1121
Ref.: _________/OPR
-2021
Date: __________,
24 Aug 2021
To:
Attn:
Fax No.: (84-24) 3826 5942
PVN
Dr. Le Manh Hung, President & CEO
Mr. Le Ngoc Son, Vice President
Mr. Nguyen Ngoc Hoan, General Manager of Production Div. - MC
Chairman, Block 15-1
Dr. Tran Manh Cuong, GM of Petroleum Contract Management Div. MC Member, Block 15-1
To:
Attn:
PVEP
Dr. Tran Hong Nam, President & CEO
Mr. Vu Minh Duc, Vice President - MC Member, Block 15-1
Fax No.: (84-24) 3772 6027
Fax No.: (84-28) 5413 3144
To:
Attn:
Perenco Cuu Long
Mr. *LOOHVG¶$UJRXJHV, President - MC Member, Block 15-1
Fax No.: (84-28) 5414 7713
To:
Attn:
KNOC
Mr. Yi, Jae-Seok, Senior Vice President, E&P - Asia Business UnitMC Member, Block 15-1
Mr. Kim, Ick Joong, KNOC Representative - Alternate MC Member,
Block 15-1
Fax No.: (84-28) 3825 7806
To:
Attn:
Fax No.: (84-28) 3827 0864
SK Innovation
Mr. Choi Jeongwon, Managing Director of HCM office, MC MemberBlock 15-1
Fax No.: (41-22) 319 2681
Geopetrol Vietnam S.A
Fax No.: (84-28) 3824 6863
Mr. Guillaume Rebilly, CEO - MC Member, Block 15-1
Mr. Duc Phuc Nguyen, Vice President - Alternate MC Member,
Block 15-1
To:
Attn:
No. of pages: 61 (including this page)
Subject:
Workover program for Development Well 15-1-SV-4P
URGENT
FOR REVIEW
PLEASE COMMENT
PLEASE REPLY
PLEASE RECYCLE
Dear Sirs and Madam,
7KH&XX/RQJ-2&¶VDSSURYHGZRUNSURJUDPIRULQFOXGHVworkover and installation ESP for
SV-4P ± as an ESP Production well.
Attached is the Workover program for this well. This procedure covers the pulling upper Gaslift
completion and run ESP gaslift/completion includes casing clean up, fix leak 9-´FDVLQJSDFNRII
installation ESP Wellhead Spool, installation new ESP completion equipment, tubing hanger, tree
and tested. We would be highly appreciated if you could approve the attached program as soon as
possible.
Thank you for your continued support and cooperation to maximize value of the Block 15-1.
Sincerely yours,
Nguyen Van Que
General Manager
Letter to Partners/PVN
Alexis Heydenreich
Deputy General Manager
Page 1 of 1
WORKOVER PROCEDURE # 001-SV-4P Aug/2021
Well
Slot
Required Activity
Start Date
ACTION
SV-4P
07
Conversion to ESP Completion
Sep 2021
NAME
POSITION
Nguyen Huy Vinh
Snr Well Operation Engineer
Tran Minh Tu
Snr Well Operation Engineer
SIGNED
DATE
NGUYEN HUY
VINH
Prepared
Digitally signed by NGUYEN
HUY VINH
Date: 2021.07.20 16:36:05
+07'00'
Digitally signed by Tu Minh
Tu Minh Tran Tran
Date: 2021.07.20 16:58:20
+07'00'
Reviewed
Aldric Beaugeois
Dep. Lead Completion Eng.
Aldric
Beaugeois
Le Minh Thao
Lead Completion Eng.
Le Minh
Thao
Tran Dung Thang
Dep. Prod. Superintendent
Miguel Caro
Prod. Superintendent
Nguyen Van Tuan
Lead Reservoir engineer
Lam Minh Tuan
Dep. Lead Drilling Engineer
Yoon Minnyeong
Lead Drilling Engineer
Luong Thi Thanh
Huyen
Dep. Subsurface Manager
Tran Ha Minh
Subsurface Manager
Nicolas Chereau
Dep. Ope. Manager.
Le Vu Dung
Operation manager.
Tran Dung
Thang
Digitally signed by Le Minh Thao
Date: 2021.07.21 09:32:57 +07'00'
Digitally signed by Tran
Dung Thang
DN: cn=Tran Dung Thang,
c=VN, o=CLJOC
Date: 2021.07.27 17:14:00
+07'00'
signed by Miguel A Caro
Miguel A Caro Digitally
Date: 2021.07.27 19:14:02 +07'00'
Nguyen Van
Tuan
Digitally signed by
Tran H. Minh
Nguyen Van Que
General Manager.
Distribution: Well File ± original
Well Services Supervisor
CPP, Contractors
Digitally signed by Tran H. Minh
Date: 2021.08.17 10:00:47
+07'00'
Digitally signed by Nicolas
CHEREAU
Date: 2021.08.20 18:45:55
+07'00'
Dep. General Manager.
Digitally signed by Nguyen
Van Tuan
Date: 2021.07.28 08:39:45
+07'00'
Luong Thi
Luong Thi Thanh Huyen
2021.08.17
Thanh Huyen Date:
10:23:42 +07'00'
Approved
Alexis Heydenreich
Digitally signed by Aldric
Beaugeois
Date: 2021.07.21 16:40:56
+07'00'
Alexis
Heydenreich
Digitally signed by Dung, Le Vu
Date: 2021.08.22 18:34:37
+07'00'
Digitally signed by Alexis
Heydenreich
Date: 2021.08.23 16:21:44
+07'00'
23/08/2021
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 2
!"#$%#$&’
6HFWLRQ:(//:25.29(52%-(&7,9(6:,7+6800$5<&203/(7,21
352&('85(
!
,QWURGXFWLRQ ...............................................................................................................................!
2EMHFWLYHV ..................................................................................................................................!
6XPPDU\....................................................................................................................................!
6HFWLRQ&88/21*6$)(7<67$7(0(17
!
6HFWLRQ:(//'$7$:(//+,6725<5(6(592,53523(57,(6$1'
(48,30(17,1)250$7,217$%/(6
!
:HOO+LVWRU\...............................................................................................................................!
&XUUHQW:HOO'DWD ......................................................................................................................!
5HVHUYRLU3URSHUWLHV ..................................................................................................................!
5LVHU&DVLQJ7XELQJ /RZHU&RPSOHWLRQ6SHFLILFDWLRQV .....................................................!
6HFWLRQ2))/,1(35(3$5$7,212)7+(:(//
!
6HFWLRQ:(//6(&85('$1'6.,' 38//,1*2/'&203/(7,21$1'),;
/($.´&$6,1*3$&.2))
!
&OHDQWXELQJZLWK+&/ SODQWRGREHIRUHKZXDUULYHFRQWLQJHQF\WRGRZKHQ
+:8LQSODFH ...............................................................................................................................!
5.1.a Shut in the well & RU pumping surface line. .......................................................................12!
5.1.b Mixing and Pumping Treatment ...........................................................................................12!
5.1.c Pumping schedule .................................................................................................................12
6HFXUHGWKHZHOO .....................................................................................................................!
5.2.a Drift Run to verify tubing is cleaned after acid job. .............................................................14!
5.2.b 6HW´;SOXJ3URQJDW'+69GHSWK P:' .......................................................14
5.2.c Set TWCV in tubing hanger (second barrier).......................................................................15
5.2.d 5HPRYHSURGXFWLRQWUHHVDQG3XOO7:&9´3OXJ .......................................................16
3XOOLQJXSSHUFRPSOHWLRQ&DVLQJ6FUDSHU6HW6WRUPSDFNHU...........................................
5.3.a Pulling upper completion .....................................................................................................17
5.3.b Casing scraper......................................................................................................................18
5.3.c Set storm packer....................................................................................................................18
)L[/HDN´&DVLQJ3DFN2II..........................................................................................!
6HFWLRQ&203/(7,21,167$//$7,21
!
2%-(&7,9(...........................................................................................................................!
5,+(63&203/(7,21.......................................................................................................!
(63,167$//$7,21352&('85(6 ..................................................................................!
6(&7,21,167$//352'8&7,2175(($1'+$1'29(5:(//72
352'8&7,21
!
2%-(&7,9(...........................................................................................................................!
,167$//$7,212)6&669:(//+($')/$1*(.........................................................!
,167$//$7,212)%211(7 ;0$675(( .................................................................!
:(//'(,62/$7,21 2IIOLQH ...........................................................................................!
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 3
6HFWLRQ:(//&21752/&217,1*(1&,(6
!
6HFWLRQ$33(1',&6
!
6X7X9DQJ6ORW$UUDQJHPHQW ................................................................................. &XUUHQW:HOO6FKHPDWLF ........................................................................................... 6793(63:2:HOO6NHWFK '5$)7 .................................................................. 'LUHFWLRQDO6XUYH\ ................................................................................................... 6302LO *DV7XELQJ+DQJHU,QIRUPDWLRQ ............................................................. :HOOKHDGWR5LVHU$GDSWRU )URP&/-2& .............................................................. 7XELQJ&RQQHFWLRQ'DWD .......................................................................................... &RPSOHWLRQ(TXLSPHQW7HFKQLFDO,QIRUPDWLRQ ......................................................... &DEOH'HFRPSUHVVLRQ,QVWUXFWLRQV .......................................................................... *DVOLIW'HVLJQ ....................................................................................................... /D\RXWGLDJUDPDQGVWDFNXSVFKHPDWLF................................................................ 6OLFNOLQH3&(58DQG7RRO6WULQJ'LDJUDP ......................................................... Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 4
Section 1. WELL WORKOVER OBJECTIVES WITH SUMMARY COMPLETION
PROCEDURE
1.1 Introduction
The Cuu Long Joint Operating Company was formed to develop oil and gas reservoirs located
offshore southern Vietnam in Block 15-1. This block is approximately 180 kilometres (120 miles)
southeast of Ho Chi Minh City, and covers 800 square kilometers (0.198 million acres). It is
situated in the Cuu Long Basin which already contains such active fields as Bach Ho, Rang Dong,
and Ruby. Su Tu Vang field includes a wellhead and facilities platform, which produces to an
FPSO anchored about 2 kilometers away. The water depth is about 52.5 meters (172 feet).
The SV-4P well was completed in October 2008 with a 13Cr gas lift completion. The workover
objective is to pull the existing completion, run an ESP/gas lift hybrid completion.
This procedure covers of:
1. Set 3.813´ plug at Nipple profile at DHSV and test to isolate reservoir section. Set TWCV
in tubing hanger
2. Nipple down the tree.
3. Lock DHSV open with keeping hydraulic in control line
4. Recover old Tubing and Completion assembly.
5. Casing cleanup for packer setting depth.
6. Set and test retrievable packer / storm valves .Skid out HWU/N/D BOP.
7. 5HFRYHU´SDFN-off and casing hanger. Replace with new and energize
8. N/U ESP tubing head spool. N/U BOP/ Skid back HWU
9. Recover retrievable packer / storm valves.
10. Run ESP/gas lift hybrid completion.
11. Install trees and test
12. Test ESP
13. Handover to production.
1.2 Objectives
1) Execute the scope of work with zero recordable safety accidents and no environmental
or ethical incidents.
2) Install the completion hardware as per design and hand the well over to Production
Operations.
3) Complete the scope of work within the cost estimation.
4) Pull old completion and perform subsequent run as per running detail procedure
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 5
1.3 Summary
OPERATION
PLAN
TIME Hrs
CUM
PLAN
Days
2
8
0.1
0.4
8
0.8
2
2.5
4
5
4
2
2
2
0.8
0.9
1.1
1.3
1.5
1.6
1.6
1.7
3
4
5
6
7
8
9
10
1) Prepare Well for Workover (Offline)
Run drift run by SLK to verify tubing
Perform hot bolting of Tree to wellhead
2) Skidding from SV-07P to SV-04P
Clean tubing by HCl 10% RU SLK to Run drift run/ And Set 3.813" Plug & Prong at the DHSV
and Test at XXXX psi
Bullhead injection seawater in the well
Set TWCV
Remove flowline, choke
Remove big hatch covers on the main & Intermediate decks.
ND Tree & Terminate WH
Dummy run TH pulling tool
Function test DHSV. Lock open DHSV by hydraulic.
N/U adaptor and riser on SV-04P
11
N/U BOP
8
2.1
12
Skid HWU to SV-04P. Aligning BOP stack and riser.
3
2.2
13
Connect BOP Stack to the riser.
3
2.3
14
Secure HWU
2
2.4
15
MU WH Jetting tool and do jetting WH
6
2.6
16
RU 5-1/2" Tubing handling equipment,
2
2.7
17
Run TH retrieval tool and engage tubing hanger
2
2.8
18
Pressure test BOP & manifolds
4
3.0
19
4
3.1
3
3.3
21
22
MU Pack Off pulling BHA/Run and pull 4-1/2" SMS Tubing Pack Off
MU 4-1/2" THG pulling to 5-1/2" Lading string. RIH and latch into
THG
Retrieve TWCV through TH pulling tool
Rig up slickline and pull the prong/ plug
2
8
3.4
3.7
23
3) Preparation for Pull tubing TH / Tubing.
3
3.8
24
25
26
27
RU TRS. Pull tubing TH / Tubing
Fill the well with seawater to minimize the oil at surface
POOH with ol upper gaslift Completion
R/down tubular handling tools for 4.5" Tubing
3
3
53
2.5
3.9
4.1
6.3
6.4
1
2
20
4) Scraper Run & Set Storm packer
28
29
30
31
32
33
34
35
36
37
38
6.4
Install wear bushing
MU 9-5/8" scraper/RIH with 9-5/8" scraper (100m below packer
setting depth)
Scrape packer setting depth
POOH & Lay down Drillpipe
MU and RIH to set Storm packer
POOH & Lay down Drillpipe
Pull Wear bushing
5) Fix leak 9-´&DVLQJSDFNRII
M/U Pack-off running tool and retrieve 9-5/8" Emergency pack off.
Skid out HWU, N/D BOP, HP Riser
Skid back HWU to SV-4P and secure
M/U and Run Spear into 9-5/8" casing.
Workover Procedure SV-4P
3
6.5
35
8.0
2
25
35
25
2
177
0
0
0
0
8.0
9.1
10.5
11.6
11.7
19.0
19.0
19.0
19.0
19.0
Well Workover Procedure
Cuu Long Joint Operating Company.
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
SV-4P
Engage spear in casing with 20Klb overpull. Attempt to free 9-´
casing slips, by gradually pulling up to 250Klb overpull by 20Klb
increment. Remove casing hanger slips and inspect casing stub.
RIH 9-´PHFKDQLFal cutter between Wellhead and MLE (~12m
below the wellhead). Cut 9-´FDVLQJ322+FXWWHU
Run casing spear and Pull upper part of the 9-´FDVLQJ
Run casing spear and release mudline tie back by 10 turns left.
Pick up 0.5m string (check string weight to confirm tieback free).
