Iadc Inspection List

Table of Contents Page 1 of 61

TABLE OF CONTENTS

(i)

Summary of Recommendations

(ii)

Report Sections 1.

Section 1 - Drilling Equipment 1.1 1.2 1.3 1.4 1.5 1.6 1.7 1.8 1.9 1.10 1.11 1.12 1.13 1.14 1.15 1.16 1.17 1.18 1.19

2.

Section 2 - Drill String & Handling Equipment 2.1 2.2 2.3 2.4 2.5 2.6 2.7 2.8 2.9 2.10 2.11 2.12 2.13 2.14 2.15 2.16 2.17 2.18 2.19 2.20

3.

Derrick & Substructure Casing Stabbing Board Crown Block Assembly Traveling Block Assembly Top Drive Drilling System Swivel Drawworks Auxiliary Brake, Electric Sand Reel Rotary Table Assembly Drilling Line Anchor Drilling Line Driller's Console & Instrumentation Ton-Mile Indicator Drilling Recorder Rig Floor Hydraulic System Wire Line Unit Cement Lines (Piping, hoses or chicksans) Hand Tools

Slips, Drill Pipe, Drill Collars, Elevators & Casing Elevator Links Tongs, Drill Pipe, Drill Collars & Casing (Manual) Tongs & Casing (Power) Safety Clamps Spinning Wrench Pipe Racking and Handling System Hydraulic Cathead Kelly Kelly Drive Bushing Master Bushings & Insert Bowls Upper Kelly Valve or IBOP Valve Lower Kelly Valve or IBOP Valve Rig Floor "Gray" Safety Check Valve Rig Floor "Full Opening" Safety Valve Drill Pipe & HWDP Drill Collars Drilling Subs & Crossovers Crossover for Rig Floor Stab-In Valves Fishing Tools

Section 3 - Mud System 3.1 3.2 3.3 3.4 3.5

Mud Pumps Mud Pits Mud Mixing & Transfer System Mud Shearing System Pit Volume Totalizer System


3.6 3.7 3.8 3.9 3.10 3.11 3.12 3.13 3.14 3.15 3.16 3.17 4.

Section 4 - Engine Room & Associated Equipment 4.1 4.2 4.3 4.4 4.5 4.6 4.7 4.8 4.9 4.10 4.11 4.12 4.13 4.14 4.15 4.16 4.17 4.18 4.19 4.20

5.

Engine Room Ventilation System Main Diesel Engines Engine Instruments Main Diesel Engine Cooling Engine Monitoring System Alarms General Fuel Transfer Pump Clean Fuel Transfer Pump Fuel Centrifuge Fuel Piping & Valves Lube Oil Piping & Valves Potable Water Makers & Purification Water Purification & Treatment Potable Water Transfer Pumps & Pressure Reservoir Rig Service Air System Air Dryers Air Receivers Bilge Monitor Sewage Treatment System Pumps

Section 5 - Electrical Systems 5.1 5.2 5.3 5.4 5.5 5.6 5.7 5.8 5.9 5.10 5.11 5.12 5.13 5.14 5.15 5.16 5.17 5.18

6.

Mud Pit Agitators Mud Process Pits Shale Shakers Desander Desilter Mud Cleaner Vaccum Degasser Poor Boy Mud/Gas Separator Mud Flow Line Return and Bell Nipple Trip Tank Bulk Storage and Transfer System Stand Pipe Manifold, HP Mud Piping & Valves

Main & Emergency AC Generator Switchboard Generators AC Motors Power Transformers DC Drive Motors DC Generators Main & Emergency Distribution AC Switchboards Wireways, MCT's, Bulkhead & Deck Penetrations Shore Power Connection System Welding Outlets General Rig Lighting & Wiring Aircraft Warning Lights Navigation & Running Lights Helicopter Area Lighting Sound Powered Telephone Rig Telephone & PA System TV Systems Emergency Generator

Section 6 - Marine Systems 6.1 6.2 6.3 6.4

Marine Documentation Manufacturer's & Third Party Documentation Navigation & Communication Equipment Storage Areas


6.5 6.6 6.7 6.8 6.9 6.10 6.11 6.12 6.13 6.14 6.15 6.16 6.17 6.18 6.19 6.20 6.21 6.22 6.23 6.24 6.25 6.26 6.27 6.28 6.29 6.30 6.31 6.32 6.33 6.34 6.35 6.36 6.37 6.38 6.39 6.40 6.41 6.42 6.43 6.44 6.45 6.46 6.47 6.48 6.49 6.50 6.54 6.52 6.53 6.54 6.55 6.56 6.57 6.58 6.59 7.

Fuel Tanks Ballast Control System Stability Hull Cathodic Protection (Anodes) Exhaust Stacks Hatches, Windows, Manholes, Openings & Coamings Walkays/Platforms Superstructures Helicopter Deck /Fueling System Anchor Racks Weather Protection Ventilation (Accomodations & Rig Area Compartments) Tank Gauging System Tank Vent & Sounding Tube System Bilge Piping & Valves General Mooring Winch/Windlass Combination Mooring System Control Primary & Auxiliary Brake System Controls, Piping & Valves Emergency Release System Mooring Tension Indicating System Tow Line/Bridle Emergency Tow Line Work Boat Back-down/Tie-up System Anchors Fairleader Mooring Wire Pendant Lines Chain Link, Kenter/Connecting Links & Shackles Buoys Slings & Shackles Cranes Billy Pugh Transfer Net (Personnel) Air Hoist (Tuggers) Man-Riding Tuggers Fork Lift/Pallet Lift Mechanical Winches Chain Falls Cargo Containers (Box, Net, Cargo Basket & Burn Baskets) Hoses - Bulk Mud, Water & Oil Quarters, Shop Furnishings & Equipment Inspection Inspection General Accomodation Room Inspection Air Conditioning System (Main Quarters) Galley Exhaust(s) Quarters' Ventilation System Fans Ducting Refrigeration Compressor System Walk-in Coolers Walk-in Freezer Air Conditioning Pump/Brine Pump (with Motor) Welding & Burning Practices, Procedures & Equipment

Section 7 - Third Party Equipment 7.1 7.2 7.3 7.4

Cementing System Well Test Piping & Valves Burners Burner Booms


8.

Section 8 - Motion Compensating Equipment 8.1 8.2 8.3 8.4 8.5 8.6

9.

Section 9 - Maintenance System Evaluation 9.1 9.2 9.3 9.4 9.5 9.6 9.7 9.8

10.

Management Organization & Administration Measures of Effectiveness Work Control Management Information System Personnel Logistics Support Maintenance Tasks / Maintenance Engineering Spare Parts

Section 10 - Subsea Blowout Prevention Equipment 10.1 10.2 10.3.1 10.3.2 10.3.3 10.3.4 10.4.1 10.4.2 10.5 10.6 10.7 10.8 10.9 10.10 10.11 10.12 10.13 10.14 10.15 10.16 10.17 10.18 10.19 10.20 10.21 10.22 10.23 10.24 10.25

11.

Riser Tensioners - General Shaffer Riser Tensioners Guide Lines, Pod/Messenger Line Tensioners Motion Compensator - General Shaffer Compensator High Pressure Air System

General Requirements Pressure Rating Ram #1 Blind/Shear Ram Ram #2 - 3 1/2" x 5 1/2" VBR's Ram #3 - 5" Pipe Ram Ram #4 Pipe Rams Annular Preventers, Upper Annular Preventers, Lower BOP Stack Mounted Valves BOP Control Unit & Remote Panels Choke & Kill Hoses Choke Manifold Manual Choke Remote Choke & Controls Diverter System Clamps, Flanges & Fasteners Ring Gaskets & Grooves Connectors Riser Telescopic Joint Riser Adapter Ball Joint Rig Positioning Equipment ROV BOP Handling System Rig Floor, Procedures & Regulations Bulletins Preventinve Maintenance Welding

Section 11 - Safety Survey 11.1 11.2 11.3 11.4 11.5 11.6 11.7 11.8 11.9

General Requirements Personal Protective Equipment Hospital Lifesaving Equipment Lifeboats Life Rafts Rescue Boat Life Preservers & Life Rings Self-Contained Breathing Apparatus


11.10 11.11 11.12 11.13 11.14 11.15 11.16 11.17 11.18 12.

Fire Pumps Fire Fighting Equipment Inert Gas Fire Fighting Systems Foam Fire Fighting Systems Alarms & Detection Plans, Permits & Supervisor's Requirements Drills Records H2S Requirements

Section 12 - Environmental Audit 12.1 12.2 12.3 12.4 12.5 12.6 12.7 12.8 12.9 12.10 12.11 12.12 12.13 12.14 12.15 12.16 12.17 12.18 12.19 12.20 12.21 12.22 12.23 12.24 12.25 12.26 12.27 12.28 12.29

Environmental Management General Discharge Control Rig Floor Discharge Mud Pump Room Mud Pit Room Sack Room/Mud Mixing Area Shakers Sand Traps Trip Tank Bulk & Fluid Transfer Hoses Bulk System Waste Containers Mud Lab / Mud Logging / Wireline Unit Koomey Unit Cement Unit Production Test Areas Engine Room Accommodations Main Deck Firefighting Waste Management Mud System Storage Tanks Diesel Filters/Centrifuges Oil/Fuel Transfer Sewage Treatment Equipment Refrigeration Units (CFC's) Spill Contingency Maintenance & Housekeeping

Summary of Recommendations Page 6 of 61

Summary of Recommendations DATE

Section 1 Drilling Equipment 1 Mechanical Major Work Scope Item # 1 2 3 4 5 6 7 8 9 10

Inspection Requirement Main Engines, 1,2,3,4 Draw Works and Elmago break Jacking System Mud Pump power end Mud Pump Fuild End Transverse skidding Forklift Air Winches Iron Rough Neck Heat exchanger for Drawworks and Elmago break

Findings

Recommendations

Note


2 Electrical Major Work Scope Item #

Inspection Requirement

1

GENERATOR 1

2

GENERATOR 2

3

GENERATOR 3

4

GENERATOR 4

5

AUXILIARY GENERATOR

6

EMERGENCY GENERATOR

Findings

Recommendations

Note


7

MAIN SWITCHBOARD

8

SCR

9

DRAW WORKS

10

TOP DRIVE


11

MUD PUMPS

12

JACKING SYSTEM

13

AIR - COND / REFRIGERATION

14

SAFETY EQUIPMENT

15 16

SEWAGE TREATMENT PLANT PIPE RACKING SYSTEM


3 Marine Major Work Scope Item # 1 2 3 4 5 6 7 8 9

Inspection Requirement Jetting line inspection UWILD for spud can Pre-load tanks Cathodic Protection (Anodes) for legs Anchors 5 Ton crane Cantiliver and substructure Bulk system Radios and communication system

Findings

Recommendations

Note

Recommendations

Note

HSE Item # Inspection Requirement 1 Smoke sensors to be provided in the accomodation area 2 Emergency lights not available in escape routes 3 FRC (Fst Rescue Craft) Paint locker on main deck (port side) 4 5 Portable fire extingishers onboard 6 SCBA sets and Cascade system 7 Derrick man escape device (Gerinimo) 8 Photo illuminated signs 9 Fire stations 10 Pyrotechnics 11 STP 12 Incinerator 13 Oily water seperator Helideck 1 2 3 4 5 1 2 3 4 5 6 7 1 2 3 4 5 6 7 8 9 10 1 2 3 4 5 6 7 8 9 10 1 2 3 4 5 6

Helideck Helideck perimeter lights Perimeter nets rusted. Helicopter crash

Fire Fighting Galley Electrical connection Hotplates not working Galley shutter Fire suppression system Drain covers Mantrap alarm in Veg chiller Freezer CRANE Load test Load cell Cameras Fire Fighting Comunication with deck team Internal telecom (paging) Emergency STOP whipline Pedal acceleration AC in crane operator cabin ACCOMODATION Sound proofing for accomodation External windows in accomodation Ceiling lights External water tighht doors in accomodation areas Emergency lights

Photo illuminated signs Sink drainage additional shlves Air conditioning Bathroom sink drain Walkways Heliedeck gratting Skirting on main deck Pump room Sack room Rack choke system Handrails

Findings

Section 1 Page 11 of 61

Section 1 Drilling Equipment Item #

Inspection Requirement Findings Recommendations As a minimum API RP 8B (section 2) Category IV recommends every five years; disassembly to extent necessary to conduct NDE of all primary load carrying components as defined by manufacturer. Owner or user of equipment should develop his own schedule of inspections based on experience, manufacturer's recommendations, and consideration for one or more of following factors: environment; load cycles; regulatory requirements; operating time; testing; repairs; re manufacture.

1.1

1.1.1

1.1.2 1.1.3

1.1.4

Derrick and Substructure

Complete inspection of derrick, substructure and raising or telescoping system per API RP 4G.

Confirm NDE performed and SWL marked on all Padeyes. Inspect ladder. Check that spacing of rungs are standard. Check that ladder is properly secured to derrick. Inspect fingers and diving board. Make sure they are properly secured and have safety wires attached.

1.2 1.2.1 1.2.2 1.2.3 1.2.4 1.3 1.3.1 1.3.2 1.3.3

1.3.4 1.3.5 1.3.6 1.3.7 1.3.8 1.3.9 1.4 1.4.1 1.4.2 1.4.3

1.4.4 1.4.5 1.4.6

Casing Stabbing Board Check condition of board in general. Examine hoist, cables or hydraulics and all safety devices. Confirm secondary means of stopping board if lifting mechanism fails. Function board through entire range of travel and fully test all safety devices. Confirm driller has an unobstructed view of casing stabber. Crown Block Assembly Complete inspection of crown and water table area per API RP 4G. Record date of last NDE as per API RP 8B. Confirm crown protection is in place and bumper blocks are wrapped in heavy-duty wire mesh or expanded metal screen. Use gauge and inspect sheaves for wear in grooves and check sheaves for excess movement to identify badly worn bearings. Raise and lower blocks while visually observing sheaves for misalignment and loose or worn bearings. Check grease fittings and verify proper lubrication. Confirm sheaves adequately protected by jumper bars to ensure that drilling line cannot jump from sheaves in event of jarring or other situations. Check condition of auxiliary line sheaves, safety slings. Confirm all shackles have safety pins. Confirm auxiliary sheave grease lines manifold together or are otherwise easily reached so they can be greased in a safe manner. Traveling Hook Block Assembly Record date of last NDE as per API RP 8B. Check grease fittings and verify proper lubrication. Raise and lower blocks numerous times. Observe for any unusual noise or movement on tracking system. Check traveling block guide track to insure it is straight and guide rollers ride freely during movement up and down. Confirm track rollers guarded so they can't fall to rig floor if they come loose. Use gauge to inspect sheaves for wear in grooves and check sheaves for excess movement to identify badly worn bearings.

Note


Item # 1.4.8 1.4.9 1.5 1.5.2 1.5.3 1.5.4 1.5.5 1.5.6 1.5.7 1.5.8 1.5.9 1.5.10

Inspection Requirement When blocks are hung off, is the hookup acceptable? Explain hookup. Cables and padeyes proper safe working load?

Top Drive Drilling System Record date of last NDE as per API RP 8B and manufacturer. Function test pipe handler. Function IBOP valves and pressure test valves to MWP. Test kelly hose and swivel packing to MWP. Verify proper operation of counter balance and motor alignment cylinder systems. Test run in forward and reverse in each gear. Check smoothness of high/low shift mechanism and indicator. Confirm proper operation of all lights and alarms. Visually inspect service loop. Confirm availability of spare conductors. Confirm compensator hoses properly bundled and travel unobstructed in derrick.

