ENI - Completion Procedures Manual
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ARPO
ORGANISING DEPARTMENT
ENI S.p.A. Agip Division
TYPE OF ACTIVITY'
ISSUING DEPT.
DOC. TYPE
REFER TO SECTION N.
PAGE.
OF
STAP
P
1
M
1
192
7120
TITLE COMPLETION PROCEDURES MANUAL
DISTRIBUTION LIST Eni - Agip Division Italian Districts Eni - Agip Division Affiliated Companies Eni - Agip Division Headquarter Drilling & Completion Units STAP Archive Eni - Agip Division Headquarter Subsurface Geology Units Eni - Agip Division Headquarter Reservoir Units Eni - Agip Division Headquarter Coordination Units for Italian Activities Eni - Agip Division Headquarter Coordination Units for Foreign Activities
NOTE: The present document is available in Eni Agip Intranet (http://wwwarpo.in.agip.it) and a CD-Rom version can also be distributed (requests will be addressed to STAP Dept. in Eni - Agip Division Headquarter) Date of issue:
28/06/99
„ ƒ ‚ • € Issued by
REVISIONS
M. Bassanini 28/06/99
C. Lanzetta 28/06/99
A. Galletta 28/06/99
PREP'D
CHK'D
APPR'D
The present document is CONFIDENTIAL and it is property of AGIP It shall not be shown to third parties nor shall it be used for reasons different from those owing to which it was given
ARPO
ENI S.p.A. Agip Division
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INDEX 1.
2.
3.
4.
INTRODUCTION
9
1.1.
PURPOSE OF THE MANUAL
9
1.2.
IMPLEMENTATION
9
1.3.
UPDATING, AMENDMENT, CONTROL & DEROGATION
9
RESPONSIBILITIES
10
2.1.
DRILLING COMPLETION AND WORKOVER MANAGER
10
2.2.
WELL OPERATIONS SUPERINTENDENT
11
2.3.
COMPLETION AND WORKOVER ENGINEER
11
2.4.
FLUIDS SPECIALIST
12
2.5.
OFFSHORE INSTALLATION MANAGER (OIM)
13
2.6.
WELL OPERATIONS SUPERVISOR
13
2.7.
PRODUCTION SUPERVISOR
14
DOCUMENTATION
15
3.1.
PRELIMINARY INFORMATION
15
3.2.
WELLSITE REPORTS
15
3.3.
FEED BACK REPORTS
15
3.4.
OTHER REPORTS
16
3.5.
PERMIT PROCEDURES 3.5.1. Guidance For Permits
16 16
3.6.
WELL HANDOVER PROCEDURES 3.6.1. Well Handover Certificate 3.6.2. Well Intervention Handover Certificate
17 17 18
HOLE PREPARATIONS
23
4.1.
PRELIMINARY CHECKS
23
4.2.
WELL CLEAN UP PROCEDURES
23
4.3.
BOP STACK CONFIGURATION AND TESTING
24
4.4.
WELL CONTROL
24
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4.5.
OIL BASED MUD DISPLACEMENT 4.5.1. Displacement Objectives 4.5.2. Logistical Considerations 4.5.3. Drilling Fluid Preparation 4.5.4. Surface Equipment Preparation 4.5.5. Well Clean Up Pill Sequence 4.5.6. Pill Functions 4.5.7. Pit Requirements 4.5.8. Pumping Sequence
24 24 25 25 26 26 27 27 27
4.6.
DISPLACEMENT OF WATER BASED MUDS 4.6.1. Drilling Fluid Preparation 4.6.2. Surface Equipment Preparation 4.6.3. Well Clean Up Pill Sequence 4.6.4. Pill Functions 4.6.5. Pit Requirements 4.6.6. Pumping Sequence
28 28 28 28 29 29 29
4.7.
COMPLETION AND WORKOVER FLUIDS 4.7.1. Brines Transportation 4.7.2. Completion And Workover Fluid Quality
29 29 30
4.8.
FILTRATION SYSTEMS 4.8.1. Fluid Cleanliness
30 30
4.9.
LOST CIRCULATION 4.9.1. Viscous Pills 4.9.2. Sized Salt Pills 4.9.3. Calcium Carbonate Pills
31 31 31 32
4.10. CASING GAUGE CONTROL
33
PERFORATING PROCEDURES
34
5.1.
GENERAL
34
5.2.
METHODS OF PERFORATING
35
5.3.
GENERAL SAFETY PROCEDURES
35
5.4.
WIRELINE CONVEYED PERFORATING 5.4.1. Casing Guns Run In Overbalance 5.4.2. Perforating Procedures For Through Tubing Conveyed Guns
37 37 38
5.5.
SAFE SYSTEM 5.5.1. SAFE System Description (Slapper Activated Firing Explosives)
39 40
5.6.
TCP PROCEDURES 5.6.1. Well Preparation for TCP Operations 5.6.2. Ancillary TCP Equipment 5.6.3. Firing Systems for TCP Operations 5.6.4. General TCP Safety Precautions and Running Procedures 5.6.5. Firing Procedure for Tubing Installed Pressure Activated Head 5.6.6. Firing Procedure for Wireline Installed Pressure Activated Head 5.6.7. Firing Procedure for Mechanical Impact Activated Head 5.6.8. Firing Procedure for Electrically Activated TCP Guns 5.6.9. Procedure For TCP Anchor Running 5.6.10. TCP Anchor Firing Head Installation
40 41 41 43 44 45 45 45 46 47 48
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5.7.
