Forest Oil Project Well Control Bridging Document2

Forest Oil Corporation Project Well Control Bridging

Document IPM-QHSE-S001

Forest Oil Corporation Project

Issue/Revision: Draft (BLC - 05/10/2001)

Operating Co: Forest Oil Corporation (FOC Alliance)

Engineering Services: Schlumberger / IPM

Rig: Field:

Agreed by: Ned Shiflett FOC Alliance Drilling Manager _________________________ (Signature) Date:

Agreed by: Art Alarcon SCHLUMBERGER IPM Project Manager ____________________________ (Signature) Date:

Agreed by: Cecil N. Colwell FOC VP - Drilling _________________________ (Signature) Date:

Approved by: Paul Hughes Schlumberger IPM NSA QHSE Manager _____________________________ (Signature) Date:

Well Control Bridging Document

OFS – IPM – R001

(Ref. IPM – QHSE – MS: 6 --- Design & Planning

2



TABLE OF CONTENTS TABLE OF CONTENTS ........................................................................................................................................ 2

INTRODUCTION: ............................................................................................................................................... 3

1. WELL CONTROL ....................................................................................................................................... 3

1.1 RESPONSIBILITY ON THE RIG: .................................................................................................................. 3 1.2 PRIMARY WELL CONTROL: ……………………………………………………………………………..3

2. BLOW OUT PREVENTION EQUIPMENT …………………………………………………………3&4

2.1 DIVERTER :……………………………………………………………………………………………...4 2.2 BOP STACK: 11”, 5,000 PSI RATED STACK ............................................................................................. 4

3. STOCK LEVELS & MINIMUM STANDARDS....................................................................................... 4

3.1 BARITE..................................................................................................................................................... 4 3.2 CEMENT ................................................................................................................................................... 4 3.3 MINIMUM STANDARDS FOR KICK DETECTION EQUIPMENT...................................................................... 4

4. REMOVAL OF BOP INTEGRITY............................................................................................................ 5

4.1 PROCEDURE ............................................................................................................................................. 5 4.2 APPROVAL ............................................................................................................................................... 5 4.3 ADEQUATE BARRIERS .............................................................................................................................. 5

5. CHOKE MANIFOLD ARRANGEMENT................................................................................................... 6

6. SHUT-IN PROCEDURES ........................................................................................................................... 6

6.1 WHILE TRIPPING WITH DRILL PIPE ACROSS BOP STACK:.......................................................................... 6 6.2 WHILE TRIPPING WITH DRILL COLLARS ACROSS BOP STACK:.................................................................. 7 6.3 WHILE DRILLING...................................................................................................................................... 8

7. PRESSURE TESTING................................................................................................................................. 8

8. SHALLOW GAS PROCEDURES .............................................................................................................. 9

APPENDIX A BOP STACK CONFIGURATION.................................................................................... 10

APPENDIX B SUBJECT MATTER & RELATED MANUAL REFERENCES..................................... 11

APPENDIX C DISTRIBUTION LIST....................................................................................................... 13

3



INTRODUCTION:

This document has been written to provide FOC Alliance, Schlumberger IPM, and Drilling Contractor with a Well Control Bridging Document between their respective manuals or policies.

It will resolve any differences that are evident between responsibilities and procedures detailed in the three Company’s Policies and Procedures Manuals.

The parties agree that procedures from the Schlumberger / IPM Well Control Manual will be used in any well control situation.

This document addresses all foreseeable circumstances. However, any discrepancy not referenced should be of a minor nature and will be discussed and resolved on the drilling unit by the FOC Alliance Well Site Supervisor and the Drilling contractors Tool pusher.

1. WELL CONTROL (Ref. IPM-Well-S011)

1.1 Responsibility on the Rig:

Responsibilities of key personal at the well site will be reviewed when preparing the projects Bridging Document and agreed to by the Operator, Schlumberger / IPM, and the designated Drilling Contractor.

(REF. MMS. Subpart D Sec. 250.400)

1.2 Each project shall have a designated Person- in-charge who has the ultimate authority for all necessary actions to be taken on the work location at all times.

• The FOC Alliance Well Site Supervisor will be ultimately responsible for well control in conjunction with the Drilling Contractors Senior Tool pusher in order to determine the best course of action to be taken in any well control situation.

• In certain projects and circumstances, the Person- in-Charge may appoint a competent person as the “responsible person” for any drilling activities.

• An organizational chart that will include well site representatives from the Operator, Schlumberger / IPM, and the Drilling Contractor will be formally developed, accessible to all persons, and visibly posted at the well site and in the working office.