1.5.11

Function test link tilt assembly and check for air leaks.

1.5.12

Record AC drive motor data insulation resistance.

1.5.13

Perform visual inspection of top drive power panel. Check all contactors, relays, power supplies, and terminal boards to see that they are properly marked and that all screws and bolts are tight.

1.5.14

1.5.15

1.5.16 1.5.17 1.6 1.6.1 1.6.2 1.6.3 1.7 1.7.1 1.7.2 1.7.3 1.7.4 1.7.5 1.7.6 1.7.7 1.7.8 1.7.9 1.7.10 1.7.11 1.7.12 1.7.13 1.7.14

Findings

Verify proper operation of driller's control panel. Verify proper operation of installed purge loss alarm system. Shut off purge air supply, note alarm, check emergency by-pass operation, let system power down. Turn on air supply to see if system will go through an automatic purge cycle. Verify proper operation of retracted position lock mechanism on raised back-up system. Visually inspect torque beam support chains on PT Drive. Swivel Record dates of last NDE as per API RP 8B. Record date and results of last lube oil analysis? Function test swivel and pressure test Kelly hose, goose neck and swivel packing to MWP. Drawworks Record date and results of last lube oil analysis. Confirm NDE of critical areas on brake bands. Check thickness of brake rims with ultrasonic tester and compare with manufacturers' specifications. Confirm ducting for drawworks blower motors meet regulatory requirements. Visually inspect all chains and sprockets for wear or damage as per API SPEC 7F. Max 3% Enlongation. Visually check alignment of sprockets, bearings and shafts. Run drawworks to check for leaks of oil or water and check for excess vibration. Function in both low and high transmission and drum. Engage and disengage air clutches several times to verify that they will operate smoothly without slippage or overheating. Function all air controls at driller's station independently and check for leaks. Check all air connections and hoses for leaks. Check operation of air valves. Operate neutral brake. Inspect oiling system.

Recommendations

Note


Item # Inspection Requirement 1.7.15 Inspect grease system. Check spear connections to drum shaft and auxiliary 1.7.16 brake. Verify packing condition and check for leaks. 1.7.17 1.7.18 1.7.19 1.7.20 1.7.21 1.7.22

1.7.23 1.7.24 1.7.25 1.7.26 1.7.27

1.7.28

1.7.30 1.8 1.8.1

1.8.2

1.8.3 1.8.4 1.8.5 1.8.6 1.9 1.9.1 1.9.2 1.10 1.10.1

Findings

Inspect shift linkage. Inspect brake linkage. Check for excess play to insure linkage is not worn. Confirm tightness of brake lining blocks, bolts, and drum brake adjustment. Confirm safety pins and self-locking nuts are in place. Visually inspect drum grooving wear ring and kickback rollers. Function 'Crown-O-Matic' with blocks moving and determine if effective. Make-up and break-out cathead should be pull tested to make sure of sufficient line pull for all expected requirements. Make-up = 8,000# line pull, Break-out = 16,000# line pull. Inspect auxilary brake to drawworks coupling. Check brake and auxiliary brake alarms for proper operation. Check high temperature and low pressure alarms. Confirm calibration of temperature and flow gauges. Inspect drawworks brake cooling system; pumps, piping and valves. Confirm heat dissipation system (fan or heat exchangers) adequate and in good condition. Insure cooling water flow is adequate and meets manufacturer's specifications. Record DC drive motors insulation resistance. Auxiliary Brake, Electric Minimum insulation resistance to ground is 5 Meg Ohm per Baylor section 6.5.4. Coil resistance should be 5.5 Ohm to 6.5 Ohm for brakes 6032 and smaller. Larger brakes will be 12+ Ohm. It is important that readings all be close. Not some at 5.5 and others at 6.5. In addition same models can vary depending on date of manufacture. Consult Baylor service manual. Air gaps should be 0.040” to 0.050” for smaller brakes. 0.055” to 0.065” on larger brakes. Insure vents are operating properly. Confirm engagement lever is locked securely in place. Insure electric brake works properly and is adequate for drilling program. Sand Reel Check braking system. Note condition of line and line spooler.

Record date and results of last lube oil analysis. Operate rotary, while observing for noise, oil leakage 1.10.2 and vibrations. Use both high and low gears and reverse during this test. 1.10.3 Check for contaminants in lubrication systems. 1.10.4 Check operation of brake. 1.10.5 Check function of torque limiter and RPM gauge. Confirm ducting for rotary blower meets regulatory 1.10.7 requirements. 1.10.8 Record DC drive motor data in section 5.5. Visually inspect all chains and sprockets for wear or 1.10.9 damage as per API SPEC 7F. Visually check alignment of sprockets. 1.10.10 Record transmission to rotary coupling alignment. 1.11

Rotary Table Assembly

Drilling Line Anchor

Recommendations

Note


Item # 1.11.1 1.11.2 1.11.3 1.11.4 1.11.5

Inspection Requirement Record date of last NDE as per API RP 8B. Visually check all bolts. Inspect brass on tie-down clamp. Check sensator gap. Check weight indicator for smooth operation increasing and decreasing weight. Erratic operation could indicate dirty or damaged bearings.

1.12 1.12.1 1.12.2 1.12.3 1.12.4 1.12.5 1.13 1.13.1

Findings

Drilling Line Minimum standards should comply with API RP 9B. Note condition of drilling line. Record length of line on spool. Review slip and cut drilling line program. Examine condition of wire line guide and rollers. Driller's Console and Instrumentation Confirm equipment meets API RP 500 for hazardous areas.

Recommendations

Note


Item # 1.13.2 1.13.3 1.13.4 1.13.5 1.13.6 1.13.7 1.13.8

Inspection Requirement Conform proper operation of all installed instruments including the following: Weight Indicator Electric Torque Meter RPM meter SPM Meter Mud Flow Fill and Stroke Panel Pressurization Control Valves, Gauges, & Regulators

1.13.9 Mud Pit Volume Totalizer 1.13.10 Tong Torque Gauges 1.14 Confirm explosion-proof integrity of each indicator and 1.14.1 sending unit as per API RP 500 for hazardous areas. 1.15 1.15.1 1.16 1.16.1 1.17 1.17.1 1.17.2 1.18 1.18.1 1.18.2 1.19 1.19.1 1.19.2

Findings

Ton-Mile Indicator

Drilling Recorder Check operation and calibration of each function. Note condition. Rig Floor Hydraulic Power System Inspect power units, controls and piping with valves and record any deficiencies. Wire Line Unit Operate and record any deficiencies. Record size and length of .092 wire. Perform twist test on 10 inch section of wire. Minimum is 23 twists for standard strength .092 wire. Consult National Standard chart for other sizes or grades.. Cement Lines, (piping, hoses or chicksans) View documentation and record date of last inspection. Test to MWP. Hand Tools Is supply of hand tools adequate? Are tools stored and maintained properly?

Recommendations

Note


Section 2 Drill String and Handling Equipment Item #

2.1 2.1.1 2.1.2 2.1.3 2.1.4 2.1.5 2.1.6 2.1.7 2.1.8 2.1.9 2.1.10

Inspection Requirement Findings Recommendations As a minimum API RP 8B (section 2) Category IV recommends every five years; disassembly to extent necessary to conduct NDE of all primary load carrying components as defined by manufacturer. Owner or user of equipment should develop his own schedule of inspections based on experience, manufacturer's recommendations, and consideration for one or more of following factors: environment; load cycles; regulatory requirements; operating time; testing; repairs; re manufacture. Slips, Drill Pipe, Drill Collars and Casing Does rig have current copy of IADC Drilling Manual? Reference IADC drilling manual, Section E. Are handling tools marked with a unique ID number so equipment can be matched to documentation? Verify that appropriately sized slips are available for each size of drill pipe to be used. Clean and well-lubricated? General condition? Any obvious cracks, dings or deformation? Record date of last NDE for DP slips. Record date of last NDE for DC slips. Record date of last NDE for casing slips. Check slips for loose or worn hinge and handle pins.

2.1.11 All pins locked in place with cotter keys? 2.1.12 Check inserts and insert slots for damage or wear. Are spare sets of inserts, dies, liners, pins, and cotter 2.1.13 keys available? 2.1.14 2.1.15 Comment on condition and record last NDE. 2.1.16 Elevators, Drill Pipe, Drill Collar and Casing 2.1.17 Record date of last NDE on DP elevators. 2.1.18 Record date of last NDE on DC elevators. 2.1.19 Record date of last NDE on casing elevators. 2.1.20 Visually inspect elevators. 2.1.21 General condition? Clean, well maintained? Check ears, pins, bore, latch and latch lug for cracks, 2.1.22 dings, or excessive wear and proper operation. 2.1.23

Elevators (Air Operated)

Visual inspection, confirm proper operation and record 2.1.24 date of last NDE. 2.1.25 2.1.26 Comment on condition and last NDE. 2.2 2.2.1 Record date of last NDE as per API RP 8B. Did NDE include inspection of entire surface area of 2.2.2 links for cracks, bends, or gross dimensional changes?

2.2.3 2.2.4 2.2.5

2.4.1 2.5 2.5.1

Elevators, Spider, Casing Elevator Links

Did NDE include caliper diameters of links, particularly at link ear and elevator contact surfaces? Did NDE confirm elevator links are of same overall effective length within 1/8". Comment on overall condition. Tongs, Drill Pipe, Drill Collars and Casing (manual)

2.3 2.3.1 2.3.2 2.3.3 2.3.4 2.3.5 2.4

Slips, Spider, Casing

Record date of last NDE on DP tongs. Record date of last NDE on DC tongs. Record date of last NDE on casing tongs. Visually inspect and comment and condition. Record date of last NDE for tongs back-up posts. Tongs, Casing (Power) Visual inspection and operationally test and comment on condition. Safety Clamps Record date of last NDE.

Note


Item # 2.5.2 2.6 2.6.1 2.7 2.7.1 2.7.2 2.8 2.8.1 2.8.2 2.9 2.9.1 2.9.2 2.9.3 2.9.4 2.10 2.10.1 2.10.2 2.11 2.11.1 2.11.2 2.12 2.12.1 2.12.2

Inspection Requirement Findings Visually inspect clamps for cracks, missing cotter keys, galled or stripped threads, rounded-off nuts or wrenches, dull teeth, broken slip springs, and slips that do not move up and down easily. Spinning Wrench Pneumatic pipe spinner Operational test and comment on condition. Pipe Racking and Handling System Operate all functions of pipe handling and racking system. Note hydraulic leaks or other problems. Hydraulic Cathead (EZ-Torque) Record date of last NDE on EZ-torque mounting post. Verify unit works properly and will deliver required amount of line pull. Kelly Record date of last NDE. Inspect condition of kelly flat and roller contact interface over full length of kelly. Any cracks in junction between upsets and drive sections? Check width of wear pattern on contact angles for excessive wear or rounding. Kelly Drive Bushing Record date of last NDE on drive pins. Visual inspection, comment on condition. Master Bushings and Insert Bowls Record date of last NDE. Visual inspection, comment on condition. Upper Kelly Valve or IBOP Valve Record date and extent of last NDE. Open and close valve. Should work easily and smoothly.

Recommendations

Note


Item # Inspection Requirement Findings 2.12.3 Pressure test to 250 psi and MWP. 2.13 Lower Kelly Valve or IBOP Valve 2.13.1 Record date and extent of last NDE. Open and close valve with wrench. Should work easily 2.13.2 and smoothly. 2.13.3 Pressure test to 250 psi and MWP. 2.14 Rig Floor "Gray" Safety Check Valve Open and close valve. Should work easily and 2.14.1 smoothly. 2.14.2 Pressure test to 250 psi and MWP. 2.15 Rig Floor "Full Opening" Safety Valve Open and close valve with wrench. Should work easily 2.15.1 and smoothly. 2.15.2 Pressure test to 250 psi and MWP. 2.16 Drill Pipe and HWDP 2.16.1 Record date and results of last NDE. Visual spot check for galling, slip and tong damage, 2.16.2 damaged shoulders, etc. 2.16.3 Properly racked and stored? 2.16.4 Does rig have up to date inventory of tubulars? 2.17 Drill Collars 2.17.1 Record date and results of last NDE. Visual spot check for galling, slip and tong damage, 2.17.2 damaged shoulders, etc. 2.17.3 Properly racked and stored? 2.17.4 Does rig have up to date inventory of drill collars? 2.18 Drilling Subs and Crossovers 2.18.1 Record date and results of last NDE. 2.18.2 Properly stored? 2.18.3 Does rig have up to date inventory of subs? 2.19 Crossover for Rig Floor Stab-In Valves 2.19.1 Are they presant on rig floor? 2.20 Fishing Tools 2.20.1 Record date and results of last NDE. 2.20.2 Properly stored and identified? 2.20.3 Does rig have up to date inventory of subs? 2.20.4 Do fishing tools meet contract requirements?

Recommendations

Note


Section 3 Mud System Item # 3.1 3.1.1

3.1.2

3.1.3

3.1.4 3.1.5 3.1.6 3.1.7 3.1.8 3.1.9 3.1.10 3.1.11 3.1.12 3.1.13 3.1.14 3.1.15

3.1.16

Inspection Requirement If washed seat/module is a problem: Confirm minimum of 75% valve seat contact area. On initial installation of seat in module, measure clearance between bottom of seat and module shoulder, minimumby= testing, 0.090”. relief valves are set as near as Confirm possible to liner rating to avoid undue stress on modules due to valves popping off frequently. (Note: Some contractors will not want to set valves higher than about 3000 psi. That is their choice, record liner size, pressure rating and relief valve setting in daily report and trip report.) Record size of DC motor blowers, DC motor power is directly related to motor’s ability to stay cool. HT operations may require 15 HP blower motors. Record last NDE of rod ends, clamps, valve covers and threaded areas on modules. Record date and results of last lube oil analysis. Inspect fluid end internally. Check wear plate seal area prior to installation of new liners. Record pre-charge of discharge dampeners. It is normally 1/3 WP to 750 PSI max unless special bladders are used. Record pre-charge of suction dampeners. Inspect screen in mud pump discharge. Determine that mud pump lubrication system is adequate for long term slow pump rates. National manual page 11. Are auxiliary electric motors and pumps in good condition? Check operation and record pressure of charging pumps; note impeller size. Perform amperage test. Are charging pump motors in good condition? Pressure test HP valves and piping to MWP. Operate each mud pump under a load individually and together for one hour at a pressure equal to 80% of liner rating MWP. Normally choke manifold is required. Plan ahead on a jack-up since rig package normally needs to be cantilevered out to a drilling position. Engine performance will be reviewed at same time. Operation could take longer than one hour if problems are encountered, or extra time is required to evaluate equipment.

Check that both mud pump motors are pulling equivalent amperage. Review pump maintenance records on fluid and power 3.1.18 end to help identify any problems pump may have. 3.1.17

3.1.19 Record hours on pump modules. Visually inspect power end, (gears, sprockets and 3.1.20 chains). Check and record crosshead clearance in thousandths 3.1.21 of an inch. State in report if clearances are or are not within specification. 3.1.22 Pump 1 RH 3.1.23 Center 3.1.24 LH 3.1.25 Pump 2 RH 3.1.26 Center 3.1.27 LH 3.1.28 Pump 3 RH 3.1.29 Center

Findings Mud Pumps

Recommendations

Note


Item # 3.1.30

Inspection Requirement LH Check and record pinion bearing and main bearing 3.1.31 clearances in thousandths of an inch:

Findings

Pump 1 3.1.32 Pump 2 3.1.33 Pump 1 Ecc.Bearings RH 0.005 Center 0.003 LH 0.004 Pump 2 Ecc Bearings RH 0.005 Center 0.003-4LH 3.1.35 0.00 Check and record runnout on crosshead extension rods. 3.1.36 3.1.34

3.1.32

Is there a sufficient supply of expendable spare parts?

