Wellbore Clean Out Services Program for Tangguh Integrated Drilling Program – a Proposal

Technical Proposal/Program – 9-7/8” Compression Set Service Packers in Conjunction with Wellbore Cleanout Equipment and Negative Test on 7” Liner

Remarks: Example Program/Proposal
Rev	Date	Modification Details	Written By
0	01/25/2017	R0	Dan Imansyah

Section 1.0

Introduction

The following program is an example of the programs submitted to clients as part of the pre job planning phase of operations.  The program does not reflect the clients own operations.

Section 2.0

Objectives

The objectives of the wellbore clean out operation are as follows:

1. Minimize rig time and maximize efficiency;
2. Mechanically clean the wellbore of debris;
3. Confirm drift ID of casing is suitable for completion equipment;
4. Scrape completion packer setting zones;
5. Condition the 12.9ppg OBM until even condition in and out of well;
6. Inflow test the 7” x 9-7/8” liner lap;
7. Displace the wellbore to 9.5 ppg CaCl2 with a specification of 0.05% solids in a single operation; and
8. Clean the Riser & BOP in a short trip

Section 3.0

Well Information

Well Depth (MD):	19,100 ft	Mud / Fluid Max Density:	12.9 ppg
TVD:	14,158	PBTD:	LC = 18,968’
Max Deviation:	59.48	BHT:	158 F
Water Depth:	5,000	RTE:	100’

Casing/Liner & Weight	Drill Pipe OD & Weight	Length (ft)	To depth of (ft)	Max Section Angle	Ann Vol (bbl)	String Vol (bbl)
Riser (19 ⅜” ID)	5 ⅞” (26.30 lb/ft)	5,070	5,070	—	1,679	125
9 ⅞” (62.8 lb/ft)	5 ⅞” (26.30 lb/ft)	9,300	14,300	59.48 deg	511	228
7” (29 lb/ft)	4” (17.58 lb/ft)	4,669	18,969	112	48
TOTALS	2,302	401
TOTAL WELL VOLUME	2,703 bbl

Section 4.0

Mechanical Tools Equipment List Wellbore clean-up

7” 29 ppf Casing
Item	Description	Qty
	Assembly 1
1	6.25” Drill Bit 3-1/2” Regular pin up	1
2	Bit Sub NC-38 Box x 3-1/2” Regular Box	1
4	Max Blade Casing Scraper NC-38 Box x Pin	1
5	6.250” Drift sub NC-38 Box x Pin	1
6	Pup joint (10ft) NC-38 Box x NC-38 Pin	1
	Assembly 2
7	Max Force HD Magnet NC-38 Box x Pin	2
8	Pup Joint X/O XT-39 Box x NC-38 Pin	1
	Assembly 3 (Only required in the event of side track or milling ops prior to clean-up)
9	X/O XT-39 Pin x NC-38 Box	1
10	Max Force HD Magnet NC-38 Box x Pin	3
11	Pup Joint X/O XT-39 Box x Pin	1
9 7/8” 62.8 ppf Casing
Item	Description	Qty
Assembly 4
12	X/O NC-38 Box x XT-39 Pin	1
13	Landing sub for 7″ PBR NC-50 Box x NC-38 Pin	1
14	Max Blade scraper NC-50 Box x Pin	1
15	Drift Sub NC-50 Box x Pin	1
16	Pup Joint X/O HT-55 Box x NC-50 Pin	1

9 7/8” 62.8 ppf Casing (Continued)
Item	Description	Qty
Assembly 5
19	X/O NC-50 Box by HT-55 Pin	1
20	MIT Packer NC-50 Box x Pin	1
21	SRCT-RL NC-50 Box x Pin	1
22	Stabiliser 9.5 OD NC-50 Box x Pin	1
23	Pup Joint X/O NC-50 Box x NC-50 Pin	1
Assembly 6
24	Max Force HD Magnet NC-50 Box x Pin	2
26	Pup Joint X/O HT-55 Box x NC-50 Pin	1

