Operational Manual QMS/Procedure and...SOP 26 Picking up Casing from Catwalk 1 SOP 27 Running 13 3/ 8” Casing 2 SOP 28 Wire Line operation with use of Drill String 2 SOP 29 Slip

QHSE OPERATIONAL MANUAL

OPERATIONAL

MANUAL

SAFE OPERATING

PROCEDURES (SOP)

QHSE OPERATIONAL MANUAL AMENDMENT HISTORY

Issue No. 1 Rev. No.: 00 Date : 01.08.2009 Safe Operating Procedures Page 1 of 1

Deleted Inserted Description of Change

SOP No. Date SOP No. Date

QHSE OPERATIONAL MANUAL CONTENTS


Reference Description No. of Sheets Amendment History 1 Contents 2 Introduction 1

SOP 01 Conducting Sea Bed Survey 1 SOP 02 Action before Pilling / Spudding 1 SOP 03 Control of Gas Sensors and Safety Alarms 3 SOP 04 Drill safety handling instructions 9 SOP 05 Drilling of hole and preparation of drill for next stage 3 SOP 06 Drilling to reach target 2 SOP 07 Drilling holes for lowering Liners and Cementation 2 SOP 08 Drilling, Conductor Casing, Installation and testing of BOP 5 SOP 09 Kick and shut in drill procedure while drilling 2 SOP 10 Well Control 11 SOP 11 Well shut-in Instruction 7 SOP 12 Plug and abandon Drilled Wells 2 SOP 13 Hang-off procedure – Cyclone / Storm Warning 2 SOP 14 Nippling up and Nippling Down BOP 7 SOP 15 Helicopter safety and Emergency procedures 4 SOP 16 Hygiene and House Keeping 4 SOP 17 Standing Instruction for Driller 2 SOP 18 Mixing Bulk Barite 1 SOP 19 Working on Mud Pumps 1 SOP 20 Picking up Pipe from Main Pipe Racks 1 SOP 21 Picking up Pipe to Rig Floor 1 SOP 22 Picking up Pipe from Mouse hole 1 SOP 23 Making a connection while Drilling 1 SOP 24 Procedure for Running in Hole 1 SOP 25 Picking up Casing from Workboat 1 SOP 26 Picking up Casing from Catwalk 1 SOP 27 Running 13 3/8” Casing 2 SOP 28 Wire Line operation with use of Drill String 2 SOP 29 Slip and Cut Drilling Line 1 SOP 30 Wire Safety System Equipment Testing Instruction 10 SOP 31 Testing of Blow out Preventer 5 SOP 32 Pressure Integrity Testing 2 SOP 33 Choke Manifold Pressure Test 2 SOP 34 Product Identification and Traceability and status of Acceptability 2 SOP 35 Customer Property 2 SOP 36 Handling, Preservation, Delivery and Dispatch 4 SOP 37 Storage and control of Perishable Materials 1 SOP 38 Control of Hazardous Substances 7 SOP 39 Transferring Cargo at Sea 3 SOP 40 Transferring Personnel at Sea 2 SOP 41 Bunkering at Sea 3 SOP 42 Anchor handling Procedure 15

QHSE OPERATIONAL MANUAL INTRODUCTION


1.1 General

To meet the requirement of QMS certification, it is essential that the structured

document system is established. In view of this, this manual is structured to

address the clauses of QMS Code. The document contains safe operating

Procedures (work instructions) for day to day as well as special operations.

Inculcation of safe habits is therefore of paramount importance.

1.1.1 To promote clear understanding an index also indicate the respective clauses is

included in the ‘Contents’ Chapters.

1.2 Purpose

The purpose of the established procedures is to ensure that the intent and

requirements of QMS established are met. Safe practices vide QHSE Manual are

implemented amongst the crew members so that zero level of accidents can be

aimed at.

1.3 Scope -To ensure that the procedures of all operations undertaken in Base and on

the Rig / Drill Ship are documented for implementation and reference for

improvement in future. This documentation also ensures that the new entrant can

be brought in the main stream smoothly. The Manual also covers all eventualities

for the safe working practices at Rig / Drill Ship while operating.

QHSE OPERATIONAL MANUAL CONDUCTING SEA BED SURVEY

Issue No. 1 Rev. No.: 00 Date : 01.08.2009 SOP No. : 01 Page 1 of 1

1 Purpose –To ascertain the strength of seabed. 2 Objective – To decide if the temporary guide base to be installed. 3 Scope – all locations to be drilled. 4 Responsibility -

Sr. No. Activity Responsibility 1 Conducting test if insisted by the

client Tool Pusher / Offshore Installation Manager

2 Decision to be taken Client’s Representative 5 Procedure

a) Run a penetration test assembly consisting of one stand of 9” DC’s drill collars on 5” drill pipe.

b) Run in and stop at the seabed. Carry out a seabed-tagging test to determine the water depth.

c) Apply a down weight of 5,000 lbs. And record depth of penetration. d) Increase weight in increments of 5,000 lbs. Recording each time until

penetration resistance permits no further movements. (If the subsoil is hard, no more than 10,000 – 15,000 lbs. Thrust may be required).

e) Using the results of test, assess the suitability of the subsoil to support a temporary guide base. Penetration in excess of 1.5m, (5 ft) usually precludes the installation of a temporary guide base.

f) Final decision rests with Clients’s Report. 6 Records S. No. Activity ID Responsibility Retention

Period 1 Sea bed test

Results IADC Report from

Tool Pusher 6 months

QHSE OPERATIONAL MANUAL ACTION BEFORE PILLING / SPUDDING


1 Purpose – To ensure all preparations, arrange necessary inputs, responsibility allocations to all crewmembers etc.

2 Objective – To have smooth trouble free well spudding and subsequent activities. 3 Scope – All wells to be spudded by the Rig / Drill Ship. 4 Responsibility Sr. No. Activity Responsibility 1 All inputs to be arranged Tool Pusher / Offshore Installation Manager 5 Procedure

I. Prior to spudding the well, hold a pre-spud meeting with company representatives and both Drill Crews present. Review the Drilling program with a special emphasis on the danger of shallow pas. Each crew member must be made be made aware of his specific duty and responsibilities

II. Make arrangements to pre-run the 30”& PGB and hang it off on the spider beams while positioning Rig / Drill Ship, if possible. (Provided no T.G.B. is to be run) a) Ensure that maximum capacity of drill water is available to max spud

once anchors are set. b) Check mud stocks and chemicals. c) (i) Check 30” and 20” casing and cementing equipment.

(ii) Ensure that the inside bore of each post top of the permanent guide base is clean.

(iii) Closely inspect the 18-3 /4” wellhead housing. d) Check that all operators and drilling contractor’s drilling and fishing

equipment is on board and serviceable. e) Check well programmes cement quantities and compositions and ensure

sufficient cement is aboard to cement the 30” and 20” strings. f) Pressure test all choke and kill manifold valves and lines to

recommended working pressures. g) Pressure test 18-3 / 4” stack on 18-3 /4” test stump. If operator wishes to

retain test graph then attach pressure recorder to system in order to keep a record of test.

h) Make up and stand back sufficient drill collars and 5” drill pipe to spud –in. i) Post positions should be marked clearly on the P.G.B. (i.e. 1, 2, 3, 4.) the

appropriate number of broad black horizontal bands is to be painted on guideposts.

6 Records S. No.

Activity FORM Responsibility Retention period

1 Availability of inputs for well spudding

IADC Report form Tool Pusher / Offshore Installation Manager

6 months

QHSE OPERATIONAL MANUAL CONTROL OF GAS SENSORS & SAFETY ALARMS


1. Purpose: To ensure that all safety, gas sensors, alarm, navigation, measuring, testing and inspection equipment have valid calibrations.

2. Objective: To ensure Rig / Drill Ship safety and efficient Rig / Drill Ship operations and achieve results conforming to the prescribed requirements.

3. Scope: All gas sensors, safety and navigation alarms, inspection, measuring and testing equipment.

4. Responsibility:

S. No. Activity Responsibility

1 Navigation instruments Chief Officer

2 Alarms and safety instruments - Drilling Chief Electrician

3 Alarms and safety instruments - Marine CO / CE

4 All sensors of gas temperature, pressure etc. – Marine Chief Engineer

4 All sensors of gas temperature, pressure etc. - Drilling Chief Electrician / Chief Mechanic

5 All instruments on derrick and drilling equipment, BOP

etc.

Chief Mechanic /Chief Electrician / Tool Pusher / Offshore Installation Manager

5. Procedures: 5.1 The instruments being used at Rig / Drill Ship under control of M/s. ABAN. These

have been divided in five categories:

I. Navigation- Standard and gyro compass, radar;

II. Operating and power generation machinery- alarm and shut down devices

etc.

III. Safety -Sensors for Hydrocarbon gases, Hydrogen Sulphide, Halon Fire and

smoke detection.