3.2

Mud Pits

Confirm customer criteria for this section and take time to inspect and test accordingly. Insure all valves work properly by testing. Denote all 3.2.2 valves that do not work properly, such as frozen or leaking. Determine useable tank volume in active and reserve 3.2.3 tanks. Fill each mud pit with sea water and check for leaks in 3.2.4 piping, valves, dumps and frames. 3.2.5 What pits can take flow line returns? Are lines and valves color-coded or otherwise 3.2.6 identified? Are low pressure gun lines operational and in good 3.2.7 condition? Is there a mud lab with appropriate mud analysis test 3.2.8 equipment? 3.2.9 Are padlocks on dump valves? Check ventilation system, ensure valves are working 3.2.10 properly in ventilation trunks. Especially HT wells. 3.2.1

3.3

Mud Mixing and Transfer System Perform following tests on all centrifugal pumps: Using amperage method where current drawn by a pump while pumping is compared with deadheaded 3.3.1 power requirement. A difference of at least 10% is required to indicate that impeller, wear plate, etc. are in good order. Use mixing pumps to transfer fluids to different pits 3.3.2 and determine rate of transfer. Determine that there are no valves leaking in mixing 3.3.3 system or on mud pits. Check condition of flexible couplings on low pressure 3.3.4 mud lines. Use mixing pumps to transfer through hoppers and 3.3.5 check capacity and suction capability of pumps and hoppers. 3.3.6 Record type and condition of hoppers. Check operation of pressure or flow monitoring devices 3.3.7 on low pressure mud lines. 3.3.8 Record discharge pressure of centrifugal pumps. 3.3.9 Is valving correctly marked from bulk tanks? Pump from mud pits to cementing unit and determine 3.3.10 rate of transfer. (Minimum 10 bbl/minute) 3.3.11 Transfer from mud pits to trip tank. 3.3.12 Transfer from mud pits to casing fill-up line. 3.4

Mud Shearing System

Recommendations

Note


Item # Inspection Requirement 3.4.1 Check operation of mud shearing system. 3.5 Check accuracy and operation of PVT system while 3.5.1 pits are full of water. 3.5.2 Is periodic testing done to confirm accuracy? 3.6 3.6.1 Operate all mud agitators. 3.6.2 Note any excess noise or vibration. 3.6.3 Check for oil leaks. 3.6.4 Are guards in place and properly secured? 3.7 3.7.1 Check shaker area for extreme noise and vibration. 3.7.2 3.7.3 3.7.4 3.7.5 3.7.6 3.7.7

3.7.8

3.8.2 3.8.3 3.8.4

3.9.2 3.9.3 3.9.4 3.9.5

Mud Pit Agitators

Mud Process Pits

Fill each mud pit with sea water and check for leaks in piping, valves, dumps and frames. Check for communication between tanks for valve integrity. Do all gates and valves work properly? Verify routing of piping to make sure solids control equipment and degasser will work properly by pumping through lines. If customer requires, provide schematic of system. If customer requires, conduct audit of solids control equipment system. Basic criteria is from IADC Mud Equipment Manual, Handbook 2, Mud System Arrangements. Object of exercise is to determine that equipment works properly and is adequate for drilling program. Shale Shakers Operate for a minimum of ½ hour and note any deficiencies. Immediately afterwards, check motors and bearings for overheating. Are screen tension bolts and rails in good condition? Evaluate overall condition and note any deficiencies.

3.9 3.9.1

Pit Volume Totalizer System

Determine useable tank volume in mud process tanks.

3.8 3.8.1

Findings

Desander Remove cones and visually inspect condition of cone body, vortex finder, inlet orifice, flow tube and header. Operate and note discharge pressure of pump. Are pumps and motors in good condition? Can unit be run by an alternate pump? Evaluate overall condition and note any deficiencies.

3.10

Desilter

Remove cones and visually inspect condition of cone 3.10.1 body, vortex finder, inlet orifice, flow tube and header. 3.10.2 Operate and note discharge pressure of pump. 3.10.3 Are pumps and motors in good condition? 3.10.4 Can unit be run by an alternate pump? Evaluate overall condition and note any deficiencies. 3.10.5 3.11 Remove cones and visually inspect condition of cone 3.11.1 body, vortex finder, inlet orifice, flow tube and header. 3.11.2 Operate and note discharge pressure of pump. 3.11.3 Are pumps and motors in good condition? 3.11.4 Can unit be run by an alternate pump? Operate for a minimum of ½ hour and note any 3.11.5 deficiencies. Immediately afterwards, check motors and bearings for 3.11.6 overheating.

Mud Cleaner

Recommendations

Note


Item # 3.11.7 3.11.8

Inspection Requirement Are screen tension bolts and rails in good condition? Evaluate overall condition and note any deficiencies.

3.12 3.12.1 3.12.2 3.12.3 3.12.4 3.12.5 3.12.6 3.12.7 3.13 3.13.1 3.13.2 3.13.3 3.13.4 3.13.5 3.14 3.14.1

Findings

Vacuum Degasser Inspect degasser internally and externally for excessive corrosion. Verify proper operation of vacuum pump. Check operation of fluid level control. Are degasser and mud/gas separators vented in a safe manner? Can unit be run by an alternate pump? Verify capacity of degasser. Evaluate overall condition and note any deficiencies. Poor Boy Mud/Gas Separator Inspect degasser internally and externally for excessive corrosion. Flush degasser with water. Are degasser and mud/gas separators vented in a safe manner? Determine size of gas vent line? Does it vent 10’ above derrick crown block? Height of mud seal? Mud Flow Line Return and Bell Nipple Evaluate overall condition and note any deficiencies.

3.14.2 Does flow-show work properly? 3.15 Measure and verify calibration of level indicator(s). 3.15.1 3.15.2 Transfer from mud pits to trip tank. Determine alternate means of filling hole should 3.15.3 primary trip tank pump fail. 3.15.4 Is pump and motor in good condition? Operate trip tank in normal fashion of usage. Note any 3.15.5 stiffness or error of level indicator. 3.15.6 Check for sea water fill up line to trip tank.

Trip Tank

Recommendations

Note


Item #

Inspection Requirement Does flow line gas vent to rig floor through mud bucket 3.15.7 return line? Is there a valve that can be closed during normal 3.15.8 drilling operations to prevent this? Is trip tank pump operated from driller's console only? 3.15.9 3.16 3.16.1

3.16.2 3.16.3 3.16.4 3.16.5

Findings

Bulk Storage and Transfer System Are all bulk storage tanks equipped with safety valves/rupture disks to prevent excessive working pressure? (Rupture disks can only be used for bulk storage in open areas.) Are testable safety valves used in enclosed areas for bulk storage tanks? Determine if relief valves are being serviced and tested on a regular basis. Record date of last inspection. Verify all bulk lines are clear including loading line, all transfer lines to surge pods and all related vent lines.

3.16.6 Are rock catchers installed in loading lines? Progressively pressure test bulk system, all lines, 3.16.7 valves, and pods to 40 psi with air (i.e., from pod to pod checking valves between each pod). 3.16.8 Check that fluffing system works properly. 3.16.9 Note any deficiencies of bulk transfer system. Determine rate of transfer while shipping cement to 3.16.10 pumping unit. 3.16.11 Verify ability/time to ship barite to cement unit. 3.16.12 Are bulk cement tanks common to other bulk tanks? 3.16.13 Does bulk tank weighing system work properly? 3.17 Stand Pipe Manifold, HP Mud Piping & Valves Pressure test stand pipe manifold and associated lines 3.17.1 and valves from mud pumps to TDS or swivel to MWP for 5 minutes with no leaks. Weld repairs and fabrications to be tested to 1.5 times 3.17.2 maximum working pressure as per ANSI B31.3, section 337.

Recommendations

Note


Section 4 Engine Room & Associated Equipment Item # 4.1 4.1.1 4.1.2


4.2.3 4.2.4 4.2.5 4.2.6 4.2.7 4.2.8 4.2.9 4.2.11 4.2.13 4.2.14 4.2.15 4.2.16 4.2.17 4.2.18 4.2.19

4.2.20 4.2.21

4.2.22

4.3 4.3.1 4.3.2 4.3.3 4.3.4 4.3.5 4.3.6 4.3.7 4.4 4.4.1 4.4.2 4.4.3 4.4.4 4.4.5 4.4.6 4.4.7 4.4.8

Recommendations

Inspect ventilation ducting louvers. Are they manual close or automatic close with actuation of fire suppression system? Is system balanced? (E.R. should have slight positive pressure) Main Diesel Engines(Third Party inspection by WARTSILA attached)

4.2 4.2.1 4.2.2

Findings Engine Room Ventilation System

Start system type? Pre-lube system type? Check turbochargers or blowers for excessive wear and noise. Check flywheel drives for excessive wear and condition. Ensure coupling guards are adequate. Check for external leaks of oil, fuel, water and exhaust gasses. Check for indications of internal leaks of fuel or water. Check that fuel lines are properly bracketed and isolation valves are installed. Test run engines under load if possible. Monitor for vibration and excessive noise. Monitor exhaust emission with load changes. Review maintenance history and oil sample data. Record total hours on all main engines. Check maintenance records for last overhaul on each engine. Are any engines due an overhaul during contract period? Test alarms, shutdown and over-speed trip. Visually inspect and test governors. Operate under various load conditions and check load sharing. Visually inspect wiring and connections. Observe for damage at engine mounting points. Examine engine before and during operation for oil and exhaust leaks. Review pyrometer readings for engine exhaust. Diesel engine air intakes shall be equipped with a device to shut down diesel engine in event of a runaway. Diesel engines which are not continuously attended must be equipped with automatic shutdown devices Engine Instruments Speed indicator. Oil pressure and temperature. Water temperature. Fuel pressure. Inlet manifold temperature. Exhaust manifold temperature. Air filter condition indicator. Main Diesel Engine Cooling Engine cooling type, radiators or heat exchangers? Cooling system individual or thru manifold Disassemble and inspect engine cooling system heat exchangers for corrosion and fouling. Check condition of sacrificial anodes. Check salt water supply and discharge isolation valves. Is cooling water available from independent sources? Inspect samples of engine coolant. Is there a low pressure alarm on cooling water for heat exchangers? Date and extent of last overhaul for engine cooling or sea water pumps.

Note


Item # 4.5 4.5.1 4.5.2 4.5.3 4.5.4 4.5.5 4.5.6 4.5.7 4.6 4.6.1 4.6.2 4.6.3 4.6.4 4.6.5 4.7 4.7.1 4.7.2 4.7.3 4.7.4 4.7.5 4.7.6 4.7.7 4.7.8 4.8 4.8.1 4.8.2 4.8.3 4.8.4 4.8.5 4.8.6 4.8.7 4.9 4.9.1 4.9.2 4.9.3 4.9.4 4.9.5 4.10 4.10.1 4.10.2 4.10.3 4.11 4.11.1 4.11.2 4.12 4.12.1 4.12.2 4.12.3 4.12.4


Findings Engine Monitoring System Alarms

Verify proper operation of the following alarms: Low oil pressure. High water temperature. Overspeed. Low pressure on cooling water for heat exchangers. High crankcase pressure. Fuel Transfer and Cleaning General Check lines for leaks. Ensure drive coupling is guarded. Check that flange type connections are fitted with ground straps across joints. Check that discharge lines are clearly marked as to service function. Are pump areas fitted with spill containment and return line(s) to holding tank? Fuel Transfer Pump Is there more than one (1) transfer pump? Check to see if an emergency shut-down is installed. Check for fuel leaks on pump and lines. Are pump areas fitted with spill containment and return line(s) to holding tank? Are lines clearly marked as to their function? Are isolation valves installed and functioning? Can bunkered fuel be pumped to mud pits and cement unit direct? If fuel is piped to mud pits, has positive isolation been provided to prevent inadvertent mud contamination? Clean Fuel Transfer Pump Is there more than one (1) transfer pump? Check to see if an emergency shut-down valve is installed. Check for fuel leaks on pump and lines. Are pump areas fitted with spill containment and return line(s) to holding tank? Are lines clearly marked as to their function? Are isolation valves installed and functioning? Can clean fuel be pumped to mud pits and cement unit direct? Is isolation provided? Fuel Centrifuge Is unit set up as a purifier or centrifuge? Check bowl retainer ring and threads for wear. Test run and monitor for vibration. Check to see if unit purifies when transferring from bunkered fuel to day tank. Are pump areas fitted with spill containment and return line(s) to holding tank? Fuel Piping and Valves Check for line and valve leaks. Check that lines and valves are clearly marked. Check that a line schematic is posted at all transfer pumps. Lube Oil Piping and Valves Check lines and valves for leaks. Check lines for proper markings. Potable Water Makers and Purification Ensure that all rotating equipment guards are installed. Ensure that all appropriate warning signs are posted such as 'Hot Surfaces', 'Steam Under Pressure', and 'Acid In Use'. Ensure that adequate protective equipment is available and in use. Ensure that acids have a proper storage facility.

Recommendations

Note


Item # 4.12.5 4.12.6 4.12.7 4.13 4.13.1 4.13.2 4.13.3 4.13.4 4.13.5 4.13.6 4.13.7 4.13.8

Inspection Requirement Check for an eyewash station and first aid kit stationed in vicinity of water maker. Check operation of chemical injection system.

Findings

Determine if brine waste lines which are direct discharge to sea are fitted with check and isolation valves and record date of last inspection. Water Purification and Treatment Ultraviolet Purification System Check that all ultra violet tubes are lighted. Determine if protective glass is clean on all water contact surfaces. Record hours in service on the tubes. Check unit for leaks and general condition. Is a bypass manifold in system to allow for service? Chemical Injection/Purification System Check that acid warning signs are posted and adequate protective equipment is available and in use.

Does system run all the time or does it have an automatic function? 4.13.10 Determine type of chemical injection system in use. Operate and determine quantity and rate of injection. 4.13.11 4.13.9

4.14 4.14.1 4.14.2 4.15 4.15.1 4.15.2 4.15.3 4.15.4 4.15.5 4.15.6 4.15.7 4.15.8 4.15.9 4.15.10 4.15.11 4.15.12 4.15.13 4.15.14

Potable Water Transfer Pumps and Pressure Reservoir Quantity? Does pressure reservoir have a relief valve fitted and venting in a safe manner? Rig Service Air System Air Compressors Record date of last inspection for relief valves, unloader valves, and over temp shut downs. Are relief valves of adequate capacity and vented in a safe manner? Are 'Danger - Automatic Start', 'High Temperature' and 'High Pressure' signs posted? Are couplings and belts properly guarded? Verify proper operation of instrumentation. Are isolation valves installed? Operate compressors and observe for overheating. Record date of last inspection of air/oil separator. Is high temp synthetic oil used in compressors? What is output rate of compressors? Are moisture separators and automatic dumps installed? What are unload and reload pressure settings? Operate cold start compressor to verify proper operation.

