sulphide detectors and sets of breathing apparatus shall be available. Gas shall be checked for the presence of hydrogen sulphide. Contingency plans in the event of significant H2S production shall be in place. Equipment and material to fight oil spills should be available on site in the areas where such spills could give rise to a hazardous situation or have detrimental environmental effects. After production testing all lines containing oil shall be flushed with water, brine or mud prior to disconnecting. An independent air supply, not connected to the rig air system, shall be used to ensure that this system is not contaminated with hydrocarbons. Do not interconnect air/oil/gas lines. Refer to the document 'Guidelines for Production Testing of Wells up to 103,000 kPa (15,000 psi) Using Temporary Equipment' (Ref. 45). for detailed procedures and information. Volume 6 of the Production Handbook 'Production Operations' (Ref. 46) also contains useful information.

7.2.2

Fracturing

The equipment up to the last wellhead valve should be hydraulically tested to a pressure above the expected fracturing pressure. This pressure shall not exceed the safe working pressure of the weakest component in the system. A check valve or other device shall be installed in the system to prevent backflow should a leak in the system occur. All piping, including vent lines, shall be adequately anchored. They should not transmit hydraulic vibrations to the wellhead. Firefighting equipment shall be placed at strategic locations and be easily accessible. Receiving vessels for relief or bleed-off lines from the wellhead or pumping equipment shall have adequate venting.

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7 Associated Activities If crude is to be used as fracturing liquid it should be weathered for at least 24 hours to eliminate the more volatile components. A pre-job safety meeting shall be held to appraise personnel of their responsibilities and any restrictions that may be imposed.

7.2.3

Acidising

Hydrochloric and other acids used for stimulating production from a well are corrosive and rapidly affect skin, causing severe burns. Breathing of the fumes shall be avoided as even small quantities can damage mucous membranes. Personnel handling acid shall be equipped with protective clothing including respirator, goggles, gloves and boots. An adequate supply of water and lime should be available to neutralise any acid spillage or contact with skin. Acid inhibitors are toxic. It is essential to obtain full HSE information before execution of any acid job. Lines from the pumping unit to the wellhead shall have a non-return valve installed in them as near to the wellhead as practicable. A pressure test of not less than the maximum expected treating pressure shall be made on the discharge lines to the wellhead. Personnel not directly involved in the operation shall stay well clear of the discharge lines during the pressure test and acid pumping operations. Pump operators should remain alert for communications from the Toolpusher or Company Drilling Supervisor throughout the acidisation. All equipment through which acid is handled shall be thoroughly washed inside and outside with water upon completion of the operation. A 'hose down' team should be on standby properly kitted out to deal with any spillage. A pre-job HSE meeting shall be held and the job performed under permit-to-work system controls.

7.2.4

Cryogenic operations

Liquid nitrogen Liquid nitrogen is hazardous because of its low temperature (- 195°C) and because it can displace air in gas form and cause suffocation. Contact of human tissue with severe cold will destroy tissue in a manner similar to high temperature burns. Freeze burns will result from contact with the cold surfaces of piping and equipment containing liquid nitrogen. Eye damage caused by liquid nitrogen is usually permanent. Wearing full eye protection is essential. An increasing dimension of hazard is added when liquid nitrogen is under pressure. These facts emphasise the need for protective clothing and a high standard of safety by the nitrogen operatives. The following protective clothing should be used: • face shield • insulated gloves • long sleeve shirts

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HSE Manual EP 95-0210 Drilling • cuffless trousers (worn outside boots). Avoid skin contact (as liquid nitrogen causes immediate damage) from: • liquid leaking from equipment • cold equipment surface. Allowing liquid nitrogen to be spilt on carbon steel or structures is dangerous as carbon steel becomes brittle at approximately -40°C. Whenever such a spillage has occurred the area should be checked for cracks.

Liquid nitrogen pumping Basic rule: keep suction pressure as high as possible above suction vapour pressure. Boiling occurs when the saturation vapour pressure equals the line pressure. Therefore the line pressure must be maintained at as high a level above the saturation pressure as possible.

Materials for cryogenic service Most construction materials are adversely affected by extreme low temperatures. It is imperative that components engineered for use in cryogenic service be chosen from suitable approved materials, e.g.: • copper and its alloys • stainless steels • aluminium • high nickel content steels.

Non-cryogenic materials These will become critically brittle if subjected to exposure to very low temperatures. They include: • carbon steel • low alloy steels • most rubbers • most plastics. Liquid nitrogen containers shall be fitted with a safety relief valve set at the safe working pressure (SWP) of the container, and a bursting disk which fails at 1.33 times the SWP. In addition a manually operated valve shall be available to vent the unit if necessary.

Liquid air hazard Ambient air condenses on the cold surfaces of liquid nitrogen piping systems. As the boiling point of nitrogen is lower than the boiling point of oxygen, liquid air can result in puddles containing approximately 52 per cent oxygen. This oxygen enriched air may cause normally non-combustible materials to become flammable and normally flammable material to burn at an increased rate. It is therefore necessary to ensure that no potentially combustible materials are left around liquid nitrogen equipment. Tidy housekeeping is mandatory for a safe operation.

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Oxygen deficiency Whilst using nitrogen, there is always the possibility that gaseous nitrogen dilutes the oxygen around the area of operation. Operators shall brief all personnel of the potential hazards of oxygen starvation. Table 7.3

Symptoms of oxygen deficiency

Percentage oxygen at 1 atm

Symptoms of O2 deficiency

12-14

Respiration deeper, pulse faster, co-ordination poor

10-12

Giddiness, poor judgement, lips blue

8-10

Nausea, vomiting, unconsciousness, ashen face

6-8

8 min, 100% die; 6 min, 50% die and 50% recover with treatment 4-5 minutes, all recover with treatment

4

Coma in 40 seconds, convulsions, respiration ceases, death

A slight oxygen deficiency results in deeper respiration, faster pulse and poor co-ordination. As oxygen deficiency increases, judgement deteriorates quickly, so that the importance of moving to a well ventilated area may not be understood. Also note that one full breath of pure nitrogen will strip blood of necessary oxygen resulting in a loss of consciousness.

7.3

Coiled Tubing Operations

The use of coiled tubing (CT) for a wide range of applications in drilling, completion, workover and well treatment operations is established as an economic means of operating to save rig time or to operate without a rig in situ. It is a rapidly developing area of the business and it is important for users to stay abreast of changing methods, techniques and controls as technological improvements widen the scope of applications. The company providing coiled tubing services shall be fully involved in the planning of operations and verify that the CT unit to be used is suitable for the application planned and that the operational procedures provide a level of control that assures the safe conduct of the operation. A number of hazards associated with CT operations have been identified. Any operations with CT in a potentially live well shall be treated in the same way as any conventional well control requirement along with its associated BOP equipment. Any CT operation with other adjacent wells producing shall be treated as a concurrent operation and subject to concurrent operational restraints and safety precautions. CT fishing operations shall be detailed in a clear CT programme specific to the application and site conditions. Every CT unit shall maintain and have available for inspection a full 'Reel Utilisation Data Sheet', which includes the following historic data: • type of work done • depths run • number of cycles (tubing passed through gooseneck)

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HSE Manual EP 95-0210 Drilling • welds. All welding carried out on CT shall be fully documented giving details of subsequent X-ray results and Rockwell hardness tests. Complete and detailed procedure are required for CT welding. A full toolbox meeting shall be held prior to each CT operation identifying responsibilities, channels of communication and emergency response in case of equipment failure or local alarm. Any non-routine repair work to coiled tubing during operations shall be covered by a permit-to-work, with potential hazards identified before work starts. Particular care should be taken when working on systems where there is relative movement between the injector head and the rig. The incorporation of a mechanical locking device on the main CT reel is recommended so that undesirable reel movement can be positively prevented in the event of power failure. During CT operations, non-essential personnel shall be kept well clear of the CT and unit. It should be pointed out to all personnel working in the area that CT can fail causing potential sprays of high pressure acid if the tubing busts or unpredictable whiplash movement if the tubing parts at surface. This is a particular hazard during fishing operations. Surface facilities, BOPs, lines and Xmas tree shall be tested to at least the maximum anticipated operating pressure prior to commencing operations.