IV. Cargo operation level alarms, monitoring and control equipment including

crane instrumentation.

V. Drilling instrumentation inclusive of mud pumps etc.

5.2 These have been further divided into operation based on their impact on the safety,

pollution prevention and quality of the processes by the Chief Officer/Chief

Engineer/ Tool Pusher / Chief Electrician / Chief Mechanic.

5.3 A register has been established to exercise control on all inspection measuring and

testing equipments.



5.3.1 Index page of the register indicates the list of all instruments used by M/s. ABAN

and also on the page No. of the relevant details of particular instruments

department.

5.3.2 Individual page bears the following details:

I. Name of instruments.

II. Identification number

III. Category of instrument (Critical/ non critical)

IV. Area of location

V. Records of calibrations

5.3.3 The frequency of the calibration is determined on the basis of the

recommendations of the OEM or as recommended by applicable Rules,

regulations or decided by competent Tool Pusher or Chief Engineer etc.

5.3.4 All instruments are guarded against mishandling and are handled by the

experienced and qualified personnel.

5.4 Calibration of critical instruments is done by approved agencies having liaison with

national or international standard. Records of the calibration and copy of the

calibration certificate are maintained in a certificate file.

5.5 Maintenance instructions are formulated on the basis of the recommendation of the

OEM and in house experience. An instrument maintenance manual have been

complied and relevant portions are issued to all departments.

5.5.1 For the critical instruments the maintenance instructions demonstrated at relevant

area and maintenance carried out recorded in daily report or log sheet of the main

equipment.

5.6 Maintenance of instruments, alarms, sensors etc is performed as per

recommendation of respective OEMs and practices followed. The records of the

maintenance are maintained in the records established on boards.

5.7 Some of the sensors, instruments and navigational aids need pre calibration or

functional checks before being use. These are carried out by authorised personnel

as explained in the installation / operating instructions by the OEM.



6. Records

Sr. No.

Activity Responsibility Retention Period

1. Register Control of measuring

testing and inspection equipment.

Chief Mechanic /

Chief Engineer

On Going

2. Records of the calibration of

masters

Chief Mechanic /

Chief Engineer

On Going

3. Plan of calibration Chief Mechanic /

Chief Engineer

On Going

4. Listing of Inspection Measuring

and testing Equipment

Chief Mechanic /

Chief Engineer

On Going

QHSE OPERATIONAL MANUAL DRILL SAFETY HANDLING INSTRUCTIONS


1 Objective:

• To have an Aban Drilling procedure to hang off and disconnect in case of an emergency

• To have a Aban -Drilling Standard And Complete Guideline To Efficiently And Safety Handling of Drill String Tubular. .

• First Importance is care of connection and proper Torque.

• Second importance is correct Handling

2 Application: Drilling Unit 3 References:

A. API Standards

B. I.A.D.C. Drilling Manual

C. Table Bl-4 -Joint Applied To High Strength Drill Pipe

D. Table Bl-5 -Dimensional Data Rotary Shouldered Connections

E. Table B-6 -Thread Form Dimensional

F. Table B-7 -Minimum 00 And Recommeded Make-Up Torque Of Weld-On

Type Tool Joints.

G. Table B2-1 -New Drill Pipe -Torsional, Tensile, Collapse and Internal

Pressure Data.

H. Table B2-2 -Premium (Used) Drill Pipe -Torsional, Tensile, Collapse and

Internal Pressure Data.

I. Table B2-3 -Class 2 (Used) Drill Pipe -Torsional, Tensile, Collapse and

Internal Pressure Data.

J. Table B4-11 -Critical Rotary Speed

4 General Provisions:

4.1 Hang off and disconnect .

• Stop drilling.

• If possible jump R.O.V. to observe unlatch



• P .O.O.H. to shoe plus amount stands required to land hang off tool on wellhead and keep the bit inside the shoe.

• Install inside B.O.P. one stand below hang off tool and one full safety valve on top and R.I.H.

• Connect TOP DRIVE and OPEN DSC and land off on 183/4" wellhead.

• Set compensator to support only the weight of the hang off string. Adjust

Compensator to mid stroke. Adjusting to keep the neutral point on running

tool thread.

• Close lower and middle pipe rams & turn to the right 7 turns to

disconnect.

• Pick up string to clear shear rams.

• Close blind shear rams. • Displace riser to sea water with TOP DRIVE

• Set tensioners to predetermined tension (as per tensioner table) Sub-Sea Eng. to check.

• Double check all choke and kill line valves are closed.

• Disconnect LMRP (LMRP connector to unlatch).

• Move off location observing guidelines tensioners.

• Recover landing string and rig up to pull riser.

4.2 Emergency hang off and disconnect . • Stop pump and pick up TOP DRIVE to hang off point (Check space out

with table on rig floor)

• Hang off tool joint on lower pipe rams (re-check space out is correct)

• Adjust compensator so that it supports all of the string weight above the

• Hang off ram plus 10-15000 lbs.

• Boost shear pressure to 3000 PS4 close shear ram and shear the pipe.

• After pipe has sheared pick up 20 feet.

• Set tensioners to predetermined tension (As per tensioner table)

• Double check all choke and kill line valves are closed.

• Disconnect LMRP (LMRP connector to unlatch

• Move off location observing guide lines tensioners.

• Recover drill string and rig up to pull riser.



4.3 General Disposition:

Item #

Item Description

1 Cleaning, inspecting, and lubricating of all tool joints connections is important in

maintaining the life of the tubulars. So the following steps should be taken in

care:

A. Pin and box should be thoroughly cleaned in preparation to adding to string.

• This removes all foreign material and permits proper make-up

• Also it permits better inspection.

• Also it permits longer life of connections.

B. Inspecting of threads and shoulders is the next step.

• Use benchmark to determine if shoulder has been dressed beyond limits.

• Check plastic coating in the pin bore as first check of pin stretch .

• Check threads and shoulders for dents, scratches, washes, etc...

C. Lubrication needs to be applied before and after use.

• A good thread compound is essential for maintaining thread life. Following

API thread compound recommendation.

• All threads should be dry before applying compound. The present of

cleaning fluid can dilute compound.

• Never thin compound for ease of lubrication. This reduces the constituent

which protects the threads.

2 Breaking in new tool joints requires recommendations which should be followed.

A. Verify recommended makeup torque.

B. Thoroughly clean any gunk on threads and dry. C. Coat all threads liberally with thread compound.

D. Make up to full torque (new) using both sets of tongs.

E. Break out, re-clean, dry, re-lubricate and re-torque to new tool joint limits.

3 Tripping (coming out of the hole) requires special attention, as all stages in

handling tubulars tool joint connections



A. When lowering the elevators ,the box shoulder may get badly damaged if

struck by elevators or hook.

• Driller must not slack off faster than his floormen can control the elevators.

• The floormen must push /pull the elevators away from the tool joint box. B. When breaking out the connection, use both breakout and back-up tongs.

• Keep joint as low as possible to prevent bending pipe on tough break outs.

• Breakout torque should be 80% -90% of make up. Anymore may indicate a

problem.

• Position tongs to bite 1" from connection.

• Keep slight tension on threads to avoid damage. To avoid that the pin

falls down into the box. This can damage the threads.

C. Standing back pipe be sure area is clean.

• Have floormen rack pipe straight in order. If one stand is out of line, do not

re-position with pipe wrench or other sharp object. This will damage the

shoulder. Use a pipe jack.

• Number the stands both ascending and descending to help driller keep

track of total stands.

• Driller should watch derrickman is clear of blocks before slacking off fast.

Special Note: Each trip out the connections should be alternated (single, double

and even) so as to keep excessive torque being applied down hole and

thereby causing galling and reduced life. Take care not to mix different

Grades of pipe and tool joint with different OD, because this can mark the

shoulders and it has a possibility to wash out and have a fishing job.

4 Tripping (running into the hole) requires different attention: -

A. Clean each tool joint and dry

• Lubricating each box.

• Use a stiff round brush works best.

• Keep brush clean from dirt.

• Rabbit must pass through all tools that go into the hole.



B. When stabbing the pipe do not allow the pin end tool joint to hit the shoulder.

• Floormen must firmly grasp pin tool joint and guide into box (use of

stabbing guide is recommended)

• Drillers' timing is needed to correctly slack off when tool joints are align.

C. Spinning the tool joint together, avoid high speeds.

D. Tonging tool joints properly is the most important single factor in prevention of

tool joint troubles.

• Torque tool joints as per I.A.D.C. Table BI-7.

• Avoid forced make up.

• Check to ensure measuring devices are in good working order and

compatible with gauges to be read.

• Keep tool joint as low as possible to prevent bending pipe.

Special Note: At any time do not mix any different grades of pipe. Check with

I.A.D.C. codes to determine the differences. Check the identification stamped

on pin.