4..16 4.16.1 4.16.2 4.16.3 4.17 4.17.1 4.17.2 4.17.3 4.17.4 4.17.5

Air Dryers Is air dryer and its instrumentation working properly? Are they desiccant or refrigerant type? Are automatic moisture dumps installed and operational? 4.17 Air Receivers Record date of last pressure vessel inspection. Record date of last hydrostatic test. Record date and results of last wall thickness examination. Record designed MWP and temperature if applicable. Are relief valves of adequate capacity and vented in a safe manner?

Recommendations

Note


Item # 4.17.6

4.17.7

Inspection Requirement Record date of last relief valve testing. API 510 Section 6 rules apply to drilling vessels. Relief valve testing need not be done by third party. Repairs must be by third party. Are automatic moisture dumps installed and operational?

4.18 4.18.1

4.18.2 4.19 4.19.1 4.19.2 4.19.3 4.19.4 4.19.5 4.19.6 4.19.7 4.19.8 4.19.9 4.20 4.20.1 4.20.2 4.20.3 4.20.4 4.20.5 4.20.6

Findings

Bilge Monitor Note operating condition and record any deficiencies. Interview responsible party and determine how oily bilge is handled. Is described procedure in compliance with guidelines in environmental criteria? Sewage Treatment System Type and capacity. How is effluent monitored? Review test records. Sewage Holding Tanks Is unit fitted with independent aeration pump or does it use rig air? Level alarms? Treatment Units Is the enzyme or chlorine feeder manual or automatic? Record last test or inspection. Determine age and condition of cell on electro-catalytic units. Pumps Drill Water Transfer Pump Note operating condition and record any deficiencies. General Service Pump Note operating condition and record any deficiencies. Main Circulation Pump/Raw Water Pump Note operating condition and record any deficiencies.

Recommendations

Note


Section 5 Electrical Systems Item #

Inspection Requirement Findings Recommendations Offshore systems to be inspected for compliance with API RP 14F. Classified zone minimum compliance standard is API RP 500. Main and Emergency AC Generator Switchboards

5.1 5.1.1

5.1.2

5.1.3 5.1.4 5.1.5 5.1.6 5.1.7 5.1.8 5.1.9 5.1.10 5.1.11 5.1.12 5.1.13 5.1.14 5.1.15 5.1.16 5.1.17

Conduct visual inspection of breakers, wiring and buss works. Note deficiencies. Review PM history and record last inspection calibration or test date for metering. Record last date of current injection for main breakers and IR survey of buss works. Confirm installed metering and protective devices. Note deficiencies. METERING Voltage * Ampere * KVAR KW Running Hours Syncroscope Power Factor ** * = Selectable for three phase monitoring. ** = Installation is optional for parallel operation PROTECTION Control voltage required to be 120 volt AC or less. Overload Short Circuit Reverse Power Under Voltage

5.1.18 5.1.19 5.1.20 5.1.21 5.1.22

Under Freq. Over Voltage Ground Fault Diff. Current * Overcurrent * * = Additional devices required for greater than 600 5.1.23 volt or 1000 KVA 5.2 Record insulation readings on stator and rotor and excitation systems. Perform visual inspection and 5.2.1 note condition of each unit. 2 M W minimum per API RP 14F. Test with 600 volt minimum. Include the following elements in inspection: 5.2.2 RESISTANCE 5.2.3 Stator 5.2.4 Rotor 5.2.5 Exciter 5.2.6 CONDITION 5.2.7 Wiring 5.2.8 Bearings 5.2.9 Cleanliness 5.3 5.3.1 Do all AC motors have earthling straps? Conduct random check of insulation resistance for 5.3.2 motors under 15 HP. Record findings below. Conduct visual inspection, operational tests and resistance check for all motors above 15 HP. Record 5.3.3 findings for motors found not satisfactory. Include the following elements in inspection: 5.3.4 5.3.5 5.3.6 5.3.7 5.3.8 5.4 5.4.1 5.4.2 5.4.3 5.5 5.5.1 5.5.2 5.5.3 5.5.4 5.5.5

Generators

AC Motors

Resistance Wiring Vibration Seal leakage Guards and foundation. Power Transformers Record insulation resistance reading of transformers. Perform visual inspection if rig is in operation. Check that guards are in place and air flow is adequate. Inspect metering and ground fault systems. Record last testing or inspection. DC Drive Motors Do all motors have earthling straps? Review PM history. Conduct visual inspection, operational tests and resistance checks for all DC motors. Record non conformance findings. Include the following elements in inspection: Armature MW Field

Note


5.5.6 5.5.7 5.5.8 5.5.9 5.5.10 5.6 5.6.1 5.6.2 5.6.3 5.6.4

MW Comm. Condition of brushes & rigging Heaters Blower & filter Safety devices D.C. Generators(Not Applicable) Perform visual inspection. Note condition of all PC boards, control transformers, air flow safety devices, starters, contactors and relays. Inspect metering, volt, ampere and ground detection systems. Perform visual inspection of Buss bars and infra-red survey, if requested. Check redundancy for all drilling equipment. Run all drilling equipment . Main and Emergency Distribution AC Switchboards

5.7 5.7.1 5.7.2 5.7.3 5.7.4

Perform visual inspection of all breakers, motor starters, and associated wiring. Record Buss resistance to ground, if operation permits. Inspect metering and ground detection system. Record last calibration or test date. Review PM history. Make random checks of starter coils and contacts, local and remote start-stop stations. Note unacceptable findings. Wireways, MCT’s, Bulkhead and Deck Penetrations

5.8 5.8.1

Visually inspect for compliance with API RP 14F. Note any deficiencies.

5.9 5.9.1 5.10

Visually inspect system.

Shore Power Connection System Welding Outlets

Visually inspect all remote outlets. Confirm wire size of 3/0 or larger. 5.10.2 Test remote shut down system. 5.11 5.11.1 Confirm lighting adequate for operations. Note general condition of fixtures and check for 5.11.2 presence of safety cables. Check for non-approved fixtures in classified zones. 5.11.3 5.10.1

5.12 5.12.1 Visually inspect. 5.13 Visually inspect for proper operation of lights, remote 5.13.1 controls and alarms. 5.14 Visually inspect lighting for broken or cracked lenses 5.14.1 and operation of flood light dimming system for night helicopter landings. 5.15 5.15.1 Confirm proper operation. 5.16 Confirm system adequate for proper rig 5.16.1 communications. Check for proper operation under drilling conditions. 5.16.2 5.16.3 Assure system clear of electrical interference. Confirm protected systems available in high noise 5.16.4 areas. 5.17 Confirm proper operation of any installed closed 5.17.1 circuit TV systems. 5.18 Test emergency power system. Simulate failure of main power plant. Determine if emergency plant will 5.18.1 start and pick up the emergency load automatically. Emergency generator should start and load within 45 seconds. Confirm that emergency generator can start on 5.18.2 compressed air and by battery power. Verify proper operation of meters, gauges, alarms and 5.18.3 engine safety devices. 5.18.4 5.18.5 5.18.6 5.18.7 5.18.8

Verify that emergency power can be fed back to main panel. Emergency power automatically supplied to following equipment: General alarm. Emergency lights. Navigation lights.

General Rig Lighting and Wiring

Aircraft Warning Lights Navigation and Running Lights

Helicopter Area Lighting

Sound Powered Telephone Rig Telephone and PA System

TV Systems

Emergency Generator


5.18.9 5.18.10 5.18.11 5.18.12 5.18.13 5.18.14 5.18.15 5.18.16 5.18.17 5.18.18

Bilge pump to drain each water-tight compartment. One fire pump. Fire detectors and alarms. Gas detectors (Combustible and H2S detectors). Helicopter deck lights. Communications. Electric BOP controls. Abandonment system. One air compressor One engine cooling pump


Section 6 Marine System Item # Inspection Requirement Findings Recommendations 6.1 Marine Documentation 6.1.1 Review all marine and vessel documentation. Confirm compliance with vessels flag and classification requirements. 6.2 Manufacturer's and Third Party Documentation 6.2.1 Review manufacturer's documentation (Wire rope certs., chain fall inspection certs., etc.) 6.2.2 Review third party inspection documentation (MPI, Underwater surveys, etc.) 6.3 Navigation and Communications Equipment 6.3.1 Confirm availability of all communications equipment required by vessels governing authorities. Included items cover the following: 6.3.2 Distress Watch Transceiver (2182 KHZ) 6.3.3 Satellite Communication System 6.3.4 Single Band Radio/Radio Telephone 6.3.5 VHF Radios 6.3.6 Lifeboat Radio 6.3.7 Walkie-Talkie Units 6.3.8 Helicopter Homing Beacon (Non-Directional Beacon NDB) 6.3.9 Satellite Navigation System 6.3.10 Radio Direction Finder 6.3.11 Emergency Position Indicating Radio Beacon (EPIRB) 6.3.12 Current Meter 6.3.13 Surface Monitor and Control 6.3.14 Visually inspect antennas. Assure non-interference with rig operations. Pay close attention to temporary third party installations. 6.3.15 Verify proper operation of installed radar, GPS, LORAN, and other navigational systems. 6.4 Storage Areas 6.4.1 Confirm storage areas comply with requirements listed in section 33, Storage Rooms of OAS safety survey. 6.5 Fuel Tanks 6.5.1 Confirm hydrocarbon storage complies with requirements. 6.6 Ballast Control System 6.6.1 Watertight doors and windows in good working order? 6.6.2 Normal ballast controls in good working order? 6.6.3 Normal and emergency ballast control procedures documented and readily available? 6.6.4 Review emergency ballast control procedures. 6.6.5 Review PM history as related to ballast control systems. 6.6.6 Perform visual inspection of pump rooms; observe operation of associated equipment. 6.6.7 Record date and results of last inspection by regulatory bodies or certifying authorities. 6.7 Stability 6.7.1 Review source of present lightship weight and center of gravity (CG) used in daily stability calculations, as well as any changes to lightship since last inclining or deadweight survey. 6.7.2 Lightship database on last inclining test is as follows: 6.7.3 6.7.4 6.7.5 6.7.6 6.7.7 6.7.8 6.7.9

Date of last inclining test or deadweight survey Lightship Weight in tons Lightship (LCG) feet aft or fwd of amidships Lightship (TCG) feet starboard or port of centerline Lightship (VCG) feet above baseline (bottom) The net weight of all additions and removals from lightship weight since last inclining test is: Net weight (addition/removal) in tons

Note


Item # Inspection Requirement 6.7.10 Longitudinal Center (LCG) feet aft or fwd of amidships 6.7.11 Transverse Center (TCG) feet starboard or port of centerline 6.7.12 Vertical Center (VCG) feet above baseline 6.7.13 Review stability and layout instructions included in operating manual and any other stability guidelines that may be available. Check daily stability calculations. 6.7.14 Do they include calculated displacement, and displacement from drafts? 6.7.15 Do they include both actual VCG (corrected for F.S.) and maximum allowable KG (for draft)? 6.7.16 Do they include a three-dimensional calculation at least weekly? 6.8 6.8.1 Observe and report general condition.

6.9 6.10 6.10.1 6.10.2 6.10.3

Cathodic Protection (Anodes) Exhaust Stacks General condition? Condition of mufflers? Does age of vessel indicate possible presence of Asbestos Containing Materials (ACM)? Pre 1984 construction is presumed to have ACM unless otherwise documented.

6.11

Hatches, Windows, Manholes, Openings and Coamings Check doors and hatches for proper closing and seal.

6.11.1 6.11.2 6.11.3 6.11.4 6.11.5 6.12 6.12.1 6.12.2 6.12.3 6.13 6.13.1 6.13.2 6.13.3 6.14 6.14.1 6.15 6.15.1 6.15.2

6.16 6.16.1 6.16.2 6.16.3 6.16.4 6.17

Findings

Recommendations

Hull

Dogs and seals are present, operational,and in good condition? Deadlights for windows are readily available, fit properly and suit purpose? Hatches, manholes, and openings are guarded when open? Coaming drain holes or cleanout openings normally remain closed when not in use for purpose? Walkways/Platforms Condition of grating, foundations, and handrails? Slip resistant material present and in acceptable condition? Housekeeping? Superstructures General appearance? Note visible repairs and structual changes in progress? Note last classification inspection or NDE surveys? Helicopter Deck / Fueling Station Confirm that Heliport and fueling facilities comply with section 18, HELIPORT in OAS Safety Survey. Anchor Racks Note last MPI or NDE inspection and results? Visually inspect for defects, cracks, or broken members and excessive wear from wire or chain rub. Weather Protection Inspect gear and procedures for heavy weather and hurricane/typhoon evacuation. Deadlights for accommodation windows. Verify chain, wire rope, soft line, shackles, boomers, etc. are readily available. Review inclimate weather and evacuation procedures and contingency plans. Ventilation (Accommodations and Rig Area Compartments)

Note


Item # 6.17.1 6.17.2 6.17.3 6.17.4 6.17.5 6.18 6.18.1

Inspection Requirement Free operation of flappers? Seal floats and screens? Fans? Ductwork? Shutdowns and alarms?

6.18.2

Compare manual tank soundings with remote tank gauges, if installed.

6.19 6.19.1 6.19.2 6.19.3 6.19.4

6.20 6.20.1 6.20.2 6.21 6.21.1 6.21.2 6.21.3 6.21.4 6.21.5 6.21.6 6.21.7 6.21.8 6.22 6.23 6.23.1 6.23.2 6.23.3 6.23.4 6.23.5 6.24 6.24.1 6.25 6.25.1 6.26 6.26.1 6.26.2 6.27 6.27.1

6.28 6.28.1 6.28.2 6.28.3 6.29 6.30 6.30.1 6.31 6.31.1

6.31.2

Findings

Tank Gauging System Take manual soundings for all tanks and void spaces.

Tank Vent and Sounding Tube System Means of plugging vents if needed? Are spark arrestor and pollution screens present on hydrocarbon tanks? Sounding tubes have spring closures and cap closures? Is distance from top of sounding tube and bottom of tank known to get accurate soundings. Are distances marked in area of sounding tube? Bilge Piping and Valves Note deficiencies. Mooring System General Moving machinery/gears properly guarded? Motors sealed or covered? Electrical equipment/cables in good condition? Dogs in good condition? Permanent wires properly stored and lubricated? Mooring bits, cleats, padeyes, fairleads and rollertype chocks in good condition? Controls properly labeled? Hydraulic hoses, fittings and shafts in good condition? Mooring Winch/Windlass Combination Mooring System Control Check motor amps under various loads. Observe clutch and gear movements for operation. Observe pawls or ratchets for proper engagement. Check wire level winds on drums for operation and adjustability. Confirm proper storage of wire on drums. Primary and Auxiliary Brake System Band brakes set properly and work properly. Controls, Piping, and Valves Check piping and valves for proper alignment and leaks. Emergency Release System Check each windlass/winch for proper operation. Activate and test emergency release system. Mooring Tension Indicating System Confirm that mooring Line Tension meter is properly calibrated. Check against motor amps and amps/tension chart. Tow Line/Bridle Inspect chain, jewelry and wire rope as per API RP 2I. Review last MPI or NDE of fishplates brackets, guides, and connection points. Inspect retrieval system, including winches, wire rope, connectors, etc. Emergency Tow Line Work Boat Back-down/Tie-up System Comment on condition. Anchors Check anchor bolts for tightness and assure retainer plates are correct and in place. Replace any missing bolts or plate. Confirm records on MPI of anchor shackle.