POOH casing spear with mudline tieback.
Run new 9-´WLHEDFNDQGVFUHZLW
Pressure test 9-5/8" casing against storm Packer.
Drop new 9-5/8" casing slip. Slowly pickup to 250K# pull.
Slackoff overpull.
Bump down on overshot and rotate to right to disengage. POOH and
laydown overshot assembly, bumper sub and drill collar.
Use 9-´LQWHUQDOFROGFXWWHUWRGUHVVWKH-´FDVLQJQHck.
Run, Energize and test new casing pack-off
6) Install ESP WH adaptor spool/Retrieve Storm packer/Scraper
Install isolation bushing
Skid out HWU
N/U ESP Wellhead Adaptor & Test
N/U 13-5/8" high pressure riser
N/U BOP
Skid back HWU to SV-4P
Pressure test BOP by set test plug
Install wear bushing
RIH DP to Pull Storm Packer
POOH lay down scraper
7) P/U & M/U ESP Pump & Run Completion
Pull wear bushing
Jetting WH & run TH dummy
P/U ESP equipment from supply boat, PU with CPP crane and M/U
ESP assembly
P/U and run ESP assembly
RIH completion
P/U SSSV & attach control line
RIH to setting depth.
Splice pig tail to power cable/ Termination cablles (ESP cable, CTS
cable, DHSV line and chemical line) at TH
M/U THRT & RIH
Land off in TH.
Set and test hanger
Rig up slickline / test / RIH / with standing valve and set in SSD /
POOH
Set packer and test
Test Completion (Tbg/ Annulus).
Inflow test SSSV.
Pull standing valve/ set plug at DHSV
Set TWCV.
Pull landing string
Disconnect Bell Nipple and clean the deck before skidding
Skid HWU some distance away from the completed well (SV-04P)
ND BOP
N/D Riser and adaptor on the completed well (SV-04P)
Install Hatch
Terminate lines through wellhead
Install Christmas tree. Test seals
Pull TWCV. Pull plugs by slickline
Workover Procedure SV-4P
Page 6
0
19.0
0
19.0
0
0
19.0
19.0
0
19.0
0
0
0
0
19.0
19.0
19.0
19.0
0
19.0
0
0
63
0
0
0
0
0
0
0
0
0
0
1
3
19.0
19.0
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.7
21.8
3.5
22.0
34
48
4
5
23.4
25.4
25.6
25.8
10
26.2
3
2
3
26.3
26.4
26.5
8
26.9
8
4
4
10
4
4
4
3
4
4
1
5
5
8
27.2
27.4
27.5
27.9
28.1
28.3
28.4
28.6
28.7
28.9
28.9
29.1
29.4
29.7
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 7
Section 2. CUULONG SAFETY STATEMENT
All operations should be conducted with the following philosophy:
³$W&88 LONG, our work is never so urgent or important that we cannot take the time to do it safely´
We will conduct our business in a manner that protects the safety, health and well being of our employees,
contractors and neighbors, and with respect and care for the environment. To accomplish this, we will:
Minimize the impact of our activities by:
x Ensuring all employees and contractors recognize that working safely is a condition of employment, and that
they are accountable for their own safety and the safety of those around them.
x Operating in a manner which reduces the risk of spills, leaks, and accidental discharges.
x Assessing the environmental impact of our operations.
x Limiting physical disturbances and employing appropriate reclamation and remediation practices.
x Ensuring responsible and efficient use of energy and natural resources.
x Limiting waste generation, discharges and emissions, and handling wastes in a responsible manner.
Systematically manage performance by:
x Establishing a goal of zero incidents, which includes no injuries, equipment damage, spills, leaks or accidental
discharges.
x Management demonstrating commitment to, and accountability for, safety, health and environmental
performance.
x Addressing safety, health and environmental concerns in all phases of our activities.
x Committing appropriate means and resources to meet stated goals and standards.
x Committing to strictly comply with Vietnamese Law regarding the environment, the safety of personnel and
the protection of property.
x Utilizing effective performance measures.
x Encouraging contractors and suppliers to conduct their business in an environmentally responsible manner.
x Ensuring that audits and follow-up actions are planned and completed.
Provide the means to achieve our goals by:
x Developing standards and ensuring responsibilities are assigned and understood.
x Assessing and managing the risks associated with our operations.
x Ensuring that all employees and contractors are trained to perform their jobs safely and in an environmentally
responsible manner.
x Maintaining and regularly testing emergency preparedness plans and capabilities.
x Thoroughly investigating and communicating all incidents to identify contributing factors, lessons learned and
needed improvements in ongoing prevention efforts.
x Promoting off-the-job safety to extend and reinforce safety, health and environmental consciousness.
x Being responsive to the concerns of employees, contractors, suppliers and the public.
x Working with government and other interested parties to develop balanced environmental standards and
expectations.
Continuously improve our safety, health and environmental performance through:
x Technology innovation and application.
x Organizational development.
x Commitment.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 8
Section 3. WELL DATA, WELL HISTORY, RESERVOIR PROPERTIES, AND EQUIPMENT
INFORMATION TABLES
3.1 Well History
Drilling and Completion :
1. SV-4P was drilled well in Basement reservoir by the Galveston Key in November 2008 with an RKB = 50.7mts
above Mean Sea Level.
2. After drilling, 4P was completed with Weatherford completion equipment and 4-´SSI± 13 Cr tubing
x
Lower completion was run with 2 x 3.313 66'¶V, two sets swell packers and FBFV.
x Upper completion ZDVUXQZLWK7XELQJKDQJHU'+69´;QLSSOH 4 x SPM/ Weatherford permanent
gauge/ ´;1QLSSOH / Nogo Locator and seal assemblies.
SLK Intervention :
x 10-Nov-2008
Run plug for packer setting
x 11-Nov-2008
Pulled plug
x 10-Mar -2009
Run and set memory gauge for Temperature / Pressure long term Survey
x 08-Apr- 2009
Pull and re-set memory gauge for Temperature / Pressure long term Survey
x 09-May- 2009
Pull gauge
x 07 to 11 Dec-2009
MPLT
x 24 to 25 - Dec-2009 Changed gaslift valve
x 03-Apr-2010
Run and set memory gauge for Temperature / Pressure long term Survey
x 02-May-2010
Pull gauge
x 21-Aug-2010
Run and set 3.313 WX Plug at SSD#2. Unsuccessful.
x 23 to 25 Oct 2010
MPLT
x 11 to 13 Dec 2010
Run and set PX Plug at SSD#2. Unsuccessful.
x 11-Jun-2012
Run and set memory gauge for Temperature / Pressure long term Survey.
x 13-Jul-2012
Pull gauge.
x 14-Nov-2012
Change gaslift valves.
x 29-Nov-2013
Run to set Memory gauge but unsuccessful.
x 11-Nov-2015
Run to doing gradient survey but unsuccessful.
x 22-Oct-2020
Run & set gauge for Temperature/Pressure long term Survey at 3.688 WRN plug.
x 17-Dec-2020
Pull gauges.
x 28-Dec-2020
Run to change gaslift valve.
x 13-Mar-2021
Run to close SSD#1,
x 17-Mar-2021
Change out gaslift valve.
Observed gas bubbles at sea. Observed Gas leak at 9-5/8´, 13-3/8´ Emergency Casing Pack off. Well keep flowing
by Gaslift (reducing gaslift injection pressure).
3.2 Current Well Data
Well Name
Structure / Slot
Quadrant / Block:
Operator for license Area
Company Supervising Operations
Current Rig name
Contractor
Depth Measurement Units
Original Rig Floor Elevation
Water Depth
RT to Seabed
Surface Co-ordinates
Type Well
TD
Well Status
15-1-SV-4P
CPP / Slot 7
Block 15-1
Cuu Long Joint Operating Company
Cuu Long Joint Operating Company
HWU
PVD tech / VELESTO
Meters
50.7
52.5mts
103.2
Latitude = N 10 22 49.425
Longitude = E 108 21 37.152
Development, Deviated Openhole Production well.
5,606 mts MDRT / 3,681 mts TVD
Workover
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
3.3 Reservoir Properties
Basement Reservoir Properties
Reservoir Nomenclature:
Hydrocarbon Type:
Reservoir Fluids:
Oil Gravity:
Oil S.G.
Producing Gas Gravity:
Gas Lift Gas Gravity:
Reservoir Pressure
Reservoir Temperature
Basement
Oil
Oil
36API (circa)
0.845 S.G. (circa)
0.89
0.75
2460 psia @ 2,800m TVDSS
1650C @Reservoir
Gas Impurities
H2S Content:
CO2 Content:
Water salinity
Max Wellhead Pressure
Min Flowing Wellhead Pressure
5 ppm (in gas lift gas)
0.2%
18,000 ppm
1630 psig (gaslift pressure)
250 psig
3.4 Riser, Casing, Tubing & Lower Completion Specifications
Casing Plan Equipment Specifications (15-1-SV-4P)
´&RQGXFWRU&DVLQJ6WULQJ:
Shoe Depth:
Nominal ID:
310 lb/ft
153.5mts MDRKB
28"
13-´&DVLQJ6WULQJ:
Shoe Depth:
Casing Detail:
13-3/8 Nominal ID:
13-3/8" Drift ID:
13-3/8" Burst:
13-3/8" Collapse:
1,349mts MDRKB,
68 lb/ft, BTC
12.415"
12.259"
5,020 psi
2,262 psi
9-5/8" Casing 47 lb/ft, L-80, NK-3SB and Hydrill 563
Shoe Depth:
3,261mts MDRT
9-´1RPLQDOID:
8.681´
9-´'ULIW,'
´
9-´%XUVW
6,859 psi
9-´&ROODSVH
4,756 psi
Tubing Specifications to Recover
Size/Weight
Grade
Connection
Maximum OD
Nominal ID
Drift ID
Body Yield
Joint Strength
Burst
Collapse
Make-Up Torque Minimum
4-´OEIW
13Cr - L80
KS Bear
4-´%RG\± 4.906" Coupling
3.958"
´
288,000lb
288,000lb
8,430 psi
7,500 psi
4,860 ft-lb
Workover Procedure SV-4P
Page 9
Well Workover Procedure
Cuu Long Joint Operating Company.
Optimum
Maximum
SV-4P
5,400 ft-lb
5,940 ft-lb
Tubing Specifications to run with new Completion
Size/Weight
Grade
Connection
Maximum OD
Nominal ID
Drift ID
Body Yield
Joint Strength
Burst
Collapse
Make-Up Torque Minimum
Optimum
Maximum
4-´OEIW
L80
Vam Top
4-´%RG\± 4.937" Coupling
3.958"
´
288,000 lb
288,000 lb
8,430 psi
7,500 psi
4,000 ft-lb
4,440 ft-lb
4,880 ft-lb
Size/Weight
Grade
Connection
Maximum OD
Nominal ID
Drift ID
Body Yield
Joint Strength
Burst
Collapse
Make-Up Torque Minimum
Optimum
Maximum
3-´ lb/ft
13Cr
JFE BEAR
3-´%RG\± 3.883" Coupling
2.992"
2.867´
207,000 lb
207,000 lb
10,160 psi
10,540 psi
3,500 ft-lb
3,870 ft-lb
3,096 ft-lb
Drill pipe Specifications (Premium)
Size/Weight
Grade
Connection
Maximum OD
Nominal ID
Connection ID
Body Tensile Strength
Connection Tensile Strength
Burst
Collapse
Make-Up Torque Minimum
Maximum
´OEIW
S135
NC 38
5.000"
2.764"
2.125"
381,900 lbs
842,000 lbs
23,708 psi
21,626 psi
10,200 ft-lb
14,000 ft-lb
Capacity Information of Tubulars and Annuli
Casing/Riser
´OEIWFDVLQJ
´OEIWFDVLQJ
´RSHQKROH
0.2402bbls/m
0.2322bbls/m
0.2303 bbls/m
Workover Procedure SV-4P
Page 10
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 11
Section 4. OFFLINE PREPARATION OF THE WELL
OBJECTIVE:
1. Prepare as much as we can SV-04P before workover offline.
SAFETY:
1. Perform Pre-Job safety meeting with all personnel involved to review objectives and identify any safety
issues for every operation
PROCEDURE
Run drift
Perform hot bolting of the Tree and wellhead and Bonnet assembly.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 12
Section 5. WELL SECURED AND SKID & PULLING OLD COMPLETION AND FIX LEAK
9-´&$6,1*3$&.2))
5.1 CLEAN TUBING WITH HCL 10% (PLAN TO DO BEFORE HWU ARRIVE,
CONTINGENCY TO DO WHEN HWU IN PLACE)
5.1.a Shut in the well & RU pumping surface line.
1.
2.
Shut in the well by Stop/Closed Gaslift valves. Naturally, flow well to THP as low as
possible. Close wing valve and manifold.
Function test DHSV / Hydraulic master valve / manual master valve - Most likely valves
are not functioning (No CFT test and scale deposit).
Remark: Tubing pressure should be bled off as low as possible.
3.
4.
5.
Connect HWU pumping line system to top WH.
Clean mixing tanks/storage tanks before mixing acid.
Pressure test surface pumping line against Swap valve to 2000psi in 10 minutes. Bleed
off to zero. Ready for pumping.
Note: The deck area where installed pumping unit, mixing tank, storage tank, must be
kept clear for monitoring chemical leakage.
Tarpaulin underneath acid mixing equipment and pumping line as required
5.1.b Mixing and Pumping Treatment
1.
&RQGXFWVDIHW\PHHWLQJDQGUHYLHZ-6$¶VIRUPL[LQJSXPSLQJWUHDWLQJIOXLG
2.
Confirm that establish clear line of communication between for the starting of the
injection pump
3.
Identify the well and apply the standard Lock-out, Tag-out procedures.
4.
Prepare treatment as per following recipe.
5.
Mixing 90bbl of 10% HCl as PV Chem procedure.
Chemical
Description
Filtered Fresh Water
HAI-OS
FE 2
FE-1A
HCl Raw Acid,32%
Musol-A
Paragon 100E+
Base fluid
Corrosion inhibitor
Iron Control
Acetic acid
Raw Acid
Mutual Solvent
Aromatic Solvent
Concentration
592
5
50
10
273
40
80
gal/Mgal
gal/Mgal
lb/Mgal
gal/Mgal
gal/Mgal
gal/Mgal
gal/Mgal
Req.
Volume
2,238
Unit
19
190
38
1032
151
302
Note:
- Mixing plan will be reviewed on location to accommodate total job volume and
available holding tank.
- Clean mixing tanks/storage tanks before mixing acid.
5.1.c Pumping schedule
Fluid
Pumping schedule
Workover Procedure SV-4P
gal
gal
lb
gal
gal
gal
gal
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Stage
Acid pumping
Displacement
10% Hcl
Acid
Filtered Sea
water
Page 13
Rate
(bpm)
Pressure (psi)
Max
Volume,
bbl
1-2bpm
TBC
90
1-2bpm
TBC
Time
(min)
400bbls
Note:
Monitor annulus pressure, report if any pressure changes (more than 200 psi)
The pumping pressure limitation can be changed upon actual rate, pressure. In any
case no go over the surface line pressure test value.