MISFIRE PROCEDURES 5.7.1. Mechanical Firing Head 5.7.2. Hydraulic Firing Head 5.7.3. Fixed Hydraulic Firing Head 5.7.4. Retrievable Hydraulic Firing Head
51 51 52 53 53
5.8.
COILED TUBING PERFORATING
53
GRAVEL PACKING PROCEDURES
54
6.1.
GRAVEL PLACEMENT OBJECTIVES
54
6.2.
SCREEN SIZE
54
6.3.
GRAVEL CALCULATIONS 6.3.1. Sand Volume Required 6.3.2. Carrier Fluid Volume
55 55 56
6.4.
COMMON GRAVEL PACK PROCEDURES
56
6.5.
OPEN HOLE GRAVEL PACK PROCEDURE
57
6.6.
CASED HOLE GRAVEL PACK PROCEDURE
59
PACKER INSTALLATION
64
7.1.
HOLE PREPARATION
64
7.2.
WIRELINE PACKER SETTING PROCEDURE 7.2.1. Running Procedure
64 65
7.3.
TUBING INSTALLED PACKER SETTING PROCEDURE 7.3.1. Workstring Running Procedure 7.3.2. Completion String Running Procedure
66 66 67
COMPLETION INSTALLATION
68
8.1.
CARBON STEEL AND PLASTIC COATED TUBING
68
8.2.
CHROME TUBULARS 8.2.1. Transportation 8.2.2. Transport From The Mill 8.2.3. Road Transport 8.2.4. Marine Transport 8.2.5. Handling At The Wellsite 8.2.6. Thread Compounds 8.2.7. Running Chrome Tubulars 8.2.8. Retrieving Chrome Tubulars
68 68 69 69 69 69 71 72 73
8.3.
EQUIPMENT PRE-INSTALLATION PROCEDURES 8.3.1. Material Requisition Lists 8.3.2. Completion Sub Assemblies 8.3.3. Tubing Hanger 8.3.4. Landing Joint 8.3.5. Control Line 8.3.6. Xmas Tree 8.3.7. Flowline
74 74 74 75 75 75 75 76
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8.4.
COMPLETION ASSEMBLIES 8.4.1. Workshop Make-up and Test Procedures 8.4.2. Sub-Surface Safety Valves 8.4.3. Wireline Nipple Assemblies 8.4.4. Side Pocket Mandrels
76 76 76 77 77
8.5.
COMPLETION RUNNING PROCEDURES 8.5.1. General 8.5.2. Running Procedure 8.5.3. TRSCSSV Installation Procedure 8.5.4. WRSCSSV Installation Procedure
78 78 79 80 81
8.6.
XMAS TREE INSTALLATION 8.6.1. Installation Procedures
82 82
8.7.
POST COMPLETION TEST PROCEDURES 8.7.1. SCSSV Test Procedure 8.7.2. Xmas Tree Valve Test Procedure
83 83 83
GAS LIFT INSTALLATION
85
9.1.
MANDREL INSTALLATION 9.1.1. SPM Installation Procedure 9.1.2. Gas Lift Valve Installation Procedure
85 85 87
9.2.
UNLOADING PROCEDURE
88
9.3.
TROUBLESHOOTING
88
10. DOWNHOLE PUMP INSTALLATION
89
10.1. ELECTRICAL SUBMERSIBLE PUMPS 10.1.1. Handling 10.1.2. Installation 10.1.3. Pulling Procedure 10.1.4. Troubleshooting
89 89 89 93 93
10.2. ROD PUMPS 10.2.1. Completion Installation 10.2.2. Tubing String Installation 10.2.3. Rod Installation
96 96 96 98
10.3. HYDRAULIC PUMPS 10.3.1. Jet Pump 10.3.2. Turbine Pump 10.3.3. Piston Pump
98 99 101 101
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11. SUBSEA COMPLETIONS
102
11.1. SUBSEA EQUIPMENT PRE-DEPLOYMENT TESTING 11.1.1. Guidewire Establishment Tool 11.1.2. Guidewire Latchess 11.1.3. Diverless Guideposts 11.1.4. Casing Hanger Elevation Test Tool 11.1.5. Tubing Hanger System 11.1.6. Tubing Hanger Running/Orientation Tools 11.1.7. Tubing Hanger Verification Tool 11.1.8. Tubing Hanger Isolation Plugs 11.1.9. Subsea Tree And Workover Equipment 11.1.10. Install the LRP/TRT onto the XT 11.1.11. Production Riser 11.1.12. Surface Xmas Tree
103 103 103 103 104 104 106 109 110 110 115 117 118
11.2. DEPLOYMENT PROCEDURES 11.2.1. Running The Completion And Tubing Hanger 11.2.2. Pull The Drilling BOPs
118 118 120
11.3. WORKOVER AND PRODUCTION CONTROLS SYSTEM PRE-DEPLOYMENT TESTING 11.3.1. Workover Controls Equipment 11.3.2. Production Controls Equipment 11.3.3. WOCS Pre-Deployment Testing 11.3.4. Production Controls Pre-Deployment Testing 11.3.5. Function Test using SEM B 11.3.6. Pressure Test Tree Valves