Recommendations

Note


Item # Inspection Requirement Findings Recommendations 6.31.3 Check fluke angle for operational needs. 6.32 Fairleader 6.32.1 Check all fairleads for proper operation (look for binding, not rolling, and easy swivel). 6.33 Mooring Wire 6.33.1 Reference API RP 21 - Recommended Practice for InService Inspection of Mooring Hardware for Floating Drilling Units. 6.34 Pendant Lines 6.34.1 Check all rig pendants for breaks, corrosion, wear, and proper lubrication. 6.34.2 Verify that all pendant jewelry is of forged construction. 6.34.3 MPI inspect all pendant jewelry. (Could be review of records and certs.) 6.35 Chain Link, Kenter/Connecting Links and Shackles 6.35.1 6.35.2 6.36 6.36.1 6.36.2 6.36.3 6.37 6.37.1 6.37.2 6.38 6.38.1 6.38.2 6.38.3 6.38.4 6.38.5 6.38.6 6.38.7

6.38.8 6.38.9 6.38.10 6.38.11 6.38.12 6.38.13 6.38.14

6.38.15 6.38.16 6.38.17

6.38.18 6.38.19

6.38.20

Verify that all shackles, swivels, and other jewelry are of forged construction. MPI inspect all shackles, swivels and other mooring jewelry which are currently accessible. Buoys Inspect buoys for holes, tears, deterioration that may cause leaking. Determine suitability for purpose. Inspect buoy lights for operation and full battery charge. Slings and Shackles Report on documentation and inspection schedule. Report on condition. 6.38 Cranes Controls properly labeled? Load moment and load indicator in good condition? Fire extinguishers provided? Hand signals posted? Moving machinery properly guarded? Boom angle indicator and stops provided? Boom structure in good condition and free of corrosion? Lower boom to horizontal position and line it up with a handrail or something else horizontal to check for a bent boom. Visually inspect for cracks or other boom damage. "Anti-two block" device provided? Personnel baskets in good condition? Back-up safety wire required between basket and hook? Drip pan provided to contain fuel/lubricant leaks? Review and record last load test. Review and record data and date on change out of boom, load lines, and pendants. Wire ropes and pendants in good condition? Inspect, measure and caliper wire as per API RP 2D. Check for reduction of rope diameter, broken or worn outside wires, corroded or cracked end connections or severe kinking or unstranding of wire. Recommend to change wire rope if measured specifications are not acceptable. Visually inspect and function sheaves, drums, clutches, brake system, gear boxes. Inspect boom sheaves for free rotation, cracks and excessive wear. Inspect shaft retainers for wear or damage. Inspect wire rope roller guides for free rotation and excessive wear. Inspect A-frame sheaves for free rotation, cracks and excessive wear. Inspect shaft retainers for wear or damage. Are boom and pedestal flood lights operational?

Note


Item # Inspection Requirement 6.38.21 Inspect main and whip load hooks for damage and missing locks. 6.38.22 Inspect split headache ball, pin and nut for any excessive wear or damage. Is split pin properly located and undamaged. 6.38.23 Verify proper operation of controls and/or remote controls. 6.38.24 Verify limit switches and load indicators are working properly. 6.38.25 Visual inspection of slip ring assembly. 6.38.26 Date and details of last grease analysis. 6.38.27 Start engine and check out all functions in cab, water temp gauge, oil pressure gauge, windshield wipers, heater, horn radio and PA system. 6.38.28 Check all crane conditions with operator and ensure he is satisfied with complete control system. 6.38.29 Can all third party equipment be mobed and demobed with rig cranes? 6.38.30 Are all problems resolved from mechanic’s reports. 6.38.31 6.38.32 6.38.33 6.38.34 6.39 6.39.1 6.39.2 6.39.3 6.39.4 6.39.5 6.39.6 6.39.7 6.40 6.40.1 6.40.2 6.40.3 6.40.4 6.40.5 6.40.6 6.41 6.41.1 6.41.2 6.41.3 6.41.4 6.42 6.42.1 6.43 6.43.1 6.43.2 6.43.3 6.43.4 6.44 6.44.1 6.44.2 6.45 6.45.1 6.45.2 6.46 6.46.1 6.46.2 6.46.3 6.46.4

Findings

Remove airbox covers and inspect for worn, broken or stuck piston rings. Check injector spray pattern on piston crowns. Check all engine filters for leaks. Check airbox drain tubes with engine running. Billy Pugh Transfer Net (Personnel) General condition? Properly stored when not in use? Life vests or jackets available for use? Is personnel net being used to lift materials or supplies? Is safety line attached above crane ball when in use by personnel? Is tag line attached and used? Is spare net available? Air Hoist (Tuggers) Wire rope in good condition and well lubricated? Wire properly stored on drum? Date of installation and last inspection? Properly marked? Brakes adjusted properly? Oil levels normal and maintenance up to date? Man-Riding Tuggers Same inspection as Air Hoist (Tuggers) Deadman type controls installed on tugger. Properly marked for man ridding? Good visual contact and hand signals between ridder and man on controls? Fork Lift/Pallet Lift General condition and maintenance records? Mechanical Winches Visually inspect. Review records and documentation. Condition of wire rope? Well lubricated? Proper markings, including SWL? Chain Falls Visually inspect. Review records and documentation. Cargo Containers (Box, Net, Cargo Basket, Burn Baskets) General condition? Proper markings? Hoses - Bulk Mud, Water and Oil General housekeeping at loading stations? Condition of hoses? Hoses suited for purpose and properly marked? Check for leaks during use? Date of last pressure testing?

Recommendations

Note


Item # Inspection Requirement Findings 6.46.5 Condition of fittings and properly fitted and secured in hoses? 6.46.6 Amount of spares and crossovers available and condition of same. 6.47 Quarters, Shop Furnishings and Equipment 6.48 Inspection 6.48.1 Perform visual inspection of living quarters, galleys, laundry facilities. 6.48.2 Perform visual inspection of heating, air conditioning, and refrigeration systems; review PM history. 6.48.3 Determine square feet of office space, type of power available, and number of power outlets. 6.48.4 Record condition and type of communication equipment available. 6.48.5 Determine type and frequency of pesticides used. 6.48.6 Does current program appear to be adequate? General Accommodation Room Inspection 6.49 Air Conditioning System (Main Quarters) 6.50 Galley Exhaust(s) 6.51 Quarters' Ventilation System 6.52 Fans 6.53 Ducting 6.54 Refrigeration Compressor System 6.55 Walk-in Coolers 6.56 Walk-in Freezer 6.57 Air Conditioning Pump/Brine Pump (with motor) 6.58 6.59 Welding and Burning Practices, Procedures and Equipment 6.59.1

Confirm welding and cutting practices meet standards outlined in section 36,Welding and Burning of OAS safety survey.

Recommendations

Note


Section 7 Third Party Equipment Item # Inspection Requirement Findings 7.1 Cementing System 7.1.1 Manufacturer of cement unit? 7.1.2 Verify no leaks on the liquid additive system, fill with water if required. 7.1.3 Cement pump drive unit, diesel or electric? 7.1.4 Cement mixing pump (with motor)? 7.1.5 Cement room controls? 7.1.6 Cement recirculation mixing unit? 7.1.7 Cement suction/mixing, discharge hose and piping with valves? 7.1.8 Test swivel joints (chiksans) and cement hose to MWP and record for five (5) minutes. 7.1.9 Test pumps, manifolds and valves to 250 PSI and 10,000 PSI, record for five (5) minutes each. 7.1.10 Verify proper operation of chart recorders. 7.2 7.2 Well Test Piping and Valves 7.2.1 High-pressure lines secured/anchored? 7.2.2 Flare line(s) secured/staked? 7.2.3 Flare lines extended minimum 150' from well; pilot light when potential for gas exists? 7.2.4 Ensure air supply for burner booms is not connected to rig air supply. 7.2.5 Is water spray system adequate? 7.3 7.3 Burners 7.4 7.4 Burner Booms

Recommendations

Note


Section 8 Motion Compensating Equipment Item # 8.1 8.1.1

8.1.2 8.1.3 8.1.4 8.1.5

8.1.6 8.1.7 8.1.8 8.1.9

8.1.10


Findings Riser Tensioners, General

Is a program in place to have the system relief valves bench tested and certified on an annual basis. (USCG requires an annual bench test of all relief valves) Record date of last inspection on APVs and relief valves. What did the inspection consist of? Inspect wire rope for signs of broken strands. Is a cut and slip program in place which determines frequency from ton-cycle exposure. Review the cumulative current ton-cycle values for compliance to the program. Note condition and length of spare tensioner wire stored on drums. Visually inspect sheaves for cracks, wear and alignment. Check tensioner and idler sheaves for wear with a sheave groove gauge. Are sheaves free and do they swivel properly? Perform a system pressure test of the tensioners to maximum anticipated system pressure + 20% or to system maximum rated working pressure with the tensioner cylinders fully stroked out. Inspect tensioner rods for signs of damage, peeling chrome, pitting , or indentations. Check oil levels before and after pressure testing. This will check integrity of HP packing.

Hold pressure for 12 hours and record pressure loss, 8.1.11 check for leaks at gland packing area, and note location of any air and oil leaks. 8.1.12 Note type of fluid in tensioners. 8.1.13 Is there indication of oil leakage? Date of last fluid samples for analysis? Record results, 8.1.14 water content, contamination, etc. Is a plan in place to determine or calculate riser tension 8.1.15 requirements. 8.2 8.2.1 Relief valves set at 2400 psi. MWP is 2260 psi. Check fluid level in high pressure accumulator bottles. With bottle bled down and relief valve removed, from 8.2.2 the coupling down to the fluid level should be 35-40 inches. Check the fluid level in the air/oil reservoir with rod retracted into cylinder, oil level should be at lower sight glass. For proper operation of the speed limiting 8.2.3 orifice and rod end hydraulic cushion, proper air/oil fluid levels must be maintained. 8.3

Shaffer Riser Tensioners

Guide Line, Pod/Messenger Line Tensioners Relief valves set at 1900 psi. MWP is approximately 1700. All rod end down (RED) guide line tensioner must have the hose in place from the end of the rod to the 8.3.2 air/oil reservoir. This is required to purge trapped air on the low pressure side of the cylinder under the piston. 8.4 Motion Compensator, General Confirm a program is in place to have the system relief 8.4.1 valves bench tested and certified on an annual basis. 8.3.1

8.4.2 Record date of last relief valve inspection.

Recommendations

Note


Item # 8.4.3

8.4.4 8.4.5 8.4.6 8.4.7 8.4.8 8.4.9 8.4.10 8.4.11 8.4.12 8.4.13 8.4.14 8.4.15 8.4.16 8.4.17 8.4.18 8.4.19 8.5

Inspection Requirement Perform a system pressure test of the compensator to MWP to confirm integrity of piping, hoses, cylinders and packing. Ensure lockbar is engaged in case of hose failure. Inspect compensator rods for signs of damage, peeling chrome, pitting , or indentations. Inspect the lock bar to determine if the safety stop will prevent unintentional disengagement. The lock bar lock/unlock position should be remotely indicated on the Driller’s console. Check DSC position indicator for proper operation. Are the compensator hoses properly bundled and protected to prevent snagging on the derrick. Check the guide dolly for loose or missing wheels Check compensator wheel alignment. Activate motion compensator to verify proper operation. Check driller's console for leaks. Perform visual inspection of compensator, control system high pressure air compressors, and relief valves. Report on condition of system hydraulic pumps. Verify proper operation of gauges, lock mechanism and indicator, and position indicator. Sample system fluid and check for contamination. Are adequate spares available on board? Condition of deceleration valves? Pre-charge of deceleration accumulator?

Findings

Shaffer Compensator

Recommendations

Note


Item #

Inspection Requirement Relief valves should be set at 2400 psi. MWP is approximately 2260 psi. Ensure all personnel are aware of test and clear of area. Test system and hoses 8.5.1 for 6 hours. Since this test precludes personnel working on rig floor. A minimum of one hour is required if operations will not permit a full test.

Findings

With at least 200 psi extending the cylinders, check each chain for wear and even tension. Document any chain wear damage to the main frame. Review this damage with Shaffer engineering to obtain a disposition for corrective action. No welding should 8.5.3 ever be performed on the main frame or hook frame plates (T-6 material). Only on special situations will Shaffer specify welding on a DSC plate. 8.5.2

Check that excessive chain stretch will not hinder proper operation of the lock bar. Ensure lock bar spring is capable of lifting the lock bar 8.5.5 when load has been lifted from lock bar. Check the fluid level in the air/oil reservoir. For proper operation of the cylinder speed limiting valve and rod 8.5.6 end hydraulic cushion, proper air/oil fluid levels must be maintained. 8.5.7 Are there any indications of improper alignment? 8.6 8.6.1 Compressors 8.6.2 High Pressure APVs 8.5.4

High Pressure Air System

Recommendations

Note


Section 9 Maintenance System Evaluation Item # Inspection Requirement Findings 9.1 Management Organization and Administration 9.1.1 Who is in charge of maintenance on board the rig? 9.1.2 Is the maintenance function centralized or compartmentalized? (Corporate or rig level.) 9.2 Measures of Effectiveness 9.2.1 At the rig level, do maintenance personnel have knowledge of prior documented machinery history? 9.2.2 Do rig maintenance personnel take proactive steps to improve machinery reliability/safety? 9.2.3 Are there any reliability indices available at the rig level? 9.3 Work Control 9.3.1 Are maintenance personnel actions accomplished via a workorder system? 9.4 Management Information System 9.4.1 Is a management information system used, either manual or computerized? Describe. 9.5 Personnel 9.5.1 Are personnel adequately trained to perform expected duties? 9.5.2 Is there structured training program for skilled trades? 9.5.3

What is the overall competence level of maintenance personnel?

9.6 9.6.1 9.7 9.7.1

Logistics Support Are parts available when needed? If not, why not? Maintenance Tasks / Maintenance Engineering Are maintenance tasks preventative, predictive, corrective, or inactive? Spare Parts Are spare parts available as needed

9.8 9.8.1

Recommendations

Note


Section 10 Subsea Blowout Prevention Equipment Item #

10.1 10.1.1

10.1.2 10.1.3 10.1.4 10.1.5 10.1.6

10.1.7 10.1.8 10.1.9 10.1.10 10.1.11

10.2 10.2.1

10.2.2

10.2.3

10.2.4

10.2.5 10.2.6

10.2.7 10.2.8

10.2.9

10.2.10

Inspection Requirement Findings Recommendations Any time testing and inspection deviates from this procedure for any reason, confirm suitability with Operator’s representative and record reason on daily report and trip report. General Requirements OAS minimum standards are API RP 53, Third Ed., March 1997. Local regulatory requirements or operator standards may exceed requirements of RP 53. Minimum Testing and Maintenance guidelines can be found in API RP 53, sec. 18 Test flange or stump should be available for BOP well bore pressure testing. Test mandrel or drill pipe should be available for all sizes of pipe required for drilling program. BOP arrangement and pressure ratings must meet Operator’s contract specifications. Confirm that rig has in place a procedure to assure BOP's are tested as required; BOP drills, closing procedures and casing pressure limit posted. Confirm stack is well secured and can be aligned conveniently if required. Determine if any milling operations have taken place in the past year. Date (last well) Confirm full opening drill string safety valve and IBOP are available on rig floor. Verify drill string safety valve handles are available in specified locations on rig floor. Confirm record of major inspection conducted for stack, choke and diverter components. API RP 53, sec. 18.10.3 recommends complete disassembly and inspection per OEM guidelines every 3-5 years. Pressure Testing Appropriate test pump and a four hour rotation chart recorder should be available for testing. API RP 53, sec. 18.3.2 Separate low and high pressure gauges to be available for testing with minimum face diameter of 4.5”. Required tests to fall between 25% and 75% of gauge full pressure range. API Spec 16A - VI B 3.2 Confirm all gauges in BOP control system have been calibrated within 1% of full scale the last 3 years. API RP 53, sec. 13.9.3g Acceptance criteria is a straight line pressure test with no test fluid leakage. No leaks is minimum standard for all pressure testing. Fluorescein dye should be added to fluid prior to commencement of testing. Operating chambers to be tested to maximum rated working pressure for 5 minutes with possible exception of annular open/close operating chambers. (Note: Do not exceed 1500 PSI on Shaffer Annulars.) Review testing procedures confirming the following points are addressed: · Low pressure testing, 200-300 PSI, with a minimum duration of 5 minutes is to be performed before high pressure testing. API RP-53, sec. 18.3.2.1 · High pressure testing is to be held stable for 10 minutes. API RP 53, sec. 18.3.2.2. (Chevron requirement) · Intervals between BOP pressure and function tests should be per government requirements or operator requirements, whichever is stricter.

