RADAR WATCH PROCEDURES

In areas of high risk, i.e., near shipping lanes or heavily traveled routes, radar procedures described below should be implemented on the drilling unit.

Radar Operation

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1. The Drilling Unit's radar installation is to be located:

• In an area providing visual contact with the surrounding outside seas, i.e., bridge, etc.

• Away from heavily traveled and noisy areas, i.e., not to be located in a radio room. Near VHF Marine radio.

2. Qualified and trained radar operators are to man the radar station 24 hours per day and be relieved by qualified marine personnel at least every 3 hours for breaks.

3. Radar unit settings shall be maintained as follows:

• Primary scanning set to 12 nm.

• Audio alarm set for 5 nm.

• Inner Guard Ring set for 2 nm.

4. Radar Watch Operator's duties shall include:

• Continuously man the radar station except when relieved for breaks.

• Maintain radar unit settings described above.

• Track all ships within a 12 nautical mile range and determine their course heading.

• Contact ships reaching 5 nautical mile range of Drilling Unit's position and request ships maintain 2 nautical mile separation.

• Maintain logbook of all contacts with ships.

Alert Procedures

1. Ships within the 12 nautical miles primary radar range will be marked with the "EBL" by the Radar Operator who will track the vessel heading and determine the course heading.

2. Ships reaching the 5 NM range will be contacted by the Radar Operator:

Radio Contact Established

• Verify the vessel crew is aware of the Drilling Unit installation's position.

• Confirm that the vessel is not in mechanical difficulty.

• Request the vessel maintain a 2 nautical mile separation from the Drilling Unit.

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Radio Contact Not Established

• Radar Watch Operator will notify the Offshore Installation Manager (OIM).

• OIM will dispatch supply/standby vessel to attract the ship's attention (e.g., fire hose, ships horn, radio).

3. Ships reaching the 4 NM range and on a course:

Radar Watch Operator

• Notify the OIM.

Offshore Installation Manager

• Contact the vessel to divert its course and/or determine if ship has mechanical difficulty.

• Notify the Operations Supervisor on duty that a collision is possible.

• Notify supply/standby vessel to intercept ship.

4. Ship reaching the 4 NM range and on a collision course which cannot be contacted and/or has mechanical difficulty (engine/steering failure):

Offshore Installation Manager

• Notify supply/standby vessel to return to rig if ship cannot be intercepted.

• Notify the Operations Supervisor on duty.

• Sound alarm and muster rig personnel at their abandonment stations.

Operations Supervisor

• Notify Drill Crew to secure the well.

• Notify Shore Base that a collision is possible and imminent.

5. Ships reaching the 2 NM range radar guard ring on a collision course:

Offshore Installation Manager

• Determine need for abandonment.

• Sound the abandonment alarm for the Drilling Unit.

• Broadcast navigational warnings continuously.

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• Notify supply/standby vessel to assist in rig abandonment.

• Abandon rig.

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SECTION 3 - APPENDIX G-I

MEMORANDUM

ExxonMobil Development Co. Drilling DATE:

TO: PRODUCTION AND DRILLING OPT. SUPTS FROM: OFFICE ENGINEERING TEAM

SUBJECT: " " Platform Drilling Program SIMOPS/MIRU Meeting BACKGROUND

The jack-up drilling rig is scheduled to begin operations at the " " Platform on about . On , a SIMOPS meeting was held to evaluate the risks involved with simultaneous drilling and production operations at the platform. Following is a summary of the review of the SIMOPS Move-In/Rig-Up Checklist for Jack-Up Drilling Rigs.

SIMOPS MIRU CHECKLIST REVIEW

1) A mudline survey with divers and/or side scan sonar may be necessary to check for any obstacles or debris that might be in the immediate area where the rig is to be positioned. Determine if area pipelines need to be buoyed for the planned approach of the rig. At those platforms where a jack-up rig has previously operated, the footprint of the rig is to be studied to determine if it can be reused.