Decisions will be based on the agreed and existing Well Control Program.

2. BLOW OUT PREVENTION EQUIPMENT (Ref. IPM-Well-S002)

Related well control equipment and BOPs, working pressure ratings, ram configurations of the BOP, and selection must provide sufficient BOP integrity and operational flexibility to accommodate all and any anticipated well control problems or situations. (Ref. MMS Sec. 250.515) and (MMS Subpart D Sec. 250.409)

4



2.1 The pressure of a working ram-type BOP must be greater than the maximum surface pressure that might be anticipated.

2.1.1 Exploration Wells – anticipated maximum surface pressure must be based on full evacuation of the well to gas.

2.1.2 Development Wells – anticipated maximum surface pressure must be the same as the maximum shut-in tubing pressure.

When required, Blow out prevention equipment should be in accordance with, or exceed API RP 53.

The closing response times of the BOP and the hydraulic fluid volume of BOB accumulators should meet or exceed the requirements of API RP 53 and API RP 16E.

3. STOCK LEVELS & MINIMUM STANDARDS (Ref. IPM-Well-S007) Stocks of sufficient mud material, fuel, cement, and other specified materials must be satisfactorily stored and maintained at the well site in order to handle any unexpected well control problems or situations.

3.1 Barite

Enough weighting material (barite) to be on board to raise the mud weight of the entire mud circulating volume by 120 kg/m³ (1 ppg), or to leak off, which ever is the lesser.

When over-pressured formations are anticipated, at least 100 tons of weighting material shall be on-site before commencing of any drilling operation.

3.2 Cement

Enough bulk cement to set one 120 meters (400 feet) open hole neat cement plug in the current hole size (offshore only)..

3.3 Fuel

Enough fuel supply to last for 48 hours.

3.4 Drill water

An 18 hour supply shall be availably and ready(this does not include any reserve firewater or emergency cooling water).

3.5 Misc. mud material

A sufficient amount of material to build the volume of the cased hole plus 300 bbls.

5



For high-pressure wells and/or remote location wells, the above minimum stock requirements should be regularly re-evaluated on a case-by-case basis, depending on the remoteness and accessibility of the well site and depending on the severity of any potential drilling problems

4. REMOVAL OF BOP INTEGRITY

4.1 Procedure A procedure will be formulated in case the pressure control equipment is to be temporarily removed from the wellhead for repair. The procedure will be recommended by the Drilling contractors Operations Manager and Schlumberger / IPM Project Manager.

4.2 Approval This procedure has to be approved by the FOC Alliance Drilling Manager and Drilling contractors Senior Management.

4.2.1 The approval will only be necessary when the removal of the pressure control equipment is not included in the approved Drilling Program.

4.2.2 The Drilling Program will include casing and or suspension details for each well drilled, as

applicable.

4.3 Adequate Barriers

Wells shall have two or more dissimilar tested and impermeable barriers at all times to ensure that the risk of an unplanned flow of the well bore and reservoir fluids to the atmosphere or seabed ia as low as reasonably practicable.

Prior to removal of the pressure control equipment adequate barriers will be in place to secure integrity of the well. The well will be flow checked after setting each barrier. The following criteria will be adopted:

4.3.1 Cased hole - No hydrocarbon sands behind casing

• Mud column or mechanical barrier, as appropriate.

4.3.2 Cased hole - Hydrocarbon sands behind casing

• Mud column • Mechanical barrier, as appropriate.

4.3.3 Open hole

• Mud column. • Cement plug across casing shoe.

6



• Mechanical barrier, as appropriate.

Notes:

i) Cased hole is defined as cemented and pressure tested casing as defined in the Drilling Program with an undrilled shoetrack.

ii) Cement plugs will be tagged and weight tested to 20,000 lbs with a minimum of 200 ft of cement above the casing shoe. Plugs will be pressure tested to a minimum of 1 ppg above leak-off/limit test at casing shoe.

iii) Mud column will be at least 200 psi overbalance.

iv) The mechanical barriers will be:

a) a retrievable packer /w kill string

b) a retrievable bridge plug

The retrievable packer/kill string will incorporate a storm valve and be of sufficient length to facilitate any kill operation.

Either packer or bridge plug will be pressure tested to the limit of the previous barrier. The setting depth will be advised as applicable.

5. CHOKE MANIFOLD ARRANGEMENT

5.1 The electives associated with choke manifold line up are as follows.

• The valve immediately upstream of the auto choke will be in closed position. • The valve immediately downstream of the auto choke will be in open position.