Note: depending on well history a Junk Trapper may be added to the BHA as well as a Riser brush for the main clean out

BOP & Marine Riser clean-up

Marine riser & BOP Clean-up
Item	Description	Qty
Assembly 1
1	Sentinel NC-38 Box x NC-50 Pin	1
2	X/O NC-38 x HT-55	1
3	Pup Joint (10ft) HT-55	TBA
Assembly 2
4	BOP Vortex tool (Connections to be confirmed. STD NC 50.  Pot to cut HT-55)	1
5	BOP Magnets (Connections to be confirmed. STD NC 50.  Pot to cut HT-55)	2
6	Pup Joint (10ft) HT-55	1
Assembly 3
7	X/O NC-50 Box x HT-55	1
8	Riser Max Brush NC-50 Box x Pin	1
9	Pup joint X/O  HT-55 Box x NC-50 Pin	1

Section 5.0

Operational Procedure

Objectives:	Scrape setting interval for completion packer Drift 9 7/8” casing and 7” liner Pump wash pills and displace well to 9.5ppg CaCl2
Well information/Status	BP installedWell filled with 12.9 ppg OBMBOP flex joint @ 5,070ft BOP installed and tested to 360 bar Top of 7” liner hanger at 14,300 ftMD 9 7/8” xxx bar with 12.9 ppg OBM 7” liner cemented and tested to 310 bar with 12.9 ppg OBM
Major operational risks:	Unable to achieve sufficient clean up Incorrect tally/space out – miss run,
Major HSE Risks:	Correct use of PPE when handling OBM Focus on routing for displacement
Technical Limits:	Minimum ID for CBP is xxxx” Max OD clean up string 9,5“ ID in 9 7/8” 62.8# casing is drifted to 9.5” ID in 7” 29# liner is drifted to 6,25″
Operational Limits:	Run in hole – 10’ heave limitation

ACTIVITY DESCRIPTION	PARALLEL ACTIVITIES – REMINDERS
1   Perform pre-job meeting
	Review operation with all involved parties	Risk: Review operational JHA   Reminders: Well control during the entire operation Check radio communication / batteries Housekeeping on rig floor. Cover all holes as required and secure all loose equipment
2  P/U Clean up BHA and RIH to above 7 5/8” LH.
	P/U and M/U Clean up BHA according to Engineer’s tally: P/U and M/U 7” Clean up assemblies (Assy 1 – 3) according to tally RIH on XT-39 drill pipe and space out to insure that with bit 8 – 15 ft from T.D. the landing sub is engaged with TOL P/U and M/U clean-up assemblies for the 9 7/8” casing (Assy 4 – 6) RIH on HT-55 DP according to tally	Ensure shakers are dressed with correct mesh screens – 170 API mesh to screen OBM Note: Space-out should allow for bit to be 8-15 ft from TD with TDM landed on TOL Compensate when running assemblies through  BOP/WH7” liner hanger assembly Minimize the use of dope Record weight of BHA prior to making up assembly 5_______LB
	With bit 1 stand above TOL record up and down weights.  Slide through liner top slowly noting any hang up points. If required engage pumps at 2-3 bpm and rotate slowly past TOL	Up weight:       _________LB Down weight:  __________ LB
	Continue RIH to Position 9 7/8” MAX Blade Scraper 45’ above production packer setting depth at  xxxxx MD	Packer depth:14,150’ MD
	Record up/down weights	Up weight:       _________LB Down weight:  __________ LB
	Make up DDM and engage pumps. Stage up to max allowable rate and allow for pressure to stabilize. Engage rotation and stage up to 60 rpm. Record all parameters.	Set torque limiter. Limit to be determined by Example DE Limited by pumping pressure (popoff valve) Record pressure at 5 BPM:____ Record pressure at Max BPM:____ MAX RPM:  __________ MAX TRQ:  __________ ft.lb
	Work scraper 3 x across packer setting zone maintaining pumps at max allowable rate and rotation of 60 rpm. Stop rotation and pumps once complete and continue RIH.	Clean 45’ +/- above and below packer setting area
3    Run to TD and condition mud.
	With landing sub 1 joint above liner top, open compensator and record up and down weights. RIH, tag PBR with 10k lb and confirm tally. Measure stick up with laser	Compensator open Up weight:       _________LB Down weight:  __________ LB
	Pick up 2 m
	With TD confirmed Increase pump rate to maximum allowable stand pipe pressure and rotate pipe at maximum allowable RPM; limited only by torque capability of string components.  Record parameters achieved.	Re-confirm Torque limiter is set MAX RPM:  __________ MAX TRQ:  __________ ft.lb MAX SPP __________ PSI MAX BPM:  __________
	Circulate and condition OBM over screens for at least 1 ½ bottoms up. Continue circulating until even mud weight in/out Reciprocate string	Dress shaker screens to remove particles in fluid (API 170) Consider opening SRCT-RL to speed up mud conditioning if rates are slow.
	When even mud weight in/out, stop rotation and then pumps