120 120 120 121 124 128 131
11.4. RUNNING THE SUBSEA XMAS TREE 11.4.1. Unplugging The Well 11.4.2. Perforating And Well clean-Up
136 136 137
11.5. PULLING THE LRP 11.5.1. Disconnect The LRP And Tree Running Tool
137 137
11.6. DEPLOYMENT OF THE TREE CAP
138
11.7. DEPLOYMENT AFTER COMMISSIONING ACTIVITIES
138
12. WELL UNLOADING
139
12.1. UNLOADING BY CIRCULATION
139
12.2. UNLOADING BY BULLHEADING
141
12.3. UNLOADING BY COILED TUBING
141
13. COILED TUBING OPERATIONS 13.1.1.
PREPARATION
142 142
13.2. SAFETY CONSIDERATIONS 13.2.1. Tubing 13.2.2. Risers and BOPs 13.2.3. H2S Considerations
142 143 143 144
13.3. PERMIT REQUIREMENTS
144
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13.4. RIG UP PROCEDURES 13.4.1. Equipment Preparation and Siting 13.4.2. Coiled Tubing Rig-Up 13.4.3. Pressure Testing 13.4.4. Treating Lines 13.4.5. Injector Frame 13.4.6. Rigging Down
145 145 145 146 148 148 148
13.5. RUNNING PROCEDURES
149
13.6. OPERATING PROCEDURES 13.6.1. Gas Lifting 13.6.2. Well Treatment 13.6.3. Sand Cleanout
150 150 151 153
14. NITROGEN PROCEDURES
155
14.1. PREPARATION
155
14.2. SAFETY CONSIDERATIONS
155
14.3. NITROGEN HANDLING 14.3.1. Safety Equipment 14.3.2. Safety Data Sheets 14.3.3. Pressurised Lines
156 156 157 157
14.4. RIG-UP PROCEDURES 14.4.1. Equipment Preparation and Siting 14.4.2. Equipment Rig-up 14.4.3. Pressure Testing 14.4.4. Treating Lines 14.4.5. Rigging Down
157 157 157 158 158 158
14.5. NITROGEN TREATMENT PROCEDURES 14.5.1. Pressures 14.5.2. Pump Rates 14.5.3. Coiled Tubing Gas Lift 14.5.4. Nitrogen Cushion - Tubing Conveyed Perforation 14.5.5. Nitrified Treatment
159 159 159 159 160 161
14.6. NITROGEN TECHNICAL INFORMATION
161
14.7. EMERGENCY PROCEDURES (During Nitrogen Operations) 14.7.1. Production Shutdown 14.7.2. General Platform Alarm 14.7.3. Prepare to Abandon Platform 14.7.4. Liquid Nitrogen Spill 14.7.5. Injury to Personnel
162 162 162 162 163 163
15. STIMULATION PROCEDURES
164
15.1. INTRODUCTION
164
15.2. SAFETY CONSIDERATIONS 15.2.1. Chemical Handling 15.2.2. Pressure
164 165 166
15.3. PERMIT REQUIREMENTS
167
15.4. RIG-UP PROCEDURES 15.4.1. Equipment Preparation and Siting 15.4.2. Equipment Rig-Up
167 167 168
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15.4.3. 15.4.4. 15.4.5.
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Pressure Testing Treating Lines Rigging Down
168 169 169
15.5. TREATMENT PROCEDURES 15.5.1. Matrix Acidising 15.5.2. Fracture Acidising 15.5.3. Acid Wash 15.5.4. Scale Dissolver 15.5.5. Bullhead 15.5.6. Coiled Tubing 15.5.7. Asphaltene and Wax/Dissolvers
169 170 170 170 170 171 171 171
15.6. STIMULATION TECHNICAL INFORMATION 15.6.1. Factors Affecting Acid Reaction 15.6.2. Acid Properties
171 172 174
15.7. ACID ADDITIVES
175
APPENDIX A - REPORT FORMS
177
A.1. Initial Activity Report (ARPO 01)
177
A.2. Daily Report (ARPO 02)
178
A.3. Cementing Job Report (ARPO 04B)
179
A.4. Waste Report (ARPO 6)
180
A.5. Perforating Report (ARPO 07)
181
A.6. Gravel Pack Report (ARPO 08)
182
A.7. Matrix Stimulation Report (ARPO 09)
183
A.8. Well Problem Report (ARPO 13)
184
A.9. Malfunction & Failure Report(FB-1)
185
A.10. Contractor Evaluation (FB-2)
186
APPENDIX B - ABBREVIATIONS
187
APPENDIX C - BIBLIOGRAPHY
192
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INTRODUCTION
1.1.
PURPOSE OF THE MANUAL
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The purpose of the Completions Procedures Manual is to guide technicians and engineers, involved in Eni-Agip’s Drilling & Completion worldwide activities, through the Procedures and the Technical Specifications for general completion operations which are part of the Corporate Standards. Such Corporate Standards define the requirements, methodologies and rules that enable to operate uniformly and in compliance with the Corporate Company Principles. This, however, still enables each individual Affiliated Company the capability to operate according to local laws or particular environmental situations. The final aim is to improve performance and efficiency in terms of safety, quality and costs, while providing all personnel involved in Drilling & Completion activities with common guidelines in all areas worldwide where Eni-Agip operates. It is intended to guide users towards using procedures which have been found to provide the most efficient and cost effective operations. 1.2.