5 Laying down drill string requires specific operations to include:

A. Wash drill string internally and externally with fresh water.

B. Apply a rust preventive compound to the threads and shoulder, especially if the

pipes are to be stored.

C. Install box and pin protectors tightly before swinging through the ‘V-Door’.

D. Keep clear all personnel from the 'V-Door' before swinging pipe through.

E. Move pipe on catwalk clear of the next joint coming, to prevent one

hitting the other and causing damage.

F. When racking tubulars on deck use wooden spacers (3) rather than metal (old

drilling line)

G. A fast lay down may be used, but first check cable, sheaves and safety pines

for good Condition. This cable must to be used only to lay down drill pipes.



6 Pulling on stuck pipe require knowing the maximum allowable pulling force on

the drill string. The following criteria should be considered:

A. If tapered string is used, then the weakest point as opposed to the depth at its

highest point is determined according to the weight applied at the weakest point.

To remember in case that use different grades.

B. It must be assumed that the pipe is near the minimum cross sectional area of its

class and will fail in tension if the load is excessive.

C. Never overpull more than the weakest calculated point of the drill string.

D. Check all allowable pull limits in the IADC Drilling Manual Table B2-1 through

B2-3.

E. Drillers never overpull more than preset limit set by Toolpusher.

7 Drill String inspections and repairs will be needed periodically to prevent costly

fishing jobs and loss time.

A. The following criteria will determine when drill string components will be

inspected: • At the beginning of contract, if requested.

• After minimum rotating hours (approximately 3000 hours on drill pipe, 300

hours on BHA components.

• After extensive jarring on stuck Strings.

B. Type of inspections required will be a combination of the following as

circumstance dictate:

• Shoulder with gauged by OD calipers.

• Thread profile determined by thread gage.

• Boxswell and/or pin stretch measured by calipers.

• Minimum tong space measured by tape.

• Magnetic particles inspection (MPI) by the wet fluorescent magnetic

particle method is preferred.

• Visual inspections done regularly.

8 Repairs will be carried out by approved pipe Inspectors. The Inspectors must



submit the certificate.

5. RESPONSIBILITIES:

5.1 Company Representative

• Analyze procedure against company policy and suggest modifications in the instruction that corresponds with company policy.

5.2 Tool pusher • Notify the Master when the Rig / Drill Ship is ready to move off location.

• Notify the Rig Manager that hang off is needed to do.

• Supervise the operation in order to guarantee the correct procedure.

• Supervise the operation of drill string handling periodically in order to

guarantee safety and maintenance of drill string.

• Keep track of all rotating hours on all drill string components.

• Notify company representative of approaching maximum hours for

inspections.

• Notify Rig Manager of impending inspections coming due on the drill

string components.

5.3 Driller

• Execute all hang off procedures

• To hold the pre job meeting with all personnel involved in the operation,

everybody must to keep control on the Rabbit that is in use.

• Train All rig floor personnel to safety maintain all drill strings components

as set forth in this procedure.

• To notify Toolpusher of any damaged pipe so proper measures can

arranged.

5.4 Assistant Driller

• Assure Assistant Driller is keeping Floor men trained on drill string

maintenance.

5.5 Crane Operator

• Always beware of the grade of pipe that is given to the drill floor, and

always rack the correct grade of pipe in its proper place.



• To take care of the pipes threads maintenance on the deck.

5.6 Sub sea Engineer

• Prepare all necessary jobs prior to disconnect

• Prepare the guideline tensioners to move the Rig / Drill Ship off location

• Prepare the guide line tensioners tension table.

5.7 Master/Marine crew

• Move the Rig / Drill Ship off location and pull back over to connect the

LMRP when safe

• Prepare Contingency Plan for move off location in case of emergency

disconnect.

• Stay in close contact with company representative and Toolpusher.

6 DEFINITIONS : • LMRP -Lower Marine riser Package

• R.O. V. -Remote Operated Vehicle

• POOH -Pull Out Off Hole

• BOP -Blowout preventer

• RIH -Run in hole

• API -American Petroleum Institute

• I.A.D.C. -International Association of Drilling Contractors


DRILLING OF HOLE AND CEMENTATION OF INTERMEDIATE CASING AND PREPARATION TO DRILL TO NEXT STAGE


1 Purpose -To successful drilling and cementation of the intermediate casing.

2 Objective -To ensure safe and smooth operations.

3 Scope -All locations under drilling for this stage of operations.

4 Responsibility

S. No.

Activity Responsibility

1 Drilling and lowering of casing Driller

2 Cementing operations Cementing engineer

5 Procedure 5.1 DRILLING 17-1/2" HOLE

a) Make up 171/2" bit and BRA according to the drilling program.

b) Run in hole, tag top of cement and drill out. Drill 1m of, new hole and perform leak-off test.

c) Drill to casing depth, following the drilling program. Mud up whilst drilling as per the drilling program.

Run Totco surveys every bit change. Investigate all inexplicable pump pressure changes or active mud pit volume variations. Change first stand above drill collars and check drill pipe tally each round trip.

Make sufficient wiper trips to ensure stability of the hole.

Ensure that, at all times, the rotary is centered over the wellhead.

Check that all 13-3/8" casing, attachments, handling tools, cementing tools and materials are on board.

Flush kill and choke lines every 2 days with mud.

d) At TD, make a wiper trip to the 20”shoe.

Drop Totco, P .O.H. and run logs as per drilling program.

It a clean-out trip is necessary during logging, use the same BH that was used to drill the 171/2" hole, and the same circulating rate.

On last trip out before logging, strap (measure) out the drill string.

e) After completion of logs, make up the 13-3/8" cementing assemblies.

f) Run in hole with 17112" BHA to TD.

Ream any tight spots and condition mud on bottom.

5.2 PULLING 18-3/4" WEAR BUSHING

a) Flush wear bushing with mud.




b) Make up running tool on one stand of 5' drill pipe.

c) Close shear rams, run and set running tool down gently on rams, and mark the D.P.

d) Run the running tool down to wellhead.

e) Make up the running tool into the wear bushing.

f) Pull the running string, running tool and wear bushing.

5.3 RUNNING 13-3/8" CASING

a) Ensure all 13-3/8" casing-running equipment is in good working order.

b) Pick up the shoe joint and float joint. Thread locks all connections on first three

joints.

c) Run 13:3/8" .casing, ensuring that the float equipment is in working order. Break circulation at the 20" shoe.

d) Install 13-3/8" casing hanger as per installation procedure. Install sub sea plug launching set onto running tool. Make up 13-3/8" running tool onto casing hanger and check operations.

Note: Installation tool and plug launching tools should be made up in the Derrick prior to running casing.

e) Continue running 13-3/8" casing to setting depth, using HWDP. Exercise caution while landing 13-3/8" casing hanger into 18-3/4" housing.

f) Ensure the running string is kept full to avoid collapse of the 13-3/8'.

g) Make up cementing head counterclockwise plug launcher, circulate prior to cementing. Drop ball and trip float equipment.

Note: If LCM is present in the mud systems, convert differential equipment to standard float shoe at surface. Float casing and fill with LCM -free mud. If severe lost circulation is encountered, precedes cement with LCM mud.

h) Cement 13-3/8" casing to inside 20", casing as per drilling program.

5.4 CEMENTING THE 13-3/8" CASING

a) Cement the 13-3/8" casing as per program.

b) Precede cement with 20 bbls of weighted cement preflush.

c) Using cementing pump, mix and pump cement.

d) Mix and pump tail in cement. Check for full mud returns whilst mixing and displacing cement.




e) Release trip dart plug.

f) Displace dart plug to wiper plug with water, using cementing pump and shear wiper plug from sleeve.

g) Switch to Rig / Drill Ship pumps and displace wiper plug to seat of 13-3/8" float collar with mud. Displace until the plug bumps. It there is no indication of the plug shearing, displace with calculated Rig / Drill Ship pump strokes to leave cement 3 joints inside the shoe.

h) After bumping wiper plug, bleed off pressure and check for back flow.

i) Set seal assembly as per program.

j) Back off 13-3/8" running tool.

k) Pick up drill pipe.

l) Flush the inside of 13 3/8" hanger and BOP's.

6 Records

Sr. No

Activity ID Responsibility Retention period

1 Details of drilling. Casing and cementation operations

IADC Report Tool pusher 6 months

QHSE OPERATIONAL MANUAL DRILLING TO REACH TARGET


1 DRILLING 121/2" HOLE

a) Run in and set 13-3/8" wear bushing in 18-3/4" housing.

b) Make up 121/4" bit and BHA as per drilling programme.

c) Run in hole and tag cement. Drill out cement with mud through baffle collar

and casing shoe with low RPM and low bit weights. d) Drill 1m of new hole and carry out leak-off test as per programme.

e) Drill to 9-5/8" casing depth as per drilling programme.