7.4

Concurrent Operations

7.4.1

General

Concurrent operations are defined as the simultaneous execution of two or more risk activities which, due to their interaction, result in an increased operational complexity and enhanced level of risk. Any combination of the risk activities is considered to increase the probability of incurring risk consequences when carried out concurrently. Such activities would include the following: • production • construction • maintenance • drilling • workover • well testing • well services • diving • heavy lifts • transport operations. This subject is summarised below but prior to any concurrent operations being undertaken, reference shall be made to the local concurrent operations manual. Where no manual exists, SIEP can assist in one's development, generally by supplying examples from other Opcos. While this process is ongoing, specific controls shall be agreed by relevant supervisors at co-ordination meetings and approved by department heads.

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7 Associated Activities The advice given in this sub-paragraph is particularly aimed at operations involving an independent rig working alongside a production platform. Some general observations are: • all supervisors involved in concurrent operations should meet daily to identify and resolve any potential overlap of operations and responsibilities • a fundamental rule for concurrent operations is to classify all operations as either hazardous or nonhazardous and only allow one hazardous operation to occur at any one time • single point responsibility is essential. All supervisors controlling operations shall report and liaise through the single point • the person in charge of concurrent operations shall be trained/competent to be able to make sound decisions • management inspections should be carried out jointly by platform and rig based supervisors • plan directional drilling logically.(high angle wells from outer slots) to minimise collision risks and make well paths uncomplicated • have a well-defined cone of uncertainty and a resulting well shut-in policy.

7.4.2

Procedures

Clear written instructions and plans are required in order to limit the extra risk associated with concurrent activities. An operations plan shall be prepared for each location where concurrent operations are to take place stating the conditions to be met and procedures to be followed. This plan shall cover at least the following areas: • a narrative description of all operations • individual duties and responsibilities • arrangement and location of equipment • integration of alarm and emergency systems between rig and platform • integration of mustering system between rig and platform • routing of all pipelines and their service • integration of hazardous zone delineations • periodic special testing and drills of safety systems and devices • conditions for securing and restarting of activities • communication procedures and reporting lines • escape routes • contingency plan • dissemination of information to all involved parties • on-site containment, rescue and evacuation training • an activities matrix determining permitted, conditional and prohibited concurrent activities.

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7.4.3

Supervision

Principle Concurrent operations necessitate optimum co-ordination of activities and defined lines of responsibility to ensure operational efficiency and the safeguarding of personnel and equipment. To this end, the OIM, or person in charge, shall chair a daily, minuted co-ordination meeting attended by all on-site department heads and others necessary for the effective conduct of the meeting. The meeting should cover the planned operations for the day, any hazards which may arise out of the individual operations or their concurrency with other operations, and permits or other requirements necessary for their safe management.

Overall supervision Single point responsibility for management of the location where concurrent operations are being carried out shall be maintained at all times. The responsible person will be the Offshore Installation Manager (OIM) or his equivalent in an onshore facility. Each individual activity shall be supervised by a competent supervisor, who has the responsibility to verify that the activity is adequately protected by a minimum of two barriers with proven integrity. He is also responsible for reporting status, and change of status, to the single point co-ordinator.

Communication Regular meetings should take place between the supervisors to discuss HSE issues and the planned work programme. Changes from a previously agreed programme shall be highlighted and adequately discussed with all involved parties.

Permits-to-work All concurrent activities other than routine production, drilling, maintenance or construction operations shall be rigorously controlled by the use of work permits signed by supervisors of the individual activities and the supervisor/manager responsible for the overall operation.

Control of personnel movement The movement of personnel between drilling rig and platform shall be strictly controlled. At no time shall there be more people on the rig or the platform than life saving equipment exists for or certification allows for. Procedures for the mustering of, or accounting for, personnel on the two locations shall be in place, well known and practised. Escape routes to and from the rig shall be clearly indicated. Personnel arriving at the installation shall be provided with any required personal protective equipment for transit from the arrival point to the accommodation and report immediately to the OIM or his nominated deputy.

7.4.4

Specific requirements

Specific requirements shall be detailed in the local concurrent operation manual and should be used in conjunction with any local statutory requirements to produce the written plan for each case.

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7 Associated Activities

Barriers Each individual activity is protected by barriers (protection mechanisms) which would have to fail before control is lost. Operations may proceed if each individual activity is protected by a minimum of two independent and tested barriers, with the provision that neither of these barriers becomes nullified by virtue of the concurrent activity. Where a barrier fails, immediate action shall be taken, within the constraints of concurrent operations, to restore two barrier integrity. The following may be considered as barriers: • drilling fluid in the hole of sufficient density to overbalance formation pressures. The drilling fluid shall be subject to continuous monitoring to qualify • a tested BOP stack • cased hole where the casing is unperforated or has not been drilled out, or where a tested cement or bridge plug is in place. For completion and workover operations the following barriers once tested may also be considered: • deepset wireline plug (below production packer) • drilling or completion fluid in the well of sufficient density to overbalance formation pressures. The fluid shall be subject to continuous monitoring to qualify • Xmas tree • a two way check valve is installed in the tubing hanger and on the annulus side: • a tested packer/completion (production) packer • tested seals on the tubing hanger The safety of the drilling or workover operation may be threatened by events occurring in other concurrent activities.

Surface Controlled Sub-surface Safety Valves (SCSSV) A Surface Controlled Sub-surface Safety Valve (SCSSV) shall not be considered as a 'programmed' barrier with regard to well intervention. In cases of emergency, where other barriers cannot be installed and tested, an SCSSV may be regarded as a barrier, provided that it was in place and tested before the emergency arose. (i.e. it has a working track record). Even in this case, management consent shall be gained prior to the start of work and contingency arrangements, in case the barrier fails, shall be in place and tested.

Well interference Attention should be paid to sub-surface cones of uncertainty of adjacent wells, with travelling cylinder collision plots being produced for critical situations. The criteria for terminating as mentioned in the 'Borehole Surveying Manual' (Ref. 47) should be expanded to include consideration for: • the situation where well bore paths are converging • actual survey depths which are frequently 10-15m off bottom

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HSE Manual EP 95-0210 Drilling When the well being drilled is on a converging course with an existing production well and the criteria mentioned above apply, the production well shall be closed-in and equipped with an inflow tested downhole plug located below the packer. Conductor driving operations also require special attention which shall include monitoring the conductor path and closing-in wells within the cone of uncertainty.

Rig moving operations When moving a rig or tender on or off the platform and while positioning same at the platform, it may be necessary to cease and secure all other activities if an unacceptable risk exists to the platform or personnel. A pre-move meeting attended by drilling, production and marine staff shall be held to plan the move and assess the risks. An effective well handover procedure shall be in place which details the status of wells and other production facilities on the platform. See 4.4.5 for additional information.

Well testing using temporary facilities Well testing activities using temporary facilities are not permitted concurrently with any activities except routine production and maintenance. No hot work permits shall be issued for the immediate vicinity while these activities are in progress.

7.4.5

Wireline activities (slickline and electric logging)

The surface integrity for completion and production wireline operation is assured by the following barriers: • the lubricator/stuffing box/BOP assembly • the Xmas tree with a remote-controlled upper master valve with wireline cutting capability (or an actuated valve installed on top of the tree). Normally the wireline retrievable SCSSV will be pulled (or when using a tubing retrievable sub-surface safety valve ( TRSSV) it will be hydraulically maintained open) during wireline operations, so that a downhole barrier will not be available. For this reason wireline work in live wells requires special attention. Wireline work may have to be interrupted and well made safe to allow other critical work to progress. The appropriate operating procedures and equipment shall be used as mentioned in 'Well Services Guidance Manual'(Ref. 48). Selected safety precautions from the referenced manual (chapter 8) are given here to emphasise their importance: • A wireline blowout preventer shall be used for work on all wells capable of flow • Control of the SCSSV and surface safety valve shall be transferred to a remote panel operated by the wireline crew during wireline operations • Where possible, when depressuring lubricators, gas should be vented through existing facilities • Depressurisation of a lubricator shall be confirmed by opening the second 1/2 inch connection in the lower section of the lubricator to check that hydrate blockage of the primary depressurisation needle has not occurred • After installation on the wellhead, the lubricator shall be pressurised and tested according to procedures.