IMPLEMENTATION The policies included in this manual apply to all Eni-Agip Division and Affiliates operations. All supervisory and technical personnel engaged in Eni-Agip’s completion and workover operations are expected to make themselves familiar with these and comply with the policies and procedures specified and contained in this manual.
1.3.
UPDATING, AMENDMENT, CONTROL & DEROGATION This is a ‘live’ controlled document and, as such, it will only be amended and improved by the Corporate Company, in accordance with the development of Eni-Agip Division and Affiliates operational experience. Accordingly, it will be the responsibility of everyone concerned in the use and application of this manual to review the policies and related procedures on an ongoing basis. Locally dictated derogations from the manual shall be approved solely in writing by the Manager of the local Drilling and Completion Department (D&C Dept.) after the District/Affiliate Manager and the Corporate Drilling & Completion Standards Department in Eni-Agip Division Head Office have been advised in writing. The Corporate Drilling & Completion Standards Department will consider such approved derogations for future amendments and improvements of the manual, when the updating of the document will be advisable.
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RESPONSIBILITIES The following job descriptions outline the individual responsibilities and duties of specific key personnel involved in Eni-Agip Completion operations. These are generalised summary of the individual responsibilities and duties which are specific to completion operations and as such augment, but do not supersede their current employer’s approved job descriptions.
2.1.
DRILLING COMPLETION AND WORKOVER MANAGER The Drilling/Completions and Workover Manager reports directly to the District Manager and supervises the Well Operations Superintendent, Completions and Workover Superintendent, Drilling Engineering/Completions and Workover Engineering. His duties include the following: •
• • • • • •
Ensuring the definition of scope of work and requisitioning of drilling and completion/workover contracts are correctly processed by the contracts department and approved first by the District Manager, in order to comply with time schedule, quality and technical conditions as defined in the programme. Ensuring the pre-qualification and technical tender evaluation phases comply with company policies and procedures and to provide the Contracts department with all technical details necessary for a thorough commercial evaluation. Approving the completions programmes, ensuring they fully meet the prognosis target, pursuing the best results in terms of safety, time schedule and cost effectiveness. Managing day-to-day completions operations, co-ordinating the activities of contractors and units/positions involved, in order to guarantee that operations meet the company policies and standards. Controlling operational costs and provides the technical approval for invoice payment. Verifies the consistency of the expenditure with AFEs and with the administration validity of the contracts. Liaising, timely and effectively, with the regulatory bodies in order to obtain consent for well related operations. Instituting, monitoring and reviewing completions safety policies within the Safety Management System, in order to maximise effectiveness and safety of the operations.
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WELL OPERATIONS SUPERINTENDENT The Well Operations Superintendent reports to the Drilling, Completion and Workover Manager and supervises rig site supervisors. His duties include the following: • • • • • • • • •
2.3.
Ensuring operational progress follows the approved well programme and provides technical advice to the rig site on a daily basis, as required. Ensuring the correct scheduling of completion materials and services, provides a timely supply to the rigs while optimising the cost of transport, materials and manpower within established programmes and budgets. Administering service contracts, providing the technical control of contractor performance giving the first authorisation to the payment of invoices and ensuring the control of current total expenditure on each contract. Ensuring that operations comply with current legislation and company standards. Preparing scopes of work and technical specification for services to be tendered and review those for services and equipment. Providing technical advice during pre-qualification and tender evaluation phases, in order to ensure that the selection of contractors and suppliers fully meet technical targets and company standards. Providing timely and accurate requisitions for all services and materials relevant to well operations. Ensuring, in liaison with AQS, the correct interface of the Contractor’s procedures are to Eni-Agip’s policies and procedures. Ensuring simultaneous completion and production procedures are reviewed.
COMPLETION AND WORKOVER ENGINEER Reports to the Drilling, Completion and Workover Manager. His duties include the following: • •
• • •
Preparing and reviewing technical specifications and scopes of work for equipment to be tendered and services for completion, workover, wireline and well testing operations. Co-operating with the Well Operations Superintendent for providing advice during pre-qualification and tender evaluation phases, in order to ensure that the selection of contractors and suppliers fully meet technical targets and company standards. Supplying well cost estimates for future operations budgets and current operations AFEs, ensuring the reliability of the data provided. Contributing, in liaison with the Petroleum Engineer and with the Reservoir Engineers, to the planning of development projects, providing technical input to the project teams, in order to optimise cost and effectiveness of the project. Monitoring, in liaison with the Petroleum Engineer and with the Reservoir Engineers, the performance of wells and reservoirs, in order to provide technical expertise and advice for identifying and initiating enhancements to well potential.