Do not drill more than 3m into a drllling break without checking.

Make sufficient wiper trips to ensure stability of hole above bit. Investigate all

inexplicable pump pressure changes or active mud system volume variations.

Run Totco surveys as per Drilling programme, for every bit run.

Check that 9-5/8" casing attachments, all casing handling and cementing

tools and materials are on board.

Ensure, at all times, that rotary table is centered over wellhead.

Use junk sub prior to coring, or when necessary. Flush the kill and choke

lines every two days with mud. f) At ill make a wiper trip to 13-3/8" casing shoe. If the hole and mud are in

good shape, drop the Totco, POH and run electric logs as per drilling

programme. Strap out the drilling string .

NOTE: If a clean out trip, for tight hole or after thirty hours of logging, is

necessary, always use -if possible -the same BHA as was used to drill the

121/4" hole. Also use the same circulating rate.

g) After completion of logs, RIH with the clean out assembly. Ream any tight

spots and circulate/condition mud at TD.

h) POOH and prepare to run 9-5/8" casing. 2 RUNNING THE 9 5/8” CASING

a) Make up casing shoes, collars and centralizes as per drilling program.

QHSE OPERATIONAL MANUAL DRILLING TO REACH TARGET


b) RIH with 9 5/8” casing and check mud return from annulus. Break circulation

at the 13 3/8 shoes.

c) Run casing hanger to wellhead with cementing head at least 3 m above

rotary.

d) Land 9 5/18" hanger body on top of 13 3/18" seal assembly as per wellhead contractor's procedure.

e) Hookup cementing hose/chick sans and use Rig / Drill Ship pump to circulate

one casing volume. f) Pressure test cement unit and lines.

3 CEMENTING THE 9 5/8" CASING The 9 5/8" casing is to be cemented as per the following program:

a) Mix and pump cement leaving the surge tank empty after cementing.

b) Mix/pump tail cement. Check pit for full returns while pumping / displacing

cement.

c) Release trip dart plug.

d) Displace trip dart plug to wiper with water, using cementing pump. Shear

wiper plug from sleeve.

e) Switch to Rig / Drill Ship pumps and displace wiper plug to set on 9 5/8" float

collar with mud and with a pre-calculated number of pump stroke. If there is

no indication of the wiper plug shearing displayed with a calculated volume,

leave cement joints inside the shoe.

f) After bumping wiper plug bleed off pressure and check for back flow.

g) Set seal assembly as per program.

h) Back off 9 5/8" running tool.

i) Pick up drill pipe 2 ft. plus heave of vessel.

j) Flush the inside of 18 3/4" housing and BOP's.

k) P.O.O.H.


DRILLING HOLES FOR LOWERING LINERS AND CEMENTATION


1 Purpose -To reach the target date or extend the existing depth of a well.

2 Objective -To ensure provision of the smooth and safe well bore for physical

evaluation of the prospective formations.

3 Scope -All wells to be drilled by the operators through M/s ABAN 4 Responsibility

Sr. No. Activity Responsibility 1 Drilling and lowering of

liners Driller

2 Cementation of liners string Cementing engineer 5 Procedure

5.1 DRILLING 81/2” HOLE

a) Run in and set the 18-3/4 ' x 9-5/8" wear bushing. b) Make up 8-1/2" bit and BHA as per drilling program. Drill out casing and 1m

of new hole.

c) Carry out leak-off test.

d) Drill to 7" casing depth, plus 15m of 8-1/2" rat hole. At all significant drilling

breaks, check for flow. Do not drill over 3m into a break without checking.

e) At setting depth, make a wiper trip to 9-5/8" casing shoe. If hole and mud are

in good shape, I.O.H. Run electric -logs as per the Drilling Program. Strap out

the drill string.

f) If the well is to be abandoned and no 7" liner is run, in hole with open drill

pipe ready to set abandonment plugs. RF.Ts may be run to test zones of

interest behind the 9 5/8" casing. 5.2. RUNNING AND CEMENTING 7" LINER

a) Run 7" liner on 5" drill pipe and running assembly to setting depth as per program.

5.3 DRILLING THE 6" HOLE

a) Run in and set 7' wear bushing.

b) Make up 6" bit and BHA as per drilling program. Drill 1m of new hole.

c) Carry out leak-off test.


DRILLING HOLES FOR LOWERING LINERS AND CEMENTATION


d) Drill to T .D. plus 15m of 6" rat hole. Check for inflow at all drilling breaks.

e) At T.D, make a wiper trip to 7' shoe. Electric-log as per drilling program.

f) When hole and mud is in good shape, P .O.O.H.

g) If well is to be abandoned and no 5" liner is to be run, in the hole with open

end drill pipe ready to set abandonment plugs. R.F.F.'s may be run to test

zones of interest.

5.4 RUNNING AND CEMENTING 5" LINER

a) Run 5" liner on 31/2" drill pipe and running assembly as per program.

6 Records

Sr. No. Activity ID Responsibility Retention Period

1 Records of well depths lowering and cementation of liners strings

IADC report Tool Pusher 6 months

2 Cementation details Cementation report

Cementing Engineer

6 months


DRILLING AND CONDUCTOR CASING, INSTALLATION AND TESTING OF BOP


1 Purpose -Continuation of drilling operations of wells and establish recommended

safety guards.

2 Objectives -To ensure conducting all future operations with required level of safety.

3 Scope -all wells to be drilled to the target depth. 4 Responsibility Sr. No. Activity Responsibility 1 Drilling and lowering of casing, well heads and BOP Driller 2 Cementing of casing Cementing engineer3 Preparing, latching and testing of BOP Sub sea engineer " 5 Procedure 5.1 DRILLING 26” HOLE a) Make up 30" pin connector onto 20" Marine Riser and attach guide frame.

b) Install new 30" gasket in pin connector and check hydraulic operation of pin &

connector.

c) Run 30" connector and latch onto wellhead. Observe operation with Subsea

TV.

d) Tag and drill out cement and shoe with sea water. High circulation rates and

bit weights should be avoided while drilling out shoe.

e) Circulate hole to mud, drill and under ream to 20" casing setting depth in one

pass.

Note: It target zones or drilling hazards are anticipated in this section, a

171/2" hole should be pilot drilled, and logs run prior to under-reaming to 20"

hole.

f) Circulate hole clean. Make a wiper trip to the 30" shoe as hole condition

dictate. POH.

g) Log hole.

h) RIH with 20" under-reaming assembly to 20" casing depth. Condition hole

prior to POH for 20" casing.

i) Unlatch and pull 30" pin connector and 20" riser, if pin connector is run.




5.2 RUNNING 20" CASING AND WELLHEAD

a) Ensure all 20" casing running equipment is in good working order.

b) Install centralizers as per drilling programme onto 20" casing joints.

c) Pick up 20" shoe joint with shoe and float collar.

d) Run 20" casing, ensuring that differential equipment is working correctly.

e) Stab 20" casing to casing depth, using HWDP. Exercise caution while landing

18- 3/4" housing onto 30" wellhead. Ensure the running string is kept full to

avoid collapse of the 20" casing.

f) Make up cementing head.

g) Cement 20" casing to sea bed. A small slug of fluid, containing mica or f

cellophane, should be pumped ahead of the main slurry to check full return.

5.3 CEMENTING 20” CASING

The 20" casing is cemented back to the seabed following the drilling program.

The gel for the blended cement is pre-hydrated is one mud pit.

a) Mix and pump cement. Observe on Subsea TV for returns at sea bed. Mix

and pump all the cement from the surge pod to leave it empty.

b) When cement is in place, check for back flow and back out 18-3/4"

running/cementing tool. c) Pick up running tool 5 ft. and flush wellhead with sea water.

d) POOH. Check the DPA running string measurements

5.4 RUNNING THE 18-.3 /4" BOP STAK AND 20" RISER

a) The BOP stack should have been tested on the 18-3 /4" test stump prior to

running and recorded in Form no. FRM/SUB/502 “BOP Test Procedure” .

b) Acutate the lengths of riser, required for the location water depth. Install the

Honeywell transponer on BOP stack.

c) Prior to running the riser, ensure that there is ample air in the air bottles for

the tensioning system. d) Test all functions of BOP stack from blue and yellow pods before removing




junction boxes from pod reels.

e) Load test the pod wires.

f) Run BOP on 20" riser. Test kill and choke lines against the inside kill and

choke failsafe valves every third joint ( or as directed), and prior to installing

slip joint.

g) Install slip joint.

h) Run BOP stack until 10' above the guide posts of the PGB. Observe on

subsea TV. k) Take the weight of the stack and riser on a combination of the riser

tensioners and

drill string compensator. 1) Visually check by Subsea TV that the wellhead connector is open and

operating pressure is on the "Open" function.

m) Install kill and choke lines. Connect air to slip joint packing gland.

n) With TV observation, carefully lower the BOP stack guide frame. If resistance

is felt no more than 5000 lbs down-weight should be applied.

o) Land the stack on the 18-3/4" wellhead housing and close wellhead

connector. Visually observe that the connector is the locked position.

p) Using the tensioning system, take a 50,000 lb. over pull on the stack and riser

to check if wellhead connector is latched correctly.

q) Test the kill and choke lines to 7500 psi against the inner failsafe valves.

r) Remove riser handling sub and make up diverter assembly.

s) Land diverter assembly and function test diverter system.