-
Slowly pump pump 90bbls of 10% HCl acid to tubing at the rate of +/- 1-2 bpm (note that
well may take fluid by gravity).
-
Function test DHSV/Master Valve.
! Disconnect DHSV control line and connect DHSV to the hand pump.
! Use hand pump to function test DHSV by monitoring pumping pressure and fluid return
to confirm the DHSV functioning.
! When the DHSV confirm can open/close. Disconnect hand pump and connect DHSV to
the DHSV control line.
-
Continue pumping with max flow rate (estimate 400bbls TSW = 1.5 tubing volume) to
push away Acid into the reservoir.
-
Close the Lower Master valve and open production wing valve. Line up the well to the test
separator.
-
Rig down pumping line out of WH. Prepare for SLK job to secure the well.
5.2 SECURED THE WELL
These notes below must be read carefully and followed strictly though slickline operations in the well
-
Before rig up, the BOP must be function and leak test, the caEOH´PXVWEHtorsion
tested before make up to the rope socket.
-
Check measuring and weight indicator systems.
-
All tools/equipment to be run in hole must be checked/ function tested. Record OD,
lengths before make up.
-
Length of the lubricator must be calculated so that the tool string can be made up above
the swab valve.
-
Smart monitor system should be installed in Wireline unit for recording Toolstring weight/
depth during slickline operation
-
During the slickline operation, use the swab valve & LMV as work valves. (Require a
double block and bleed for all tool change outs). The valve turns should be counted to
make sure that the swab valve is fully opened or closed. The UMV should be controlled
by Vendor Control panel and lock opened when wire in hole by Lock out cap (as a backup).
-
Check all the needle valve on DHSV control line to make sure this valve is opened and
controlled by PVD well head control panel.
-
Record toolstring weight in the lubricator (air weight).
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 14
-
Record FTHP, SITHP, and all annulus pressure.
-
Record the liquid level in the well if possible.
-
The speed of running and pulling must be reduced when the tool string passes through
the down hole completion equipment as: Tubing hanger, DHSV, Nipple, Gaslift
mandrels, PDHG, packer, end of tubing and when the tool string is pulled out 200m
from the surface
-
Weigh the tool string every 500 m when run in hole and record static, slack off and pick
up weight at the speed of 15 mpm for reference to the next run.
-
Weigh tools 10m above nipple profile, and above sudden changes in wellbore ID
-
Function test tree valves and SCSSV to ensure pressure integrity and 2 barriers before
removing tree cap.
5.2.a Drift Run to verify tubing is cleaned after acid job.
All depth mentioned in this parts reference to Tubing hanger
1.
Shut in well, bleed off pressure from Annulus/tubing to minimum.
2.
Line up SW to annulus & tubing to fill in 100lbs for tubing and 400lbs for Annulus.
3.
Rig up X-RYHU ´ 5LVHU SXPS-in tee, BOP, Quick test sub and Lubricator above
production tree. (See the schematic attached).
4.
Make up dummy run tool string w/ 3.7´tubing swage tool.
5.
Calibrate the weight indicator, depth measuring device (counter). Zero depth when the
bottom of tool string at the tubing hanger. Pull the tool string in to lubricator.
6.
Make up lubricator/QTS.
7.
Pressure test full PCE string against Swap valve up to 2000psi/10min.
8.
Slowly open Swab valve / LMV. Run in hole with the tool string.
9.
Continue to RIH to 3034 m THS (approx. 10 m above the SSD#1 depth @ 3044 m THS),
check the pulling weight.
10.
Slowly lower the tool string completely hangs on depth of the safety SSD. POOH.
11.
Confirm the tool string is fully in Lubricator. Close the Swab valve and LMV. Count turns
to make sure all valves are fully closed.
12.
Depressurize Lubricator; break open Lubricator at QTS to remove 3.7´ tubing swage
tool.
5.2.b Set 3.813´ X plug / Prong at DHSV depth (170m WD)
13.
Bullhead injection water in the well
14.
Function test ´;ORFNSOXJto make sure that this lock is in working condition.
15.
Make up the ´;ORFNSOXJWR´;UXQQLQJWRRORun in non-selective position.
16.
Calibrate the weight indicator, depth measuring device (counter). Zero depth when the
ORFN¶VNH\DWWKH7XELQJKDQJHU3XOOWKHWRROVWULQJLQWROXEULFDWRU6WDEOXEULFDWRURQ
QST
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 15
17.
Re-test the lubricator system by quick test sub 2000 PSI in 5 minutes. Bleed off pressure
from QTS. Slowly open the swab valve. Run in hole with the tool string.
18.
Continue to run to 160 m (approx. 10 m above the DHSV @ 170 m), weigh the tool
string.
19.
Slowly lower the tool string to X nipple. Jar GRZQWRVHW´ORFN:KHQWKHORFNVHW
properly, over pull 250 lbs to reconfirm. Jar up to release running tool. POOH.
20.
When tool at surface, close Swab valve/ LMV valve and depressurize lubricator; break
open Lubricator at QTS to remove ´;UXQQLQJWRRO
21.
)XQFWLRQFKHFN´-'&UXQQLQJWRRO0DNHXS´-'&ZLWKX prong.
22.
0DNHXSWKH´-'&SURQJto the string.
23.
Calibrate the weight indicator, depth measuring device (counter). Zero depth when the
end of toolstring at Tubing hanger. Pull the tool string in to lubricator. Stab lubricator on
QST
24.
Re-test the lubricator system by quick test sub 2000 PSI in 5 minutes. Bleed off pressure
from QTS. Slowly open the swab valve. Run in hole with the tool string.
25.
Continue to run to 160 m (approx. 10 m above the DHSV @ 170 m), weigh the tool
string.
26.
Slowly lower the tool string to ´;ORFN. Tap down to set SURQJDQGVKHDU´-'&WR
release. POOH.
27.
Confirm the tool string is fully in Lubricator. Close the Swab valve and LMV. Count turns
to make sure all valves are fully closed.
28.
Depressurize Lubricator and break open Lubricator at QTS to remove tool string.
29.
Install test cap on top of QTS. Open water injection system/ Open Swab valve/ LMV.
Filled up tubing with seawater (10 bbls). Pressure up tubing with incremental 500- 10002000 psi in 5-5-10 minutes. Monitor and Record THP/ annulus and casing pressure
during testing.
30.
Bleed off tubing pressure to zero. Bleed off annulus pressure to zero if any. Close Swab
valve and LMV. Rig down slickline equipment from the well± ready for setting
TWCV/BPV in tubing hanger
5.2.c Set TWCV in tubing hanger (second barrier).
1.
Apply PTW with JSA. Pre-job safety meeting with people involved.
2.
Rig up lubricator with TWCV on top of the tree. Pressure test TWCV lubricator 2000 psi
for 10 minutes. Bleed off THP to zero.
3.
Open Swab valve/ LMV and set TWCV as per SPM Oil & Gas procedure
4.
When finish setting TWCV, nipple down SPM Oil & Gas equipment.
5.
Remove choke
Barrier:
Tubing side:
x
x
´X plug set and tested at the DHSV level (Pressure test at 2000psi)
TWCV set on the tubing hanger profile.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
x
SV-4P
Page 16
Column of seawater in hole / DHSV
Annulus side:
x
x
Production packer
Tubing hanger tested.
The well is ready for removing the tree
5.2.d Remove production trees and 3XOO7:&9´ Plug
1.
Nipple down trees as SPM Oil & Gas procedure.
2.
Check tubing hanger condition. Terminate SCSSV control line. Function test DHSV 3
times. Pressure test DHSV control line 4000 psi and trap pressure with two barriers (with
needle valve) to keep DHSV opened. Secure control line in Tubing hanger.
3.
Dummy run TH pulling tool.
4.
Rig up wellhead adaptor and HP riser
5.
Skid the HWU an align BOP stack to 4P well.
6.
Connect BOP to riser
7.
Secure HWU as per VELESTO Procedure
8.
MU WH jetting toll and do jetting WH
9.
Rig up Tubing hanger pulling tool with landing string (5-´.6EHDUWXELQJ 10.
Run and latch tubing hanger.
11.
Test BOP/riser as VELESTO procedure
12.
MU Pack off pulling BHA. Run in to pull 4-´6067XELQJ3DFNRII
13.
MU 4-´7+*SXOOLQJWRROWR-´/DQGLQJVWULQJDQGlatch into THG.
Pull TWCV/3.813X plug
14.
Retrieve TWCV from tubing hanger as SPM Oil & Gas procedure.
15.
Rig up slickline equipment on top of landing string.
16.
Make up slickline tool string with Prong pulling tool.
17.
Pressure test Slickline PCE 2000 psi in 10 minutes against TIW valve
18.
%OHHGRIISUHVVXUHIURP3&(RSHQ7,:5XQLQKROHWRUHWULHYH´;SURQJDWGHSWK
170m
19.
POOH. Confirm the tool string inside Lubricator. Close TIW. Bleed off pressure from
lubricator if any.
20.
Break PCE at QTS and change JDC tool to GS pulling tool
21.
Make up lubricator and re-test PCE via QTS with 2000 psi in 5 minutes.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 17
22.
Bleed off pressure from QTS. Open TIW valve. RIH with GS pulling tool
23.
Latch lock at 170m, jar up to free the lock.
24.
POOH. Confirm the tool string inside Lubricator. Close TIW. Bleed off pressure from
lubricator if any.
25.
Rig down slickline tool / equipment.
5.3 PULLING UPPER COMPLETION, CASING SCRAPER/SET STORM PACKER
5.3.a Pulling upper completion
1.
Latch elevators to landing string and slowly pickup to expected completion weight of
134,000# (dry weight)
2.
Increase pulling weight to 154,000# to release seal assembly from packer bore
Remark: Locator seal Assy sting into the Quantum packer of the lower completion
3.
Weight should be seen to decrease when seals are free from packer bore.
Note:
Contingency case if cannot release packer. RU slickline to lock open DHSV (detail
procedure as appendices
Eline and tubing cutter to be available in case packer does not release, so we will
5,+ (OLQH Z WXELQJ FXWWHU WR FXW ´ tubing at 2965m (mid of joint J183-07 in
running tally)
4.
Stop pulling and flow check well.
5.
Be prepared to fill up well with treated seawater (tubing & annulus).
6.
Wait @30minutes to allow packer element to relax.
7.
When Tubing hanger at rotary. Bleed off pressure from control line. Cut DHSV control
line below TH.
8.
Break out TH and lay down.
9.
Start pulling tubing removing control line protectors and spooling control line and gauge
cable.
10.
Top fill seawater to annulus at 25 BPH while pulling tubing.
11.
Lay out tubing with thread protectors on both ends
12.
Remove DHSV / WX nipple/ SPM #1/ SPM # 2/ SPM #3/ SPM #4/ gauge mandrel/ WRN
nipple/seal assembly and lay out.
13.
Inspect pulled equipment and report any defects/corrosion.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 18
5.3.b Casing scraper
While running scraper assembly continue to pump water to casing at 25 BPH & Set
Storm Packer
1.
Install wear bushing
2.
Make up scraper assembly.
3.
5,+VFUDSHUDVVHPEO\RQò´GULOO pipe
4.
RIH to +/-1500 m (storm packer setting area) double scrape over setting area.
5.
RIH to +/-2100 m (ESP packer setting area) double scrape over setting area.
6.
Pump 200bbls seawater to ensure tailpipe below lower packer is free of debris.
7.
Pull out of hole and lay down Scraper assembly running tool.
5.3.c SET STORM PACKER
1.
Make up Storm packer assembly.
2.
5,+VWRUPSDFNHUDVVHPEO\RQò´GULOO pipe
3.
RIH to +/-1500 m (storm packer setting area) double scrape over setting area.
4.
Pump 200bbls seawater to ensure tailpipe below lower packer is free of debris.
5.
Set packer at 1500 m as Baker/ BJ procedure. (to make sure storm packer below liquid
level)
6.
Fill well and pressure test to 500 psi/5min, 2000psi/10min.
1RWHGXHWRIDLOHG´ & 13-´SDFN off we will not be able to apply pressure.
7.
POOH with running tool. At ~200/300m spot 10 bbls of HiVis
8.
L/D running tool.
9.
Pull Wear Bushing
10.
Skid HWU away 4P.
11.
N/D BOP/RISER
5.4 FIX LEAK 9-´&$6,1*3$&.2))
Primary Plan
1.
Recover 9 5/8 casing pack off as per SPM OIL & GAS procedure. Æ Pack-off retrieving
tool.
2.
RIH spear assembly (Baker/BJ) as follows:
x
ó´,Weco type releasing spear.
x
Bumper sub
x
´GULOOFROODU
x
1jt 3 ò´GULOO pipe
3.
Engage spear in casing and slowly pick up to try and disengage casing hanger slips.
Note that slips were set with 35k# overpull.
4.
Pressure test 9-´FDVLQJWRSVLWRFRQILUP0/6KDVSUHVVXUHLQWHJULW\
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
5.
Slowly pickup to 250K# pull and drop in new casing slip.
6.
Slack-off over-pull.
7.
Install new 9-5/8´ Casing Emergency Pack off. (Final cold cut casing if required)
Page 19
Contingency plan:
Note: If casing slip unable to retrieve or 9-5/8´ casing end not good for sealing.
(Required to cut and release the 9-5/8´ MLE).
x
RIH 9-5/8´ casing mechanical cutter between Wellhead and MLE (~12m below the
wellhead).
x
Cut 9-5/8´ casing. POOH cutter.
x
Run casing spear and Pull upper part of the 9-5/8´ casing.
x
Run casing spear and release mudline tie back by 10 turns left.
x
Pick up 0.5m string (check string weight to confirm tieback free).
x
POOH casing spear with mudline tieback.
x
Run new 9-5/8´ tieback.
x
Slowly pickup to 250K# pull and drop in new 9-5/8´ casing slips.
x
Slack off overpull.
8.
Pressure test internal of the 9-5/8´ casing up to 2000psi/10min at surface.
9.
Bump down on overshot and rotate to right to disengage.
10. POOH and laydown overshot assembly, bumper sub and drill collar.
Note: Casing stub may need to be dressed off to correct length after setting casing
hanger
11. Use 9-´LQWHUQDOFROGFXWWHUWRGUHVVWKH-´FDVLQJQHFN.
12. M/U pack-off running tool.
13. ,QVWDOOQHZ´SDFN-off and pressure test as per SPM OIL & GAS procedure. POOH
with pack-off running tool and 3 ò´GULOOSLSHOD\LQJdown.
14. Install new THS with isolation bushing and test as per SPM Oil & Gas procedure.
15. N/U 13-´5LVHU.
16. N/U BOP.
17. Skid back HWU to 4P
18. Pressure test BOP
19. Pressure test storm packer as done previously (2000psi) to confirm that the
communication between A and B annulus has been fixed.