5.2 For details of remaining line up sequencing see Schlumberger / IPM (Well Control Manual, Section 3, Page 78, Revision Date: 1999)

6. SHUT-IN PROCEDURES (Ref. IPM-Well-S013)

Full authority and sole responsibility shall be given to the driller, so he can take immediate corrective action, to shut in the well, by using the hard shut-in method.

To shut in a well, the response time will be minimized by using the proper kick detection equipment. The shut-in procedures notice will be displayed / posted at the driller’s position.

6.1 While tripping with drill pipe across BOP stack:

In case any doubt of a flowing well exists:

7



• Alert rig crew • Lower stand until tool joint is at a working height. Set slips • Install and make up fully open safety valve. • Close safety valve • Check well for flow

If flowing, the well will be closed in using the Hard Shut-in Method or Fast Shut- in Method.

• Close annular preventer • Open remote control choke line valve (HCR) • Notify person in charge (FOC Alliance Well Site Supervisor and Drilling contractors

Senior Tool pusher) • Make up a Kelly or top drive (Insert a pup joint or single joint between safety valve and

top drive) • Open stabbed in safety valve • Record the following: •

o Shut in drill pipe pressure o Shut in annulus pressure o Pit Gain

NOTE: The preferred course of action after closing in on a kick while tripping will be to return the pipe as close as possible to bottom. If it is decided to strip back in the hole, follow the procedure described in II.2.5 of the Schlumberger / IPM Well Control Manual. Possible expansion of the influx volume due to migration and the effect of running the string into the influx are to be taken into account during stripping operations.

• Determine the well kill method.

6.2 While tripping with drill collars across BOP stack:


• Alert rig crew • Lower stand until tool joint or drill collar connection is at a working height. Set slips. • Install the appropriate cross-over • Pick up a joint or a stand of drillpipe, make up and run joint or stand in the hole • Make up full opening safety valve and close same • Check for flow

If flowing, the well will be closed in using the Hard Shut-in Method as follows:

• Close annular preventer • Open remote control choke line valve (HCR) • Notify person in charge (FOC Alliance Well Site Supervisor and Drilling contractors

Senior Tool pusher)

8



• Record the following: • Shut in drillpipe pressure • Shut in annulus pressure • Pit Gain • Install an inside BOP above the safety valve

The string can now be stripped to bottom if necessary.

6.3 While drilling


• Alert the rig crew • Stop rotary and pick up off bottom • Shut down mud pumps • Check well for flow

If flowing, the well will be closed in using the Hard Shut-in Method as follows:

• Close annular preventer • Open remote controlled choke line valve (HCR) • Notify person in charge (FOC Alliance Well Site Supervisor and Drilling contractors

Senior Tool pusher) • Check space out and close pipe rams and ram locks • Bleed off pressure between pipe rams and annular (if possible) • Record the following: • Shut in drillpipe pressure • Shut in annulus pressure • Volume of influx • Determine the well kill method.

7. PRESSURE TESTING (Ref. IPM-Well-S001)

All BOP’s and related equipment shall be tested on a regular basis. This applies to well operations where diverter/BOP’s are in use

7.1 Procedures describing this area of testing: (Schlumberger / IPM Well Control Manual, section lll.6) and (MMS Subpart D Sec. 250.405) and (MMS Subpart D Sec. 250.407)

• The BOP stack and ancillary pressure control equipment and surface circulating equipment will be pressure tested within intervals not exceeding 14 days or sooner as noted in the approved

9



• Application for Permit to Drill. If necessary to exceed the approved interval as a result of drilling operations, approval must be granted from the MMS and the office must be notified. All pressure tests must meet the requirement of 30 CFR 250.407

• All pressure tests will be at a low test pressure between 200-300 psi for 5 minutes and at the final high test pressure for 5 minutes. Failure is deemed when a test does not hold the required test pressure and the problem must be remedied and the affected components retested. The low pressure test must be conducted first.

• The BOP will be accepted when pressure tested on a test stump to the following pressures at commencement of contract:

o pipe, variable bore and shear/blind rams, to 5,000 psi o choke and kill lines/valves and flexible hoses to 5,000 psi o annular preventer to 3,500 psi

• During operations the ram type preventers will be tested to 5,000 psi, annular preventer to 3,500 psi, and choke manifold equipment to 5,000 psi unless otherwise stated in the Drilling Operations Program and approved in the Application for Permit to Drill.