5.5 TESTING THE 18-3/4" BOP STACK ON WELL HEAD

a) Ensure wear bushing is not in the wellhead housing

b) Run the test tool on grade "G" drill pipe, with one stand of HWDP below the test tool and land in the wellhead.

NOTE: Extreme care should always be taken when running tools through the BOP stack. The compensator should never be locked.

c) Flush the kill and choke lines with water and ensure that both the riser and D.P. are full.




d) Test the wellhead connector, rams, kill and choke lines and surface equipment to75% of working pressure. Annulars to 60% of working pressure.

Note 1: If leaks are observed during testing, pressure should be bled off to avoid

possible pressure cutting of any seals.

Note 2: Release pressure slowly after testing, to avoid sucking debris into the kill and /or choke lines.

e) Finally record the same in the form no. FRM/SUB/502 “BOP Test Procedure”.

5.6 RUNNING 18-3 /4" WEAR BUSHING

a) Make up running tool and run wear bushing. b) Run the running tool and wear bushing down to wellhead on 5" drill pipe.

Gently check the depth of the shear rams on the way in, and mark the drill pipe.

c) Set the wear bushing carefully into the wellhead. d) Release the running tool from the wear bushing and pull the running string to

surface.

Note:

As there is very little clearance between the wear bushing and the 18-3/4"

wellhead housing, the Rig / Drill Ship must be lined up over the wellhead to

ensure the wear bushing fully lands in the wellhead.

6. Records S. No.

Activity ID Responsibility Retention period

1 Drilling, casing and cementing details

IADC report Tool pusher 6 months

2 Sub sea testing and lowering details

Sub sea engineer log Sub Sea Engineer 6 Months

3 BOP Test PRocedure FRM/SUB/502 Sub Sea Engineer 3 years

QHSE OPERATIONAL MANUAL KICK AND SHUT IN DRILL PROCEDURE WHILE DRILLING


1 Purpose -To check the alertness of the driller while drilling.

2 Objective -To enhance level of effectiveness of the preparedness of the drillers.

3 Scope -All drills.

4 Responsibility

Sr. No. Activity Responsibility

1 To check preparedness Tool Pusher / Offshore

Installation Manager

2 Responding to the unsafe

Situation

Driller

5 Procedure

5.1 Kick drill procedure while drilling

I. While Tool Pusher / Offshore Installation Manager goes to mud pits &

without warning either lifts or holds down float on active pit and records

time taken for driller to respond to influx gain or decrease loss of mud in

active pit.

II. While drilling driller should have PVT turned on to monitor active pit

volume at all times (no exceptions )

III. When PVT alarm sounds off drill immediately picks up off bottom stops

pumps & rotating top drive.

IV. Places hole on trip tank to monitor increase and check for lost returns.

V. If there is a continuous gain he should go to shut in procedure this action

is for him to decide without notifying anyone just carry out the shut in

procedure and finally record the same in Form No. FRM/DRL/106 “Trip

Sheet”. 5.2 Shut in procedure while drilling

I. Sound of PVT alarm stop pumps p/u off bottom & stop rotating.

II. Place string in the hang off position and close annular

III. Notify Rig Manager and company man.

IV. Start to monitor pressures.

QHSE OPERATIONAL MANUAL KICK AND SHUT IN DRILL PROCEDURE WHILE DRILLING


V. It is up to the driller to decided to flow check or not it is his responsibility to make the decision to check the hole or go for a shut, do not wait or ask for this action to be decided by anyone else.

6 Records

S. No.

Activity Form No. Retention period

1 Trip Sheet FRM/DRL/106 3 years

QHSE OPERATIONAL MANUAL WELL CONTROL


1 Purpose -To ensure control of wells in minimum period with inherent safety.

2 Objective -To keep the damage to the minimum possible level.

3 Scope -To cope with all potential unsafe well situations.

4 Responsibility


1 Detection of unsafe situation Driller

2 Immediate actions to control well Driller

3 Analysis and detail planning Tool Pusher and

operators representative

4 Application of well control processes till final control on well

Tool Pusher / Offshore Installation Manager and operator representative

5 Procedure for WELL CONTROL

5.1 GENERAL POLICIES

a) All drilling and supervisory staff must be familiar with standard practices

concerning blowout prevention and well control

b) Strict adherence to the no-smoking and fire regulations is required.

c) All surface drilling equipment, plus the B.O.P. stack in use, is to be tested

once a week, prior to drilling out casing shoes, and at a bit change prior to

entering an expected pay zone. The above test must be witnessed by the

operator's Supervisor.

d) Mud pit checks must be made constantly. The mud logging unit indicators,

and the drilling indicator, must be monitored continuously during operations.

Pit meter alarms are to be set at + 10 barrels, normally.

e) Formation strength tests should be carried out after drilling out 20”, 13-3/8”

and 9-5/8" casing shoes. The information derived from the test is to be

inserted in the well control data sheet, to ensure that excessive annulus

backpressure is avoided during killing operations.

From this information, calculate the maximum allowable surface pressure

for various mud weights.



f) The operation of slipping and cutting and drilling line should be carried out

with the bottom hole assembly at the casing shoe.

g) A minimum overbalance of 200 psi should be maintained on the formation at

all time, conditions permitting. Furthermore, the mud weight should be such

that, when the marine riser is displaced to seawater, there should be at least

50 psi overbalance on the formation, conditions permitting.

5.2 WELL CONTROL EOUIPMENT

a) Pit level indicators, stand pipe pressure gauge, annulus vernier pressure

gauges and pump stroke counters, to be located near the driller.

b) The degasser should be operated daily. If it is not working properly,

immediate steps must be taken to carry out repairs.

c) An appropriate Hydril "Drop-in" type check valve to be located in the string

while drilling, with matching dart ready for use on the drilling floor.

d) A full opening Kelly Cock must be installed at the base of the kelly at all times

while drilling. A spare with matching connection should be ready on the Drill

floor.

e) An emergency inside Hydril Check valve, with the right connections, to be

available on the Drill floor while drilling. f) Minimum 10,000 psi W.P. rated Circulating Head Assembly to be ready for

immediate use, when drilling and tripping.

g) A cross-over from casing to chicksan line, with a valve, is to be available on

the Drill floor at all times when running casing. To be able to circulate.

5.3 STANDARD PRACTICES

a) Pre-kick calculation sheet should be filled out every 150m drilled below the

20" and 13-3/8" casings, and every 60m drilled below 9-5/8" and 7" casing.

To be kept up to date and prominently displayed. Also, when there have been

major changes in the drilling parameters, such as change of mud weight,

nozzle size etc., this sheet should be updated.



b) Prior to drilling with a new bit and at the start of each shift, the Driller has to

establish pump pressure at slow circulating rates of 30, 40, 50 and 80 strokes

per minute.

The results are to be reported in the daily drilling report.

The driller must keep a careful check on the trip tank volume, at all times

while pulling and running pipe.

c) Kick drills should be held once a week, for each crew. This includes landing

the string on the rams and installing the circulating head. When making hole,

the bit should be pulled back to the casing shoe, before holding Kick drill.

Kick drills are to held prior to drilling out below the first casing shoe, and

repeated until every crew member is familiar with the procedure.

d) The following precautions should be taken when drilling in formation with an

expected over pressure;

(i) One bulk tank should be full of barite.

(ii) One tank of kill mud, with an over balance of 0.1 psi/ft weight, should be

available. e) Flow checks are to be held at drilling breaks, and before tripping. When

tripping, pull first ten Stands slowly and check for swabbing. In the event of

gas cutting, or increase of chlorides, shut down the pump and check flow.

f) The trip tank must be; used while tripping. On critical casing jobs, and critical

trips in hole, the trip tank must be used to check the mud returns.

g) When a round trip is; to be made, and swabbing is likely to happen, do not

pump a heavy pill when pulling off bottom. Pump the pill when the bit is in

the shoe, or when it is certain that swabbing is not taking place. This allows

for a more accurate check on swabbing.

h) At the commencement of operations at each drilling location, the contractor's

representative will prepare the "drill pipe hang-off chart". This is to take into

consideration the sea water depth, the dimensions of the wellhead and guide

base, the dimensions of BOP stack and the location of the pipe rams in



stack. Once prepared, the chart is to be kept in a prominent location in the

drilling office. A copy to be posted on the Drill floor.

i) The Driller must check the total pressure loss each day when drilling ahead,

and record same in the daily drilling and contractor's tour reports.

j) The Driller must check that the surface automatic choke "maximum

allowable choke pressure" guide is set at less than both the casing burst

pressure and the formation break down pressure.