20. Install wear bushing
21. RIH Storm Packer retrieving tool and recover packer/ storm valve. POOH.
22. R/D drill pipe handling equipment and prepare to run ESP completion.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 20
Section 6. COMPLETION INSTALLATION
6.1 OBJECTIVE:
1.
Successfully RIH with ESP assembly and power cable / 2´;SSD / ESP Production
Packer / Chemical injection line / CTS gauge / */0¶Vtubing, TRSV control line such
that no damage occurs.
2.
Connect and terminate TRSV control line / power cable through the Tubing Hanger /
chemical injection line / CTS gauge control line.
3.
Run Tubing Hanger.
4.
Run and set 2´SOXJIRUVHWWLQJSDFNHU
5.
Set Production Packer, pressure test tubing hanger, annulus, tubing, and safety valve.
6.
Do not lose any junk or tools down well.
SAFETY:
1.
2.
3.
4.
5.
6.
At Cuulong, our work is never so urgent or important that we cannot take the time
to do it safely.
Perform Pre-Job safety meeting with all personnel involved to review objectives, define
responsibilities and identify any safety issues.
All equipment, such as tubing elevator, lifting slings etc should be certified and the
certificates verified.
Ensure a full bore TIW with pumping tee with the correct connections is available on the
rig floor and ready for use.
When pressure testing control lines, tubing etc, ensure proper safety barriers are erected
and safety alerts have been broadcast. Before tightening or breaking any connections
ensure any pressure is fully bled-off.
Hole covers to be available and in place when working on components, i.e. control line
clamps. Hand tools should be tied off when working around the table to prevent dropping
them in the hole.
NOTES:
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
Review final completion schematic and tally prepared by Schlumberger on rig after lower
completion is set.
Completion equipment will be L80, 13CR. All handling of completion tubular on the rig
must be done under the supervision of BJ Tubular services.
In the event that the primary and backup torque turn equipment fails, running completion
will cease until the equipment is repaired or replaced.
Only clean and uncontaminated API Modified thread compound will be used on upper
and lower completion tubing and subassemblies.
All tubing pin and box threads to be thoroughly cleaned prior to make up.
'ULIWXWLOL]LQJD´ Teflon drift and measure the correct lengths of 4-´ L80
Vam Top tubing and 2.867´7HIORQGULIWIRU-´&5-)(%HDU
API Modified thread compound will be applied sparingly, as specified, to pin-end,
top half of the box thread and the seal face of the box. Fresh API Modified thread
compound shall be used (new bucket, ensure thread compound is stirred before
use).
During make-up operations, the torque shall be continuously monitored.
After stabbing the connection will be made up a minimum of 3 threads using a WFT
micro wrench or strap wrench. The PVDWS tong will then be placed on the joint and the
connection made up to full make up torque, speed of the tong should 4 to 6 rpm in low
gear until full make up torque is reached.
Always use stabbing guide. Do not rock pipe.
Ensure tubing joints are made up to the correct torque values. See Section 3.0.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
12.
13.
SV-4P
Page 21
All equipment will be jet washed prior to pick-up.
Install the tubing split bowls (with a cut out for the cable). Exercise care when setting
and pulling slips to avoid crimping control line and power cable.
Maximum rate through the gas lift orifice valve is 1 bpm to avoid flow cutting the check
valve.
Aker Solutions will utilize the Single Trip Tubing Hanger Running Tool for this completion
program.
14.
15.
6.2 RIH ESP COMPLETION:
General Rules:
x
x
x
x
All equipment needs inspection prior to be run.
Threads must be cleaned and tried (for new items)
All internal diameters must be drifted as per specification
$OOHOHPHQWVQDPHGDQGODEHOHGRQWKH³FRPSOHWLRQVKHHW´GRFXPHQW
1RWH 6SHFLDO FDUH PXVW EH WDNHQ ZKHQ VHWWLQJ WKH SDFNHU $YRLG VHWWLQJ WKH
SDFNHULQIURQWDFDVLQJFRQQHFWLRQ
1.
Hold tool box safety meeting on the rig floor with all operation personnel involved. Be
aware of possible simultaneous operations taking place below the rotary table on the
wellhead platform.
Note: Ensure that the tubing handling procedures are discussed prior to picking
the tubular
Note: cable to be tested every 10 joints for insulation and continuity.
1RWH5XQQLQJVSHHGWREHOLPLWHGWRMRLQWSHUPLQXWH
2.
RU PVDWS Services tubing running tools including torque turn computer, Fluid Grip
power tongs with integral back-up, grooved rotary inserts and RP dies to allow clearance
for running the control line, and square shouldered 4-´ HOHYDWRUV VLQJOH MRLQW
elevators, 3-´Hlevators, 3-´VLQJOH elevators, safety clamp, stabbing guide, and
other essential tools.
3.
Pick up tubing hanger complete with the tubing hanger running tool (THRT). Ensure
landing string has been cleaned and inspected. Calculate the length of the landing string
required to allow approximately 1 meter above the rotary table when the tubing hanger
is landed. The landing string will be 5-´-)(%HDUWXELQJZLWK-´,)%R[[´-)(%HDU3LQ;-over at the top for handling. Make up the landing string to the
tubing hanger running tool complete with tubing hanger. Perform dummy run, drain BOP
stack, verify scribed line on tubing hanger is visible through the annulus valve and mark
pipe. POOH and lay down.
Note: Ensure that all the seals are removed from the tubing hanger body and neck and
ensure that the tubing hanger running tool is in the running configuration.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 22
6.3 ESP INSTALLATION PROCEDURES
Note: Cable cutters to be placed on rig floor prior to installation
1.
Position ESP equipment (pumps, motors..) shipping boxes facing the v-door
2.
Remove the units from their boxes and layout on the pipe racks.
3.
Electrical test Motor, Sensor and Cables using megger prior to running them into the
well. After megger is used, DO NOT discharge the built up electrical charges by
sparking out directly to ground but discharge it through the resistance in the
megger.
4.
Identify and verify that there is enough MLE cable on the reel to run the ESP
equipment up to the packer depth.
5.
Very carefully lift the cable gooseneck and hang it on both beams available at the Top
Basket as directed by the ESP servicemen. Pick up the MLE reels and the discharge
pressure control line reel onto the Work basket (Top basket) floor. Install the reels on
the temporary stands. Ensure that the reels are not obstructing the rig operation or
create hazard to personnel working on the Top basket. Otherwise place the MLE reels
onto a cable spooler and position the spooler on the main deck of the platform.
6.
Lift the work table onto the Top basket and place it in the middle of the basket as
directed by the ESP Servicemen.
7.
Pick up the motor + sensor + chemical injection sub with the main crane following the
lifting procedures and carefully transfer it to gin pole line on the top basket.
8.
Install the Pd line to the sensor
9.
Install chemical injection line to injection sub.
10.
Pump through chemical injection line to ensure open.
11.
slowly RIH the assembly
12.
Land assembly on work table.
13.
Pick up the upper tandem motor with main crane and carefully transfer to gin pole line
14.
Make up to lower motor assembly
15.
Install protectolizer at connection
16.
RIH assembly.
17.
Pick up lower protector with the main crane following the lifting procedures and
carefully transfer it to gin pole line on the top basket
18.
Make up the lower protector to the motor as per standard Trident/Maximus installation
procedure.
Caution: Observing correct alignment for the position of the MLE, Pd line and
chemical injection line.
19.
Remove the motor lifting clamp.
20.
Install MLE to the upper motor and fit a protectolizer to the motor/protector connection.
Note: Test the motor and cable continuity and insulation from the cable drum
21.
Slowly RIH the assembly and land assembly on work table.
22.
Pick up the upper protector with the main crane following the lifting procedures and
carefully transfer it to gin pole line on the top basket.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
23.
SV-4P
Page 23
Make up the upper protector to the lower protector as per standard Trident/Maximus
installation procedure.
Caution: Observing correct alignment for the position of the MLE, Pd line and
chemical sub.
24.
Install protectolizer at connection.
25.
RIH assembly and land on work table.
26.
Make up intake to upper protector.
27.
Pick up first pump section with the main crane following the lifting procedures and
carefully transfer it to gin pole line on the top basket.
28.
Make up pump to intake. Install protectolizers at both intake connections.
Caution: Observing correct alignment for the position of the MLE, Pd line and
chemical injection line.
29.
Slowly RIH the assembly and land on work table.
30.
Pick up second pump section with the main crane following the lifting procedures and
carefully transfer it to gin pole line on the top basket.
31.
Make up second pump to first pump. Install protectolizer at connection
Caution: Observing correct alignment for the position of the MLE, Pd line and
chemical injection line.
32.
Slowly RIH the assembly and land on the work table.
33.
Perform final shaft rotation check from the top of the upper pump.
34.
Make up the pressure discharge sub to the top of the pump observing correct
orientation for position of the Pd line.
35.
Terminate and secure the Pd line. Install protectolizer at connection
36.
Once complete ESP assembly is made up test motor lead extension cable insulation
and continuity.
37.
Slowly RIH one joints tubing.
38.
38DQG08´66' PDNHVXUH66'IXOO\FORVHG
39.
Slowly RIH one joint tubing.
40.
Motor lead extension to be clamped to tubing using Lassale type cross coupling
protectors every joint.
41.
The packer should have been prepared for +/-2500 psi setting pressure.
42.
Space out for MLE length and add Pup joints as needed
43.
P/U and M/U packer assembly.
44.
Check and re-orient alignment of the MLE cable and penetrator port. (add more pup
joints below packer and tap the clamp to adjust the MLE cable).
45.
Connect chemical line to connection above/below packer.
46.
Feedthru and connect MLE to packer penetrator.
47.
Test MLE, penetrator and motors for insulation and continuity.
48.
Connect power cable to upper side of packer penetrator.
49.
Test complete power cable for insulation and continuity.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
50.
Ensure that downhole gauge is functioning
51.
P/U and run one joint tubing.
52.
Continue to RIH tubing at 0.5 joint per minute and testing cable every 10 joints.
53.
Pump through chemical injection line every 20 joints
54.
Install GLM #2 at +/-2065 m MD
Page 24
1RWHVSHFLDOSURWHFWRUVWREHLQVWDOOHGDERYHDQGEHORZ*/0
55.
Continue to RIH tubing at 0.5 joint per minute and testing cable every 10 joints.
56.
Pump through chemical injection line every 20 joints
57.
Install GLM #1 at +/-1130 m MD
58.
Continue to RIH tubing at 0.5 joint per minute and testing cable every 10 joints.
59.
Pump through chemical injection line every 20 joints
60.
M/U SCSSV assembly.
61.
Purge control line with Aqualink HT and ensure it is air free.
62.
M/U control line to SCSSV
Note: After having made up the control line to the SCSSV, unscrew the jam-nut fitting
to check that the ferrule is located in the correct position. Make up the control line again
to the hydraulic port loosely. Flush control line/safety valve hydraulic port. Tighten jamnut fitting.
63.
Pressure test the port on the SCSSV and control line to 7500 psi for 15 minutes as per
Schlumberger SCSSV installation procedure. Disconnect pump and maintain 5000psi
control line pressure and monitor during RIH.
Note: Pressure is maintained in the control line in order to obtain an immediate
indication of control line rupture should it occur.
&RQWLQXH WR 5,+ WXELQJ DW MRLQW SHU PLQXWH DQG WHVWLQJ FDEOH HYHU\ MRLQWV XQWLO
SDFNHUVHWWLQJGHSWKLVUHDFKHG
64.
Record P/U and S/O weights.
65.
Before P/U hanger assembly double check against tally to ensure the packer will not
be set across a 9-´FDVLng collar. If necessary use pups to space out
66.
Ensure tubing hanger assembly numbers are correctly recorded on the running tally.
Prepare the Tubing Hanger (TH) and Tubing Hanger Running Tool (THRT) per Weir
Installation Procedures.
67.
Pick up the Tubing Hanger complete with tubing hanger running tool and make this up
to the last joint of tubing.
68.
Lower the completion assembly until Tubing Hanger is at a workable height. Bleed off
pressure on safety valve.
69.
Set slips on tubing below the Tubing Hanger assembly.
70.
Remove the tubing hanger running tool by rotating 10 turns to the right (clockwise),
pick up and set the tool aside, prepare to start work on the control line/downhole cable
/ chemical injection line installation to the tubing hanger.
71.
Cut the SCSSV control line with sufficient length to allow 6 wraps around the tubing
hanger neck.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 25
72.
,QVHUWWKH6&669OLQHWKURXJKWKHKDQJHUDQGWHUPLQDWHZLWKó´VZDJHORFNILWWLQJVWRS
and bottom.
73.
Cut the chemical injection line with sufficient length to allow 6 wraps around the tubing
hanger neck.
74.
,QVHUWWKHFKHPLFDOLQMHFWLRQOLQHWKURXJKWKHKDQJHUDQGWHUPLQDWHZLWK¶¶VZDJHORFN
fittings top and bottom.
75.
Test the top and bottom Swagelok fittings to 5,000 psi through the test port in the
hanger body.
76.
Wrap the control line / chemical injection line around the tubing hanger neck 6 times
and secure with cable ties.
77.
Install lower pigtail to electrical penetrator
78.
Cut main power cable to length and splice to lower pigtail
79.
Test power cable from the top of the penetrator for insulation and continuity.
80.
Ensure that downhole gauge is operating correctly
81.
Re-install the neck and body seals to the tubing hanger. Apply grease to the running
threads of the tubing hanger.
82.
Suspend the THRT above the tubing hanger. Pass any control lines that are to be run
to surface thru the holes in the top of the THRT and connect them to the appropriate
FRQWUROOLQHZUDSSHGDURXQGWKHWXELQJKDQJHUQHFNZLWKDó´DQG¶¶6ZDJHORN
union. Lower the THRT and install to the tubing hanger by 10 left hand (counterclockwise) rotations OR until the tool just touches the tubing hanger locking sleeve.
Note: Ensure that the tubing hanger lock ring is not expanded prior to running the tubing
hanger through the rotary table.
83.
Function-test the SCSSV with Aqualink HT 804 to 7500 psi as per the SCSSV
Installation Report. Report volume pumped and check returns. Maintain and monitor
5000 psi while landing the Tubing Hanger.
84.
Pump through the chemical injection line to ensure it is open.
85.
Drain the BOP stack by opening the A annulus. This should remain open while setting
the hanger.
86.
Prior to running the tubing hanger, an indicator mark can be painted on the tubing
KDQJHUUXQQLQJWRRO¶VODQGLQJMRLQW7KHLQGLFDWRUPDUNZLOOEHHYHQZLWKWKHURWDU\WDEOH
when the hanger is properly landed. Slowly lower the tubing hanger through the BOP
stack and land it on the tubing hanger landing shoulder. Monitor the pressure on the
SCSSV and vent valve lines as the tubing hanger is landed.