Note


Item # 10.2.11

10.2.12

10.2.13

10.2.14

10.2.15

10.2.16 10.2.17

10.3.1 10.3.1.1 10.3.1.2 10.3.1.3 10.3.1.4

10.3.1.5 10.3.1.6

10.3.1.7 10.3.1.8 10.3.1.9

Inspection Requirement Findings Maximum interval for function testing should not exceed one week. Function testing should be alternated from drillers to remote panels. API RP 53, sec. 18.3.1. (UK and Chevron requirements will supercede) Pressure testing should be conducted prior to spud, after change of any BOP element or at an interval not to exceed 21 days. API RP 53, sec. 18.3.3 (UK and Chevron requirements will supercede) · Ram locking devices should be operated and operation demonstrated while pressure testing per a preset schedule. (Rams closed, locks engaged, operating pressure bled off, perform wellbore test.) API RP 53, sec. 17.5.8 · Annular preventers and multiple size rams should be tested on all sizes of pipe to be used on well. Preventers should be operated with standard operating pressure while testing. · Valves shall be tested from direction in which they shall see pressure in service, such as kill lines and valves between buffer chambers and chokes. · Each piece of equipment undergoing test should be recorded on the test chart. · Problems and corrective actions should be recorded either on the chart or on a separate document.

Recommendations

Ram #1 Check throughbore for keyseating damage and record findings. Check vent ports and bodies for signs of hydraulic fluid or wellbore fluid leakage. Check preventer exterior for signs of hydraulic or wellbore fluid leakage. Check ram cavities for the following: (if possible have bonnets/doors opened prior to arrival of audit team) · Ram change rods, ram shaft sealing surfaces, & bonnet sealing surfaces shall be in good condition. · Ram shaft packing retainer shall be in position. Check for excessive corrosion in the area of retainer ring groove. · Ram blocks shall be checked for damage caused by closing on tool joints · Check P/N to verify H2S service ram blocks are in use if required by operator.. · Confirm ram elastomers are in excellent condition. Elastomers on BOP’s which have been out of service more than 6 months should be considered for replacement. API RP 53, sec. 18.5.11

10.3.1.10 Conduct a hydraulic operating chamber pressure test to maximum working pressure. Pressure to working pressure of operator and held for 5 minutes while recorded on chart. 10.3.1.11 Perform well bore pressure test at 250 psi and to MWP. 10.3.1.12 Confirm integrity of ram locking system during well bore tests. 10.3.1.13 Confirm ability of shear rams to cut drill pipe to be used. Reference information from the appropriate manufacturer’s engineering bulletin. Note that developments in quality of tubulars has left some shearing systems unable to cut pipe. Use of special ram blocks, large bore or tandem boosters may be required for some operations. 10.3.1.14 Confirm spare ram blocks are suitable for intended drilling program.

Note


Item # 10.3.2 10.3.2.1 10.3.2.2 10.3.2.3 10.3.2.4 10.3.2.5

Inspection Requirement Findings Ram #2 Check through-bore for key-seating damage and record findings. .Verify ram preventers have adequate clearance for tool joints between pipe rams to allow ram to ram stripping. Check vent ports and bodies for signs of hydraulic

Recommendations

fluid or well-bore fluid leakage. Check preventer exterior for signs of hydraulic or wellbore fluid leakage. Check ram cavities for the following: (if possible have bonnets/doors opened prior to arrival of audit team)

· Ram change rods, ram shaft sealing surfaces, & bonnet sealing surfaces shall be in good condition. 10.3.2.7 · Ram shaft packing retainer shall be in position. Check for excessive corrosion in the area of retainer ring groove. 10.3.2.8 · Ram blocks shall be checked for damage caused by closing on tool joints 10.3.2.9 Check P/N to verify H2S service ram blocks are in use if required by operator. 10.3.2.10 · Confirm ram elastomers are in excellent condition. Elastomers on BOP’s which have been out of service more than 6 months should be considered for replacement. API RP 53, sec. 18.5.11 10.3.2.6

10.3.2.11 Conduct a hydraulic operating chamber pressure test to maximum working pressure. 10.3.2.12 Perform well bore pressure test at 250 psi and to MWP. 10.3.2.13 Confirm integrity of ram locking system during well bore tests. 10.3.2.14 Ram cavity specified for drill pipe hang off shall be equipped with hang-off ram blocks. Verify manufacturer’s P/N. State capacity. 10.3.2.15 Confirm spare ram blocks are suitable for intended drilling program. 10.3.3 10.3.3.1 Check through-bore for key-seating damage and record findings. 10.3.3.2 Verify ram preventers have adequate clearance for tool joints between pipe rams to allow ram to ram stripping. 10.3.3.3 10.3.3.4 10.3.3.5

Check vent ports and bodies for signs of hydraulic fluid or well-bore fluid leakage. Check preventer exterior for signs of hydraulic or wellbore fluid leakage. Check ram cavities for the following: (if possible have bonnets/doors opened prior to arrival of audit team)

· Ram change rods, ram shaft sealing surfaces, & bonnet sealing surfaces shall be in good condition. 10.3.3.7 · Ram shaft packing retainer shall be in position. Check for excessive corrosion in the area of retainer ring groove. 10.3.3.8 · Ram blocks shall be checked for damage caused by closing on tool joints 10.3.3.9 · Check P/N to verify H2S service ram blocks are in use if required by operator. 10.3.3.10 · Confirm ram elastomers are in excellent condition. Elastomers on BOP’s which have been out of service more than 6 months should be considered for replacement. API RP 53, sec. 18.5.11 10.3.3.6

10.3.3.11 Conduct a hydraulic operating chamber pressure test to maximum working pressure on open and close side.

Ram #3

Note


Item # Inspection Requirement Findings 10.3.3.12 Perform well bore pressure test at 250 PSI and to MWP. 10.3.3.13 Confirm integrity of ram locking system during well bore tests. 10.3.3.14 Ram cavity specified for drill pipe hang off shall be equipped with hang-off ram blocks. Verify manufacturer’s P/N. State capacity. 10.3.3.15 Confirm spare ram blocks are suitable for intended drilling program. 10.3.4 Ram #4 10.3.4.1 Check through-bore for key-seating damage and record findings. 10.3.4.2 Verify ram preventers have adequate clearance for tool joints between pipe rams to allow ram to ram stripping. 10.3.4.3 10.3.4.4 10.3.4.5

Check vent ports and bodies for signs of hydraulic fluid or well-bore fluid leakage. Check preventer exterior for signs of hydraulic or wellbore fluid leakage. Check ram cavities for the following: (if possible have bonnets/doors opened prior to arrival of audit team)

10.3.4.6

Ram change rods, ram shaft sealing surfaces, & bonnet sealing surfaces shall be in good condition. 10.3.4.7 · Ram shaft packing retainer shall be in position. Check for excessive corrosion in the area of retainer ring groove. 10.3.4.8 · Ram blocks shall be checked for damage caused by closing on tool joints 10.3.4.9 · Check P/N to verify H2S service ram blocks are in use if required by operator.. 10.3.4.10 · Confirm ram elastomers are in excellent condition. Elastomers on BOP’s which have been out of service more than 6 months should be considered for replacement. API RP 53, sec. 18.5.11 10.3.4.11 Conduct a hydraulic operating chamber pressure test to maximum working pressure. 10.3.4.12 Perform well bore pressure test at 250 psi and to MWP. 10.3.4.13 Confirm integrity of ram locking system during well bore tests. 10.3.4.14 Ram cavity specified for drill pipe hang off shall be equipped with hang-off ram blocks. Verify manufacturer’s P/N. State capacity. 10.3.4.15 Confirm spare ram blocks are suitable for intended drilling program. 10.4.1 Annular Preventer, Upper 10.4.1.1 Check through-bore for key-seating damage and record findings. 10.4.1.2 Check vent ports and body for signs of hydraulic fluid or well-bore fluid leakage. 10.4.1.3 Examine annular element, look for major tears and protrusion into well-bore. 10.4.1.4 Conduct a hydraulic operating chamber pressure tests to maximum working pressure. (Do not exceed 1500 psi on Shaffer annulars.) 10.4.1.5 Well-bore pressure test annular to 250 psi and MWP. Annular BOP’s, with joint of pipe, may be tested to 70% rated MWP. API RP 53, sec. 18.3.1-3 (UK and operator requirements will determine test pressure.) 10.4.1.6 10.4.1.7 10.4.2

Test annular with smallest OD pipe to be used on well. API RP 53, sec.18.5.3 Conduct drift test per API 16A - Appendix C525. Element must return to full bore within 30 minutes. Annular Preventer, Lower

Recommendations

Note


Item # 10.4.2.1 10.4.2.2 10.4.2.3 10.4.2.4

10.4.2.5 10.4.2.6 10.5 10.5.1 10.5.2

10.5.3 10.5.4 10.5.5 10.6 10.6.1 10.6.2

10.6.3

10.6.4 10.6.5

10.6.6

10.6.7

10.6.8

10.6.9

10.6.10 10.6.11 10.6.12

Inspection Requirement Findings Check through-bore for key-seating damage and record findings. Check vent ports and body for signs of hydraulic fluid or well-bore fluid leakage. Examine annular element, look for major tears and protrusion into well-bore. Conduct a hydraulic operating chamber pressure tests to maximum working pressure. (Do not exceed 1500 psi on Shaffer annular) Test annular with smallest OD pipe to be used on well. API RP 53, sec.18.5.3 Conduct drift test per API 16A - Appendix C525. Element must return to full bore within 30 minutes. BOP Stack Mounted Valves Target flanges shall be removed for verification of lead content and erosion. Subsea valves shall be hydraulically pumped opened and allowed to close with spring force alone to verify proper operation of the assist-close system. (If a separate hydraulic close assist system exists the operation will be verified.) Pressure test valves from the top prior to BOP going subsea. Pressure test operating chambers to MWP. Pressure test valves to 250 PSI and MWP. BOP Control Unit and Remote Panels To what standard, API, contractor, or operator, is the accumulator unit sized? Conduct an accumulator volume test according to API RP-53, 3rd edition, section 13.3.2 and 18.7.1 The accumulator bottles shall be able to deliver, with the pumps turned off, enough usable fluid to close and open all ram preventers and one annular preventer. The combination of all pump systems should be capable of charging the accumulator system from the minimum calculated operating pressure to the system maximum rated pressure in 15 minutes. API RP 53 section 13.4.1 Confirm surface accumulator precharge is 1000 psi for 3000 psi systems. API RP 53,sec. 13.3.7 Open reservoir inspection ports and confirm proper fluid level and that no bacteria or contamination is in the fluid. Perform random fluid check to a few pod pilot lines on each pod. They are susceptible to bacteria growth. Bacteria in lines will eventually cause excessive corrosion, damage in pod valve components, and pod valve failure. Does the rig have a fluid condition monitoring program? Are fluid strainers cleaned on a schedule? Confirm fluid meets requirements of API RP 53, sec. 13.3.9 Record for corrective action any functions, regulators, or relief valves leaking fluid into the reservoir. Determine if hydraulic power unit has two power sources to recharge accumulator bottles in the event one should fail. API RP 53, sec. 13.4.1 Verify accumulator bottle isolation valves are in the open position. Does rig implement safe work permit or isolation permit system when working on HP accumulators? Are all hydraulic power unit and remote panel functions and gauges clearly labeled? API RP 53, sec. 13.9.3 f

Recommendations

Note


Item # 10.6.13

10.6.14 10.6.15 10.6.16

10.6.17 10.6.18 10.6.19

10.6.20 10.6.21

10.6.22

10.6.23

10.6.24

10.6.25 10.6.26 10.6.27

10.6.28 10.6.29

Inspection Requirement Findings Confirm controls for shear rams have a cover to prevent accidental operation. Cover shall not be locked. API RP 53, sec. 13.9.3 f Operate all functions and regulators from remote panels and at main unit. Pressure test the control system: Place control system in drilling position and apply full system pressure to the unit, rig piping, hoses, and preventers. ( 1,500 psi max. Shaffer annulars) · Repeat pressure test with preventers in the closed or killing position. Are accumulator unit and controls safe distance from rig floor.? API RP 53, sec. 13.5.1 Are rig personnel trained on operation of BOP controls? What type of well control certification, and is certification up to date? Check the control system for external leaks at pipe fittings, hoses and couplings. Check subsea, surface and pilot accumulator bottles, plus annular surge bottles for correct precharge per the water depth. Check surface and subsea accumulator bottles for proper N2 precharge per water depth, including all pilot, failsafe and annular surge bottles where applicable. Control system pods shall latch and unlatch properly. No obstructions shall be above the pod to prevent their retrieval. Check that control system regulators have been upgraded to allow operation with the loss of rig air supply. Any newly assembled control system hoses shall be pressure tested to 1.5 x WP prior to installation. All critical hoses (e.g. shear ram close, connector unlock) shall be pressure tested to 1.25 x WP. All functions, gauges and regulators shall operate properly from the remote panels and the hose reel panels. Record the gallon count and time required for each function from both pods. Function response times shall meet API RP-53, 3rd edition, section 13.3.5. Rams shall close within 45 seconds and annulars shall close within 60 seconds.

10.6.30

Pressure test the complete control system at full system pressure of 3,000 psi for 20 minutes, lining up each pod in both the drilling position and the killing position. (only 1,500 psi on Shaffer annulars)

10.6.31

Review the current ROV capabilities for correct installation and propose changes or additions if required. Operate the ROV functions.

10.7 10.7.1 10.7.2 10.7.3

10.7.4 10.7.5

Choke and Kill Hoses Choke and kill hoses adequately sized; properly secured? Examine armor for signs of physical damage. Conduct visual inspection per API RP 53, sec. 18.10.2 Have C/K lines been pressure tested as required? Testing required same as BOP’s API RP 53 , sec. 18.10.2 Review records of HP hose tests. · HP choke, kill, and cement hoses shall be inspected and tested per manufacturer’s recommendations. Appropriate equipment manuals should be available at each rig.