8. SHALLOW GAS PROCEDURES (Ref. IPM-Well-S019)

In case there is a possibility of the presence of Shallow Gas, a contingency plan should always be in place if the problem arises. (Schlumberger Well Control Manual, Sec. ll.1.1.3, ll.1.2.3, ll.2.2 & Appendix 6).

8.1 Shallow Gas Considerations are not applicable to this program as all wells are re-entry applications with surface pipe set and primary BOP equipment nippled up during the entire operation. 8.2 To Ensure that careful consideration is given to the possibility of encountering Shallow Gas, at both the planning and operational stages of the well.

Any and all available information will be used to assess the risk of encountering ShallowGas. 8.2.1 If there is any indication of the presence of a Shallow Gas problem, the gas will be assumed

to be present, and every consideration will be made to move the well surface location.

8.3 Pre-job Shallow Gas Planning Requirements and Survey:

8.3.1 By using the best available means, to ensure that the evaluation of the risk has been carried out. 8.3.1.1 Exploration & appraisal wells drilling operation program will contain the results of the assessment relative to Shallow Gas, the top hole drilling strategy, contingency plans for Shallow Gas, and any relevant information from any nearby wells.

10



8.3.1.2 Development wells drilling operation program will contain the top hole drilling history, contingency plans for Shallow Gas, and any relevant information gathered from any nearby wells.

11



APPENDIX B SUBJECT MATTER & RELATED MANUAL REFERENCES

1) Well control certification requirements for drilling personnel

• Schlumberger / IPM, FOC Alliance Rig Contract (Appendix 6) / HSE Management Systems (Item 1.3.3) & Bridging Documents (Appendix A).

2) Well control drills: types and frequency

• Schlumberger / IPN Well Control Manual (Section IV)

3) BOP configuration. Requirement for casing rams

• Schlumberger / IPM Policies and Procedures (Policy IPM-Well-021)

4) BOP (& related equipment) tests: function tests, pressure tests, frequency, test pressures, BOP test sheet.

• FOC Alliance Approved Application for Permit to Drill and Schlumberger / IPM Well

Control Manual Sections I.13 and III.6.1 and III.6.2, MMS Regulations 30CFR 250.407

5) Casing pressure testing requirements: test pressure for each casing size.

• Drilling Operations Program

6) Leak-off test or limit test policy.


7) Kick tolerance while drilling

• Schlumberger / IPM policy (Policy IPM-Well-009)

8) Policy regarding drilling breaks

• Schlumberger / IPM Well Control Manual (Section II)

9) Flow Check policy (frequency and duration)

• Schlumberger / IPM Well Control Manual (Section II)

10) Amount of pressure overbalance to maintain in static conditions

• Well Control Bridging Document (Section 1.2)

12



11) Review of kick detection equipment (flow indicators, mud pit level monitoring)

• Well Control Bridging Document (Section 3.3)

12) Inventory of barite and cement to maintain at the well site.

• Well Control Bridging Document (Sections 3.1 and 3.2)

13) Policy (frequency, etc.) for recording of circulating pressure (s) at reduced pump speed (s).

• Schlumberger / IPM Well Control Manual (Section II.2.4.1 )

14) Agreement on general well kill methods. Pre-recording of information and frequency of revisions. Standardized kick control worksheet (s) and formulae to use.

• Schlumberger / IPM Well Control Manual (Appendix 3)

15) Detailed shut in procedure (agreed step by step procedure to be posted in the vicinity of the BOP Driller’s panel).

• Schlumberger/ IPM Well Control Manual (Section II) / Well Control Bridging Document (Section 6)

16) Stripping check list

• Schlumberger / IPM Well Control Manual (Section II.2.5)

17) Well site individual responsibilities and line of command during well control operations.

• FOC Alliance - Schlumberger / IPM – Drilling contractors Bridging Document and Well Control Bridging Document, (Section 1.1)

18) Surveying policy for vertical wells


13



APPENDIX C DISTRIBUTION LIST

1. IPM Project Manager

2. IPM Drilling Engineer

3. IPM Supervisor

4. FOR Alliance Well Site Supervisors

5. Drilling contractors Tool pushers

6. Drilling contractors Operations Manager

7. Schlumberger / IPM Operations Manager

8. QHSE Manager OFS and IPM –Houston

9. FOC Alliance Drilling Manager

10. FOC Alliance Engineering Manager

11. FOC Alliance HSE Supervisor / Manager

Forest Oil Project Well Control Bridging Document2

Documents

Transcript of Forest Oil Project Well Control Bridging Document2