87.
Verify that the tubing hanger has landed correctly by ensuring that the indicator mark
on the landing string is level with the rotary table and looking through the annulus
outlet. The indication groove should be in the center of the outlet.
88.
7HVWWKHWXELQJKDQJHUVHDOVYLDWKHô´137WHVWSRUWVPDUNHG³7(67325712´
to a maximum of 5,000 psi. If the tubing hanger seals do not test, pull tubing hanger
running tool with tubing hanger back to the rig floor, and check seals. Replace seals if
damaged.
89.
After successful test, lock tubing hanger in place by rotating tool another 5 rounds to
the left.
Note: It may require about 500 ft-lbs of torque to rotate the 5 rounds.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 26
90.
To confirm the tubing hanger is locked in place, an over pull of 25,000# over the
landing string weight should be pulled (followed SPM procedure).
91.
Close the A annulus valve.
92.
R/U slickline on landing string. TIW valve and pump in sub to be included below the
slickline BOP.
93.
0DNHXS´VWDQGLQJYDOYH
94.
Calibrate the weight indicator, depth measuring device. Zero depth with bottom of tool
string at RT. Pull the tool string into the lubricator and stab lubricator on QTS
95.
Pressure test the lubricator system via the pump in sub to 4000 psi for 5 minutes.
Bleed off pressure.
96.
Slowly open TIW valve and RIH.
97.
Stop 10m above Nipple at +/-2075 m. Take hanging, P/U and S/O weights.
98.
RIH to Nipple depth. Slowly tap down and jar down
99.
Jar down to set standing valve.
100. Slowly pick up toolstring. Monitor tension drop. POOH.
101. When tool at surface, close TIW. Break open lubricator to remove the 3.0" SB tool,
check to confirm standing valve is set.
102. Remove lubricator and install cap on top of QTS.
103. Rig up high pressure line to Pump in T sub on the Slickline PCE from cement unit and
pressure test lines to 4,000 psi for 15 min. In addition, rig up a line to the casing valve
from the HWU pump unit to be able to pressure up the annulus. (Always use chart
recording for annulus and tubing pressure).
104. Check downhole pressure from downhole gauge and calculate annulus fluid level.
105. Pump enough inhibited seawater to clear untreated seawater from annulus. (max rate
4 BPM)
106. Check downhole pressure again and calculate differential on packer. This will give
surface pressure required to shear packer setting pins.
107. Calculate and check DHSV control line to ensure open during packer setting process.
108. Set production packer by pressuring up on tubing to +/-2500 psi (engineer need to
calculate the pressure pumping to set the packer). Monitor the pressure for first 500
and 1000 psi for ten minutes each to ensure tubing integrity, then increase the tubing
pressure to +/-2500 psi to fully set the production packer. Hold final pressure for 15
minutes.
Note: Monitor and record all volumes pumped and returned.
Note: A annulus valve should be open while setting packer.
109. Bleed off tubing pressure to 2500 psi.
110. Close A annulus valve and pressure test line to 3000 psi for 10 minutes
111. Open annular valve and fill up with inhibited seawater, pressure test annulus to 2,000
psi for 15 minutes to verify packer has set and test tubing hanger seals. Bleed off
pressure to zero.
112. Close SCSSV by bleeding off control line pressure to zero.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 27
113. Bleed off tubing pressure to 500 psi above SCSSV flapper for 15 minutes and monitor
for inflow test. Pressure up tubing to 2,500 psi to equalize across the SCSSV.
114. Bleed off tubing pressure to 200 psi.
115. Bleed the control line pressure to zero to close the SCSSV.
116. Bleed off tubing pressure to 0 psi.
117. R/U slickline on landing string. TIW valve and pump in sub to be included below the
slickline BOP.
118. Make up 3.0"SB pulling tool.
119. Calibrate the weight indicator, depth measuring device. Zero depth with bottom of tool
string at RT. Pull the tool string into the lubricator and stab lubricator on QTS
120. Pressure test the lubricator system via the pump in sub to 4000 psi for 5 minutes.
Bleed off pressure.
121. Slowly open TIW valve and RIH.
122. Stop 10m above Nipple at +/-2075 m. Take hanging, P/U and S/O weights.
123. RIH to Nipple depth. Slowly tap down for tool string to be latched to 2.313" fishing neck
of 2.813"standing valve.
124. Over pull to above 500lbs, then Jar up. Monitor pressure on tubing, expect water
above standing valve will be dropped to below thru equalizing port on the standing
valve.
125. Wait for a while. Continue Jar up until tool free and POOH.
126. When tool at surface, close TIW. Break open lubricator to remove the 3.0" SB tool,
check to confirm standing valve retrieved.
127. Remove 2.813"Standing valve with 3.0"SB pulling tool
Set 3.812´SOXJDW'+69
128. 0DNHXS´;OLQHUXQQLQJWRROVHOHFWLYHORFNDVVHPEO\WRVOLFNOLQHWRROVWULQJ
129. Calibrate the weight indicator, depth measuring device (counter). Zero depth when the
bottom of tool string at the tubing hanger. Pull the tool string into lubricator.
130. Snap lubricator on top of QTS. Pressure test Lubricator via QTS with 2000 psi ± 5mins.
Bleed off QTS to zero
131. Slowly open Swab valve / LMV. Run in hole with the tool string.
132. Continue to RIH to 188 m THS (approx. 10 m above the DHSV depth @ 198 m THS),
check the pulling weight.
133. Lower the tool string through the tubing until the plug drops through the DHSV.
134. Pickup to trip the running toRODQGVLWGRZQLQWKH´QLSSOHSURILOH
135. Tap down lightly to push vee packing assembly to go inside seal bore. Continue to tap
down to set the lock.
136. When the lock is properly set, over pull 250lbs two times to check. Jar up to free
running tool. POOH.
137. When tool at surface, close Swab valve / LMV and depressurize lubricator and break
RSHQOXEULFDWRUWRUHPRYHWKH´;OLQHUXQQLQJWRRO
138. Make up equalizing prong to JDC running tool.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 28
139. Make up JDC and prong assembly to the slickline tool string.
140. Calibrate the weight indicator, depth measuring device (counter). Zero depth when the
bottom of tool string at the tubing hanger. Pull the tool string into lubricator.
141. Snap lubricator on top of QTS. Pressure test Lubricator via QTS with 2000 psi ± 5mins.
Bleed off QTS to zero
142. Slowly open Swab valve / LMV. Run in hole with the tool string.
143. Continue to RIH to 188m THS (approx. 10 m above the DHSV depth @ 198 m THS),
check the pulling weight.
144. Lower the tool string through the tubing until the prong contacts the plug body.
145. Tap down to set prong and shear JDC. Slowly pick up to make sure the prong set.
POOH.
146. When tool at surface, close Swab valve / LMV and depressurize lubricator and break
open lubricator to remove JDC running tool.
147. Pressure test 500psi/10mins from above to below.
148. Rig down slickline
149. RU and set TWCV by dry rod.
150. Release THRT by applying 16 turns to the right (clock wise), then lift the tool and
landing string and lay aside.
Note: When releasing the tubing hanger running tool, ensure that the control lines are
disconnected at surface and in tension before rotating the landing string to release the
tubing hanger running tool. As a precaution walk the control lines around with the
rotation of the landing string, as the swivel in the tubing running tool sometimes binds
up and the entire tool rotates and the control lines can get wrapped around the landing
string and possibly break.
7KHUHZLOOEHDQRSWLRQWRUXQDQGVHWSOXJSURQJDW´;66'WRVHWSDFNHU
Barriers now in place are:
Tubing
Tested barriers installed on the tubing side:
A) Deep plug set and tested.
B) Liquid column in tubing
C) SCSSV inflow tested.
D) Back pressure valve
Annulus
Tested barriers installed on the annulus side:
A) Tubing Hanger tested from below.
B) Production Packer tested from above.
C) Liquid column in Annulus
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 29
SECTION 7.0 INSTALL PRODUCTION TREE AND HANDOVER WELL TO PRODUCTION
7.1 OBJECTIVE:
1.
Safely remove BOP and riser to gain access to TH and wellhead FOR Tree installation,
after the barriers have been installed and tested.
2.
Ensure communication with downhole equipment such as TRSV is achieved through
the wellhead.
3.
Install and test production tree.
SAFETY:
1.
At Cuulong, our work is never so urgent or important that we cannot take the time
to do it safely.
2.
Perform Pre-Job safety meeting with all personnel involved to review objectives, define
responsibilities and identify any safety issues.
3.
All equipment, such as lifting subs, lifting slings etc should be certified and the
certificates verified.
4.
When pressure testing control lines, tubing etc, ensure proper safety barriers are erected
and safety alerts have been broadcast. Before tightening or breaking any connections
ensure any pressure is fully bled-off.
5.
Hole covers to be available and in place when working on components, especially on
the well bay area.
PROCEDURE:
Before the tree is picked up the following must have been carried out by a SPM Oil & Gas
Engineer
x
x
x
Ensure that the tree has been drifted with BPV with both the UMV and LMV held
open
Make sure that all tree valves have been stroked 3 times and excess tree grease
removed from the ID of the tree before installation
Ensure that all bolts which are removed or broken out are cleaned
Under SPM Oil & Gas Solutions supervision
1.
Nipple down the BOP stack as per PVD standard procedures.
2.
Wash the top of the tubing hanger area with high pressure water and blow dry with air.
3.
Remove the two flange outlets for SCSSV and vent valve lines on the wellhead.
7.2 INSTALLATION OF SCSSV WELLHEAD FLANGE:
4.
Un-wrap the control lines and chemical injection line from around the tubing hanger
neck. Feed the SCSSV control line through their repective ports on the wellhead body.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 30
Ensure that the outlet selected is in accordance with Production Operations
requirements.
5.
,QVWDOO WKH ´ 137 [ ´ %RUHG 7KURXJK 6ZDJHORN ILWWLQJ ZLWK ´ DQG ´ RSHQ
end/ring spanners over the SCSSV control line and make up into the wellhead body.
Make up Swagelok ferrules and nut to control line. Make sure control line not in tension.
&XWRIIFRQWUROOLQHò´RXWIURP6ZDJelok fitting.
6.
Carry out same procedure for CTS gauge line.
7.
Carry out same procedure for chemical injection line except that swagelok fitting will be
ERUHG¶¶
8.
0RXQWWKH6&669ZHOOKHDGRXWOHWIODQJHRQWRWKHZHOOKHDGERG\E\D´$)3W
socket wrench (Flange Screw Torque = 150 ft-lbs).
9.
0RXQWWKH&KHPLFDOLQMHFWLRQZHOOKHDGRXWOHWIODQJHRQWRWKHZHOOKHDGERG\E\D´
A/F 12 Pt socket wrench (Flange Screw Torque = 150 ft-lbs).
10.
5HPRYH WKH ´ 137 SOXJ DQG HQVXUH 6&669 LVRODWLRQ YDOYH LV RSHQ ,QVWDOO the
wellhead outlet fittings and pressure gauge and pressure test the SCSSV connection
and control line by applying a maximum test pressure of 5,000 psi to the SCSSV outlet.
11.
5HPRYHWKH¶¶137SOXJDQGHQVXUHFKHPLFDOLQMHFWLRQLVRODWLRQYDOYHLVRSHQInstall
the wellhead outlet fittings and pressure gauge and pressure test the chemical injection
connection and control line by applying a maximum test pressure of 5,000 psi to the
chemical injection outlet.
12.
Terminate CTS gauge line through wellhead.
Note: Record opening and closing pressures and return volume of SCSSV after
each pressure test and note on the SCSSV installation report and on the sequence
of events.
7.3 INSTALLATION OF BONNET & XMAS TREE:
13.
Ensure that the S-seals are in good condition. Replace any that are worn or damaged.
14.
Install the DA Carrier into the top of the tubing hanger and a ring joint gasket onto the
top of the wellhead body.
15.
Pick up the Xmas Tree and bonnet assembly using the lifting slings and suspend this
over the wellhead.
16.
Orientate the Xmas Tree and bonnet assembly to line up with the hanger electrical
penetrator.
17.
Slowly lower the Xmas Tree over the extended neck of the tubing hanger and land the
bonnet on top of the wellhead body. Release all weight and make up the 12 pt cap screw
connection between the bonnet and the wellhead body. Torque up the cap screw evenly
to 1,677 ft-OEVE\XVLQJWKH´$)3WKLJKWRUTXHK\GUDXOLFZUHQFKHV
18.
Pressure test the DA carrier float ring and S seals on the tubing hanger neck by applying
a maximum of 5,000 psi for 10 minutes to the upper test port in the bonnet body. Ensure
that the annulus test port on bonnet is vented.
19.
Pressure test the cavity between the ring joint gasket and the tubing hanger to bonnet
S seals and wellhead seals by applying a maximum test pressure of 5,000 psi for 10
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 31
minutes to the lower test port in the bonnet body. Ensure that the carrier test port is
vented.
20.
Pick up the xmas tree assembly using the lifting slings and suspend this over the
wellhead.
21.
Orient the xmas tree to line up as near as possible to flowline.
Note: Complete orientation may not be possible due to eccentric tubing hanger
and no alignment pin. Final modification of flowline may have to be done in the
field.
22.
Slowly lower the xmas tree onto the bonnet flange. M/U flange and pressure test xmas
tree to 5000 psi for ten minutes.
23.
R/U Aker Solutions lubricator and remove BPV from tubing hanger. Extreme caution is
required as thermal expansion of fluid in the tubing may have created pressure and
passed SCSSV up to under BPV.
24.
Remove the lock open cap on the UMV and R/D/ Aker Solutions lubricator.
25.
Secure wellhead by ensuring all test ports are closed, bleed offs closed on blinds and
annulus valves closed.
26.
Test top of hanger electrical penetrator for insulation and continuity.
27.
Connect surface power cable to hanger penetrator.
28.
Power can now be turned on at VFD to read downhole pressure and test pump rotation.
7.4 WELL DE-ISOLATION (Offline)
5HFRYHU´3;SOXJIURP´66'
1.
Connect up Hydraulic well control panel to Hydraulic Master Valve and open downhole
SCSSV.
2.
Confirm valves are operating correctly by function testing.
3.
Rig up X-RYHU´5LVHUSXPS-in tee, BOP, Quick test sub and Lubricator above
production tree. (See the schematic attached).
Note: Check the stuffing box, slickline tools to make sure they work correctly before rig
up
4.
Make up JDC to recover prong. Set zero at RKB.
5.
Stab lubricator and pressure test Slickline pressure control equipment to 2,000 psi for
10 minutes. Bleed off pressure to zero.
6.
Open Swab valve, LMV and run in hole.
Note: Count turn when opening/ closing swab valve and LMV to make sure they
are fully opened/closed
Note: Check and record pick up/ slack off weights every 500 m while running in
hole.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 32
7.
6WRSPDERYHWKH´66'GHSWK, refer to run tally, take pulling and hanging
weight of tool string.