(NOTE: The side scan sonar is typically performed if a jack-up rig has not been at the location within 12 months, or if any substantial construction or workover work has been performed within the last year). Note, if any pipelines are within 490 ft of the rig, the MMS requires buoys, unless a waiver is obtained. Global positioning is usually sufficient to obtain a waiver unless the spud cans are very close (~50 ft) to the pipeline.

•

2) Evaluate the punch-through potential of the rig legs.

•

3) Evaluate the platform leg batter and positioning of dolphins for potential interference with rig legs.

Drilling/Subsurface engineering will provide scale drawings of the rig, spud cans, etc.

•

4) Review the location of all pipelines, underwater flare lines, process equipment vent lines, pipeline risers, etc. and determine if any relocation or protection work is necessary. Active pipelines that are expected to be located beneath the jack-up barge shall be depressurized during the MOB/DEMOB. For those lines to be reactivated following MIRU, a joint decision by Drilling and Production Operations Management is made regarding any special precautions necessary to ensure that an appropriate level of safety is maintained.

•

5) Determine if the main deck production processing equipment located beneath the cantilever requires protection or relocation. (NOTE: There are to be no unprotected pressurized process vessels, such as separators, glycol contact towers, etc., located beneath the cantilever, nor any gas venting in this area).

•

6) Unprotected process equipment located within 10 ft. of the cantilever shall have a fire monitor, operated from the rig, directed on it.

•

7) Locate all fire protection equipment stations on the main deck, and determine if they require relocation.

•

8) If the platform has a firewater system, ensure that it is operable and meets the deliverability requirements for that facility.

•

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9) Ensure that the location of the rig's designated safe welding area meets all MMS and ExxonMobil regulations (consider distances from existing combustible material or any process equipment containing hydrocarbons).

•

10) A scale drawing depicting platform/rig equipment layout shall be developed highlighting the designated safe welding area, as well as areas in which Hot Work is prohibited.

•

11) Inspect all platform deck grating, plating, boards, and handrails, and arrange for repair or replacement as needed.

•

12) Ensure that all aids to navigation are operating properly.

•

13) Record all casing pressures on both producing and non-producing wells. This information is transmitted to the Drilling or Workover Engineer.

• Casing pressures on ALL are as follows:

Well Name Inside Drive Pipe Inside Conductor Inside Surface

Note: NA means that there is no pressure seal & gauge on the annulus.

14) Review with the Field Superintendent the rig move schedule to coordinate Production Operations while the rig is being mobilized/demobilized and cantilevered into position over the platform.

•

Field Supts: & , x- or

EMDC Drilling Supts: at ( ) -

15) A scale drawing showing the position of the rig and cantilever in relation to the platform process equipment, fire protection equipment, lighting, escape routes, etc. is developed and distributed.

•

16) Ensure the contractor crane complies with the inspection requirements of API RP2D. Documentation of this inspection is required.

•

17) An Emergency Evacuation Plan (EEP) data sheet is completed and submitted for approval to the local Officer in Charge of Marine Inspection of the United States Coast Guard prior to spud. The Field Superintendent shall gather the data for the EEP and forward it to the Regulatory Affairs Engineer.

•

18) If the rig is located on a platform with production quarters, the rig's emergency alarm system is connected to the production alarm system and these alarms are to be compatible.

•

19) Ensure that sufficient emergency lighting is available at all living quarter exits, along escape routes, and at the escape capsules to provide safe transit to the muster areas.

•

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PERSON IN CHARGE (PIC)

• The will be the PIC. The Drilling and Field Superintendents will work together to coordinate tying the rig and platform ESD systems together, utilizing the I&E Technician, per the SIMOP's Manual.

• The PIC and Field Superintendent should communicate each day prior to the 6:00 AM Production safety meeting regarding safety issues and work status.

APPROVALS

Drilling Ops. Supt. Production Ops. Supt.

SIMOPS Meeting Attendees:

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SECTION 3 - APPENDIX G-II

In document Exon-Mobile Drilling Guide (Page 90-97)