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7 Associated Activities During concurrent operations the work shall be discussed at the daily co-ordination meeting and appropriate controls put in place to assure its safe conduct. The same guidelines as listed above are valid for non-rig assisted logging work.

7.5

Wireline Operations (Slickline)

Wireline (slickline) operations may be conducted through the rotary table for a number of purposes. During any wireline operations the Driller on shift is responsible for the overall safety on the rig floor and for maintaining primary pressure control over the well. When a Christmas tree is installed, the wireline operator shall use wireline blowout preventers and a lubricator. Pressure integrity shall be confirmed prior to running tools in the hole. Operational safety procedures are similar to electric logging operations, see 7.1.

7.6

Diving/ROV Operations

Diving work is undertaken less frequently than in the past as many of the tasks which required human intervention are carried out by remotely operated vehicles (ROVs). Where diving is undertaken the requirements of the document 'Underwater Handbook - Diving' (Ref. 49) shall be followed. The Diving Supervisor shall be kept fully informed of all on-going work. His advice on matters involving the health and safety of divers shall be followed. The following guidelines are taken from the document 'Diving Operations Management Guidelines' (Ref. 50): • seek to minimise the need for exposure of personnel to hyperbaric (i.e. raised pressure/underwater) environments • contract all diving work as a service • invite bids only from those diving contractors with a good record of capability, health and safety in all aspects of diving • apply as a minimum contractual standard the UK legislation for diving operations (and require contractors to adopt the guidance, recommendations and instructions contained in the UK Health and Safety Executive Diving Safety Memoranda) as the underwater service industry consensus of the 'state of the art' for diving operations • require contractors to utilise underwater service industry accepted techniques to monitor and protect the health of divers. In this context 'monitor' means to record both the time/depth exposure of divers and any chemical and physical factors which may be hazardous to health • inspect/audit the personnel, equipment, procedures and controls against contract conditions • require contractors to demonstrate proper functioning of critical systems • require all diving operations to be carried out under appropriate Work Permit procedures.

7.6.1

Special precautions

• The diving system should be set up on the rig clear of any drilling equipment but still close enough for the bell to be within ready access to the subsea equipment for diver convenience and safety. • Notices shall be posted on the rig when diving is in progress and everyone made aware that nothing will be put or dropped into the water when divers are in the water.

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7.6.2

Restrictions

No diving operations shall be carried out during the following operations: • top hole drilling • during total losses or dump flooding the well from the sea bed • well control activity, well under pressure • pressure testing sub-surface equipment (floating drilling operations) • during heavy lifting • loading/offloading supply boats • emergency alarm status, e.g. H2S or fire • seismic recording in the vicinity, particularly if using explosives. When the dive is carried out, the following operations shall cease: • movement of equipment outboard • use of thrusters, except on DP vessels • ballasting or de-ballasting • dumping of mud • sea suctions shall be isolated as required, though the firefighting system should not be incapacitated The standby vessel shall be informed that diving is being carried out.

7.7

Standby Vessels

Offshore rigs should have a standby vessel in attendance at all times. In some areas of operations this is mandatory. If, for any reason, it is decided not to provide the service, this shall only be done after a documented risk assessment has been carried out to consider the implications, and any necessary changes to standards and procedures have been made. In some areas, rules and regulations govern the construction, survey and operation of standby vessels. Typical are the documents 'Assessment of the Suitability of Standby Vessels Attending Offshore Installations' (Ref. 51). and 'Offshore Installation (Emergency Procedures) Regulations 1976' (Ref. 52).

7.7.1

General requirements

Standby vessels shall at all times be not more than 20 minutes steaming distance from the installation it is supporting. The vessel shall be classified as capable of carrying the total number of personnel on the installation and shall be equipped to provide first-aid treatment. Fast rescue craft shall be kept on board the standby vessel, which shall be immediately available for launching to rescue personnel.

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7 Associated Activities

7.7.2

Duties

The main duties are: • to rescue personnel who have fallen into or deliberately entered the sea to escape from the installation • to assist in the evacuation of the installation and accommodate rescued personnel • to provide first aid to survivors • to monitor the safety zone of 500 m around the installation and to warn vessels to stay outside this zone • to maintain close observation of personnel working over the side of the rig • to provide radio communications with rescue facilities in an emergency situation. In lieu of legislative requirements in some areas, the following details some other standby vessel requirements: The Master of the standby vessel shall ensure that: • the vessel is under power with at least one engine running 24 hours a day and the other on standby for immediate start • the vessel is at no time further than 20 minutes steaming from the rig on one engine • a 24 hour radio and visual watch of the rig is maintained at all times. In case of poor visibility, vessel and rig shall closely monitor each other's position and the position of other shipping on the radar • the vessel proceeds immediately to the area of an emergency, as indicated by the rig. The rig will indicate by radio/horn/signal and give full details of the emergency as quickly as possible • on arrival or departure of the helicopter, the vessel is to be within 500 m upwind of the rig, clear of the flight path of the helicopter and with both engines running • the vessel observes for and reports to the rig any gas bubbling during top hole drilling • the vessel reports to the rig any oil/pollution slick observed, regardless of its source • the vessel monitors for and collects any floating debris (e.g. logs, plastics, etc) which is sighted within the 500 metre exclusion zone, thus protecting the rig's DP system from damage (as applicable) • in conjunction with the rig, the vessel regularly performs emergency drills of all types • the fast rescue boat engine is run at least once per week and the boat is launched and tested (weather permitting) The Master of the vessel shall also ensure the following: • the prohibition of alcohol/drugs/weapons • leaving the location is permitted only after the prior permission of the rig's OIM • vessel is moved immediately upwind of the rig in the event that an H2S alarm is given • regular checks are made of the vessel's portable radio sets and life support equipment to ensure that these are maintained in full working condition at all times • no waste is dumped overboard.

7.7.3

Responsibilities

The standby vessel shall be under the authority of the senior person on the installation (the contractor's Senior Toolpusher or Offshore Installation Manager).

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HSE Manual EP 95-0210 Drilling If the standby vessel is contracted by the Company, the Company Drilling Supervisor on the installation is required to ensure that contractual obligations are fulfilled. Regular 'man overboard' drills shall be performed and logged. These drills shall not be conducted when weather conditions present unacceptable hazards to standby vessel personnel. Likewise, routine work on the rig, which requires the support of the standby vessel shall not be undertaken if conditions are such that attempts to rescue a man overboard place the lives of would be rescuers in jeopardy.

7.8

Helicopter Operations

Helicopters will generally be used as the principle means of transporting personnel between rig and shore in an offshore operation. Regulations governing the use of helicopters are contained in Shell Aircraft Ltd Manual (Ref. 53).

7.8.1

Training

All personnel travelling by helicopter to and from an offshore installation are required to be briefed on safety procedures prior to boarding the aircraft. The drilling contractor is required to train and properly equip helideck firefighting crews, one of whom shall be present at every landing and take off. Additionally a Helicopter Landing Officer (HLO) shall be appointed and appropriately trained. In addition certain rig crew shall be trained in helicopter marshalling for the handling of slung loads, and where appropriate, in refuelling procedures.

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APPENDIX I POLICIES Figure I.1

Policy guidelines on health, safety and the environment

It is the policy of Shell companies to conduct their activities in such a way as to take foremost account of the health and safety of their employees and of other persons, and to give proper regard to the conservation of the environment. They aim to be among the leaders in their respective industries in these matters. Health Shell companies seek to conduct their activities in such a way as to avoid harm to the health of their employees and others, and to promote, as appropriate, the health of their employees. Safety Shell companies work on the principle that all injuries should be prevented and actively promote amongst all those associated with their activities the high standards of safety consciousness and discipline that this principle demands. Environment Shell companies: •

pursue in their operations progressive reductions of emissions, effluents and discharges of waste materials that are known to have a negative impact on the environment, with the ultimate aim of eliminating them

•

aim to provide products and services supported with practical advice which, when used in accordance with this advice, will not cause injury or undue effect on the environment

•

promote protection of environments which may be affected by the development of their activities and seek continuous improvement in efficiency of use of natural resources and energy.