4   Inflow test Operation
	Position stand in rotary to break pipe. Break pipe and drop 1 ¾” drag set prevention ball.  Re make pipe and DDM and pump with 3 BPM, record pump pressure and note landing pressure and total strokes	Re confirm ball OD prior to dropping! Zero stroke counter prior to pumping ball to seat
	With ball landed increase SPP to 4,200 psi to blow seat. Continue to pump and confirm returns with similar flow rate to recorded when pumping the ball to seat.	Insure even mud weight.  If imbalance this will effect pressure required to release drag lock MAX SPP __________ PSI MAX BPM:  __________ LANDING SPP __________ PSI TOTAL STROKES:  __________
	Continue to RIH and re-tag TOL, continue to slack down 35 k lb +/- to set packer.	Compensator open
	With packer set. Line up to pressure test packer integrity. Close annular and line up on kill line.  Pressure up to max pressure to be seen across packer during inflow test xxxx psi and hold for 10 minutes recording pressure drop.	Cement Unit for Pressure test Pressure@ start of B/S test:  __________ PSI Pressure@ end of B/S test:  __________ PSI
	With good test bleed off annulus and open Annular	The following Inflow test method is suggested until Company provide their procedure for insertion
	Pick up 6 ft to release packer and hold for 10 minutes. Note SPP when picking up for evidence of elements being retracted	Note weight of string will be lighter with Base oil
	Pump 280 bbls of base oil at 3 bpm to simulate underbalance Note well to be displaced to 9.5ppg CaCl2. Record final static displacement pressure and compare with expected.	SP after pumping B Oil:  __________ PSI Use all pumps when initially pumping base oil so as to flush clean
	Re-set packer slacking of 35k lb from new down weigh
	Bleed of SPP pressure in 500psi increments until at monitoring pressure of 100psi (accounted for in Base oil volume).  Monitor annulus and SPP for leaks.	Insure annulus is monitored on the trip tank throughout operation Consider picking up weight equivalent for 500 psi increments to offset reverse ballooning effect on SRCT-RL
	Monitor increase in pressure over 10 minute increments. Bleeding back to 100psi after each increment.	Note: pressure increase will occur during the initial stages of the inflow test due to thermal effects
	Once a declining trend is seen to level for 3 increments the test can be determined successful.  Record Final 3 pressures.
	With inflow test confirmed good re-pressure string to same as recorded in step 4.7 and pick up to unset packer pick up 6’ noting for free pipe movement.  Hold for 10 minutes to allow elements to relax	Packer unset time:  __________ Time string is moved after release:  __________
	Pick up to maximum height allowable and Run back in hole to position landing sub 1 joint above TOL.  Record up and down weights	Up weight:       __________ LBDown weight:  __________ LB