Recommendations

Note


Item # 10.7.6

10.8 10.8.1 10.8.2

Inspection Requirement Findings Record manufacturer, serial number, WP and date of manufacture on all choke and kill flexible hoses. This information is lettered on the ends of the hose. Choke Manifold Confirm choke manifold meets operator contract specifications. Confirm choke manifold meets API RP 53, sec. 8.2.

10.8.3

Components subjected to well bore pressure should be flanged, clamped or welded. API RP 53 3,sec. 8.2.b

10.8.4

Open and inspect targets for erosion or lead content as follows:

10.8.5 10.8.6 10.8.7 10.8.8

1. Targets in manifold T 2. Targets in C/K lines between manifold and droop hoses. 3. Targets on BOP

10.8.9 10.8.10 10.8.11 10.8.12 10.8.13 10.8.14 10.8.15 10.8.16 10.8.17

10.8.18 10.8.19 10.8.20 10.8.21

10.8.22 10.9 10.9.1 10.9.2 10.9.3 10.9.4

10.10 10.10.1 10.10.2

10.10.3 10.10.4 10.10.5 10.11

Confirm proper calibration of manifold and drill pipe well control pressure gauges. Confirm that a fill-up line separate from the kill line is available. Choke and kill lines plus manifolds should be secured and all 90o bends targeted. Is choke line diameter and pressure rating adequate for the intended operation? Confirm availability of adequate spares per API RP 53, sec. 8.5 Check that choke lines are manifolded so fluids can be: · Dumped overboard · Degassed and mud recovered Check valve hand wheels for free operation. Review rig’s schedule for valve greasing. Do valves appear to have been greased per schedule? Confirm use of OEM recommended lubricant. Perform low pressure testing to 250 PSI /5 minutes and high pressure testing / 10 minutes to MWP. Visually inspect interior of mud/gas separator for corrosion. Refer to API RP 53, sec. 16.9 Sketch mud/gas separator, note height of mud seal. Is separator of adequate volume, vent line of proper diameter and mud seal of adequate height for the operation? Measure gas vent line ID. Is height adequate for safe operation? Manual Choke Verify proper operation and record any deficiencies. API RP 53, sec. 18.6.3 Manual and hydraulic chokes shall be opened to check for erosion or damage Adjustable chokes do not require full sealing. API RP 53 3rd ED sec. 18.6.4 Confirm manual choke position indicator is readable and remote choke position indicator is functioning and properly calibrated. Remote Choke and Controls Verify proper operation and record any deficiencies. API RP 53, sec. 18.6.3 Chokes shall be opened to check for erosion or damage. Pressure test chokes to confirm they are working properly. Adjustable chokes do not require full sealing. API RP 53, sec. 18.6.4 Verify operation of remote choke panel pump stroke counter. Verify operation of alternate power supply for the remote choke. Diverter System

Recommendations

Note


Item # 10.11.1

10.11.2 10.11.3

10.11.4 10.11.5

10.11.6 10.11.7 10.12 10.12.1 10.12.2

10.12.3

10.13 10.13.1 10.13.2 10.14 10.14.1

10.14.2 10.14.3 10.14.4

10.14.5

10.14.6

10.14.7 10.15 10.15.1

10.15.2 10.15.3

10.15.4 10.15.5

Inspection Requirement Findings Function test the diverter packer and both insert and diverter assembly lockdown dogs, checking for signs of leakage. Examine the flow line seals for damage. Replace severely seals. Pressure test ball joint seals with grease gun and a pressure gauge. Diverter systems are typically tested to low pressure only after they are installed. (200 psi typical because the slip joint seal is the limiting factor.) API RP 53, sec.18.4.1d Inspect and test insert packer lock down dogs. Confirm alignment pins are properly installed. Confirm vent line valves are full-opening type and designed to automatically open before diverter closes. Per API RP 53, Section 5.2.3 Function test diveter system and any interlock(s). Refer to API RP 53, sec. 18.4.1-2 If system cannot be function tested document why. Clamps, Flanges and Fasteners Confirm all studs are B7 and nuts are 2H. Review rig bolt pre-loading procedures and lubricant. API RP 53, sec. 18.11.2 and 18.11.4, API Spec. 6A Any wellbore pressure connection should be re-torqued after a full pressure test. Confirm face to face contact for assembled AX, BX and CX flanges and hubs. Disassemble and fault determination is required for properly torqued connections failing to make face to face contact. Ring Gaskets and Grooves Examine all grooves for signs of damage. Assure no resilient gaskets are in use or available on rig. API RP 53, sections 18.11.2 Connectors Connectors shall have a flag on the position indicator which can be observed by the rig camera and the ROV camera. Connectors shall be lubricated with the lubricant specified by the manufacturer. Gasket retainer pins shall function properly. If the wellhead connector has a POCV check valve installed in the lock hydraulic line, function and pressure test. Unlatch the connectors checking that the required unlatching pressures are within the limits specified by the manufacturer. Record required primary or secondary unlocking pressure after closing with 1,500 psi or 3,000 psi closing pressure. Consult Vetco’s OSP #335 for allowable unlocking pressures. Actions shall be taken to correct connector operation. Riser Visually inspect each riser box and pin. Check condition of riser locking mechanism. Surface finish of pins shall be acceptable. If pins have been skim cut, adequate diameter shall be verified with original manufacturer. Inspect riser buoyancy and attachment straps. Report damage and inadequate attachment. Riser seals shall be in as new condition. Adequate choke and kill line seals shall be on board to replace all seals for the anticipated water depth. Check that choke and kill lines end float is per the manufacture’s recommendation. Check to insure all riser choke and kill line clamps are properly bolted and in good condition.

Recommendations

Note


Item # 10.15.6

Inspection Requirement Findings Review the riser NDE procedures. All used riser end connections and butt welds are to be MPI inspected to a correct procedure. 10.15.7 Date and results of last wall thickness survey C & K lines? 10.15.8 Riser Joint NDE/wall thickness 10.15.9 Riser Spider NDE 10.15.10 Riser Handling Tools NDE 10.15.11 Elevator and Bales NDE 10.15.12 500 ton elevators and bales are recommended for stack handling. 10.16 Telescopic Joint 10.16.1 Telescopic joint NDE / wall thickness? 10.16.2 Review NDE procedures. All end connections and butt welds are to be subjected to NDE after every 180 service days. 10.16.3 Date and results of last wall thickness survey Surveys should be conducted every 5 years. 10.17 Riser Adapter 10.17.1 Details of NDE and record wall thickness. 10.17.2 Check through bore for key-seating and record findings. 10.18 Ball Joint 10.18.1 Check through bore for key-seating and record findings. 10.18.2 Ensure that condition of lower to upper body studs are satisfactory and torqued to manufacturer’s specs. This pertains to both ball and flex joints. 10.19 Rig Positioning Equipment 10.19.1 Rig positioning system shall be properly calibrated by a person competent in its operation. 10.20 ROV 10.20.1 Review current ROV capabilities and for correct installation. Propose changes or additions as required. 10.21 10.21.1 10.21.2 10.21.3 10.21.4 10.22 10.22.1 10.22.2

10.22.3

10.22.4

10.22.5

10.22.6

10.22.7 10.23 10.23.1

BOP Handling System Comment on condition of the BOP handling system. Record date system was inspected by qualified personnel. Do cables appear in good condition? Record in service date of cables. Rig Floor, Procedures and Regulatory Confirm well control equipment and associated operations comply with local regulatory requirements. Intervals between tests should be per government requirements or operator requirements, whichever is stricter. Maximum interval for function testing should not exceed one week. Function testing should be alternated from driller's to remote panels. API RP 53, sec. 18.3.1. Pressure testing should be conducted prior to spud, after change of any BOP element or at an interval not to exceed 21 days. API RP 53, sec. 18.3.3 Confirm that rig has in place a procedure to assure BOPs are tested as required; BOP drills, closing procedures, casing pressure limit posted and emergency riser unlatch procedures Confirm record of major inspection conducted for stack, choke and diverter components. API RP 53, sec. 18.10.3 recommends complete disassembly and inspection per OEM guidelines every 3-5 years.

Are rig personnel current on required well control training? Bulletins Is current file available containing OEM (original equipment manufacturer) safety and repair notices for installed equipment. API RP 53, sec. 18.12.2

Recommendations

Note


Item # 10.23.2 10.24 10.24.1

10.24.2 10.24.3 10.24.4 10.24.5

10.24.6 10.25 10.25.1

10.25.2

Inspection Requirement Findings Have all OEM recommendations and modifications been implemented? Preventative Maintenance Review rig PM system. Are well control equipment items included and maintained as required? API RP 53, sec.18.12.1 Are repair and maintenance records accurate and up to date? Is a history file maintained per API RP 53, sec.18.13.2? Confirm adequate BOP spare parts are on board. API RP 53, sec. 7.6, 9.4, 11.5 Are API documents (spec 6A, 16A, 16C, 16D, RP 53, 16Q, 64) available as recommended? Reference API RP 53, sec.18.13.5 Is stored BOP equipment maintained according to guidelines in API RP 53, Sec.18.11.5? Welding Inspect well-bore pressure containing components for signs of unauthorized welding. Weld repairs can be performed only in compliance with guidelines referenced in API RP 53, sec.18.11.7 Examine all components for evidence of unauthorized weld repairs. Examine rig high pressure lines for patches.

Recommendations

Note


Section 11 Safety Survey Item # Inspection Requirement 11.1 11.1.1 Check “Hazardous Area Enclosure Register” and ensure annual inspection is being carried out. 11.1.2 Safety equipment available and worn? 11.1.3 Appropriate warning and safety signs displayed? 11.1.4 Qualified first-aider on each crew? 11.1.5 First-aid supplies. 11.1.6 Emergency eyewash station.

11.1.7 11.1.8 11.1.9 11.1.10 11.2 11.2.1 11.2.2 11.2.3 11.2.4 11.2.5 11.2.6 11.2.7 11.3 11.4 11.5 11.5.1

Findings General Requirements

Recommendations

Note

Emergency phone numbers posted? Welding/cutting procedures as required. Lockout/Tagout procedures as required. Designated smoking areas with matches, lighters and materials controlled? Personal Protective Equipment Hard hats and steel-toed boots/shoes worn? Eye protection. Gloves. Protective clothing. Hearing protection. Respiratory protection. Belts and safety lines. Hospital Lifesaving Equipment Lifeboats Clear, easy access provided?

11.5.2 11.5.3 11.5.4 11.5.5 11.5.6 11.5.7 11.5.8 11.5.9 11.5.10 11.5.11 11.5.12 11.5.13

Craft labeled per regulation? Maintained in working order? Start engine. Test emergency start. Test VHF radio. Lower boat. Launch/Release hook. Test sprinkler system. Test bilge pump. Is EPIRB included? (IMO 11.4.1.3) Check engine operation. Raise boat.

11.5.14 11.5.15

Does boat stop before striking platform? Is hoisting mechanism and cable in good condition? Falls used in launching shall be turned end for end at intervals of not more than 30 months and be renewed when necessary due to deterioration of falls or at intervals of not more than 5 years, whichever is earlier.

11.5.16

If falls cannot be turned end for end, then they must be replaced every 4 years. (IMO MODU Code 10.18.4)

11.5.17 11.5.18 11.5.19 11.5.20 11.5.21 11.6 11.6.1 11.6.2 11.6.3

Are provisions adequate? Regularly inspected and tested? Record date of last inspection. Record personnel capacity. Record overall condition.

11.6.4 11.6.5 11.6.6

Size. Record date of last inspection. Is a spare available to use during servicing?

(SOLAS Chapter III 19.4),

Life Rafts Manufacturer. Type/model. Quantity.

Yes


Item # 11.6.7 11.6.8 11.6.9 11.6.10 11.6.11 11.7 11.7.1

Inspection Requirement Record condition of raising and lowering system. Inflatable life rafts - stored in good condition? Inspected annually? Instructions posted? Launching mechanism in good condition?

11.7.2 11.7.3

Launch, operate, and retrieve rescue boat. Record date of last inspection.

11.7.4 11.8 11.8.1 11.8.2 11.8.3 11.8.4 11.8.5 11.8.6 11.8.7 11.8.8 11.8.9 11.8.10 11.8.11 11.8.12

Record any deficiencies.

Findings

Rescue Boat Fast Rescue Craft per regulation?

Life Preservers and Life Rings List manufacturer, date and model. Check total quantity on board. Check condition. Check quantities at each stowage location. Coverage of life preservers per regulation? Properly stored? Approved? Labeled? Whistles? Lights and reflective tape? Immersion suits per regulation? Quantity? Work vests provided and used for work over water?

11.8.13

Ring life-buoys - proper number, position properly equipped?

11.9 11.9.1 11.9.2

Self-Contained Breathing Apparatus Compressor: Inspect hoses for chaffing or excessive wear damage.

11.9.3 11.9.4

Condition and tension of drive belts. Condition of cable and plug for cuts, flattened or pinched sections. Record date of last air filter change. Run compressor on test for several minutes.

11.9.5 11.9.6 11.9.7 11.9.8 11.9.9 11.9.10 11.9.11 11.9.12 11.9.13 11.9.14 11.10 11.10.1 11.10.2 11.10.3

11.10.4 11.10.5 11.10.6 11.10.7

11.10.8 11.11 11.11.1

Inspect mask and hose contamination, damage or corrosion. When were cylinders sent off rig for inspection/recertification. Check cylinder gauge for damage. Check cylinder pressure. Examine harness for excessive wear or damage. Are SCBAs located outside areas with automatic fire suppression systems? Fire Pumps Are at least two (2) fire pumps installed? Insure that pumps are isolated from each other. Test each fire pump for adequate output pressure and record. Check for vibration and overheating. Check mechanical seal for leakage. Record date of last major overhaul. Test installed helideck foam monitor. Test water cannons. Test rig floor and cellar deck deluge system. Is accommodation sprinkler system operational? Is maintenance being carried out as per PM system? Check operating pressure at sprinkler tank. Record any drop from set pressure. Does a fire pump run from emergency generator board? Fire Fighting Equipment Inspect each fire station (fire main) for readiness and condition.

Recommendations

Note


Item # Inspection Requirement 11.11.2 Fire hose (minimum 50 feet)? Inspect hoses and their threaded connections for damage. 11.11.3 Combination nozzle, wrench and fire station valve in good condition? 11.11.4 Fire extinguishers charged, mounted, tagged, and sealed? Record date of last 3rd party inspection. Check for proper storage, accessibility, visibility and condition of boxes. Ensure operating instructions are clear and legible. 11.11.5 Check general condition of all equipment in safety and crash kit for any evidence of damage, deformation or deterioration. Ensure B/A bottles are fully charged. Check that contents of box match inventory list. 11.12 11.12.1

11.12.2

11.12.3

11.12.4 11.12.5 11.13 11.13.1 11.13.2 11.13.3 11.13.4 11.13.5 11.13.6

11.14 11.14.1 11.14.2 11.14.3 11.14.4 11.14.5 11.14.6 11.14.7

11.14.8 11.14.9

11.14.10 11.14.11 11.14.12

11.14.13 11.15 11.15.1

Findings

Inert Gas Fire Fighting Systems Inspect installed inert gas fire fighting systems, i.e., C02, halon. General inspection of entire system to ensure there is nothing to interfere with operation of equipment or access to release controls. Inspect all components of system such as piping, nozzles, valves, sirens, remote pull controls and boxes for visible damage or corrosion. Examine all nozzles and piping for obstructions from paint, oil, grease, dirt or any matter that would interfere with proper operation. Check associated alarms. Record date of last 3rd party inspection. Foam Fire Fighting Systems Date of last foam analysis? Quantity of spare foam on board? Quantity of foam required for system. Type of foam used? (example AFFF 3%) Condition of piping, valves, monitors and check valves? Start foam pump, run for several minutes to check for vibration, overheating or mechanical seal leakage. Check operation from alternative stop/start station. Record date of last major overhaul. Alarms and Detection General alarm. Fire detection alarm. Smoke alarm. Hydrocarbon alarms. Ensure low level alarm initiates at 20%. H2S alarm. Insure low level alarm initiates at 10 PPM, and high level initiates at 20 PPM. Bilge flooding alarms. Machinery space alarms. Can alarms be heard at all points on rig, including inside mud logging unit, wireline work shop and high noise areas? Visible alarm in high noise area? Rig personnel to test one call point, one heat detector, one smoke detector and one flame detector at random from separate zones. Test fault circuits from 2 or 3 zones. Inspect sensors in dirty or recently painted areas for cleanliness and damage. Check control panel and verify all channels are operational on gas detection system. Rig personnel to apply calibration gas and confirm meters display correct percentages of combustible gas as per calibration gas mixtures. Select and test random number of sensors and locations. Plans, Permits and Supervisor's Requirements Check to see if following contingency plans are available on board.