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• • •
• •
•
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Appraising new completion, workover, wireline and well testing technology and products to determine their application to Eni-Agip’s completion operations, in order to improve time cost performance and safety conditions. Preparing and reviewing completion, workover, wireline and well testing programmes and final reports and to ensure the production of adequate feedback about the operations as per the Safety Management System corporate requirements. Reviewing daily the operations versus the programme, providing a thorough investigation of operational times. Providing engineering assistance to the Well Operations Superintendent in the follow up of operations. Providing reports and analysis on the operated and non-operated activities for presentation, meetings and reporting to the management and to ensure the operational feedback reporting system is consistent with Eni-Agip and corporate requirements. Assisting his supervisor in contacts with partners and regulatory bodies providing the necessary documentation and reports. Providing the monthly updates on the variance between actual and estimated expenditures for each job centre for each class of cost, also to liaise with the Completion/Workover Superintendent, in order to update the expenditure on each contract. Ensuring the production and review of the Completions Procedure Manual in order to comply with company policies and the current legislation.
FLUIDS SPECIALIST Reports to the Drilling, Completions and Workover Manager for routine operational matters. His duties include the following: • • • • • • •
Preparing technical specifications for tenders. Advising on pre-qualifications and tender evaluations exercises. Preparing programmes ensuring the compliance with regulatory requirements. Ensuring the compilation of final fluids reports and the feedback documents relevant to the activities under his scope of work. Maintaining up to date knowledge of the technical and regulatory evolution’s for the activities under his scope of work. Liaising with logistics department for ensuring the provision of services, transportation and materials to well site. Liaise with the appropriate service companies and suppliers on a daily basis.
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OFFSHORE INSTALLATION MANAGER (OIM) If applicable, his duties include the following: • •
• • •
2.6.
Reporting directly to Asset Operations Manager. Co-ordinating and supervising all operations on the installation. The senior representatives for each discipline are responsible for the activities of their own discipline and must keep the OIM informed on their own respective operations. The Production Supervisor will keep the OIM informed on the status of production operations. Authorise all work permits in accordance with the Permit to Work System, and will ensure countersignature by the Well Operations Supervisor, or other Discipline Heads. For completion operations, he will delegate responsibility to the Well Operations Supervisor or another Company Representative (e.g. Production Supervisor) as dictated by asset ownership or control at the time of the ongoing operations. Is responsible for the actions to be followed under the various installation operating modes. The OIM will require advice from the Well Operations/Production Supervisor or other Discipline Heads, e.g. Maintenance Supervisor, etc.
WELL OPERATIONS SUPERVISOR Represents Eni-Agip’s interests on the installation with respect to the Drilling Contractor and Service Companies. The Senior Well Operations Supervisor is directly responsible for the drilling and completion equipment and all operations conducted during the drilling completion and workover phase. His duties include the following: • • • • •
• •
Ensuring all Company policies relating to drilling and completing operations and emergency situations are adhered to at all times for the safety of personnel, rig equipment, well stability and control. Directing the Drilling Contractor and Service Company representatives in the operations to be performed and supervises the conduct of the operations. Ensuring all operations, detailed in the Drilling and Completion Programme, are performed efficiently and safely using the procedures detailed in the programme and/or Completion Procedures Manual. Responsibility for the Hot Permit System when ‘hot work’ is being conducted in the drilling module. Requisitioning the equipment and materials required to complete the operations. He will requisition the materials when appropriate and liaise with the Completion and Workover Superintendent to ensure arrival at the rig-site in ample time to allow inspection and preparation prior to use. Ensuring all tools are suitable for purpose, inspected and dressed prior to running in the well. Introducing changes to the Drilling and Completion Programme but only in an emergency or when operating conditions do not allow for communication with the Drilling and completion Workover Department.
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• •
2.7.
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Ensuring all reports required, are accurate in content and are submitted as required. Reporting requirements are outlined in section 3. Liaising with the OIM, Company Production Supervisor, and other operational Heads on a daily basis to discuss operational considerations and the possible impact on the other operations. Supervising and directs well control operations in accordance with the Eni-Agip Well Control Manual. Liaising with the OIM to give advice on what actions to take, if any of the Platform Operating Modes are associated with the drilling operation, or arise from operations in the drilling module. On completion of the programme, i.e. Xmas tree is secured with all operations completed, officially handing over the well to the Production Department (Production Supervisor). Both parties must sign the relevant well handover document. Co-ordinating all completion activities including wireline and/or coil tubing/nitrogen, acid stimulation, perforating as well as all preliminary pressure testing of equipment. Ensuring the safe and correct installation of all tubulars and completion subassembly components, i.e. in the correct order and proper depth as per the completion programme.
PRODUCTION SUPERVISOR Reports to the Company Production Superintendent (Office). His duties include the following: • • • •
Representing Eni-Agip’s interests on the platform with respect to production, and when dealing with service companies involved with operations during the production phase. Ensuring that, during heavy lift operations such as handling Xmas trees etc., neighbouring wells are closed-in to minimise risk to wellheads, flowlines, production equipment, the platform and personnel. Informing the Well Operations Supervisor, OIM and other Discipline Heads on the status of the production operations and the possible impact on other operations in general. Prior to a workover being carried out, handing the well over to Drilling/Completion (Well Operations Supervisor) stating the exact condition of the well. Both parties must sign the handover document.
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DOCUMENTATION This section outlines the documentation necessary for conducting efficient completion operations and reporting of these operations.
3.1.