Common HSE aspects Shell companies: •

assess health, safety and environmental aspects before entering into new activities and reassess them in case of significant change in circumstances

•

require contractors working on their behalf to apply health, safety and environmental standards fully compatible with their own

•

recognise the concerns of shareholders, employees and society on health, safety and environmental matters, provide them with relevant information and discuss with them related Company policies and practices

•

develop and maintain contingency procedures, in co-operation with authorities and emergency services, in order to minimise harm from any accidents

•

work with government and others in the development of improved regulations and industry standards which relate to health, safety and environmental matters

•

conduct or support research towards the improvement of health, safety and environmental aspects of their products, processes and operations

•

facilitate the transfer to others, freely or on a commercial basis, of know-how developed by Shell companies in these fields.

Endorsed by the Committee of Managing Directors - June 1991.

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Appendix I Policies Figure I.2

Policy on substance abuse

Definition Substance is defined as any substance which chemically modifies the body's function resulting in psychological or behavioural change. In this context substance includes but is not limited to alcohol, intoxicating products and medication. Substance abuse is the use of these substances in a harmful or improper way. Background The Company conducts its business against high standards of safety and concern for the environment. In all areas of activity it pursues the reduction of risk to both. Also, the Company is committed to maintaining a healthy and productive workplace. All employees are expected to share in these objectives. The abuse of substances in any quantity however small can impair performance at work, and can be a serious threat to safety and environment, health and productivity. The Company wishes to ensure that all employees recognise this threat and aims at minimising the risks involved. In order to achieve this, the following policy will apply and will be part of the employee's conditions of employment. Policy 1.

2. 3. 4. 5.

6. 7.

8.

The Company recognises alcohol or drugs dependence as a treatable condition. Employees who have an alcohol or drugs dependence are encouraged to seek medical advice, and to follow appropriate treatment promptly. The Company will assist an employee to obtain treatment and employees who seek such help will not place employment in jeopardy by doing so, although alternative work might be considered. The normal Company benefits which apply in the case of any illness will be available. Being at work while impaired by drugs or alcohol is strictly prohibited. The illicit use of legal substances or the use, possession, distribution or sale of illegal substances on Company business or locations is strictly prohibited. Preceding employment, the Company will test for substance abuse. The Company may conduct unannounced searches for drugs and alcohol or any other substance on Company locations. It may also require employees to submit to alcohol and drugs testing where a good faith reason exists to suspect alcohol or drug abuse. Unannounced, periodic or random testing will be conducted when an employee meets any one of the following conditions: – holds a safety and environmentally sensitive position – holds a dedicated management position – holds a position where testing is required by law – holds a position where the individual acts alone or unsupervised. If a test result is positive, in most cases, on a first time basis only, the employee will be allowed to continue in employment provided there is compliance with the appropriate rehabilitation procedures (e.g. education, counselling, treatment and unannounced testing). Dismissal will normally occur in the following circumstances: – failure to co-operate with the implementation of this policy – failure to comply with the appropriate rehabilitation procedures – the use, possession, distribution or sale of illegal drugs or substances on Company business or locations – the use or possession of alcohol on Company business or locations unless previously authorised, and the use or possession of alcohol in safety or environmentally sensitive positions – a second positive test result following a prior positive result from a Company initiated test where employment has been continued, or after an earlier identification of an abuse problem. All contractors are required to ensure that their employees do not create a presence of substance abuse on Company business or locations. In addition, contractors who perform safety or environmentally sensitive work are required to provide evidence of a comprehensive substance abuse policy and practices at least equivalent to those in force within the Company.

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APPENDIX II RESPONSIBILITIES OF KEY STAFF II.1

Company Operations Staff Responsibilities

II.1.1

Head of Drilling Engineering

The Head of Drilling Engineering shall be responsible for ensuring that appropriate technical and operating standards are in place and to provide cohesion, direction and consistency throughout his area of responsibility for HSE such that staff discharge their duties in a professional manner and to a consistent standard. Core activities will include: • the specification, maintenance and monitoring of policies, procedures and standards • the harmonisation of Company and contractor policies, procedures and standards to a consistent and unambiguous approach • the dissemination of technical information • the maintaining of appropriate contacts in the Shell Group and with external resources. • the provision of guidelines to his subordinate supervisors • maintaining an awareness of the professional competence of all staff and co-ordinating their development through appropriate operational exposure and training.

II.1.2

Company Drilling Supervisor

The Company Drilling Supervisor is the Company 's senior representative on site. His role with regard to HSE is to verify that the drilling contractor and service and subcontractors perform work, under their respective contracts, in a manner which assures the health and safety of staff and avoids harmful emissions to the environment. As such he should be familiar with the provisions of the various contracts and be competent to verify correct implementation. His specific responsibilities relating to HSE include: • verifying the implementation of hazards and effects management controls • making quality assurance checks on contractors inspections • taking part in accident investigations as dictated by the application of the 'Incident Potential Matrix' • participating in HSE meetings • making structured inspections of the facility in conjunction with the senior contractor representative and following up on corrective actions • verifying that well integrity is being properly maintained • verifying that effective lines of communication between the various contractors are being maintained • alerting base supervisors to any changes which have a significant negative impact on well or operational HSE • keeping themselves fully appraised of ongoing operations.

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Appendix II Responsibilities of Key Staff

II.1.3

Wellsite Drilling Engineer

The Wellsite Drilling Engineer's HSE responsibilities include observing that the following activities are performed safely and without endangering the health of personnel or damaging the environment by verifying that: • electric logging operations are conducted such that: – radioactive sources are handled in a manner that avoids non-logging contractor staff being exposed to levels of radioactive emissions above 2.5 micro-Sieverts/hr – logging contractor staff wear their film badges; – radio silence procedures are observed during pertinent operations; – hazardous areas are prohibited to non-essential staff. • radioactive sources are stored such that: – the area in which radioactive emissions exceed 2.5 micro-sieverts/hr is barriered – the area where radioactive emissions fall between 2.5 - 1.0 micro-sieverts/hr is designated as 'no stay' • the radioactive source register is kept up to date • primary and secondary explosives are stored separately either in an area protected by a deluge system or on a jettisonable platform • the explosives register is kept up to date • mud chemicals and mud testing chemicals are stored and handled in a manner that assures the safety of staff • chemical safety data sheets are posted and a copy kept by the medic

II.2

Contractor Line Staff

II.2.1

Contractor Rig Manager

The contractor Rig Manager is accountable for the following HSE matters: • liaising with the Company's Head of Drilling Engineering to assure compatibility between Company and contractor safety systems, plans and objectives • developing HSE objectives and plans to meet those objectives which derive from the contract, his company's corporate policy and the drilling programme • maintaining the rig HSE Case(s) for the rig(s)under his control • establishing the organisation and controls which ensure that all activity, including those performed by service and subcontractors, is conducted in accordance with the HSE Case • demonstrating his commitment to high HSE standards by making regular structured visits to the rig with specific HSE objectives and through providing the resources to effect recommended improvements • ensuring that staff are trained such that they develop the necessary competence to enable them to work safely and avoid damage to the environment • liaising with the Company, to select service and subcontractors who can meet the same standards as themselves and monitor their work to confirm these standards are being maintained

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II.2.2

Contractor Rig Superintendent (Senior Toolpusher)

On an offshore rig the contractor Rig Superintendent or Senior Toolpusher will often also be the OIM with responsibilities defined by legislation and/or Company policy. The contractor Rig Superintendent is responsible for the execution of all well and associated work programmes. This includes, rig moving, the drilling, completion, perforation and testing of new wells, the repair of existing wells by workover and the maintenance of the drilling facility, safety of the installation and all personnel on board. Key safety responsibilities include assurance that: • hazards are identified, assessed and controlled and plans for recovery are effectively in place • injury to personnel, assets or the environment, is prevented • the emergency/contingency plan is operable and tested and all site staff are competent to perform their assigned duties • safe working codes and practices are implemented for all operations in accordance with recognised policies, standards and procedures as agreed by the Company • prompt action is taken to rectify any deficiencies in working practices or conditions • all employees receive appropriate induction and training in all aspects of their work and observe such safety requirements as the work situation warrants • safety rules and procedures are followed and should transgressions be observed, corrective action is taken to ensure future compliance • HSE meetings are held as follows: –

weekly for all personnel with records being kept of attendees, topics discussed, action items arising, action parties responsible for close out and target date for completion

–

daily with work teams (crews) to discuss the shift work plan and any expected hazards. This should be logged, in the daily report

–

prior to non-routine operations, with all involved personnel, to ensure the job and its inherent hazards are understood, controls are in place, the tools and work practices are appropriate, relevant expertise is available and permit requirements are understood and verified as being in place.