8.
Slowly run to prong and latch, jar up to release prong. Monitor downhole (RMS, CTS)
pressure
9.
POOH.
10.
At surface close LMV and Swab valves. Bleed off any pressure.
11.
Make up GS to recover PX plug. Set zero at RKB.
12.
Stab lubricator and pressure test Slickline pressure control equipment to 2,000 psi for
10 minutes. Bleed off pressure to zero.
13.
Open Swab valve, LMV and run in hole.
Note: Count turn when opening/ closing swab valve and LMV to make sure they
are fully opened/closed
Note: Check and record pick up/ slack off weights every 500 m while running in
hole.
14.
6WRSPDERYHWKH´66'GHSWKUHIHUWRUXQWDOO\WDNHSXOOLQJDQGKDQJLQJ
weight of tool string. Monitor pressure to make sure it plug equalized before run to
latch.
15.
Slowly run to plug and latch, jar up to release plug.
16.
POOH.
17.
At surface close LMV and Swab valves. Bleed off any pressure.
18.
Rig down all the Slickline equipment; disconnect all hydraulic lines from the DHSV and
UMV.
19.
Record status of all valves on tree, wellhead and SCSSV on Well Handover Sheet and
hand well over to Production Operations.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 33
Section 8. WELL CONTROL CONTINGENCIES
NOTES:
1. All contingency operations must be discussed and approved by Drilling Superintendent prior to execution
(excepting emergencies).
2. If control lines are cut and run in below fluid level, contamination to control fluids and fluid egress into
gauge line will occur.
3. Ensure that ALL well control valves and cross over subs are made up and ready for deployment.
4. Carry out a well control kick drill prior to starting the operation. This will include handling well control
devices.
5. Function Hydril for correct operation.
6. All well control equipment should be available ready for rapid installation.
7. Continually monitor well behavior and establish loss/fill rate.
PREPARATION
Ensure that all the following items are made up ready to be used.
1. Well Control Cross Over & X-overs
x 6DIHW\9DOYH 7,: ò´,)%R[[3LQ
x 4-1/2" IF BOX X 3-1/2"IF PIN DOWN
x Crossover 4 ò´,)%R[[-´-)(%HDU3LQ
x Crossover 4 ò´,)%R[[-´-)(%HDU3LQ
x Crossover 4-1/2 IF JFE Bear Box x 4-1/2 Vam Top Pin
x Crossover 4-1/2 JFE Box x 3-1/2 JFE Pin
x Triple bushing 3-¶¶,)%R[[-¶¶9DP7RS3LQ[-¶¶+\GULOO3LQ
Ensure the threads/connections are inspected and are made up and thoroughly
functioned before running.
Have slung and ready to be picked up with air hoist for rapid deployment.
x
x
x
x
x
x
x
1 Joint of 4-´VAM TOP Tubing
1 joint of 3-1/2 9.2 # JFE Bear pin
Crossover 4-1/2 JFE Box x 3-1/2 JFE Pin
6DIHW\9DOYH 7,: ò´,)%R[[3LQ
4-1/2" IF BOX X 3-1/2"IF PIN DOWN
&URVVRYHUò´,)%R[[-´-)(%HDU3LQ
Crossover 4-1/2 IF JFE Bear Box x 4-1/2 Vam Top Pin
Ensure the threads/connections are inspected and are made up and thoroughly
functioned before running.
Should be made up and sitting in the V-Door. Have slung and ready to be picked
up with air hoist for rapid deployment.
2. Control Line/Cable Cutter
x Pair of heavy duty cable / control line cutter
If this task has to be carried out ensure that the cable is cut just above a clamp
3. Ensure BOP is set up with correct rams for completion procedure
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 34
EXECUTION
If
the well kicks, RIH set slips and quickly pick up Well Control Cross Over with air hoist
and make it up to tubing string making sure there are no control line protectors across the
Hydril.
Option # 1
1. Shut in the well by closing the TIW valve and by closing the Hydril.
2. Control or stabilize well.
Option # 2
1. If Hydril fails to hold adequate pressure around control lines or surface leaks become
unacceptable cut all control lines with Control Line Cutter.
x
If safe to do so and time permits make up blank caps to ends of control line for
protection.
2. Strip-in tubing string sufficient distance to enable cut off control line ends to clear
Hydril.
3. Control or stabilize well.
Option # 3
1. If Hydril fails to hold adequate pressure around tubing or surface leaks become
unacceptable.
2. Strip-in tubing string sufficient distance to enable cut off control line ends to clear pipe
rams.
x
If necessary to do so pick up drill pipe and crossover to enable this.
3. Close the pipe rams
4. Control or stabilize well.
Option # 4
1. If pipe rams fail to hold adequate pressure around tubing or surface leaks become
unacceptable
2. Strip-in tubing string sufficient distance to enable cut off control line ends to clear
alternative pipe rams and continue to gain control of the well.
3. Control or stabilize well.
Option # 5
1. If pipe rams fail to hold adequate pressure around tubing or surface leaks become
unacceptable the next option is to drop the completion string in the well.
x
Ensure all control lines are cut if not already.
2. Close Hydril. Ensure all pipe rams are open then slack off on traveling block to allow
the string to be supported by the Hydril.
x
If the Hydril is unable to support the weight of the completion string it will be
necessary to close pipe rams on the string then open the Hydril.
3. With the elevators slacked off, unlatch elevators and clear all personnel from the rig
floor.
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 35
4. Open Hydril or pipe rams and allow the completion string to drop into the well.
5. Close the blind rams.
6. Control or stabilize well.
LAST RESORT
As a last resort the blind shear rams would be functioned, in which case the tubing
and all the control lines will be severed and dropped in the hole. It would then be
necessary to strip in with a kill string ± kill the well ± fish the well.
Section 9. APPENDICS:
9.1 Su Tu Vang Slot Arrangement
Operation sequence for Workover campaign is : SV-07P, SV-04P and SV-06P
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 50
9.2 Current Well Schematic
COMPLETION
SV-4P
Depth & deviation
Min ID
Max OD
RTE
Wireline
Inch
MD
m
MD
m
Inch
Tbg Hgr
4-1/2" Tubing 12.6" PPF
3.903
30.7
0.0
Top flow pup
3.958
DHSV- WPE-5 3.813" X
Bottom flow pup
3.813" WX nipple
Top flow pup
3.813
6.925
201.0
170.3
5.012
1067.7
1055.7
1037.0
1025.0
1034.3
7.082
1140.2
1109.5
7.080
2018.7
7.080
Volum e
tvdSS
Dev
m
m
Degrees
bbl
bbl
30.7
-20.0
0.0
0.000
0.000
201.0
150.6
0.0
8.499
32.652
1045.7
995.3
17.6
51.745
198.794
1115.2
1064.7
15.0
55.364
212.698
1988.0
1872.7
1822.2
39.0
99.202
381.117
2672.0
700.7
2641.3
670.0
2367.4
2317.0
39.0
131.800
506.352
7.082
2990.8
2960.1
2615.2
2564.7
36.0
147.708
567.469
ITEM
tvd
Tubing
Ann
3.958
3.813
3.958
GLV1 w ith 1.5" R-2, port 3/16"
3.852
Bottom flow pup
3.958
Top flow pup
3.958
GLV2 w ith Nova valve 32/64
3.852
Bottom flow pup
3.958
Top flow pup
3.958
GLV3 w ith 1.5" R-2, Nova valve
3.852
Bottom flow pup
3.958
Top flow pup
3.958
GLV4 w ith 1.5" RO-2 port 7/16"
Bottom flow pup
3.852
3.958
4-1/2" Dow n hole gauges
3.958
5.856
2998.6
2967.9
2628.0
2577.5
36.0
148.098
568.966
3.688" WRN Nipple
3.463
5.010
3014.7
2984.0
2641.1
2590.6
36.2
148.900
572.049
Nogo locator
3.964
6.980
3017.6
2986.9
19.8
-30.7
36.2
149.048
572.616
9-5/8" Quantum packer 47-53.5 ppf
6.000
8.450
3019.0
2988.3
2644.6
2594.1
35.0
149.115
572.874
7" LBFV
3.958
5.020
3026.9
2996.2
2651.0
2600.6
36.0
149.510
574.391
3.313" Optim ax SSD (Open)
3.313
5.480
3064.8
3034.1
2681.2
2630.7
37.0
151.399
581.650
3280.0
3249.3
2843.2
2792.7
43.0
162.140
622.914
3734.0
3704.0
9-5/8" Casing shoe
F#2
4-1/2" Sw ell packer
3.910
7.760
3735.2
3704.5
3093.8
3043.4
70.0
184.855
710.178
3.313" Optim ax SSD (Open)
3.313
5.480
3771.4
3740.7
3106.5
3056.0
69.6
186.662
717.124
3. 313" WX Landing Nipple
3.313
5.003
3786.3
3755.6
3111.7
3061.2
69.6
187.404
719.975
F#3
4334.0
F#4
4768.0
F#5
4864.0
4-1/2" Sw ell packer
3.910
7.750
5082.0
5051.3
3539.5
3489.1
71.0
252.058
968.362
Liner shoe
6.20''
7.698
5088.0
5057.3
3541.5
3491.1
71.0
252.361
969.525
86.0
296.122 1137.647
F#6
5193.0
F#7
5344.0
F#8
5390.0
F#9
5540.0
TD
8.500
5965.0
Workover Procedure SV-4P
5934.3
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 37
9.3 STV-4P ESP WO Well Sketch (DRAFT)
(Note: Depth of equipment can be changed)
STV-7P_ESP Completion WO Schematic_2021
Prepared For
CLJOC
Prepared By
Hieu NV.
Revision / Date
13-Jul-2021
Rev 1
Type
-"
Production
Csg
Open Hole
-$
Type
-(
Item
Deviation (deg)
35
Approved By
Mongkol K.
RKB (m)
30.54
Deviation KOD
TBC
Final MD (m)
6412
Water Depth (m)
102.7
OD
(in)
Weight
(lbm/ft)
9-5/8
47.00
8-1/2
OD
(in)
4-1/2
3-1/2
Weight
(lbm/ft)
12.60
9.20
Assembly
Part Number / MAX
Grade
Material
L80
13Cr
L80
13Cr
Grade
Material
L80
L80
13Cr/4140
13Cr/4140
Serial Number
Comment/weight
-*
4-1/2 SW
103609329
--
A2
SCSSSV
8.681
8.525
8.500
Tubing Data
ID
(in)
3.958
2.992
Drift ID
(in)
3.833
2.867
Short Description
Tubing
Elevation (wellhead to RKB)
Tubing hanger (below Hang off point)
4.5 12.6# VAMTOP Pup joint
TUBING SWIVEL, LOCK, 4-1/2 12.6PPF
VAM TOP BOX x PIN
4.5 12.6# VAMTOP Pup joint
4.5 12.6# Vamtop Tubing
4.5 12.6# VAMTOP Pup joint
TRMAXX 5E, 4.5 #12.6 VAMTOP BxP
-+
A1
Density
TBC
Max Dogleg (deg/100ft)
3.2
BHP (psia)
TBC
Casing Data
ID
Drift ID
(in)
(in)
101882445
-,
GLM
-)
A4
GLM
-%
A5
-"#
XOVER
A6
103605806
103180440
ESP PACKER
A7
A8
SSD
A9
XN NIPPLE
-"$
101474021
-"(
103605809
-"*
A10
BOH + DPS
2004519
."