Recommendations

Note


Item # 11.15.2 11.15.3 11.15.4 11.15.5 11.15.6 11.15.7 11.15.8 11.15.9 11.15.10

Inspection Requirement Man overboard. Fire. Abandon rig. Critical H2S wells (sour gas). Current well control training? Confined Space Entry procedures as required. Incident report forms. Procedure for reporting accidents. Accident/injury forms filled out & copies to Operator's Supervisor? 11.15.11 Drilling Safety Program Manual. 11.16 11.16.1 Are fire drills conducted weekly? 11.16.2 Are abandonment drills conducted weekly? 11.16.3 Review / critique drills. 11.16.4 Drills follow IADC guidelines? 11.16.5 Check records of drills. 11.17 11.17.1 Regular safety inspections performed and corrections made; records on-site? 11.17.2 Accident prevention program in effect? 11.17.3 Safety meetings held regularly? Safety meeting minutes on record? 11.17.4 Personnel training (API RP-54, well control, H2S; FA/CPR, fire) records available? 11.17.5 Employees trained in safety policies; orientation given to all new employees?

Findings

Drills

Records

Recommendations

Note


Item # Inspection Requirement 11.17.6 Local doctor and hospital telephone numbers posted by phone in tool pusher's office? 11.17.7 Maintenance program and records for critical equipment? 11.18 11.18.1 Depending on expected H2S concentration, government regulation and management direction, is a copy of appropriate H2S regulations available? 11.18.2 Contingency plan on location, if required? 11.18.3 Annual H2S safety training of personnel? 11.18.4 First-aid training for H2S exposure provided in employee training? 11.18.5 Materials and equipment selected for H2S service? 11.18.6 Protective breathing equipment maintained at two (2) places on well site? 11.18.7 Two (2) wind direction indicators at strategic locations? 11.18.8 Automatic H2S detection and alarm system? 11.18.9 System of breathing air manifold, hoses and masks on rig floor and in briefing areas? 11.18.10 Cascade system to refill individual bottles? 11.18.11 O2 resuscitator; stokes litter, retrieval ropes with harness? 11.18.12 Facial hair requirements? 11.18.13 Chalk boards; bull horns? 11.18.14 Weekly H2S drills? 11.18.15 Safe breathing areas designated?

Findings

H2S Requirements

Recommendations

Note


Section 12 Environmental Audit Item # Inspection Requirement 12.1 Environmental Management 12.1.1 Does rig have copies of the Operator/Contractor environmental policy posted? 12.1.2 Date of last environmental audit? 12.1.3 By whom? 12.1.4 What were findings of the audit? 12.1.5 Have adverse findings been corrected? If not, explain. 12.1.6

What environmental inspections are routinely performed (daily visual, oil and grease spills, etc.)?

12.1.7

Are records on training requirements in environmental matters (hazardous waste, non-hazardous oilfield waste, etc.) documented? Are MARPOL Annex V placards posted? Where? Is the required oil pollution placard posted? Where?

12.1.8 12.1.9 12.1.10 12.1.11 12.1.12 12.1.13 12.2 12.2.1

12.2.2

12.2.3 12.2.4 12.2.5 12.2.6 12.2.7 12.2.8 12.2.9 12.2.10 12.2.11 12.2.12 12.2.13 12.2.14 12.2.15 12.2.16 12.2.17 12.2.18 12.2.19 12.2.20 12.2.21 12.2.22 12.2.23 12.2.24

12.3 12.3.1 12.3.2 12.3.3

Findings

Is there a current facility chemical list? Is MSDS file current and indexed? Are personnel aware of MSDS file, its location and use? Are Material Safety Data Sheets posted in areas where chemicals are being used? Is the Flag State required Oil Record Book current? General Discharge Control Are all discharge points from rig identified, inventoried, flow rates, and compositions of effluent(s) identified? Does rainwater drain overboard or to a tank or sump? What facilities are available to stop a direct overboard discharge in case of a deck spill? Is there evidence of mud leakage from rig floor? Check containment for the following: Draw-works. Rotary table. Diverter housing. Mouse/Rat holes. Wire-line anchor points. Are rig drains kept clean? In areas of oil-based mud usage are drains isolated? Where rig drains discharge to a collection tank: What provision exists to separate oil and water? How are levels monitored? Are all areas of engine room free from oil, particularly the bilges? Are open drains protected from oil ingress? Are there holes drilled or plugs removed to allow spillage to drain from containment areas? Is there evidence of oil loss overboard from the anchor/jacking winches, lifeboat winches, etc.? Is containment provided? Are there drain lines from deck containment areas? Are absorbent spill kits available at strategic deck locations? Are deck cranes capable of losing oil overboard? Are crane engine/hydraulic compartments sealed or fitted with drain lines? Where do drain lines discharge? Do all gravity drains have water traps or other means to prevent gas escaping through the drain? [Refer to 30 CFR 250.40(b)(4).] 12.3 Rig Floor Discharge Routing of drains - direct overboard or to collection tank. If drains connect to a collection tank: Where is it?

Recommendations

Note


Item # Inspection Requirement 12.3.4 Are there alarms on it? 12.3.5 Where does mud bucket discharge? 12.3.6 Is rig fitted with a drip tray under the rotary table? Where does it discharge? 12.3.7 Are mouse-hole and rat-hole blanked off? Where do they discharge? 12.3.8 Where is the standpipe bled to? 12.3.9 Where does the Draw-works chain lube oil tank discharge? 12.3.10 Where does the rotary gear oil tank discharge? 12.3.11 Where does the Draw-works cooling water discharge if drained? 12.3.12 What type of inhibitor is used? 12.3.13 Where is the Elmagco brake system discharge? 12.3.14 Is there any leakage from the slip joint? 12.4 12.4.1 Are the mud and charging pumps within a containment area? 12.4.2 Where does the containment area(s) drain? 12.4.3 Where are the pop-off lines routed? 12.5 12.5.1 Are there locking devices on the dump valves? 12.5.2 Is there a common drain for all the dump valves? Is there a master dump valve in the common drain line? 12.5.3 12.5.4 12.5.5 12.5.6 12.5.7 12.6 12.6.1 12.6.2 12.6.3 12.6.4 12.6.5 12.7 12.7.1 12.7.2 12.7.3 12.7.4 12.7.5 12.7.6 12.7.7 12.7.8 12.8 12.8.1 12.8.2 12.8.3 12.8.4 12.8.5

12.8.6

Findings

Mud Pump Room

Mud Pit Room

Are the suction lines recessed into the bottom of the pits? Are the pits able to be completely emptied without discharging into the sea? Are mud pits covered? Where does the sink in the pit room drain? Is there good ventilation in the pit room? Sack Room/Mud Mixing Area Where do the drains from this area lead? Is the proper equipment available for handling drums? Are the mixing pumps within containment and where does the area drain? Is the air around the mixing hoppers well ventilated and filtered? When the deck is washed down, where does it drain? Shakers Are the open sections of flow-line fitted with splash guards? Is the header box designed to prevent rig roll losses? Is there a high pressure wash-down system in the shaker area? What is the condition of the cutting retaining wall at the end of the shakers? Where are the drains routed on the shaker deck? Is the area ventilated? Where does the cutting's chute go? Where does the discharge from the "gumbo box" go? Sand-traps Are the dump valves lockable? Are they locked? Is there a common drain line with a master dump valve? Does the drain line go overboard or elsewhere? Can the sand-traps be completely emptied without discharge to the sea? How are the centrifugal pumps for desilter, desander, or centrifuges inside containment? Where does the containment drain? Where does the discharge from the solids removal equipment go?

Recommendations

Note


Item # 12.9 12.9.1 12.9.2 12.9.3 12.9.4 12.10 12.10.1 12.10.2 12.11 12.11.1 12.11.2


Findings Trip Tank

Is the dump valve lockable? Is it locked? Where does the dump line discharge? Where does the overflow line discharge? Is the trip tank pump inside containment? Where does the containment drain? Bulk and Fluid Transfer Hoses What is the condition of the hoses and spares? Are there dedicated hoses for brine, base oil, fuel oil, cement, barite, etc.? Bulk System Is all excess bulk back-loaded or blown off? Are vents to all bulk tanks filtered before discharging into the atmosphere?

12.12 12.12.1

Waste Containers Is waste separated into paper/metal/general waste, etc., so it can be recycled or sent to a landfill? 12.12.2 What happens to damaged sacks of chemicals? 12.12.3 What happens to empty plastic and metal drums? 12.12.4 What happens to galley waste? 12.13 Mud Lab / Mud Logging / Wireline Unit 12.13.1 Where are the sinks routed? 12.13..2 Are there suitable receptacles for waste chemicals, etc.? 12.14 Koomey Unit 12.14.1 Where is the BOP control fluid discharged? 12.14.2 What is type of BOP fluid in service? 12.15 Cement Unit 12.15.1 Where is the excess mix water put or discharged? 12.15.2 What happens to cement contaminated mud returns? 12.15.3 Where do trail mixes of cement get put or discharged? 12.15.4 12.15.5 12.15.6 12.16 12.16.1 12.16.2 12.16.3 12.16.4 12.17 12.17.1 12.17.2 12.17.3 12.17.4 12.17.5 12.17.6 12.18 12.18.1 12.18.2 12.19 12.19.1 12.20 12.20.1 12.20.2 12.21 12.21.1 12.21.2 12.21.3 12.21.4 12.21.5 12.21.6

Where does tank cleaning effluent go? Where are the cement unit/lines flushed? Where is the cement surge tank emptied? Production Test Area Are all produced hydrocarbons and cushions flared? Is produced water dumped overboard? Is mercury free sampling performed? Are sand analysis and oil gravity tests collected in waste oil drums and sent to town? Engine Room Where are the sinks routed? Where does the parts washer discharge? What type of solvent is used? Is there containment around all main generators? Where does the waste oil go? Where are deck drains in the engine room routed? Accommodations Where do the washing machines used in the accommodations area discharge? Where does the gray water (galley, sinks, lavatories, showers, etc.) go? Main Deck Where does the deck washing discharge? Firefighting Where does foam from fire drills discharge? Are Halon systems installed? Waste Management Who is responsible for handling waste, refuse, and trash on the rig? What type of training have they received? When was the training conducted? Who is responsible for completing waster manifests/shipping documents on the rig? What type of training have they received? When was the training conducted?

Recommendations

Note


Item # 12.21.7 12.21.8 12.21.9 12.21.10 12.21.11

Inspection Requirement Are waste shipments properly manifested? Are copies of manifests maintained on the unit? Are they accurate and complete? Do provisions exist for the recycling of waste? Are any programs or policies in effect to minimize the generation of wastes (waste minimization)? 12.21.12 Are wastes stored in proper receptacles (i.e., as not to create a health hazard, containers netted, etc.)? 12.21.13 12.21.14 12.21.15 12.21.16

Is trash burned? Describe. Is there a trash compactor on the rig? Is there a garbage grinder on the rig? How are empty containers for drilling mud chemicals (bags, plastic pails, barrels, etc.) disposed?

12.21.17 Are waste oil containers being sealed and tested for halogens? 12.21.18 Are waste oil manifests being properly completed? 12.22 12.22.1 Are diesel lines to the pit room isolated or blanked? 12.22.2 12.22.3 12.23 12.23.1 12.24 12.24.1 12.24.2 12.25 12.25.1 12.25.2 12.25.3 12.25.4 12.25.5 12.25.6

12.25.7

12.26 12.26.1 12.26.2 12.26.3 12.27 12.27.1 12.27.2 12.28 12.28.1

12.28.2

Findings

Mud System

Are records of calibration of mud level indicators present? Are records of all mud pit volumes kept at all times? Storage Tanks What provisions are provided for overflow and vents on storage tanks? Diesel Filters/Centrifuges How are fuel filters and centrifuge waste disposed? Is diesel fuel centrifuge package in a containment area? Oil/Fuel Transfer Are written procedures available on the unit for oil and fuel transfers? (Refer to 33 CFR 155.720.) Are procedures maintained current? Are oil/diesel transfers properly documented? Do vents and bunkering stations have appropriate containments? Are all check and isolation valves in good order? Are hoses used for oil or diesel transfer marked with words "Oil Service", the maximum allowable working pressure, date of manufacture, and the latest test date? MAWP must be at least 150 PSI. Oil transfer hoses must be tested annually. (Refer to 33 CFR 154.500, 155.899, 156.170.) Are there any interconnections between fuel, chemical, base oil, or oil-based mud systems and the open drains, seawater, potable water, ballast water, or other systems which have the potential to discharge overboard? Sewage Treatment Equipment What type of sewage treatment equipment is used on the rig? Are results of overboard discharge testing from sewage treatment plant current? Who is responsible for sewage treatment plant sampling? Refrigeration Units (CFC's) Is the required CFC recovery and recycle equipment aboard? (Refer 40 CFR 82 subpart F.) Are consumption records maintained for CFC's? Spill Contingency Are spill absorption kits or suitable stocks of materials immediately available for dealing with spillages? Are a range of bungs for open drains similarly available?

Recommendations

Note


Item # Inspection Requirement Findings 12.28.3 Are all personnel aware of this equipment and its purpose? 12.28.4 Is there a copy of the Operator's oil spill contingency plan available for inspection? 12.28.5 Is spill reporting information (contact and telephone numbers) posted for easy access? 12.28.6 Are procedures in place for reporting all spills and environmental incidents? 12.28.7 Are records kept of reported spills and incidents? 12.29 Maintenance and Housekeeping 12.29.1 Are all work areas clean and tidy? 12.29.2 Is rig wash being used of a type proven to be environmentally acceptable for the operating area? 12.29.3 Do drums which are in use have visible labels? 12.29.4 Are drum storage areas tidy and drums fitted with drip trays when in use? 12.29.5 Are drums in containment areas? 12.29.6 Is the waste oil tank located away from an open drain? 12.29.7 12.29.8 12.29.9 12.29.10 12.29.11 12.29.12

Chemical Storage: Are chemical pallets stored to prevent falling? Are chemical pallets properly labeled? Are chemicals stored in a segregated fashion? Is storage area tidy? Can stored chemicals be released to the environment?

12.29.13 Does containment exist in liquid chemical storage areas?

Recommendations

Note

Iadc Inspection List

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