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Appendix II Responsibilities of Key Staff • drilling and associated equipment is inspected and maintained in accordance with the inspection programme and the preventive maintenance system • all accidents causing injury to personnel or damage to equipment and all significant near misses are reported in accordance with procedures and are investigated at the appropriate level, in the appropriate depth and that remedial actions are implemented • employees use personal protective equipment as necessary • hazardous work is performed under the permit-to-work system • all relevant information is communicated between personnel at shift change.

II.2.3

Night Toolpusher

The contractor's Night Toolpusher is responsible, during his shift, for the safe execution of all well work programmes issued through the contractor's Rig Superintendent. This requires that he: • enforces the provisions of the drilling contractor's HSE policy, procedures and plan • verifies that staff under his authority are knowledgeable of their role and competent to perform it • ensures drilling equipment is maintained in a safe and operable condition • where necessary applies for work permits and verifies that their provisions are followed • ensures that all accidents and significant near misses are reported and takes part in their investigation. Disseminates findings amongst all staff in order to avoid recurrence • verifies the quality of safety inspections performed by subordinates • regularly monitors well conditions by liaising with relevant staff and ensures that proactive steps are taken to maintain primary well control • provides emergency response support, both personally and together with drilling crews, and conducts a regular programme of exercises • acts as the link between senior and junior rig supervision by attendance at both groups meetings and disseminating information as appropriate.

II.2.4

Driller

As the first line in the supervision of personnel, the Driller's prime objective is to ensure that instructions are carried out competently and therefore safely. He is to verify that crew personnel are competent to carry out their work and use safe working practices. He disseminates to his crew information on HSE and new safety procedures. Additionally he is to inform senior staff of safe working procedures suggested by his crew and other personnel. The introduction of any consequent change in procedure should be implemented under the direction of the Driller with guidance and approval from the Rig Superintendent if appropriate. The Driller is instrumental for the following: • seeing that all instructions of the contractor's Toolpusher concerning work methods and equipment are carried out • ensuring that crew members fully understand their duties when carrying out a job • taking necessary steps to correct hazardous conditions and incorrect practices and checking that protective devices are in good condition and used when needed

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HSE Manual EP 95-0210 Drilling • anticipating hazardous conditions and remove the cause of possible accidents • ensuring that crew members complete each job in an orderly way and leave no hazardous conditions behind • promptly reporting any unsafe equipment that cannot be corrected by the drilling crew • encouraging all crew members to make HSE suggestions and recognise their ability to contribute to accident prevention • assisting in the investigation of all accidents in his line of responsibility • seeing that all crew members are trained in correct operating procedures and policies. He is to make a particular effort to make new crew members HSE conscious and verify their job knowledge • training the Assistant Driller so that he can competently perform the Driller's duties when necessary • being conversant with the Company well control methods and be able to react accordingly • setting an example to the crew by observing all HSE regulations • adjusting the pace of operations to meet the competence of his crew • ensuring proper use is made of the 'Permit-to-work System' • preparing an adequate handover to ensure continuity during shift changes • holding a pre-shift safety meeting to appraise crews of planned operations.

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APPENDIX III LAND RIG MOVE PLAN This appendix details the actions to be taken at each stage in a typical land rig move.

III.1

Scouting Trip

• Measure and photo overhead lines • Survey bridges • Obtain weather information • Survey port facilities • Assess security situation • Prepare map showing: – Fuel and water supplies – Hospital/medical facilities – Overnight stopping points – Road quality – Communication facilities – Hazards through villages.

III.2

Establish Convoy Procedures

• Specify truck requirements • Number of trucks per convoy • Distance between trucks • Truck inspection procedures • Verify driver competence • Select convoy leaders • Prepare load plan/prioritise loads • Establish speed limits • Organise police/military escorts • Establish journey management procedures • Define night driving policy • Hold pre-job safety meeting • Make radio checks • Establish drugs/alcohol policy • Define contingency procedures • Define safety equipment requirements

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Appendix III Land Rig Move Plan • Define refuelling procedures.

III.3

Loading and Unloading Procedures

• Establish requirements and confirm suitability of: – Supervisors – Labour – Hardware • Hold safety meeting • Identify hazardous loads • Establish weight of loads • Establish lifting signals.

III.4

Pre-departure Checks

• Loads secure • Fuel tank full • Water available (truck and driver) • Lights and horn work • Wheel nuts tight • Tyre conditions including spare • Radios • Escorts notified • Route hazards removed • Toolbox safety talk held.

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APPENDIX IV CLASSIFICATION OF HAZARDOUS AREAS The classification of hazardous areas with respect to electrical equipment shall be in accordance with the Institute of Petroleum (IP) Area classification Code for Petroleum Installations (Ref. 23). The following is only a summary of the requirements of the Code and is provided to give a ready appreciation but should not be used as a substitute for the Code. Hazardous zones defined under the IP or any similar code should not be confused with any other type of hazardous area established, e.g. sour gas, high tension (HT) overhead no-go areas, radioactive store hazardous area.

IV.1

Grades of Flammable Gas or Vapour Release

Continuous sources are where flammable fluids (gases) are normally present or present for more than 1000 hours per year. Such atmospheres are normally present only in fixed roof tanks and at process vents. Continuous grade sources are not part of the drilling fluid circulation, wellhead or BOP system. Primary sources are those which can release flammable vapours or gases in normal operation. Primary sources include vents and active mud tanks, ditches and mud treating equipment. Particular caution in the mud-gas separator piping is necessary due to the potential of high volumes of primary gas released both through the vent pipe outlet and via the mud drain. Secondary sources are those which do not release flammable gases or vapours normally but can do so under abnormal (i.e. failure) circumstances. This includes minor and temporary containment failures such as occur from day to day, not catastrophic failure such as vessel rupture, burst pipes or blowouts.

IV.2

Classification of Hazardous Zones

The hazardous zone resulting from a continuous source will be a greater hazard than the zone resulting from a primary source, because the probability is higher than it will contain a flammable mixture. To show this, hazardous zones are classified according to the type of source of flammable vapour or gas: • the hazardous zone resulting from a continuous source is normally classified as Zone 0 • the hazardous zone resulting from a primary source is normally classified as Zone 1 • the hazardous zone resulting from a secondary source is normally classified as Zone 2. The parts of the facility which are not classified as hazardous zones can be designated non-hazardous but may still contain a flammable mixture under calamity conditions. Hazardous zone classification depends on the grade of release and the ventilation available as shown in Table IV.1: Table IV.1

Hazardous zone classification and impact of ventilation

Grades of release

Open air situation and adequately ventilated spaces with unrestricted air movement, i.e. at least 12 changes per hour

Restricted ventilation, e.g. inside modules with ventilation stopped or less than 12 changes per hour

No ventilation, e.g. inside tank

Continuous

Zone 0

Zone 0

Zone 0

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Appendix IV Classification of Hazardous Areas

Primary

Zone 1

Zone 1

Zone 0

Secondary

Zone 2

Zone 1

Zone 0

For land rigs, the open air situation is the norm, with restricted ventilation only present where the drill floor is shrouded, or inside the free space of active mud tanks, ditches and well cellar areas. There should be no Zone 0 areas on any drilling rig installation. Outside Zone 0, 1 or 2 the worksite is 'non-hazardous'.

IV.3

Hazardous Zone Dimensions

According to the IP Code (1990) for Drilling and Workover Installations (where diagrams are provided), the Zone 2 hazardous zones around the rig equipment extend to: 1.

A cylinder 7.5 m around the bell nipple extending 9 m below the wellhead deck (offshore) or to ground level. The upper extent of the Zone 2 is 7.5 m above the rig floor, extending to the top of any existing wind break around the derrick area. Only the wellhead cellar and sunken ditches within the Zone 2 are classified as Zone 1.