A11
ESP Pumps
A12
2-3/8" XOVER
A13
A14
DCIN
100134310
102901531
102901531
103110758
103208437
103208442
103211170
103456361
103307104
103605811
103609330
69
Muleshoe
B1
MLE
ESP cable
Discharge line
3/8" x 0.065" tube
1/4" x 0.049" tube
3524.00
3524.00
6412.00
2888.00
Comments
Length
(m)
Comments
ID
(in)
Length
(m)
Top Depth
(m)
Bottom
Depth
(m)
0.00
30.54
31.81
30.54
30.80
33.81
4.500
3.958
30.54
0.26
2.00
6.078
3.952
0.51
33.81
34.32
4.500
4.500
4.500
3.958
3.958
3.958
2.00
161.63
2.00
34.32
36.32
197.95
36.32
197.95
199.95
1.53
199.95
201.47
3.958
3.958
2.00
912.00
201.47
203.47
203.47
1115.47
4.5 12.6# VAMTOP BOX x JFE BEAR
PIN Crossover Pup
4.500
3.958
0.51
1115.47
1115.99
4.500
3.958
1.93
1115.99
1117.92
Gas Lift Mandrel #1, 4.5, #12.6 JFE BEAR
4.5 12.6# JFE BEAR BOX x PIN Pup joint
6.330
4.500
3.870
3.958
3.00
1.94
1117.92
1120.92
1120.92
1122.86
4.5 12.6# JFE BEAR BOX x VAMTOP
PIN Crossover Pup
4.500
3.958
0.74
1122.86
1123.60
4.5 12.6# Vamtop Tubing
4.500
3.958
921.50
1123.60
2045.10
4.500
3.958
0.52
2045.10
2045.61
4.500
7.093
4.500
3.958
3.930
3.958
1.93
3.01
1.93
2045.61
2047.55
2050.55
2047.55
2050.55
2052.48
4.500
3.958
0.74
2052.48
2053.22
4.500
4.955
3.500
3.500
3.500
3.958
2.973
2.992
2.992
2.992
2.938/2.07
5
2.992
2.959
1.93
0.38
1.40
2.00
1.40
2053.22
2055.15
2055.53
2056.93
2058.93
2055.15
2055.53
2056.93
2058.93
2060.33
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR Pup joint
SSD, 2.812X, 3.5 #9.2 JFE BEAR BxP
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR Tubing joint
3.5 9.2# JFE BEAR Pup joint
2.813 XN Type Landing Nipple, 3-1/2"9.2#
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR Pup joint
X-Over 3.5 9.2 JFE Bear Box x 4.5 12.75#
EUE Pin
HEAD: BOLT ON DISCHARGE PMP 675,
CS, 4 1/2 MMS 8RD EUE 12.75 LB/FT
DPS: REDA 675, 4140, 14 HOLES
PUMP: J12000N C-CT 35 STG 675/675 120
PUMP: J12000N C-CT 35 STG 675/675 120
INTAKE: BOI, 675/540 CS, 1.18 INC 718, MPROTECTOR: ADVANCED, MAXIMUS,
PROTECTOR: MAXIMUS, LSBPB, 540/540,
MOTOR: 562, 14, F140M, MAXIMUS, RAMOTOR: 562, 14, F140M, MAXIMUS, RA-LT,
BASE GAUGE: XT175 TYPE 1,
;2YHU(8(3LQ±
JFE BEAR Pin
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR Pup joint
DCIN-II, 3.5, 9.2# JFE BEAR BxP
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR Pup joint
Mule Shoe, 3.5 #9.2 JFE BEAR Box
Existing Lower Completion
! "#$%"&’()#* +
8.320
3.500
3.907
2060.33
2061.79
2061.79
2063.19
2063.19
2065.19
4.515
2.953
0.64
2065.19
2065.83
2.969
2.992
2.812
2.992
2.992
2.992
2.667
2.992
2.992
1.50
2.00
1.26
2.00
9.50
2.00
0.45
2.00
1.97
2065.83
2067.34
2069.34
2070.59
2072.59
2082.09
2084.09
2084.54
2086.54
2067.34
2069.34
2070.59
2072.59
2082.09
2084.09
2084.54
2086.54
2088.51
4.545
2.953
0.30
2088.51
2088.81
6.750
NA
0.24
2088.81
2089.05
6.750
6.750
6.750
6.750
5.370
5.370
5.620
5.620
4.500
3.75
NA
NA
NA
NA
NA
NA
NA
NA
0.23
5.36
5.36
0.37
2.90
2.71
10.27
9.78
0.58
2089.05
2089.28
2094.64
2100.00
2100.37
2103.26
2105.97
2116.24
2126.02
2089.28
2094.64
2100.00
2100.37
2103.26
2105.97
2116.24
2126.02
2126.60
3.958
1.996
0.30
2126.60
2126.90
3.500
3.500
5.165
3.500
3.500
3.500
2.992
2.992
2.923
2.992
2.992
2.992
2.05
2.05
0.45
2.05
2.05
0.28
2126.90
2128.95
2131.00
2131.44
2133.49
2135.54
2967.92
2128.95
2131.00
2131.44
2133.49
2135.54
2135.82
MLE: 562/738 TRIDENT P/I-450, GEN 4, 1/1 PEEKLTB, M5F, 200FT 1.678 x 0.622 inch
"#$%&#%%&
CABLE: REDALEAD 1, 5KV (1/1 ELB .020 G5F) 1.655 x .635 inch
’($#"#")
DISCHARGE PRESSURE TRANSFER LINE ASSY 160FT
"##"$#*#$
CL 3/8 .065 316L BARE W&D F0-00
"#"+$&%*#
"#"""+#",
CL 1/4 .049 316L BARE W&D F0-00
Workover Procedure SV-4P
1.46
1.40
2.00
3.937
3.500
5.000
3.500
3.500
3.500
4.040
3.500
3.500
, )- * #+)"#+
Operation Notes:
0.00
3524.00
Connectio Top MD Bottom MD
(m)
(m)
n
VAMTOP
JFE BEAR
OD
(in)
Length
(m)
3.812
TUBING SWIVEL, LOCK, 3-1/2 9.2PPF
JFE BEAR BOX X PIN
-""
Bottom MD
(m)
4.500
4.500
4.5 12.6# VAMTOP Pup joint
X-Over 4.5 #12.6 VAMTOP Box x 3.5 #9.2
3.5 9.2# VAM TOP Box x JFE BEAR Pin
3.5 9.2# JFE BEAR Pup joint
3.5 9.2# JFE BEAR BOX x VAM TOP PIN
9-5/8 X 3-1/2 X 2-3/8 BLUEPACK ESP (47AA: Penetrator 2- 53.5), 41XX (80), AFLAS (90-80-90), 3-1/2
3/8" EU Pin, 32' L, 3.5 9.2# VAM TOP Pin x JFE BEAR Pin
OD: 3.125"
3.5 9.2# JFE BEAR Pup joint
103609328
Vamtop
Top MD
(m)
6.923
4.5 12.6# VAMTOP BOX x JFE BEAR
PIN Crossover Pup
4.5 12.6# JFE BEAR BOX x PIN
Gas Lift Mandrel : MANDREL: GAS
4.5 12.6# JFE BEAR BOX x PIN
4.5 12.6# JFE BEAR BOX x VAMTOP
PIN Crossover Pup
-&
Connection
Mid Perfs TVD
TBC
Rig Name
HWU
Field
Su Tu Vang
4.5 12.6# VAMTOP Pup joint
4.5 12.6# Vamtop Tubing
4.5 12.6# JFE BEAR BOX x PIN Pup joint
A3
Zone MD
TBC
Completion Fluid
Gaslift, ESP
BHT (ºC)
165.000
, * . $/ ’0’(* #1$/
45.64
2060.33
37.80
2131.44
199.95
2%"$* 3$"%
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 38
9.4 Directional Survey
SV-4X Definitive Survey Report
! "#$%&’( ) &"*’’
1 83"4&*’’
=3"87*’’
+&%, : &, %"’/’+8$&*’’
B "88*’’
D$%"6$8"*’’
FB G/; HGI*’’
+, %- ". ’J ) 2 "’/’( ) &"*’’
@$%&’/’; K( ’/’( ( G’/’C! ( ’%)&3$*’’
E%37’1 $$%734) &"’+. L&"2 *’’
0$: ) &3$4’0) &/0$4?*’’
0$: ) &3$4’E%37’J /C’M/N*’’
E%37’1 $4- "%?"4: "’; 4?8"*’’
E%37’+: ) 8"’=) : &$%*’’
1 $2 2 "4&L
Tie-In
5 ") L, %"7
( "#&6
S’2 ’T
+, %- ". ’/’( 0+’1 $2 #, &) &3$4’5 "&6$7*’’
9 "%&3: ) 8’+": &3$4’; <32 , &6*’’
9 "%&3: ) 8’+": &3$4’> %3?34*’’
@9 ( ’! "A"%"4: "’( ) &, 2 *’’
@9 ( ’! "A"%"4: "’C8"- ) &3$4*’’
+") ’D"7’/’E%$, 47’0"- "8’C8"- ) &3$4*’’
5 ) ?4"&3: ’( ": 834) &3$4*’’
@$&) 8’=3"87’+&%"4?&6*’’
5 ) ?4"&3: ’( 3#*’’
( ": 834) &3$4’( ) &"*’’
5 ) ?4"&3: ’( ": 834) &3$4’5 $7"8*’’
J $%&6’! "A"%"4: "*’’
@$&) 8’1 $%%’5 ) ?’J $%&6’OP’E%37’J $%&6*’’
0$: ) 8’1 $$%734) &"L’! "A"%"4: "7’@$*’’
! " #$%&$’ () * +(, - - .
3 %%7: 1; (<= 3
A%(B%(C&1;
AC(B" 2 FG&5" (6(AG:5(H- I
) * K) KACKLM
ACKLM
ACKLM(N" O010504" (6(/ &$PQ(, ) +(, - - L
) . - ?- ) * @(6(>* I ) ?* . (2 (6(S?* - >(6(- ?RS,
T B/ (U: 1" (L. D(K(V WA. L+(/ " 5" $8
D() - (, , (LR?L, * +(E() - . (, ) (>I ?) * L
D() ) LRL) I ?) * ) (2 +(E(. S. - >. ?>- - (2
Z- ?S- S) * SR* @
) ?- - ) , I SLS
G4: 834) &3$4
; <32 , &6
S’7"?’T
S’7"?’T
@9 (
+, QO+") ’@9 (
9 "%&3: ) 8
+": &3$4
S’2 ’T
J+
CB
S’2 ’T
( 0+
D, 387’! ) &"
B ) 8R’! ) &"
S’2 ’T
S’2 ’T
0.00
85.00
126.30
154.20
182.00
0.00
0.00
0.34
0.42
0.26
0.00
0.00
73.52
58.80
42.66
0.00
85.00
126.30
154.20
182.00
-31.50
53.50
94.80
122.70
150.50
0.00
0.00
-0.12
-0.29
-0.46
0.00
0.00
0.03
0.11
0.21
0.00
0.00
0.12
0.28
0.41
0.00
0.00
0.25
0.14
0.20
0.00
0.00
0.25
0.09
-0.17
0.00
0.00
0.00
-15.83
-17.42
209.90
238.50
267.20
295.30
323.70
0.09
0.75
1.60
2.96
4.65
242.07
232.10
237.76
238.08
239.71
209.90
238.50
267.19
295.27
323.60
178.40
207.00
235.69
263.77
292.10
-0.50
-0.29
0.30
1.41
3.29
0.25
0.12
-0.21
-0.80
-1.77
0.44
0.27
-0.22
-1.16
-2.78
0.37
0.69
0.90
1.45
1.79
-0.18
0.69
0.89
1.45
1.79
-172.68
-10.46
5.92
0.34
1.72
352.20
380.70
409.20
437.60
466.00
6.63
8.28
9.71
10.61
12.14
238.21
238.02
234.97
235.40
236.02
351.97
380.22
408.37
436.33
464.17
320.47
348.72
376.87
404.83
432.67
6.08
9.76
14.21
19.22
24.82
-3.22
-5.17
-7.64
-10.50
-13.65
-5.18
-8.32
-12.03
-16.14
-20.77
2.09
1.74
1.59
0.95
1.62
2.08
1.74
1.51
0.95
1.62
-1.58
-0.20
-3.21
0.45
0.65
494.40
523.10
551.50
579.80
608.20
11.81
12.47
13.45
14.62
15.11
236.10
234.53
234.93
234.68
232.86
491.95
520.01
547.68
575.14
602.59
460.45
488.51
516.18
543.64
571.09
30.70
36.74
43.10
49.96
57.25
-16.94
-20.38
-24.06
-28.01
-32.32
-25.66
-30.62
-35.82
-41.43
-47.30
0.35
0.77
1.04
1.24
0.71
-0.35
0.69
1.04
1.24
0.52
0.08
-1.64
0.42
-0.27
-1.92
636.90
665.40
694.20
722.60
751.20
15.93
14.75
15.16
16.86
15.72
231.78
232.41
233.38
235.30
235.75
630.24
657.73
685.55
712.85
740.30
598.74
626.23
654.05
681.35
708.80
64.93
72.46
79.89
87.73
95.74
-37.01
-41.65
-46.13
-50.69
-55.23
-53.38
-59.33
-65.25
-71.62
-78.23
0.91
1.25
0.50
1.88
1.20
0.86
-1.24
0.43
1.80
-1.20
-1.13
0.66
1.01
2.03
0.47
779.60
808.10
836.90
865.10
893.60
15.02
14.84
14.32
14.41
15.18
236.25
235.03
234.49
234.57
235.21
767.68
795.22
823.09
850.41
877.97
736.18
763.72
791.59
818.91
846.47
103.26
110.60
117.85
124.84
132.12
-59.44
-63.59
-67.77
-71.83
-76.01
-84.47
-90.53
-96.46
-102.15
-108.11
0.75
0.38
0.56
0.10
0.83
-0.74
-0.19
-0.54
0.10
0.81
0.53
-1.28
-0.56
0.09
0.67
922.20
950.70
979.20
1007.60
1036.30
16.01
16.58
16.41
16.20
17.65
235.39
230.22
228.70
229.94
230.78
905.51
932.87
960.20
987.46
1014.91
874.01
901.37
928.70
955.96
983.41
139.81
147.79
155.86
163.82
172.16
-80.39
-85.22
-90.48
-95.68
-101.01
-114.43
-120.79
-126.94
-132.98
-139.42
0.87
1.64
0.49
0.43
1.54
0.87
0.60
-0.18
-0.22
1.52
0.19
-5.44
-1.60
1.31
0.88
1064.70
1093.40
1122.10
1150.50
17.59
16.40
15.25
15.29
229.87
227.21
230.66
230.92
1041.98
1069.43
1097.04
1124.44
1010.48
1037.93
1065.54
1092.94
180.74
189.09
196.89
204.36
-106.50
-112.04
-117.19
-121.92
-146.04
-152.33
-158.22
-164.01
0.30
1.49
1.55
0.08
-0.06
-1.24
-1.20
0.04
-0.96
-2.78
3.61
0.27
Workover Procedure SV-4P
S’2 ’T
/ 0102 %2 (3 %$4&5%$" (6(7%#01890
, >>?* * - @
D(- ?- - - (2 +(E(- ?- - - (2
J : 5&$’ (B&#G"
>) ?* (2 ($" G&504" (5: (/ A7
K* , ?* - - (2 ($" G&504" (5: (/ A7
K- ?) - . @
L) , L. ?RL, (1B
S?) I R@
! " #$%&$’ (, I +(, - - S
XWW/ (, - - I
W$0Y(D: $5Q
K- ?I ) L@
V " GG([ " &Y
S’7"?/UV’2 ’T S’7"?/UV’2 ’T S’7"?/UV’2 ’T
Well Workover Procedure
Cuu Long Joint Operating Company.