PRELIMINARY INFORMATION Before performing any well operations the following documentation and information must be available: A detailed programme including: • • • • • • • • •
3.2.
Name of Field Name of Well Well Code Well Co-ordinates (wellhead and bottom hole) Cost Centre Number RKB Elevation Completion String Schematic (completion components ID, length, tubing size/weight, depths, etc.) Intervals to be perforated Specifications of Completion Equipment.
WELLSITE REPORTS To schedule future operational programmes, all operations must be properly documented and kept on file to maintain the history of operations performed on any well. The operations performed during rig operations (completion string gauging, packer setting, etc.) will be reported in the Daily Well Report. This and other service reports for gravel packing, stimulation and other well operations are shown in Appendix A. It is responsibility of the Well Operations Supervisor to compile and forward the reports (indicated below) to the Well Operations Superintendent. The Superintendent will then check and approve the reports before distribution and filing.
3.3.
FEED BACK REPORTS The following reports are compiled at the end of the operations: a)
FB-01
Report on Equipment Damage and Malfunctions
b)
FB-02
Service Company Evaluation Report
Refer to Appendix A for copies of appropriate reports.
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OTHER REPORTS The Eni-Agip Representative must sign the Service Reports of the Service Companies which must include the following information : • • • • • • •
3.5.
Name of Well Name of Field Order Number Date Personnel and equipment used Description of the operations conducted Starting and completion dates for service company charges.
PERMIT PROCEDURES No work can be performed without a valid permit to work. All requirements as laid out in the Company Permit to Work Procedures must be adhered to at all times. Although the operation of a permit system is the responsibility of the installation manager, safe operating practice is compulsory and the responsibility of all personnel involved in completion operations. The Permit to Work System is drawn up in accordance with standard Oil Industry practices in order to improve offshore safety during all phases of operations. All personnel involved in completion operations should clearly understand the particular installation Permit to Work System, and be aware that the issuing of a permit in itself cannot guarantee that any job is safe. As each installation will have its own distinct PTW system according to the type of installation, location and country, it is not possible to describe a generic system in this manual.
3.5.1.
Guidance For Permits Examples of activities which require permits to work (hot and cold) must listed in Permit to Work Procedures. Those activities not normally requiring a work permit must also be listed. It should be stressed however, that some of these activities will be brought within the Permit to Work System from time to time as circumstances dictate. It remains the responsibility of the Area Authority to ensure that the correct permits and certificates are in force during all phases of operations. The responsibilities of those individuals involved in the administration of the Permit to Work System should be clearly defined in the Permit to Work Procedures.
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
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3.6.
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WELL HANDOVER PROCEDURES Operations performed on a well will be the responsibility of a designated ‘Area Authority’. The Well Operations Supervisor will be the responsible person for drilling, completion, workover, wireline, coiled tubing, and stimulation operations. The Production Supervisor will be the responsible person for production operations. The Production Supervisor will be the competent person during Xmas tree repairs or change-outs even when these works are performed by maintenance personnel with the assistance of a vendor service engineer. The action of transferring the responsibility for a well between area authority will be documented and recorded on the ‘Well Handover Certificate’ or ‘Well Intervention Handover Certificate’. All preparatory work and the status of the well when handed over will be described in the appropriate Handover Certificate. A typical example of a Handover Certificate (Eni-Agip) with the information to be recorded is shown in figure 3.a and figure 3.b. The completed Handover Certificate must be signed by the responsible persons handing over and receiving the well. It must be placed in the appropriate well file. Copies are to be faxed to the Well Operations Superintendent when a new well is handed over. There are two types of Well Handover Certificates: • •
3.6.1.
Well Handover Certificate Well Intervention Handover Certificate.
Well Handover Certificate The well Handover Certificate is to be used for all new wells and wells worked over (Drilling, Completion through to Production). New Wells Following the successful drilling and completion of a new well, the Operations department will complete a Well Handover Certificate. Prior to handover of the well to Production, the well status should be outlined as below: • • • • • •
Xmas tree installed and fully pressure tested Swab cap installed and pressure tested SCSSV installed and fully tested All wireline plugs removed All obstructions removed, the wellhead and Xmas tree areas are clean and tidy Written procedure for the venting of annular pressure, if necessary.
Once the Production Supervisor is satisfied that the status of the well is satisfactory, he will sign the handover certificate in acceptance of the well. Examples of Well Handover Certificates are shown in figure 3.a and figure 3.b.
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
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Workover Wells Workover is defined in this instance as any well operation which involves the change-out of any completion component from the wireline re-entry guide to the Xmas tree. Following the successful completion of a well which has been worked over, Well Operations department will complete a Well Handover Certificate. Prior to handover of the well to Production the well status should be outlined as below: • • • • • •
Xmas tree installed and fully pressure tested Swab cap installed and pressure tested SCSSV installed and fully tested All wireline plugs removed All obstructions removed, the wellhead and Xmas tree areas are clean and tidy Written procedure for the venting of annular pressure, if necessary
Once the Production Supervisor is satisfied that the status of the well is satisfactory, he will sign the handover certificate in acceptance of the well. 3.6.2.
Well Intervention Handover Certificate The Well Intervention Handover Certificate is to be used for all interventions such as: • • • • •
Mechanical wireline operations Electric wireline operations Coiled tubing operations Snubbing operations (except where these constitute a ‘Workover’) Well stimulation operations.