(Determined from leak-off test).

k) At the commencement of each shift, Driller must check that the subsea

stack valves and choke manifold valves are all set correctly, and that all

valves downstream of the choke, are opened to the degasser.

1) Take care of annular preventers and note that each sealing element will

vary in characteristics, which will change continually during its working life. If

the operating pressure is kept at 1500 psi, normally, this will ensure the

fastest possible closure, and a positive initial seal around the pipe in the

hole. Before stripping or rotating, however, the hydraulic closing pressure

must be bled back to 400 psi, or less, it there is well pressure below the

element

5.4 GENERAL WELL KILLING PRACI1CES

After the Driller has identified the fact that the well is flowing, he should

make the well safe, as detailed in the following section. The following

practices should be observed:

a) A full bore Kelly Cock should be stabbed onto the pipe, before installing the

circulating head or safety valve. Once the chicksans have been connected,

the line should be pressure tested to 2500 psi., using the Rig / Drill Ship

pump.

b) The pipe should be spaced out, the rams closed and the Hydril opened, at

the earliest opportunity.



c) Then shut-in drill pipe pressure, and shut in casing pressures, should be

constantly monitored, to obtain the true stabilized values.

d) If a drill pipe float is installed, pump down the drill pipe at the slow

circulating rate for a few strokes. As soon as the drill pipe pressure

stabilizes, the drill pipe pressure will be the SIDPP, plus system pressure

loss. If the casing pressure does rise, before the drill pipe pressure can be

established, then read the drill pipe pressure whilst circulating at the slow

circulating rate and maintain the casing pressure at the SICP. The resulting

circulating drill pipe pressure will then be the SIDPP, plus the system

pressure loss.

e) The Tool pusher will direct all operations and ensure that well killing

measures are started with all expediency. He shall keep the Master informed

of development.

5.5 WELL KILLING PROCEDURES

a) Kick occurs while out of hole

The Driller and his crew will;

i) Open all the subsea valves on the kill line.

ii) Close shear rams.

iii) Close surface chokes and downstream valves, in order to record the

closed in well pressure.

iv) Ensure that maximum allowable pressure is not exceeded. During these operations the Driller must inform the Tool Pusher, and

Operator's Representative.

Kill the well by squeezing the intruding fluid, or gases, back into the

formation. The new mud weight must be calculated to kill the well after

injecting the casing volume only. If this can be done, and the well is killed

temporarily, run the drillpipe in, carefully, to casing shoe. Condition the mud

to TD, in stages. Gradually lightening the mud weight, as the drill string gets

deeper.

b) Kick occurs while tripping;



i) Check hook load and set slips

ii) If float valve leaks, or if not fitted, drop in check valve or install grey valve

& close hydril. Shut in Annular BOP & hang off.

iii) Open all subsea valves on the kill line.

Call Tool Pusher and Operator's Report.

Continue to hang off, and kill the well as per this procedure.

Note:

If the bit is a long way off bottom, it may be necessary to try and strip into

the hole, to a more effective circulating depth.

c) Kick occurs while running casing.


i) Close the annular preventer and adjust to stripping pressure.

ii) Open all subsea valves on the choke line and be prepared to open the kill

line subsea valves also.

iii) Close the surface chokes carefully, whilst monitoring annular pressure.

Try to anticipate the casing being hydraulically lifted upwards.

iv) Set the casing on the casing slips in the rotary table.

v) Screw the casing/drillpipe crossover, or water bushing, into the exposed

top casing collar. It the casing is flowing, make up a Hydril sub as well.

Whilst doing this, the Driller will inform the Tool pusher and Operator's

Repr. Use the drillpipe to strip the casing into the hole, until the shoe of

the casing is as near total depth as possible. Hang this combined

casing/drillpipe string from the top pipe rams on a drill pipe tool joint, as

per the Rig / Drill Ship's "Hanging off' -chart. (Keeping the lower set of

pipe rams as reserve)

The circulating control head on top of the drillpipe should then be at least

3m (10 ft) above the rotary table.

If there is flow from the drillpipe, install check valve before stripping in.



It should also be noted that the total pressure loss will be relative to the

length and size of the drill string. This total pressure loss should be

obtainable from the IADC daily report for the current hund-off depth.

It is important to remember, when stripping in, to bleed of an equivalent

volume from the annulus to compensate for the drill pipe displacement in

the casing. Open-ended 5" drillpipe displaces 1/2 bbl per 28m (90ft)

stand, while plugged 5" drillpipe displaces 2 bbls per 28m (90ft) stand.

If the annular pressure appears to impede the stripping in operation, it will

help to fill the drillpipe with mud.

A standard precaution taken while stripping through an annular preventer,

is that tool joints must be stripped very slowly through the sealing

element. The variation in pressures, in opening and closing chambers,

take about 2 seconds to adjust.

Some leakage for lubrication should be allowed, when stripping or

rotating with element closed. The element should be opened again, after hanging off, so that any

leakage in the closed pipe rams can be detected, provided there is no shut in pressure between the annular preventer and the upper pipe rams. If there is pressure in this section, it must be bled off through the chokes, before attempting to open the annular preventer.

d) Kick occurs while running pipe, not catered for in BOP rams.


i) Open all subsea valves in the kill line.

ii) Close the annular preventer and adjust to stripping pressure.

iii) Close the surface chokes and immediate downstream valves.

Set the pipe, on appropriately sized slips, in the rotary table and screw in

the crossover from this pipe to drill pipe.

(Whilst doing this, the Driller will inform the Toolpusher and Operator's

Repr.)

Continue hanging off and killing the well. If the pipe in the hole should

begin to lift, try closing one set of pipe rams, even though the rams are



the wrong size. However, always keep one set of pipe rams in reserve, on

which to hang off:

5.6 WAIT AND WEIGHT METHOD

* Aim to have ready mixed weighed kill mud available (approximately 2 ppg

over M.W. in use).

The primary difference between this method and the Driller's method is that

the kill weight mud is pumped in, while the influx is being circulated out. In

addition, the shut-in drill pipe pressure will be reduced to zero when kill

weight mud has been displaced as far as the bit.

a) Determine the kill weight mud, Pm, from Equation (1)

Pb = Pm x 0.052 + Pdp………………………………… (1)

Where Pb = Bottom hole pressure, in PSI

Pdp = Shut-ib drillpipe pressure, in PSI

D = Well depth in FT; Pm = Mud Density in PPG

b) Determine the drill pipe capacity.

c) Estimate the increase in Pc due to heavier mud as follows:

PmL

Pc (new) = Pm * Pc (old)

Were PmL = Kill mud weight; Pm = Mud weight.

i.e: The drill pipe pressure must be systematically reduced from the pumping pressure (psi) to the Pc (new), both at the same kill rate speed, while kill weight mud is being pumped to the bit at the calculated drill pipe capacity (strokes).

d) Determine the drill pipe pressure reduction schedule.

e) Raise the mud weight in the section pit to that of the kill weight mud.

f) Bring both the pump speed and the drill pipe pressure to kill rate. (The

slow circulating rate established earlier).

g) Mix barite fast enough to maintain the suction pit at kill weight mud during

displacement.

h) If, after applying the calculated drill pipe capacity, the drill pipe pressure is

still greater than Pc (new) at kill rate, subtract Pc (new) from the actual



drill pipe pressure and reduce the annulus pressure by that result and

wait for 5 minutes for the response on the drill pipe. Continue this

procedure until the desired drill pipe pressure is obtained.

i) Continue the displacement until all gas is out if the annulus and kill weight

mud has reached the surface.

j) Shut down the pump and check for flow. No flow is observed and Pa =

Pdp = zero.

k) Raise the mud weight to an acceptable trip margin.

l) Drill ahead.

m) During the above procedures; it must be appreciated that the overall

surface volume will increase appreciable due to expansion of the influx,

as it is circulated out of the hole. Unless a large spare surface volume is

available, mud will invariably be lost. Careful consideration will need to

be given on the advisability of dumping any mud, even severely gas cut.

This volume of mud will have to be replaced, possibly making large

inroads into chemical, and more importantly, barite reserves.

5.7 DIVERTER OPERATIONS

Diverter operations should be regarded as a temporary means to control

shallow gas, whilst other measures are being implemented. They should not

be used as the primary means of controlling a shallow gas kick.

a) Policy

O.N.G.C Policy is to safely maintain control of all wells drilled at all times

by: Identifying potential area of shallow gas from site surveyor offset well

data and selecting the drilling location accordingly.

