DaA-14 Slickline on Platform Procedure - August 4, 2014

DAMAR-A DEVELOPMENT DRILLING PROGRAM

SLICKLINE DIAGNOSTICS ON DAA-14

ORIG: DAMAR-A WELL FILECC: WEST LEDA DRLG SUPV

DaA-14 Slickline Diagnostics Procedure of 22

Well Name Slot AFE NoDamar-A14 5 909/13009.1.01.01

TABLE OF CONTENT

BACKGROUND

PROCEDURE OUTLINE

EQUIPMENT REQUIRED

WELL INTERVENTION PROGRAM

ATTACHMENTSA. WELL SCHEMATIC

B. DEVIATION SURVEY

C. STETHOSCOPE DATA

D. SLICKLINE PRESSURE CONTROL EQUIPMENT (PCE) DIAGRAM

E. 'H' MANIFOLD AND PUMPING LINE LAYOUT

F. BHA diagrams


Background

As of July 30th 2014, Drilling operations are on-going at Damar A with the West Leda Jack-up Rig. The production hole of DaA-5 is currently being drilled / cased.

DaA-14 was completed on June 16, 2014. While start-up checks were conducted on this well to ready it for production, it was found that the production casing annulus had sustained pressure. Pressure would build back up gradually after each bleed down. Surface diagnostics have been conducted on this well, indicating that there could be a tubing leak in this well. This leak also appears to be small based on the pressure build up rate in the production casing annulus. The plan for DaA-14 is to conduct further diagnostics to pin point the location of the leak while DaA-5 is drilled and completed. This work needs to be completed before DaA-5 is completed to allow option to workover the well while the drilling rig is at location.

Note: High Rate Water Pack (HRWP) in DaA-14 was compromised during installation. It is suspected that the screens have failed and there may be gravel in the LS below the upper completion (2,515m RKB onwards). If any intervention is to be done past this depth, proceed with extra caution and conduct pull tests regularly prior to passing this depth. Discuss with town prior to proceeding with any intervention past this depth.

Plans for Slickline

Based on current drilling activity outlook, the slickline activity described in this document is tentatively planned for Aug 7th, 2014, after successful production casing cementing operation. The window to perform this job is from Aug 7th to Aug 15th, when DaA-5 is expected to be completed. This slickline activity is expected to last 4 – 5 days.

The following is an outline of the plan for this activity:1. Clear the south side of the Damar A platform with the rig crane to make room for slickline and other

associated equipment2. Spot slickline and other required equipment on to the south side Damar A, which is accessible by the

rig crane3. Plan to position equipment to minimize need to move after initial spotting position4. Using a combination of tuggers below the rig floor and keelhauling, replace the hatch cover currently

on DaA-14 with the hatch cover which allows slickline rig-up (hatch cover with opening in the middle)5. Using tuggers below the rig floor and keelhauling, move equipment to the final positions (particularly,

telescopic mast, lubricator skid, wellhead control panel, ‘H’ manifold, and coflex lines / hard piping)6. Rig-up ‘H’ manifold, hard piping, and colfex lines as required7. All lifting and handling of equipment/tools below the rig floor structure will utilize a combination of

tuggers under the rig floor structure, tuggers/pulley rigged-up on the platform main deck for keelhauling, and the slickline telescopic mast

8. Similarly, after slickline operations is completed, equipment will be moved back to the south side of the platform in a similar fashion, for handling by the rig crane

The plan for this work is to have dedicated Wellwork Supervisors to supervise the slickline operations for 24hours. Wellwork Supervisors supervising the slickline activity will advise the Drilling Supervisor on work progress/issues, while drilling activities continues to be led by the Drilling supervisor. The Senior Drilling Supervisor remains as the DPIC and is responsible for the overall operations.Projects activity will be suspended during this period due to POB, deck space, and multiple SIMOPs considerations.


Procedure Outline

All pressures shall be monitored and recorded in every step of this program as part of the diagnostics. Signs of communication between strings shall be observed at all times.

1. Fill up and pressure up the tubing by Production Casing Annulus (PCA).2. Set tubing plug in Short String (SS) and pressure up SS to check communication with PCA.3. Pressure up Long String (LS) to check communication with PCA.4. Pressure up LS against lower completion.5. Contingency to investigate leak in lower completion in LS.

Equipment

1. Deleum slickline unita. Reel skidb. Power pack X 2c. Telescopic mastd. BOP / SCSSV control panele. Lubricator skidf. Tool containerg. Logging container – with EMR gauge, MPLT, and Ultrasonic toolh. Air compressor (contingency)

2. SVP equipmenta. ‘H’ manifoldb. Treating lines and coflex hosesc. 2-1/16” 5K flange to 2” 1502 X-over for PCA

3. Tubing plugsa. 2.813” X-lock mandrel – 3

220093411 MANDREL,X-LOCK,3-1/2",OTIS#810XO28106

b. 2.81” plug body – 4220071517 PLUG,PXN,2.813",OTIS#24-PXX-28100

c. Vee packings – 20220071182 PACKING,VEE,OTIS#91V1330,2.813"X2.370"


Well Intervention Program

• Due to the nature of the diagnostics program, changes in step sequence is expected as new data is received through-out the program. If there is no significant changes to the steps or condition of the well, changes to the sequence of steps can be made by the Superisor leading the operations after consulting with Drilling Engineer and Drilling Ops. Supt. If there is significant changes to the program or well condition, MOC approval must be obtained from the Drilling Ops. Supt.