Prior to handover of the well by Production to Well Services the Production Supervisor will complete a Well Intervention Handover Certificate and ensure the following procedures are completed: 1) 2)
3) 4) 5)
All chemical injection lines on the flowline will be bled down and isolated. The test and production, or injection, header isolating valves will be closed, and the flowline bled down to the closed drains and isolated when no liquid or gas is observed at the sample point. Blind flanges should be installed on the flowline termination. The SCSSV control lines will be bled off ready to be disconnected. All lines from the wellhead to the remote control panel will also be bled down. If the tree is to be removed all instrumentation and control lines will be removed from the well. All obstructions (e.g. scaffolding) all instrumentation and control lines will be removed.
Once the Well Operations Supervisor is satisfied that the status of the well is satisfactory he will sign the Well Intervention Handover Certificate in acceptance of the well.
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
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Following an intervention operation the Well Operations Supervisor will complete a Well Handover Certificate. Prior to handover of the well to Production, the well status should be outlined as below: • • • • • •
Xmas tree installed and fully pressure tested. Swab cap installed and pressure tested. SCSSV installed and fully tested. All wireline plugs removed. All obstructions removed, the wellhead and Xmas tree areas are clean and tidy Written procedure for the venting of annular pressure, if necessary.
Once the Production Supervisor is satisfied that the status of the well is satisfactory, he will sign the Well Intervention Handover Certificate in acceptance of the well. An example of a Well Intervention Handover Certificate is shown in figure 3.c.
ARPO
IDENTIFICATION CODE
ENI S.p.A. Agip Division
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WELL HANDOVER CERTIFICATE Well No:
Date: WELL DETAILS
Well Type:
Producer/Injector/Gas Lift/__________________ PERFORATION DETAILS ft MD/TVD
ft MD/TVD
ft MD/TVD
ft MD/TVD
ft MD/TVD
ft MD/TVD
ft MD/TVD
ft MD/TVD
Last Hold Up Depth:
ft MD/TVD
Date:
Details of Junk: Bridge Plug(s)
ft MD/TVD TUBING DETAILS
Tubing Size
Tubing Grade
Condition
Producing or Injecting
Tubing Fluid
Shut in Wellhead Pressure
Date last on line
SAFETY VALVE DETAILS String
Valve Open or Closed
Type
Date Last
Remarks
Tested
TUBING PLUG DETAILS String
Plug Type
Depth
Date Tested
Test Pressure
Remarks
Figure 3.A - Example Handover Certificate (Eni-Agip UK)
ARPO
IDENTIFICATION CODE
ENI S.p.A. Agip Division
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XMAS TREE DETAILS Type:
Pressure Rating: psi
Tested to:
Date Tested:
S/N of Block Valve
S/N
Status
Valve
S/N
Swab Valve
Manual Master
Hydraulic Master
Hydraulic Wing
Manual (prod)
Manual (kill)
Wing
Status
Wing
ANNULUS DETAILS Annulus
Pressure
Fluid
Status e.g. Shut-in, Open, Venting, Seized Valves, etc.
Flowline Status: ADJACENT WELLS Well No
SCSSV Status
Plugs Tested
Date
Status
Tested
Date
All Production/Operations equipment removed from area ?
Depth
Xmas Tree
Flowline
Status
Status
Y/N
Remarks: Changes From Programme Status:
Authorised By: Production/Operations Accepted By: Production/Operations Figure 3.B - Example Handover Certificate (Continued)
ARPO
IDENTIFICATION CODE
ENI S.p.A. Agip Division
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WELL INTERVENTION HANDOVER CERTIFICATE Well No:
Date:
Well Details : Producer/Injector :
Single/Dual String :
Permit Order No: Description of Operation BARRIERS REQUIRED
BARRIERS REMOVED (SITE TIDY) SAFETY VALVE DETAILS
Handover String
Status**
Handback Remarks**
String
Status**
Remarks**
XMAS TREE DETAILS Handover Valve
Status **
Handback Valve
Valve
Status **
Status **
Valve
Prod Side
Ann Side
Prod Side
Ann Side
Flow Wing
Man Wing
Flow Wing
Man Wing
Choke
Status **
Choke
Swab Valve
Man Master
Swab Valve
Man Master
Hyd. Master
Hyd Master
Hyd. Master
Hyd Master
Man. Master
Man. Master
**OPEN/CLOSED, HYDRAULICS ISOLATED/DE-ISOLATED ANNULUS DETAILS Handover Annulus
Pressure
Handback Fluid
Above P-Off
Status
Annulus
Pressure
Fluid
Status
Above P-Off
DOWNHOLE TUBING DETAILS (e.g.: equipment set in nipple/component failures/fish in hole etc.) Handover String
Detail
Depth
Handback Remarks
String
Detail
Depth
Authorised By : Production/Well Services
Authorised By : Production/Well Services
Accepted By :
Accepted By :
Time/Date :
Production/Well Services
Production/Well Services
Time/Date :
Figure 3.C - Example Handover Certificate (Continued)
Remarks
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
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4.
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HOLE PREPARATIONS The procedures in this section described the preparation of the hole and surface facilities for completion operations.
4.1.