2.

A space around active mud tanks 3 m from the top and sides of each tank to ground level extending to 7.5 m from the sides of each tank at a height of 3 m. Inside the tank walls is Zone 1. Enclosures around the tank, unless adequately ventilated are classified as hazardous Zone 1 with Zone 2 extending 3 m from openings to the enclosure.

3.

Around the shale shaker Zone 2 extends 7.5 m above and around the exterior surface of the shaker, and Zone 1 extends 1.5 m from the outer surface . If enclosed the enclosed space shall all be classified as Zone 1, with Zone 2 areas extending 7.5 m from any openings.

4.

For any gas vent outlets, the extent of the hazardous zone is based on guidelines provided in Chapter 5 of the IP Code. If flow rates and type of effluent figures are not known the hazardous (Zone 2) should extend at least 15 m from the vent outlet in all directions.

5.

For wireline operations, the point of reference is not the bell nipple but the stuffing box with other dimensions and zone classifications the same as with drilling rigs on land and to the main deck offshore.

For the purpose of ignition protection against small releases of flammable fluids around the rig floor area, the interior of the derrick or mast structure is classified as Zone 2. All purge air, cooling air and internal combustion engine air intake shall be taken from well outside Zone 1 and 2, i.e. from a designated nonhazardous zone. Equally, all electrical equipment in the derrick shall be suitably protected. Requirements are defined in the IP Code. Cellars or pits below ground level in a Zone 2 space should be classified as Zone 1. Any enclosed premises, containing source of hazard which may give rise to a dangerous atmosphere under abnormal conditions should be classified as follows: The interior of the enclosure Zone 1; the surrounding space in open air within a 7.5 m radius from any point of egress from the premises as Zone 2. Any enclosed premises not containing a source of hazard but located in a Zone 2 space should be classified as Zone 1, unless entry of a dangerous atmosphere is prevented by, e.g. fire walls, ventilation, etc where the enclosure may be classified as a Zone 2 or even as a safe zone if the space is ventilated and over-pressurised. In naturally well-ventilated conditions (e.g. offshore) outside the limits of the derrick or mast, the vertical extent of the 'hazardous zone' above the highest source of hazard may be reduced to 3 m and extends over the whole classified area and below the source of hazard to ground level, except as described in the cases above. For full details refer to IP15 Chapter 6.

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HSE Manual EP 95-0210 Drilling It must be clearly emphasised that the dimensions and conditions quoted are to be considered as the minimum case, and where any doubt exists, the dimensions (or even classification) of the hazardous zone should be increased by appropriate degree.

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APPENDIX V OPERATION OF DIESEL ENGINES IN HAZARDOUS AREAS The following data is taken from the document' Recommendations for the Protection of Diesel Engines Operating in Hazardous Areas' (Ref. 13)

V.1

Introduction

There are considerable problems in providing assured protection to diesel engines for use in hazardous Zones 0, 1 and to a certain extent in zone 2 as defined by the document 'Electrical Safety' (Ref. 54) and by 'Code of Practice for Selection, Installation and Maintenance of Electrical Apparatus for Use in Potentially Explosive Atmospheres' (Ref. 55). The use of permanently installed diesel engines in Zone 0 is unacceptable, and the use of permanently installed diesel engines in Zones 1 and 2 should be avoided wherever possible. Note: The effectiveness of protective devices is dependent upon a high standard of maintenance and inspection of the equipment; certain items need to be checked regularly. Table V.1

Recommendations for protection of diesel engines on drilling rigs which are permanently installed in hazardous Zones 1 and 2

Nature of Hazard

Zones 1 and 2

Discharge of sparks from electrical equipment

The starter shall be of the following non-electric types: pneumatic, hydraulic, spring recoil, inertia or hand start. Any other electrical equipment associated with the engine shall be flame proof as defined in BS 4683 'Specification for electrical apparatus for explosive atmospheres', or intrinsically safe as defined in BS 1259 'Intrinsically safe electrical apparatus and circuits for use in explosive atmospheres' (see also BS 5345 Part 1: Selection, installation and maintenance of electrical apparatus for use in potentially explosive atmospheres). Electrical equipment shall be effectively earthed and bonded to the main engine frame.

Discharge of sparks from mechanical causes

Cooling fan blades shall be made from non-metallic materials.

Generation and discharge of static from belt drives

All belts shall be of antistatic fire-resistant type.

Discharge of sparks or flames from the exhaust system

A gas conditioner box and a flame trap shall be installed. Alternatively, the exhaust should be designed to discharge to a location within a 'safe' zone.

Flashback through induction system

Wherever possible, air intakes for engines shall be located in a 'safe' zone as defined by the Institute of Petroleum Electrical Safety Code. Alternatively, a flame trap should be provided (Barber valve).

Overheating due to failure of cooling water system or loss of lube oil pressure

Alarms or automatic shutdown devices shall be provided, actioned by excessive water temperature and low lube oil pressure.

Table V.1

Recommendations for protection of diesel engines on drilling rigs which are permanently installed in hazardous Zones 1 and 2 (continued)

Nature of Hazard

Zones 1 and 2

Excessive engine vibration

A system using an alarm or trip device to protect the engine from

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Appendix V Operation of Diesel Engines in Hazardous Areas

excessive vibration should be considered. Explosions in engine crankcase; discharge from crankcase and cylinder head relief valves and breathers

An engine having a crankcase volume of over 0.5 m3 shall be provided with relief devices. Relief valves, preferably of BICERI design, or breathers on engines shall be fitted with flame traps or alternatively discharge into the induction system downstream of the flame trap, if fitted, and upstream of the shut-off valve, if fitted. Dipsticks and/or filler caps should be screwed or effectively secured by other means.

Explosions in intake or exhaust systems

Intake and exhaust systems shall be designed in accordance with Appendix 3.3 of the OCMA MEC-1 document.

Flame transmission to atmosphere by opening of decompression pots

Decompression systems should not normally be provided. However, if they are essential, then the decompression ports should be provided with flame traps and ducted away to a safe zone.

Reverse running of engine

The fuel injection pump and governor where fitted should be so designed that reverse running of the engine is not possible.

Excessive temperature of exhaust gases and excessive surface temperature of engine and exhaust system

The surface temperature of the engine and exhaust system shall not exceed 250°C when tested under full load conditions. In some situations cooling of the exhaust manifold and piping may be necessary, using water jacketing or finned coolers and/or high temperature cut-outs or alarms should be provided. In this connection it should be noted that air cooled or supercharged diesel engines generally have significantly higher exhaust temperatures than water cooled engines. Conversely, engines operated below their maximum power rating will have correspondingly lower exhaust gas and surface temperatures. Given conditions of normal operation, for the majority of refinery and petrochemical flammables in the regions of natural convection surrounding the hot surfaces of diesel engines, surface temperatures of 250°C are acceptable. Exceptions are:

• when free movement of air is restricted by thermal or acoustic shielding

• when the auto-ignition temperature of the flammable, determined by ASTM test D2155-66 is below 200oC.

If either of these two conditions exists, no engine exposed surface temperature shall exceed that determined for the flammable by the ASTM test. Note: The IP Code indicates that where the principal mobile combustible fluid is known to be methane gas, then higher engine surface temperatures (e.g. 500oC) may be considered acceptable. Overspeeding of the engine due to induction of flammable gas or vapour

A means shall be provided to stop the engine when flammable gas or vapour in the atmosphere can cause the engine to overspeed.

For a complete specification, discussion and explanation of the above requirements, reference to the original document is recommended. The document 'Area Classification of Flammable Gas Atmospheres' (Ref. 56) is also used as a source to define the principles of diesel engine operation in hazardous zones.