• Toolstring configuration proposed in this program are guidelines and can be changed by the Supervisor at site as needed (adding stems, roller boogies, and overall configuration as needed). Toolstring configuration must be tracked and recorded clearly.

• Unless otherwise stated, the working fluid for this program will be 9.9ppg completion brine.

• Through-out this diagnostics program, all pressure readings from the Production Casing (PCP), Short String (SS) and Long String (LS) Tubing Head Pressure (THP) and Downhole Pressure Gauges (DHPG) should be monitored and recorded. Signs of communication between strings to be observed at all times.

1. Spot Deleum and SVP equipment on the platform and prepare to rig-up on well.All lines should be hooked-up as necessary and pressure tested to 200/3,500psi.

The ‘H’ manifold will be hooked-up to:• Tubing string via pumping tee• Production Casing Annulus via 2-1/16” 5K flange to 2” 1502 X-over• Flow back well via tree top X-over• Cementing unit on the rig via a high pressure coflex line

2. Fill up the Production Casing Annulus (PCA) with 9.9 NaCl brine via the lubricate and bleed method and measure volume required to fill up PCA.Attempt to lock 2,000psi in PCA. Discuss results with town.

3. Rig-up slickline PCE on SS. Pressure test PCE to 200/3,500psi.Lock the SSV actuator with fusible cap.Open the SCSSV with Deleum’s control panel – observe for pressure equalizing (SCSSV is of the self-equalizing type).Zero slickline unit on tubing head spool (Elevation is 25.1m)

4. RIH with 2.80” gauge ring to tag XN Nipple at 2,458m RKB.Slow down across SCSSV to ensure SCSSV is fully open before passing SCSSV.Conduct pick-up checks as needed to ensure there are no abnormalities.POOH.

5. RIH with 2.813” PXN plug body and set at XN-Nipple at 2,458m RKB. POOH.RIH with plug prong and set in same.POOH.

6. Lubricate and bleed SS tubing full of 9.9 NaCl brine, pressure up to 2,000psi, attempt to lock pressure in SS. Observe all pressures for 30 minutes.

7. If SS is in communication with the PCA, attempt to maintain 2,000psi in the SS while bleeding off pressure from the PCA. (If pressure test on SS is good, skip this step and proceed with step 8).• While maintaining differential pressure between SS and PCA, RIH with ultrasonic log to PXN plug,

and log-up at 30ft/min. If leak rate is high such that it is able to establish flow rate of 0.25bpm, consult town on potential of running MPLT tool instead of ultrasonic tool.

• After logging is done, pressure up SS and allow PCA to equalize, testing SS and PCA as a system against top packer and PXN plug.

• Discuss with town on logging results, and if repeat runs needs to be conducted.


8. Rig-down from slickline PCE from SS and rig-up on LS.Pressure test PCE to 200/3,500psi.Lock the SSV actuator with fusible cap.Open the SCSSV with Deleum’s control panel – observe for pressure equalizing (SCSSV is of the self-equalizing type).

9. Pressure up on LS to 2,000psi, monitor all pressures for 30 minutes.

10. Attempt to pressure up LS against the lower completion (if PCA is in communication, allow PCA pressure up increase and equalize with LS and pressure up LS and PCA as a system against lower completion)

11. If it is suspected that pressure in the LS is lost to the lower completion,• RIH 2.80” gauge ring to 2,500m RKB (past SSD at 2,476m RKB).• Set 2.813” PXX plug body at 2,476m RKB, POOH.• RIH to set plug prong in plug body. POOH.• Pressure up LS (and any other strings that are in communication with the LS) to 2,000psi. This is to

confirm that the top packer is holding pressure.

12. If LS is in communication with the PCA, proceed with the following sub steps.• If not performed yet, RIH 2.80” gauge ring to 2,500m RKB (if no plug at SSD at 2,476m RKB)• Attempt to maintain 2,000psi in the LS while bleeding off pressure from the PCA• RIH with ultrasonic log to 2,476m RKB, and log-up at 30ft/min. If leak rate is high such that it is able

to establish flow rate of 0.25bpm, consult town on potential of running MPLT tool instead of ultrasonic tool.

• Discuss with town on logging results, and if repeat runs needs to be conducted.

13. Discuss with town prior to conducting the following steps• Retrieve plug prong from LS SSD at 2,476m RKB.• Allow pressure to equalize across plug body prior to retrieving plug body at 2,476m RKB.• RIH 2.80” gauge ring to tag 2,873m RKB – proceed with extreme caution and conduct pick-up tests

regularly.• RIH with either MPLT or Ultrasonic tool to find leak depending on the leak rate, RIH to deepest depth

reached by gauge ring in clearance check.