Following good drilling practices to prevent unnecessary well control situations arising.

Controlling shallow gas kicks with the safety of personnel the first priority.

Second priority is the safety of the Rig / Drill Ship and surrounding

environment.



Recognizing that gas may be present in the surface wellbore of all wells.

Note:

Recent studies of well control statistics have shown that diverter

systems have failed in around 50% of shallow gas emergencies. The

principal causes have been malfunction of valves and erosion of internal

surfaces of the system. (Research further concludes that flow conditions

in diverter systems, currently employed in the North Sea, are so severe

that is cannot be expected that the diverter system will withstand a

shallow gas kick for more than a few minutes.

b) General procedure for surface holes:

Before drilling conductor and surfaces well, control contingencies will be

discussed with the Operator and procedures established. Meetings will

then be held with all relevant crew members and shallow gas

contingency drills implemented. It is essential that all personnel on

board are trained to handle emergency situations immediately they

occur, reaction times being of extreme importance.

i) When drilling 26" hole sections in water depths greater than 100m, it

is recommended that riser less drilling be performed, allowing any

kick to flow into the sea. Be ready to move upwind, or up-current, of

the wellhead location immediately, if the gas plume appears near to

the Rig / Drill Ship.

ii) When drilling 26" hoe sections in water depths less than 100m the

riser system must be run on top of a pin connector, and the diverter

system installed.

Note: This system may be required for greater water depths than

100m, to provide better hole cleaning, mud properties, stability, or

geological sampling.

iii) In the event of a kick during drilling or under reaming, the diverter

should be closed to prevent any gas or flow reaching the rig floor. The



pin connector should be unlatched and the Rig / Drill Ship moved

upwind or up current of the wellhead location, immediately.

Note: If there is low formation strength at the 20" casing shoe, a shut-

in may result in formation breakdown and cratering to seabed. In such

case, the Rig / Drill Ship must be prepared to disconnect and move up

wind or up current of the wellhead location.

6 Records

S.No. Activity ID Responsibility Retention period

1 Well control activity IADC report Tool pusher 6 months

2 Specific reports Specific reports Tool Pusher 6 months

QHSE OPERATIONAL MANUAL WELL SHUT- IN INSTRUCTION


1 Objective - To have Aban Offshore Drilling standards to Shut in the well in case of well bore influx (well flowing)

2 Application - Floating Drilling Unit. 3 Reference - In accordance with the guidelines set by: I.A.D.C. 4 General Disposition:

4.1 Maintain the information and previous preparations verified and actualized.

Always maintain 15 BARRELS OF NEW ACTIVE MUD IN TRIP TANK

during drilling.

During drilling record the STATIC AND DYNAMIC volume in mud pits, on

proper spread sheet.

Measure and record SCR through RISER with each mud pump each shift

or when the characteristics of the mud changes.

Circulate at least once the mud volume in the Kill & Choke lines ad record

SCR each shift, or when the characteristics of the changes.

• Verify the space-out to hand-off the drill string after running wear bushing

to wellhead. Maintain the record on for the driller a visible place.

• Maintain the operating pressure for the annular prevented 500 psi.

• Keep in usable conditions a comparable crossover to the string in use, to

be able to use safety-valve as well as a sub 6 5/8" Reg box – 4 1/2" IF

box in case of disconnecting on top of lower IBOP on the PTD,

• Keep in working conditions a comparable crossover with threads on drill

collars in use: 6 5/8” Reg pin – 4 1/2" IF box and one 4" IF pin – 4 1/2" IF

box.

4.2 SHUT-IN WELL DURING DRILLING ON DRILLSHIPS

• Stop PTD and pick-up the string until the connection is above the rotary

table to the pre-established high to close the BOP. Verify the space out

taken into consideration the tide changes.

• Stop the pumps.

• Verify that the operating pressure on the annular is adjusted to 500 psi.



• Close upper annular.

• Open the failsafe valves upper choke and kill (automatic choke closed).

The valve isolating kill and choke line on manifold shall be closed. Verify

annular element is sealing, in case negative increase the pressure on

annular until sealing.

• Notify the Company Man and the Toolpusher and Master. That must to

stop immediately the crane, supply boat operation and welder jobs.

• Record the shut in pressures on casing (SICP) and drill pipe (SIDPP)

every minute until stabilized (if not a float valve is installed). If there is a

float valve in the string, pump through the drill string until the drill pipe

pressure increase and casing pressure increase simultaneously, record

same and decrease the casing pressure to the previous value.

• Record gained volume, considering static and dynamic volume.

• Continue to the HANG OFF. 4.3 Procedure for HAMG OFF (Middle Pipe Ram -5")

• Close Middle Pipe Ram with reduced pressure (aprox. 500-750 psi) and

lower the string until it sits down on Middle Pipe Ram. Verify the pre-

established space out, considering the tide.

• Adjust the compensator to midstroke putting 15-20.000 lbs down on the

ram. Regulate the pressure on the ram to Full Closing Pressure (1500

psi). Transfer the string weight on to the ram, maintaining the string

weight above the ram in tension with 10.000 lbs. Pay attention to the

ram capacity.

• Proceed to bleed off the excessive pressure below the annular through

the Automatic choke -Close Automatic choke and upper choke valves.

• Verify that the Ram is sealing. Controlling by trip tank.

• Open lower choke valves. Continue monitor SOCP through kill-line.

• Calculate and fill out the kill sheet.

• Start circulating following the procedures to kill using DRILLERS

METHOD to control the kick.



• Well killed. TO follow "U" tube procedure clean stack gas, annexed.

4.4 Closing during trip on Drillships with drillpipe on BOP.

• Monitor the Trip Tank continuously accompanying through proper

spreadsheet. If well indicates influx, proceed to close the well without

flow check.

• Lower string; set slips, close the upper Annular with adjusted pressure to

500 psi (check if the annular closed pressure permit the drill string

movement, due the heave movement) and open elevator. Install a safety

valve (Drill Pipe Safety Valve) fully open and make up same. If there is

influx through drillpipe CLOSE SAFETY VALVE. Open the PTD upper

valve and open the full safety valve if it was closed. Pick up the string.

Verify that annular is sealing, controlling by trip tank.

• Notify Company Man, Rig Manager or Toolpusher that to must stop

immediately crane, supply boat operation and welder jobs.

• OPEN UPPER CHOKE VALVES (AUTOMATIC CHOCK CLOSED)

• Open Compensator to midstroke. Position string in working position

considering tide.

• Read and note the shut in pressure on casing and drillpipe (SICP and

SIDPP) (If there is not float in string). If there is a "Float Valve" in the

string proceed as in item 11.4.2.7. SHUT IN WELL DURING DRILLING.

• If conditions of the well imposes, proceed to instructions for HANG OFF

like In SHUT IN WELL DURING DRILLING or STRIP to .bottom of the

hole.

• Effectuate the calculations on the kick sheet and follow the kill procedures

applying VOLUMETRIC METHOD until gas surpasses bit, followed by

using "DRILLERS METHOD" to control the well.

• After eliminating influx, in case it is necessary to raise the mud weight to

kill the well, analyse if the bit depth allows well control with the kill mud

from this point to surface. In case negative, close DRILLPIPE SAFETY



VALVE, install the INSAID BOP, open DRILLPIPE SAFETY VALVE and

STRIP string back to the bottom of well.

• After killing the well, run string to bottom to even out the mud to adequate

weight (BEFORE OPEN THE WELL to procedure following item 11.4.3.8)

4.5 TRIP WITH BHA IN BOP

• WITH STABILIZERS IN BOP

• In case the stabilizers are in the BOP, pull out string until bit is above the

BOP and proceed SHUT IN as described as follows with well without

string.

• WITH STABILIZERS BELOW BOP

• Stop the trip, set slips and retrieve the elevator. Install the fully open valve

and the inside BOP and prepare to STRIP to HAND OFF the string.

• Close the upper annular with adequate closing pressure for drill collar.

Remember that the string is in the slips, subject to movement of the

vessel.

• Close hydraulic choke.

• Connect the PTD and compensate for the weight of the string.

• Open the failsafe valves on CHOKE LINE.

• Wait on pressure to stabilize and record SICP.

• Eliminate the influx with the VOLUMETRIC METHOD

4.6 WIHTOUT DRILLING IN THE HOLE

• Close the shear rams.

• Close the hydraulic choke.

• Open the valves on choke line immediately below the shear rams.

• Wait on pressure to stabilize and record SICP.

• Follow the kill procedures using VOLUMETRIC METHOD 4.7 WITH WIRELINE TOOLS IN THE HOLE

• Close upper annular.

• Open the failsafe valves on kill and choke line.

• Close the hydraulic choke.



• Wait on the SICP to stabilize.

• Verify the possibility to put tool connected at the end of the cable below

the production zone so that the cable stay in tension.