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127

HSE Manual EP 95-0210 Drilling Fixed diesel-engine equipment shall be located outside a hazardous zone, unless adequate and effective protection to all electrics, hot surfaces, exhaust systems, etc can be achieved, in which case it may be located in Zones 1 or 2. Such protection should normally include the provision of an air source from a non-hazardous zone. However, if this is impracticable, the engine shall be fitted with an automatically operated combustion air cut-out to prevent engine runaways in the event of flammable vapour ingestion. Mobile diesel-engine equipment should preferably not be used in a hazardous zone, but if this is unavoidable it should be fully protected as for fixed diesel installations or have a minimum of protection and operate under a permit-to-work system. The minimum protection should be spark arrestors, hot surface cooling and, in addition for Zone 1, an automatic air cut-off. Note: In no case should a diesel engine be allowed to operate in Zone 0. Rigs which have been designed and equipped with diesel engine power supply to the drawworks, rotary table and mud pumps according the document 'Classification of Areas for Electrical Installation at Drilling Rigs and Production Facilities on Land and/or Marine Fixed and Mobile Platforms' (Ref. 24) do not always comply with hazardous zone restrictions as defined under the IP Code. As it is costly to retrofit diesel engines on rigs, they should, in relation to the document 'Recommendations for the Protection of Diesel Engines Operating in Hazardous Areas' (Ref. 13) preferably be selected for conformity with the IP Code.

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ABBREVIATIONS BOP CT DC DP DP EPBM ESM HEMP HP/HT H2 S HSE HSE MS LMRP LWD MODU MPI NDT OBM OIM PMS POB PPE ROV SCSSV SCR SMS SO2 SWL TCP TRSSV

130

Blowout Preventer Coiled Tubing Drill Collar Drill Pipe Dynamically Positioned Exploration and Production Business Model Enhanced Safety Management Hazards and Effects Management Process High Pressure/ High Temperature Hydrogen Sulphide Health, Safety and Environment Health, Safety and Environmental Management System Lower Marine Riser Package Logging While Drilling Mobile Offshore Drilling Unit Magnetic Particle Inspection Non-Destructive Testing Oil based Mud Offshore Installation Manager Preventive Maintenance System Personnel On Board Personal Protective Equipment Remotely Operated Vehicle Surface Controlled Sub-surface Safety Valve Silicon Controlled Rectifier Safety Management System Sulphur Dioxide Safe Working Load Tubing Conveyed Perforating Tubing Retrievable Sub-surface Safety Valve

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GLOSSARY A glossary of commonly used terms in HSE is given in both EP 95-0100 HSE Management Systems and EP 95-0300 Overview Hazards and Effects Management Process.

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REFERENCES 1

EP 92-2195, E&P Business Model, SIEP EPD/75, November 1992.

2

Report No. 6.23/173 Substance Abuse Management Strategies, E&P Forum, July 1991.

3

EP 91-0725, Guidelines for Single String Venture Drilling Operations, EPO/51, April 1991.

4

EP 88-1000, Shallow Gas Procedures Guidance Manual, EPO/515, July 1989.

5

EP 89-1500, Pressure Control Manual for Drilling and Workover Operations, EPO/515, 1989.

6

EP 93-1760, Making the Most of Drilling Waste Management, SIEP EPO/512, September 1993.

7

Shell Safety and Health Committee, Guide for Safety Performance Reporting, August 1993.

8

Management Safety Inspections, SIEP, April 1987.

9

Unsafe Act Auditing, Shell Safety Committee, June 1987.

10

Incident Investigation and Analysis Guide, Shell Safety and Health Committee, August 1993.

11

Incident Potential Matrix, Shell Safety and Health Committee, October 1991.

12

Accident Investigation, Shell Safety and Health Committee, January 1994.

13

Publication 107, Recommendations for the Protection of Diesel Engines Operating in Hazardous Areas, Engineering Equipment and Material Users Association (formerly OCMA MEC-1).

14

EP 88-0550, Marine Safety of Mobile Offshore Units, EPO/5/6 and EPD/11, March 1988.

15

EP 89-0550, Practice for the Site Specific Assessment of Jack-up Units, EPD/5, May 1989.

16

EP 90-3490, Jack-up Structure Condition Assessment and Condition Monitoring, EPD/51, November 1990.

17

SPE Paper No. 21979, SIEP Practice for Site Specific Structural Fitness for Purpose Assessment of Jack-up Rigs, SPE/IADC, 1991.

18

Technical and Research Bulletin 5-5, Society of Naval Architects and Marine Engineers (SNAME), 1993.

19

EP 93-0473, Mooring Standards for Mobile Units, EPD/53, 1993.

20

Road Safety Management, Shell Safety Committee, December 1987.

21

Seat Belts, Shell Safety and Health Committee, September 1989.

22

EP 46804, Offshore Rig Move and Anchor Handling Operations.

23

Model Code of Safe Practice, Part 15, Area Classification Code for Petroleum Installations, Institute of Petroleum, March 1990.

24

Recommended Practice 500, First Edition, Classification of Areas for Electrical Installation at Drilling Rigs and Production Facilities on Land and/or Marine Fixed and Mobile Platforms, API, June 1991.

25

Personal Protective Equipment Guide, Shell Safety and Health Committee, June 1989.

134

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References

26

Drilling Manual, Section L3, Derricks and Masts Report of Visual Field Inspection of Derrick or Mast and Substructure, IADC.

27

Specification 4E, Third Edition 1988 and Specification 4F, Third Edition 1985 Specification for Drilling and Well Servicing Structures, API.

28

Specification 8A, 12th Edition, Specification for Drilling and Production Hoisting Equipment, API, June 1992.

29

Specification 7, Rotary Drilling Equipment, API, 1990.

30

Recommended Practice 8B, Fifth Edition, Hoisting Tool Inspection and Maintenance Procedures, API, October 1992.

31

EP 53738, Guidelines for Detection and Control of Hydrogen Sulphide During Drilling Operations, EPO/51, 1981.

32

Hydrogen Sulphide, Shell Safety Committee, December 1986.

33

Recommended Practice 49, Second Edition, Safe Drilling of Wells Containing Hydrogen Sulphide, API, April 1987.

34

EP 53777, Contingency Plan for Drilling Sour Oil and/or Gas Wells, Shell Oil Company (USA), 1981.

35

Recommended Practice 53, Second Edition, Blowout Prevention Equipment Systems for Drilling Wells, API, May 1984.

36

Specification 6A, 16th Edition, Valves and Wellhead Equipment, API, 1989.

37

Noise Guide, Shell Safety and Health Committee, December 1991.

38

Management Guidelines for Hearing Conservation, Shell Safety and Health Committee, December 1991.

39

Environmental Management Guidelines, Shell Product Safety and Environmental Conservation Committee, May 1992.

40

EP 94-1980, EP Environmental Assessment Guide, November 1994.

41

Report No. 2.58/196, Exploration and Production (E&P) Waste Management Guidelines, E&P Forum, September 1993.

42

Environmental Auditing Guide, Shell Product Safety and Environmental Committee, June 1989.

43

Ionising Radiation Safety Guide, Shell Safety and Health Committee, November 1993.

44

EP 91-1645, Radiation Safety Manual for Well Logging Operations, September 1991.

45

EP 93-1300, Guidelines for Production Testing of Wells up to 15000 psi Using Temporary Equipment, EPO/53, December 1993.

46

Production Handbook Volume 6, Production Operations, EPO/53, 1991.

47

EP 59300, Borehole Surveying Manual, Volume 1, EPO/51, October 1984.

48

EP 87-1006, Well Services Guidance Manual, EPO/53, 1987.

49

EP 93-0777, Underwater Handbook - Diving, EPF/52, 1993.

50

Diving Operations Management Guidelines, Shell Safety and Health Committee, December 1991.

51

Assessment of the Suitability of Standby Vessels Attending Offshore Installations, UK

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HSE Manual EP 95-0210 Drilling Department of Transport, 1991. 52

SI 1976 No. 1542, Offshore Installation (Emergency Procedures) Regulations, HMSO London, 1976.

53

Management Guide Aircraft Operations, SAL (draft document under revision), 1994.

54

Model Code of Safe Practice, Part 1, Fifth edition, Electrical Safety, Institute of Petroleum, 1965.

55

BS 5345, Code of Practice for Selection, Installation and Maintenance of Electrical Apparatus for Use in Potentially Explosive Atmospheres, British Standards, 1989.

56

MF 80-0470, Area Classification of Flammable Gas Atmospheres, SIEP, March 1980.