14. Discuss with town prior to conducting the following steps• Rig-up slickline on SS, pressure test PCE as required.• RIH to retrieve prong from PXX plug body at XN-Nipple at 2,453m RKB.• Allow pressure to equalize across plug body prior to retrieving plug body from 2,453m RKB.

End of procedure


Attachments

Completion Report


Deviation Survey


Stethoscope Data


Slickline PCE diagram

Job: Client:Well No: Date:

Description Top Connection Bottom Connection WP Svc Length (ft)

Stuffing Box 5-3/4" Otis Pin 10K H2S 3 ft

Lubricator 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 8 ft

Lubricator 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 8 ft

Lubricator w 1/2" NPT 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 8 ft

Quick Test Sub 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 3 ft

Dual Ram BOP 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 4 ft

Pump In Tee x 1502 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 3 ft

Riser 5-3/4" Otis Box 5-3/4" Otis Pin 10K H2S 10 ft

Tree top X-Over 5-3/4" Otis Box 4.75"-4 ACME Bowen 10K H2S 2 ft

ExxonMobilDAMAR A-14

PCE Stackup Diagram


‘H’ manifold and pumping lines lay-out

Line to flowBleed-off Line back well

From rigcement unit

PCA valve,hook-up 2-1/16" 5K flange to 2" 1502 X-Over

SS or LS Slickline Pumping Tee

1

1

2

DaA-14Flow back

well

2

2

2

22

2

1

2

2

H-Manifold

Flowline to drain vessel /

production system

ProductionWing Valve


BHA diagrams


Standard Slickline Toolstrings

Field Name: Rig Name:

Slickline Supervisor: Date:

OD(in)

1.875"

2.4"

1.875"

1.875"

2.4"

2.4"

1.875"

1.875"

Service tools TOTAL

OD Tool Length Total TS lengthwith service tool

(in) (in) (ft)

2.72" 19.000 18.013 23.400 208.400

2.720 24.500 18.472 17.000 202.000

2.800 9.000 17.180 4.800 189.800

2.74" 14.97 17.678 15.400 200.400

2.838" 16.510 17.806 19.840 204.840

KNUCKLE JOINT

DELEUM BHA PROPOSAL

Company Rep:

DAMAR Well No:

Weight (lbs)

8.300

17.000

79.400

Max Deviation

ROPE SOCKET

DESCRIPTION

ROLLER BOOGIE

5' TUNGTEN STEM

10.000

17.000

17.000

28.000

8.300

ROLLER BOOGIE

ROLLER BOOGIE

MECH JAR 20" STROKE

MALE QLS X-OVER x 15/16” / 1-1/16” BOX

185.000

STANDARD TOOLSTRING

SERVICE TOOLS DESCRIPTIONTool Weight

(lbs)Total TS weight

with service tool (lbs)

24.500

24.500

42.660

6.000

3" GR PULLING TOOL

3" GS PULLING TOOL

2.8" GAUGE CUTTER

3" RB PULLING TOOL

197.160

3" SB PULLING TOOL

A-1468.4⁰

Length

(in)

6.000

24.500

60.000

9.000


MPLT toolstring

Field Name: Rig Name:

Slickline Supervisor: Date:

OD

(in)

1.875"

1.875"

1.875"

1.875"

1.875"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

1.69"

TOTAL

Total in ft

DELEUM BHA PROPOSAL

Company Rep:

DAMAR Well No: A-14

Max Deviation 68.4⁰

STANDARD TOOLSTRING

DESCRIPTION LengthWeight (lbs)

(in)

ROPE SOCKET 6.000 8.300

SWIVEL JOINT 14.140 8.800

5' TUNGTEN STEM 60.000 79.400

KNUCKLE JOINT 9.000 10.000

MEMORY BATERY HOLDER 17.600 6.200

MALE QLS X-OVER x 15/16” / 1-1/16” BOX 6.000 8.300

IN LINE SPINNER 17.280 6.000

23.100 9.500

PRODUCTION KNUCKLE JOINT 6.480

PRODUCTION GAMMA RAY

6.480 3.500

23.000 10.000

290.720 190.100

CONTINUEOS FLOW SPINNER METER 5.760 2.300

18.480CAPACITANCE TEMPERATURE FLOW 5.400

ULTRA MEMORY TOOL 12.500 5.900

QUARTZ PRESSURE CASING COLLAR LOCATOR

18.900 9.000

FLUID DENSITY RADIATION

3.500

PRODUCTION KNUCKLE JOINT

PRODUCTION ROLLER CENTRALIZER 23.000 7.000

24.2

PRODUCTION ROLLER CENTRALIZER 23.000 7.000


Ultrasonic Toolstring


DaA-14 Slickline on Platform Procedure - August 4, 2014

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