5  Displacement Operation
	U-tube out 130 bbls of base oil on choke back to base oil pit	Do not free fall the base oil.  This must be done on the choke.  Trip tank pump will not keep up with U-tube rate.
	With required Base oil in string. Dump trip tank back to the active and flush so as to make ready for clean brine when tripping out of hole.  Fill choke Kill & Boost line with wash pill Rig to confirm volume required	Note: Wash pill will remain in lines until pills are at the well head at which time the riser will be boosted Consider using the cement unit to pump to the Choke and Kill lines so as to insure it is flushed.
	Pump pills as per displacement plan found in Section 5 of Appendix 1. With maximum allowable rate and rotation	Max pump rate is only limited by pop off Rotation is limited to 120 rpm or Max allowable based on torque limit set based on free rotating torque and the weakest connection.  Example to confirm in alignment with torque and drag model found in Appendix 2
	When indicated in the pumping table activate the SRCT-RL as per Weatherford instruction; Slack off lower string weight accounting for buoyancy and hole angle and apply additional 60k lb.  Start pumps and pick up to have 10k lb compression force on the SRCT-RL and start to rotate string.	Ensure to adjust for rotating weight when starting to rotate on SRCT-RL. Torque limit with SRCT-RL in the OPEN position can be adjusted to suit the string components in the 9-7/8” section. SRCT-RL will be confirmed open by a significant drop in SPP pressure Operation of tool should take no more than 2-5 minutes. MAX weight on bearing = 50k lb for 6 hours
	With well displaced to specification of 0.05% solids.  Stop rotation and Pumps.  Flow check well as per Example standards.  Prepare to short trip back 5,300 ft +/- to pick up BOP and MR cleaning BHA.	Take samples as per fluids procedure in Appendix 1 to confirm fluid specification.
6   BOP & MR cleaning Procedure
	POOH xxxx ft and make up BOP clean out assemblies 1-3 as per Engineer’s BHA and trip in hole until sentinel 1 joint above flex joint.	SRCT-RL will close as soon as the sting is picked up in to tension Reference MR & BOP schematic in section 6. Insure Riser brush is spaced out 4-6’ above the flex joint when the Jetting sub has tagged the bore protector. Sentinel should be 2 stands in the 9-7/8” casing. While tripping in hole maintain boost pump so as to carry out any debris removed from the riser walls.  Vortex tool will be run in open position.
	Open compensator and carefully RIH and tag bore protector with 2-5 k lb.  Pick up to space out drill pipe across rams.  Stop boost pump and function rams to dislodge debris. Open rams.	OPEN COMPENSATOR. Do not function Shear Rams.
	Re-tag bore protector and pick up 2 -3 ft.  Start pumps at maximum rate allowable.  Rotate string with 10 RPM.  Reciprocate string 3-5 times across BOP maintaining parameters.  Record all parameters.	Vortex tool washes cavities and creates a venturi effect to suck debris from cavities.  Pump with max flow rate to generate the best suction. MAX RPM:  __________ MAX TRQ:  __________ ft.lb MAX SPP __________ PSI MAX BPM:  __________
	On last up stroke continue to pick up to position the vortex tool above the LMRP and reciprocate until bottoms up of the riser volume has been circulated.  With bottoms up circulated.  Stop rotation and pumps. Position pipe to break.  Break pipe and drop closing tag / ball. Pump 2.25” ball with 3 BPM until ball seats continue to pressure up to 2,000 psi to shear seat and close jetting tool. Flow is now returned to the bit.  Record all parameters when pumping ball to seat.	Zero stroke counter prior to dropping 2.25” ball MAX SPP __________ PSI MAX BPM:  __________ LANDING SPP __________ PSI SHEAR PRESSURE________PSI TOTAL STROKES:  __________
	Flow check as per Example procedure
	POOH until bit is above TOL and flow check as per Company procedure.	Inspect tool condition as POOH, photograph and record debris type and weight for EOWR. Lay down for backload.
	POOH until bit is below mill is positioned below the wellhead and pipe is across the BOP and flow check.	Inspect tool condition as POOH, photograph and record debris type and weight for EOWR. Lay down for backload.

Section 6.0

Schematics

Run # 1 Inflow Test & Displacement Operation

Run # 2 Marine Riser & BOP Clean-up

written by dachnial dan imansyah

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