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INDEX

Derricks and masts, foundations............................ .........59

A

Derricks and masts, inspection....................... ................59

Acidising................................................................ .........99

Diesels, in hazardous areas......................... ......45, 56, 126

Air......................................................................... ..........99

Diving operations.................................................... ......107

Alarm systems............................................................. ....81

Drains...................................................... .......................45

Atapulgite................................................. ......................75

Drawworks safety..................................... ......................58

Auditing........................................................... ...............31

Drill collars...................................................... .........70, 72

B

Drill pipe.................................................................. .70, 80

Barriers................................................. ................105, 106 Blowout preventer.................................................... .65, 79 BOP control system...................................................... ...67 Breathing apparatus...................................... ............57, 82

C Camp sites....................................................................... 46 Catheads......................................................................... .65 Catlines................................................................ ...........65 Certification...................................................... ..............69 Chiksan............................................................. ..............67 Coiled tubing operations...................................... .........101 Competence.................................................................. ...11 Concurrent operations.............................. .......25, 101, 102 Conductor............................................................. ...71, 106 Contract. .7, 11, 17, 20, 25, 28, 37, 48, 50, 54, 56, 83, 114 Coring operations...................................................... ......83

Derricks and masts, loading........................................ ....59

Drilling line............................................... .....................64 Drilling programme....................... .................8, 20, 48, 79 Drills........................................................... ............28, 110 Drills, H2S.................................................... ......30, 84, 97

E Electrical safety............................................................. ..57 Elevators................................ ...........62, 63, 69, 70, 72, 89 Emergency procedures............................ ..............8, 17, 28 Environmental auditing................................................. ..88 Environmental hazards.................................................... 87 Environmental protection............................................ ....31 Experience............................................... .................14, 16 Explosives..............13, 24, 44, 46, 89, 90, 91, 93, 94, 108 Explosives storage..................................... .....................90 Explosives, radio transmissions.............................. ........93

F

Corrective action.................................................... .........39

Fire drills...................................................... ..................47

Crane operations............................................... ..............77

Fire extinguishers........................................ ...................46

Cranes................................................................ .............77

Flare lines...................................................... .................80

Crown block............................................................. .......64

Food storage............................................................. .......46

Cryogenic operations...................................................... .99

Fracturing.................................................................... ....98

D

Fuel storage.................................................................. ...46

Deadline anchor................................................. .............60

G

Degassers........................................................... .............80

Gas cylinders.................................................................. .76

Derricks and masts, crown protection....................... ......60

H

Derricks and masts, erection..................................... ......59 Derricks and masts, escape lines.................. ..................60

Handling, casing.......................................... ...................71 Handling, hazardous chemicals..................................... ..75

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Index Handling, marine riser........................................ ............71

Liquid............................................................................ ..99

Handling, tubing............................................ .................71

Location approval........................................................... .24

Hazard....................................................................... ......99

Location, land............................................ .....................44

Hazardous zones.....................33, 45, 56, 81, 97, 103, 122

Location, offshore..................................... ......................48

Health, occupational................................... ....................85

Logging, electric........................................ .....................89

Heavy lifts................................................................ .......77

Logging, electric fishing............................ .....................96

Helicopter operations........................................ ............110

Logging, operations...................................................... ...89

Hot work............................................ ...............24, 98, 106

M

Housekeeping......................................................... .85, 100 HSE audit.................................................................... ....37 HSE Case.............................. ....3, 5, 7, 16, 19, 27, 39, 115 HSE Case remedial actions........................................ .....40 HSE Case revision.......................................... ................40 HSE Department.................................................... .........10 HSE Management System................1, 3, 5, 16, 19, 37, 39 HSE meetings...................10, 18, 32, 36, 42, 99, 114, 116 HSE policy...................................................... ............6, 41 Hydrogen sulphide............................................ ..............78 Hydrogen sulphide, monitoring..........................80, 83, 98 Hydrogen sulphide, procedures................................... ....30

Maintenance, preventive.................. .....56, 61, 62, 73, 116 Manuals................................. .................65, 102, 104, 106 Marine riser................................................. ...................71 Masts, guy lines............................................... ...............60 Masts, raising and lowering..................................... .......59 Materials, low temperature................................... ........100 Materials, stacking...................................................... ....52 Medical facilities.......................................... ..................48 Mud................................... .....................31, 51, 52, 75, 87 Mud logging.................................................... ....82, 83, 97 Mud programme............................................................. .79

Hygiene........................................................... ..........46, 86

N

I

Nitrogen, liquid........................................................... ....99

Incidents.................. .....................6, 10, 18, 22, 32, 35, 41 Induction programme.......................... ..............14, 83, 116

Noise.................................................................... ...........87 Noise control........................................................... ........85

Inspection, elevators................................ .......................63

O

Inspection, lifting gear..................... .............62, 64, 65, 69

Occupational health..................................... ...................31

Inspection, materials.......................................... .............52

Offshore survival course.............................. ...................12

Inspection, rig......................... ................17, 23, 31, 37, 61

Oil spill contingency plan................................ ...............29

Inspection, slings, hooks, shackles................................ ..62

Oil spills.................................................. ...................9, 98

Inspection, winches................................................. ........63

Organisation................................................................ ......8

Inspections, electrical............................................... .33, 47

Oxygen deficiency.................................................... .....101

Inspections, management................................... .............33

P

J Job description........................................ ................11, 114

L Lifting gear.......................................... .....................61, 62

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Perforating, tubing conveyed.................... ......................94 Performance indicators.............................. .....................32 Permit-to-work......12, 24, 33, 45, 65, 86, 90, 94, 99, 102, 128 Personnel movement control................................. ........106

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Stabbing board.................................................... ............61

Policy, substance abuse................................... ..........7, 113

Standards.................................................... ....................19

Pollution................................................................ ..26, 109

Standby vessels.................................................. ...........108

Pressure control................................... .....................13, 90

Subcontractor, HSE................................................. ........17

Pressure testing...................................................... .........78

Substance abuse...................................................... ..........7

Pulsation dampeners, charging.................. .....................58

T

Q

Tender assisted operations................................ ..............51

Qualifications............................................................. .....12

Tongs......................................................................... ......73

R

Torque, working in a string..................................... ........74 Training........................................................... ..12, 83, 110

Radio transmissions............................................ ............92 Radioactive source register................................ .............96 Radioactive sources............................ ......................46, 95 Radioactive sources, storage.............................. .............95 Radioactive sources, use................................... ..............95 Relief valves............................................... ....................59 Relief well plan............................................................. ..29 Rescue of personnel........................................ ..............109 Resources............................................................. ...........10 Responsibilities, company.................. ......................9, 114

Training, H2S...................................... .....................13, 79 Transport, air............................................ ......................53 Transport, road........................................................... .....52 Transport, sea................................................................ ..53 Travelling block................................................. .............64 TRIPOD DELTA............................................... ..............31 Tripping.................................................. ..................74, 83 Tubulars, making up and laying down......................72, 74

U

Responsibilities, contractor................................... ....9, 115

Unsafe act auditing........................................ .................34

Rig................................................................................... 37

V

Rig assessment...................................................... ....48, 50 Rig moving, land........................................................ .....53

Visitors............................................................. ...14, 46, 83

Rig moving, offshore................................................. ......54

W

Running casing................................... ......................61, 71

Waste disposal.......................................... ......................46

S

Waste management................................. ..................31, 88

Safety factors, wire rope.............................. ...................64 Separators, mud/gas............................................... .........80 Shallow gas............................................. ......24, 30, 48, 49 Site survey....................................................................... 48 Site, drainage.................................................... ..............45 Site, land................................................................ .........44 Site, sewage disposal........................................ ..............45 Slings......................................................... ...............62, 72 Slips.................................................................. ..............72 Spare parts............................................. .............52, 56, 66

Water, potable................................................. ................46 Weather forecasting........................................................ .26 Weather, adverse............................................. ..........25, 69 Weight indicator........................................................ ......60 Well control..................................12, 29, 66, 83, 101, 108 Well interference...................................................... .....105 Well testing........................................................ .............97 Winches......................................................................... ..62 Winches, man riding........................................ ...............65 Winches, operation of................................ .....................62 Wire ropes................................................................ .......64

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Index Wireline (slickline) operations.............................106, 107

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141