PRELIMINARY CHECKS Sometime prior to completions operations, the following equipment should be checked to confirm availability and to specification for the forthcoming operations: a) b) c) d) e) f)
g) h) i) 4.2.
Workstring of the appropriate grade and size in sufficient length, taking into consideration if a tapered string is to be used. BOPs are equipped with the correct size-pipe/variable (single or dual) rams to cover all the range of tubulars to be run in the hole. Wear bushing for the tubing hanger spool, equipped with the running/pulling tool. BOP test tool with the appropriate running and pulling tools and a sufficient quantity of seals. All relevant handling tools for the workstring including elevators and slips verifying they are in good working condition. Safety valves have been tested and are available already made up with the crossovers to the workstring and Weco connections to suit the kill line connection. The rig has been equipped with the safety and emergency systems as per the contract and that they are fully operational. Rig pumps are equipped with the appropriate liner sizes and that they have been tested. Mud logging or monitoring system is installed and operational.
WELL CLEAN UP PROCEDURES After the production casing, or liner, has been cemented in place, a bit and scraper assembly will be run. The purpose of this trip is to clean out any excess cement within the casing, and particularly to remove any cement that may be on the casing wall at the packer setting depth. A suitably sized bit, or junk mill, and tandem scraper assembly will be run to clean out the casing or liner of any excess cement, and to scrape the intended perforated interval(s). The packer setting depth will also be scraped during this operation to ensure it will have a good setting area. Precise details of packer setting depths, perforation intervals and maximum clean out depth will be given in the well operations/drilling programme. Note:
The casing and liner string may be pressure tested at this point, and an inflow test on liner laps and shoe tracks performed.
For detailed procedures on how to perform inflow and pressure tests refer to the Drilling Procedures Manual. If a liner lap is a found to be leaking it may be necessary to run a tie back packer into the top of the liner lap, otherwise it will be necessary to perform a remedial cement squeeze. The decision on which method to adopt will depend on the location and nature of the leak.
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
4.4.
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BOP STACK CONFIGURATION AND TESTING a)
The BOP stack configuration including ram sizes should be in accordance with the Well Programme.
b)
All components must be fully certified and will be tested with water in accordance to company policy or local regulations, whichever is the most stringent. testing on a new completion will be accomplished by using either the test tool or the tubing hanger with the tubing hanger plug installed.
c)
Duration of pressure tests will be 10min with a maximum allowable pressure drop of 100psi unless local legislation dictates otherwise.
d)
If it is necessary to use a cup tester for testing the BOP stack, the test pressure must not exceed the safe working pressure of the casing.
e)
The test schedule will be according to local regulations but will be at least every 14 days. If operational constraints prevent a scheduled pressure test, a dispensation will be requested and issued by the authorities and held on file.
f)
The function and pressure tests will be recorded on a chart recorder and the charts held in file.
g)
In workover operations prior to pulling the tubing, the BOP stack will be tested against plugs set in the tubing hanger.
h)
Function test at the same time as the BOP stack the surface control panel, accumulator package and remote control panel. if using a subsea BOP stack, check from both blue and yellow pods.
WELL CONTROL Well control procedures will be in accordance with the Company Well Control Policy Manual, a copy of which must be kept available on the rig.
4.5.
OIL BASED MUD DISPLACEMENT Prior to displacing the well to the completion brine, it will be necessary to displace the drilling mud from the well. In order to ensure that circulation time, rig time and filtration time are kept to an absolute minimum, it is essential that the well clean up is as efficient (and economical) as possible in removing the mud, solids and any other associated debris in the well.
4.5.1.
Displacement Objectives • • • • • • •
Displace oil based mud out of the well with a minimal interface between the oil based mud and the clean up chemicals. Keep the brine interface to an absolute minimum. Minimise filtration time and cost. Change the wetability of all downhole surfaces from oil wet to water wet. Prevent the discharge of oil based mud, contaminated water and/or contaminated brine to the environment. Minimise the requirement for back-loading oily water for disposal. Remove pipe scale, solids, mud solids and other contaminants from the wellbore.
ARPO
ENI S.p.A. Agip Division
IDENTIFICATION CODE
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4.5.2.
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Logistical Considerations In advance of the displacement, the logistics of the operation from start to finish should be addressed. The areas which should be addressed include (but are not limited to) the following:
4.5.3.
a)
Vessel(s) for back-loading mud and taking on the clean up chemicals, brine and kill pill material.
b)
The quantities of clean up chemicals, brine and kill pill material required including any contingency material that may be required.
c)
Pit space requirements for mud and brine and the permits required for cleaning the appropriate pits and lines.
d)
The equipment required to install and operate the filtration equipment.
e)
Personnel requirements and available accommodation.
Drilling Fluid Preparation 1)
2)
3)
4)
5)
6)
Pick up the workstring with scrapers placed in it to ensure that the liner or casing packer setting depths are thoroughly scraped during the trip. Once on bottom, bottoms up should be circulated to remove any additional debris. Circulate and condition the oil based mud with oil mud thinner or oil wetting agent in order that the yield point and gel strengths are reduced but not to a point where the fluid loses the ability to keep barite/drilled solids in suspension. Typically, the yield point should be reduced to 12 lbs/100 ft2 and the 10min gel to
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