• Follow the kill procedures using the VOLUMETRIC METHOD to control

the Kick

4.8 CASING IN BOP

• Set slips in rotary table.

• Close upper annular with adequate closing pressure for the casing.

Remember that the slips is subject to movement of the vessel.

• Fill the casing with identical mud to the hole through the hose, to avoid air

bubble and increase string weight in order to that the same will not be

thrown out of hole and not pushed out of the slips by the heave of the

vessel.

• If landing string is not run, connect RUNNING TOOL, CASING HANGER

assembly to the casing string.

• Connect PTD and compensate for the weight of the string.

• Close hydraulic choke.

• Open the failsafe valves on kill and choke line.

• Wait for pressure to stabilize and record SICP.

• In case the pressure (SICP) admits, initiate the control of the influx using

the Volumetric Method

5 RESONSIBILITIES

5.1 Company Man

• Analyse the procedure in relation to the Company Policy and suggest

modifications in our procedures which correspond to our policy.

• Fill out the kill sheet after closing the well in, caused by influx.

5.2 Tool Pusher / Offshore Installation Manager

• Notify the Master in case the well is shut in due to influx.

• Notify the Rig Manager that the well is closed in.

• Supervise the operation in order to guarantee correct close in.



• Prepare kill sheet.

• Avaliate the Company's suggestions and apply them when possible.

5.3 Sub Sea Engineer

• Stand by on rig floor and be responsible for BOP panel operations and

koomey unit.

5.4 Driller

• Execute all close in procedures.

• Notify the Company Man and the Aban Offshore’s Rig Manager regarding

the well shut in conditions.

• Fill out the kill sheet.

5.5 Asst. Driller

• Responsible for choke manifold alignment.

5.6 Master

• To stop all crane, supply boat operations and welder jobs.

• To follow the operation and assist the Tool Pusher / Offshore Installation

Manager when necessary.

6 Definitions

• S.I.C.P. -shut in Casing Pressure.

• S.I.D.P.P. -Shut in Drill Pipe Pressure.

• S.C.R. -Slaw Circulating Rate

• P.T.D. -Portable Top Drive

• B.O.P. -Blow Out Preventer

• I.B.O.P.-Inside Below Out Preventer

• B.H.A. –Bottom Hole Assembly

7 Appendix:

We Control Sheer for Drillships.

“U” Tube Procedure.

Well Control operation sheet.

QHSE OPERATIONAL MANUAL PLUG AND ABANDON DRILLED WELLS


1 Purpose -To abandon the well on temporary or the permanent basis.

2 Objective -To ensure safety and prevention of pollution of marine environment.

3 Scope -All drilled wells to abandon. 4 Responsibility


1 Preparing and abandoning well Tool pusher

2 Pumping of cement slurry Cementing engineer 5. Procedure -PLUG AND ABANDONMENT PROCEDURES

5.1 PLUG WELL. a) Set cement plugs across reservoir sands in 150m stages if a liner was set

cement off perforations. If a number of drill stem tests are to be

performed, it is possible to isolate each tested set of perforations by use

of a cement retainer. Squeeze top of the retainer.

b) Set a 150m plug across 9-5/8" casing shoe i.e. 60m outside and 90m

inside shoe. Weight test this plug to 10/15000 lbs and pressure test

casing. If a liner was set, set this plug across the liner top.

c) Set a bridge plug at 400m below seabed level and place 150m cement

plugs on top.

d) Perforate casing 200m below sea bed level to ensure no pressure is

trapped in 13-3/8" or 9-5/8" annulus. Observe for flow. It there is a

detectable flow, place a 100m cement plug across the perforations and

apply squeeze pressure.

e) Pull 18-3/4" stack and riser.

f) Cut all strings of casing, in one operation, 6m below sea bed level. This

may be accomplished either by explosive or mechanical means,

depending on water depth.

g) Run 18-3/4” wellhead recovery tool and recover all casing strings and

P.G.B. in one go.

5.2 Abandonment

QHSE OPERATIONAL MANUAL PLUG AND ABANDON DRILLED WELLS


The method chosen for the abandonment of a well will depend upon the

circumstances prevailing at the time. Procedures to satisfy conditions within

the well itself, are dealt with below:

a) Whether a well is to be abandoned or suspended, it is essential to

separate individual pressure zones in the well by suitable

emplacement of cement plugs, or bridges. If a cased hole is to be

abandoned, any potential leaks through casing should be prevented by

plugging at the appropriate intervals and the shoe of the lowermost

string of casing must also be bridged with cement. The well must

always be kept full of drilling fluid. .

b) Subsequent work differs according to whether the well is to be

abandoned or suspended and is followed as per the instructions of the

operators. The specific procedure shall be drafted for each of the active

zone or a well to be abandoned as per the guide lines to be followed by

operator (These may be as per API OR NPD regulations.).

6 Records

S.

No.

Activity ID Responsibility Retention Period

1 Abandoning of wells IADC report Tool pusher 6 months

QHSE OPERATIONAL MANUAL HANG-OFF PROCEDURE – CYCLONE / STORM WARNING


1 Purpose -To prepare for safe pulling out from location after well has been secured.

2 Objective -To ensure safety of the temporary abandoned well.

3 Scope -In case of storm! cyclone warnings. 4. Responsibility Sr. No. Activity , Responsibility 1 Cyclone or storm warnings Master / Barge Supervisor 2 Instructions to hang off Tool Pusher / Offshore Installation Manager 3 Performing activities to hang off Tool pusher

5. Procedure

5.1 In the event off adverse weather conditions cyclone/ storm warning, the

following will be carried out on the instruction of the Tool Pusher.

I. * All marine riser handling will be Positioned on/near the rig floor*

II. All drilling operations will cease.

III. Clear the derrick of all-tubular.

IV. Pull bit back to last casing shoe depth + drill pipe equivalent to rig

floor to well head length.

V. Install internal bop valve in the full open position and make up.

VI. Install gray-valve, make up and remove top sub and plunger rod.

VII. Install hang-off tool and make up. VIII. Run down and land out in well head, back out running tool from hang-

off tool.

IX. Pull back 3-4 feet (one meter) circulate to displace riser to sea water.

X. Pull back to above shear rams.

XI. Close lower pipe rams and close blind/shear rams.

XII. Pull out of hole laying down all drill pipe.

XIII. Secure all rig floor equipment, remove any excess equipment.

XIV. Unlatch L.M.R.P. pull back and remove choke and kill line's.

XV. Continue pull back, laying out marine riser.

XVI. Prepare to move Rig / Drill Ship off location.

QHSE OPERATIONAL MANUAL HANG-OFF PROCEDURE – CYCLONE / STORM WARNING


6. Records

S. No. Activity ID Responsibility Retention

period

1 Details of hang off IADC report Tool pusher

QHSE OPERATIONAL MANUAL NIPPLING UP AND DOWN BOP


A. NIPPLING UP B.O.P.

1. Hold safety meeting and highlight the dangers of BOP and riser handling

operations.

2. Obtain work permit for running the BOP and ensure all safety equipment is in place

prior to commencing operations

3. Install 500 Tons elevators and bails.

4. Charge Riser Tensioners and Compensator system to the required air pressures.

5. Ensure the following equipment has been serviced and is ready for use. a. Slip Joint

b. Riser Joints

c. Riser Spider

d. Riser handling tools

e. Torque wrench set to 900 ft-lbs.

f. Spare riser seals and dog assemblies

g. Diverter with handling tool installed

h. Impact wrenches fitted with 13/4" sockets

i. Hose bundle clamps

6. Remove mouse hole and layout. 7. Remove bushings and outer ring from rotary and install riser spider. Ensure spider

spacer. blocks are installed on spider dogs.

8. Install riser handling tool in the 500 ton elevators.

9. Make up two 50 ft joints of riser and torque riser dogs to 900 ft-lbs.

10. Slack off guidelines to allow the BOP trolley to be skidded aft.

11. Move BOP aft to well centre.

12. Lower riser through rotary and make up to the BOP and torque riser dogs to 900 ft-

lbs

13. Attach a minimum of three tugger lines to the lower frame of the BOP to secure

prior to lifting the BOP.

QHSE OPERATIONAL MANUAL NIPPLING UP AND DOWN BOP


14. Back out gasket-retaining bolts on wellhead connector, unlatch wellhead connector

and pick up B.O.P to clear the test stump, securing lines for the BOP must be kept

tight during this operation.

15. Move trolley fwd, remove old connector gasket from the test stump, clean test

stump and install new gasket on stump. Move trolley aft under B.O.P and land

BOP on test s

Documents

Operational Manual QMS/Procedure and...SOP 26 Picking up Casing from Catwalk 1 SOP 27 Running 13 3/ 8” Casing 2 SOP 28 Wire Line operation with use of Drill String 2 SOP 29 Slip