29.25
2605.08
SV-4P
Page 39
1178.80
15.40
231.81
1151.73
1120.23
211.85
-126.59
-169.86
0.28
0.12
0.94
1207.10
1235.70
1264.40
1293.30
1321.84
15.35
15.60
15.69
15.95
15.93
231.49
231.35
230.56
230.25
229.81
1179.01
1206.58
1234.21
1262.02
1289.46
1147.51
1175.08
1202.71
1230.52
1257.96
219.35
226.97
234.70
242.57
250.39
-131.25
-136.01
-140.88
-145.90
-150.94
-175.75
-181.71
-187.72
-193.80
-199.80
0.10
0.27
0.24
0.28
0.13
-0.05
0.26
0.09
0.27
-0.02
-0.34
-0.15
-0.83
-0.32
-0.46
1357.23
1385.93
1414.43
1442.98
1471.14
17.13
17.97
18.97
21.13
23.43
228.94
228.61
229.77
233.29
235.92
1323.39
1350.75
1377.78
1404.60
1430.66
1291.89
1319.25
1346.28
1373.10
1399.16
260.43
269.06
278.06
287.84
298.51
-157.50
-163.20
-169.10
-175.17
-181.35
-207.44
-213.95
-220.79
-228.46
-237.16
1.04
0.88
1.12
2.60
2.67
1.02
0.88
1.05
2.27
2.45
-0.74
-0.34
1.22
3.70
2.80
1500.06
1528.97
1557.75
1586.06
1614.66
26.01
28.09
30.98
33.52
36.54
236.60
237.02
235.59
234.70
233.99
1456.93
1482.67
1507.71
1531.65
1555.07
1425.43
1451.17
1476.21
1500.15
1523.57
310.59
323.71
337.88
352.98
369.39
-188.06
-195.25
-203.13
-211.77
-221.34
-247.22
-258.22
-270.02
-282.41
-295.75
2.69
2.17
3.10
2.74
3.20
2.68
2.16
3.01
2.69
3.17
0.71
0.44
-1.49
-0.94
-0.74
1642.93
1671.66
1700.02
1728.54
1757.08
38.75
40.10
39.93
40.01
39.83
232.92
232.57
232.55
232.26
231.99
1577.45
1599.64
1621.37
1643.22
1665.11
1545.95
1568.14
1589.87
1611.72
1633.61
386.66
404.90
423.13
441.45
459.76
-231.62
-242.67
-253.75
-264.93
-276.17
-309.62
-324.14
-338.62
-353.13
-367.59
2.45
1.43
0.18
0.21
0.26
2.35
1.41
-0.18
0.08
-0.19
-1.14
-0.37
-0.02
-0.31
-0.28
1785.05
1813.30
1841.26
1869.58
1897.96
39.61
39.44
39.51
39.33
38.93
231.56
231.69
231.62
231.48
231.78
1686.62
1708.42
1730.00
1751.88
1773.89
1655.12
1676.92
1698.50
1720.38
1742.39
477.63
495.59
513.36
531.33
549.23
-287.23
-298.39
-309.42
-320.60
-331.72
-381.63
-395.73
-409.67
-423.75
-437.79
0.38
0.20
0.09
0.21
0.47
-0.24
-0.18
0.08
-0.19
-0.42
-0.46
0.14
-0.08
-0.15
0.32
1926.78
1955.01
1983.58
2011.97
2040.62
38.13
38.38
38.66
39.35
39.52
231.93
233.03
233.59
234.81
235.98
1796.44
1818.60
1840.96
1863.02
1885.15
1764.94
1787.10
1809.46
1831.52
1853.65
567.18
584.65
602.45
620.31
638.50
-342.81
-353.46
-364.09
-374.54
-384.87
-451.91
-465.77
-480.04
-494.53
-509.51
0.84
0.77
0.47
1.09
0.80
-0.83
0.27
0.29
0.73
0.18
0.16
1.17
0.59
1.29
1.23
2069.43
2097.44
2125.60
2154.19
2182.33
39.38
39.53
39.76
40.16
40.40
235.95
236.20
236.35
235.98
235.55
1907.39
1929.02
1950.70
1972.62
1994.09
1875.89
1897.52
1919.20
1941.12
1962.59
656.79
674.57
692.52
710.86
729.04
-395.12
-405.05
-415.03
-425.25
-435.49
-524.68
-539.45
-554.40
-569.65
-584.69
0.15
0.23
0.27
0.49
0.39
-0.15
0.16
0.25
0.42
0.26
-0.03
0.27
0.16
-0.39
-0.46
2211.15
2268.46
2297.01
2354.93
2383.86
40.58
41.40
41.87
42.02
42.22
235.07
234.10
233.78
233.43
233.43
2016.00
2059.26
2080.60
2123.68
2145.14
1984.50
2027.76
2049.10
2092.18
2113.64
747.74
785.33
804.30
843.01
862.41
-446.14
-467.92
-479.09
-502.06
-513.62
-600.08
-630.71
-646.04
-677.21
-692.79
0.37
0.54
0.54
0.14
0.21
0.19
0.43
0.49
0.08
0.21
-0.50
-0.51
-0.34
-0.18
0.00
2412.56
2440.80
2498.06
2526.49
2583.63
42.23
42.16
41.88
41.47
39.65
233.10
233.36
232.59
231.91
230.39
2166.39
2187.31
2229.85
2251.09
2294.50
2134.89
2155.81
2198.35
2219.59
2263.00
881.70
900.67
939.00
957.89
995.01
-525.15
-536.51
-559.59
-571.16
-594.46
-708.25
-723.44
-754.04
-768.99
-797.93
0.23
0.20
0.31
0.64
1.09
0.01
-0.07
-0.15
-0.43
-0.96
-0.34
0.28
-0.40
-0.72
-0.80
2640.21
2668.37
2697.10
2725.75
2754.12
38.77
39.23
39.31
39.20
38.44
229.46
228.53
228.23
228.65
228.56
2338.34
2360.22
2382.47
2404.65
2426.75
2306.84
2328.72
2350.97
2373.15
2395.25
1030.71
1048.37
1066.48
1084.54
1102.26
-617.48
-629.11
-641.19
-653.21
-664.97
-825.30
-838.67
-852.26
-865.83
-879.17
0.56
0.79
0.22
0.30
0.81
-0.47
0.49
0.08
-0.12
-0.80
-0.49
-0.99
-0.31
0.44
-0.10
2782.46
2814.74
2838.80
2867.47
2896.01
38.36
37.64
36.56
35.51
35.04
228.11
228.68
229.80
229.64
229.40
2448.96
2474.40
2493.59
2516.77
2540.07
2417.46
2442.90
2462.09
2485.27
2508.57
1119.79
1139.58
1154.05
1170.88
1187.32
-676.68
-689.87
-699.35
-710.25
-720.95
-892.32
-907.18
-918.17
-931.04
-943.58
0.31
0.74
1.59
1.10
0.52
-0.08
-0.67
-1.35
-1.10
-0.49
-0.48
0.53
1.40
-0.17
-0.25
2924.85
2952.50
2981.75
34.68
34.17
34.92
229.29
229.16
229.98
2563.74
2586.55
2610.64
2532.24
2555.05
2579.14
1203.76
1219.35
1235.89
-731.69
-741.90
-752.66
-956.08
-967.92
-980.54
0.38
0.56
0.91
-0.37
-0.55
0.77
-0.11
-0.14
0.84
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 40
3010.40
3038.90
36.24
38.06
230.50
230.69
2633.94
2656.65
2602.44
2625.15
1252.54
1269.72
-763.32
-774.24
-993.36
-1006.66
1.42
1.92
1.38
1.92
0.54
0.20
3067.85
3095.55
3124.24
3152.62
3180.83
39.03
39.84
40.63
41.27
41.82
230.77
230.94
230.92
231.15
230.71
2679.30
2700.69
2722.59
2744.03
2765.14
2647.80
2669.19
2691.09
2712.53
2733.64
1287.74
1305.32
1323.83
1342.41
1361.10
-785.66
-796.77
-808.45
-820.14
-831.94
-1020.62
-1034.27
-1048.66
-1063.12
-1077.64
1.01
0.89
0.83
0.70
0.66
1.01
0.88
0.83
0.68
0.58
0.08
0.18
-0.02
0.24
-0.47
3209.26
3237.91
3285.03
3312.54
3341.87
42.42
42.89
44.78
46.12
47.65
230.29
231.05
231.65
231.82
232.59
2786.23
2807.30
2841.29
2860.58
2880.63
2754.73
2775.80
2809.79
2829.08
2849.13
1380.14
1399.53
1432.14
1451.73
1473.14
-844.06
-856.37
-876.75
-888.89
-902.01
-1092.36
-1107.37
-1132.86
-1148.25
-1165.17
0.70
0.73
1.23
1.47
1.67
0.63
0.49
1.20
1.46
1.56
-0.44
0.80
0.38
0.19
0.79
3369.91
3398.37
3427.08
3455.01
3484.37
49.81
50.51
52.49
54.62
55.16
233.48
233.38
233.85
234.02
235.00
2899.13
2917.36
2935.23
2951.82
2968.71
2867.63
2885.86
2903.73
2920.32
2937.21
1494.21
1516.06
1538.53
1560.99
1585.01
-914.68
-927.69
-941.02
-954.25
-968.19
-1182.01
-1199.56
-1217.65
-1235.81
-1255.37
2.42
0.74
2.10
2.29
0.99
2.31
0.74
2.07
2.29
0.55
0.95
-0.11
0.49
0.18
1.00
3513.79
3541.26
3570.15
3598.73
3627.41
57.53
58.99
60.55
62.32
64.45
235.84
236.04
235.07
234.16
234.80
2985.01
2999.46
3014.01
3027.67
3040.52
2953.51
2967.96
2982.51
2996.17
3009.02
1609.48
1632.82
1657.77
1682.86
1708.50
-982.09
-995.17
-1009.29
-1023.82
-1038.72
-1275.53
-1294.88
-1315.46
-1335.93
-1356.80
2.52
1.61
1.84
2.04
2.31
2.42
1.59
1.62
1.86
2.23
0.86
0.22
-1.01
-0.96
0.67
3655.85
3684.79
3713.17
3741.55
3762.10
66.58
68.88
69.91
69.29
69.59
234.71
235.35
235.78
234.31
232.90
3052.31
3063.27
3073.26
3083.15
3090.37
3020.81
3031.77
3041.76
3051.65
3058.87
1734.37
1761.14
1787.69
1814.28
1833.52
-1053.65
-1069.00
-1084.02
-1099.26
-1110.68
-1377.93
-1399.88
-1421.79
-1443.59
-1459.08
2.25
2.46
1.17
1.60
1.98
2.25
2.38
1.09
-0.66
0.44
-0.09
0.66
0.45
-1.55
-2.06
3800.86
3828.64
3856.68
3886.32
3914.82
70.13
70.02
69.80
69.58
69.50
234.14
233.45
235.44
235.29
236.35
3103.72
3113.18
3122.82
3133.10
3143.07
3072.22
3081.68
3091.32
3101.60
3111.57
1869.91
1896.03
1922.36
1950.14
1976.82
-1132.31
-1147.74
-1163.05
-1178.85
-1193.85
-1488.34
-1509.41
-1530.83
-1553.70
-1575.79
0.99
0.71
2.01
0.26
1.05
0.42
-0.12
-0.24
-0.22
-0.08
0.96
-0.75
2.13
-0.15
1.12
3943.21
3972.03
4000.47
4029.01
4057.65
69.15
69.08
69.91
70.13
70.20
234.91
233.99
234.85
234.08
232.14
3153.09
3163.36
3173.33
3183.08
3192.80
3121.59
3131.86
3141.83
3151.58
3161.30
2003.36
2030.29
2056.92
2083.74
2110.68
-1208.84
-1224.50
-1240.00
-1255.59
-1271.76
-1597.72
-1619.62
-1641.29
-1663.11
-1684.66
1.47
0.90
1.22
0.80
1.91
-0.37
-0.07
0.88
0.23
0.07
-1.52
-0.96
0.91
-0.81
-2.03
4085.93
4114.10
4142.93
4171.32
4191.69
70.32
70.75
71.15
71.90
72.35
232.19
233.84
232.69
232.91
233.84
3202.35
3211.74
3221.15
3230.14
3236.40
3170.85
3180.24
3189.65
3198.64
3204.90
2137.29
2163.85
2191.10
2218.02
2237.41
-1288.09
-1304.06
-1320.36
-1336.64
-1348.21
-1705.68
-1726.90
-1748.74
-1770.18
-1785.74
0.14
1.72
1.21
0.82
1.46
0.13
0.46
0.42
0.79
0.66
0.05
1.76
-1.20
0.23
1.37
4227.43
4259.96
4282.33
4312.02
4340.42
71.84
73.28
73.46
73.15
71.08
234.87
233.60
233.33
231.76
232.54
3247.38
3257.13
3263.54
3272.07
3280.79
3215.88
3225.63
3232.04
3240.57
3249.29
2271.41
2302.44
2323.88
2352.31
2379.33
-1368.03
-1386.17
-1398.93
-1416.22
-1432.80
-1813.38
-1838.56
-1855.78
-1878.36
-1899.70
0.93
1.74
0.42
1.55
2.32
-0.43
1.33
0.24
-0.31
-2.19
0.86
-1.17
-0.36
-1.59
0.82
4369.09
4399.14
4427.50
4455.80
4484.59
69.98
69.47
69.54
69.17
70.14
232.43
233.73
234.45
234.75
235.67
3290.34
3300.76
3310.69
3320.66
3330.67
3258.84
3269.26
3279.19
3289.16
3299.17
2406.35
2434.54
2461.10
2487.58
2514.56
-1449.26
-1466.20
-1481.78
-1497.12
-1512.52
-1921.14
-1943.67
-1965.19
-1986.77
-2008.94
1.16
1.32
0.72
0.49
1.35
-1.15
-0.51
0.07
-0.39
1.01
-0.12
1.30
0.76
0.32
0.96
4513.01
4541.45
4569.52
4599.57
4629.10
70.74
70.97
71.63
71.51
71.33
236.54
235.64
235.66
234.47
233.07
3340.19
3349.52
3358.52
3368.02
3377.43
3308.69
3318.02
3327.02
3336.52
3345.93
2541.32
2568.16
2594.73
2623.22
2651.21
-1527.45
-1542.44
-1557.44
-1573.77
-1590.31
-2031.17
-2053.47
-2075.42
-2098.79
-2121.37
1.07
0.93
0.71
1.13
1.36
0.63
0.24
0.71
-0.12
-0.18
0.92
-0.95
0.02
-1.19
-1.42
4679.17
4708.87
70.33
70.91
234.50
235.32
3393.87
3403.72
3362.37
3372.22
2698.51
2726.51
-1618.25
-1634.36
-2159.52
-2182.45
1.01
0.98
-0.60
0.59
0.86
0.83
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
Projection to TD
SV-4P
Page 41
4738.72
4768.33
4798.08
70.79
70.50
71.23
234.88
234.72
235.40
3413.52
3423.33
3433.08
3382.02
3391.83
3401.58
2754.70
2782.63
2810.73
-1650.49
-1666.60
-1682.69
-2205.57
-2228.40
-2251.44
0.43
0.33
0.98
-0.12
-0.29
0.74
-0.44
-0.16
0.69
4827.98
4856.75
4886.22
4916.07
4961.06
70.63
70.24
70.40
70.30
71.36
234.22
233.53
234.28
233.15
232.24
3442.85
3452.48
3462.41
3472.45
3487.22
3411.35
3420.98
3430.91
3440.95
3455.72
2838.98
2866.09
2893.84
2921.95
2964.44
-1698.98
-1714.96
-1731.31
-1747.94
-1773.70
-2274.54
-2296.43
-2318.86
-2341.52
-2375.32
1.27
0.79
0.74
1.07
0.91
-0.60
-0.41
0.16
-0.10
0.71
-1.18
-0.72
0.76
-1.14
-0.61
4991.47
5021.23
5050.37
5079.35
5106.91
71.55
71.11
71.01
70.67
70.86
232.52
231.77
231.76
231.64
231.91
3496.89
3506.42
3515.88
3525.39
3534.47
3465.39
3474.92
3484.38
3493.89
3502.97
2993.26
3021.45
3049.00
3076.36
3102.36
-1791.30
-1808.60
-1825.65
-1842.62
-1858.72
-2398.15
-2420.41
-2442.06
-2463.55
-2483.99
0.32
0.84
0.10
0.37
0.35
0.19
-0.44
-0.10
-0.35
0.21
0.28
-0.76
-0.01
-0.12
0.29
5136.61
5161.71
5181.40
5213.12
5244.58
71.22
70.53
69.98
69.48
69.30
233.15
233.23
233.00
232.85
233.54
3544.12
3552.34
3558.99
3569.98
3581.06
3512.62
3520.84
3527.49
3538.48
3549.56
3130.45
3154.16
3172.69
3202.45
3231.89
-1875.81
-1890.02
-1901.14
-1919.08
-1936.72
-2506.28
-2525.27
-2540.09
-2563.83
-2587.41
1.24
0.83
0.90
0.49
0.64
0.36
-0.82
-0.84
-0.47
-0.17
1.25
0.10
-0.35
-0.14
0.66
5272.31
5301.21
5331.61
5358.92
5388.74
68.95
68.47
68.26
68.19
68.30
234.69
234.10
234.49
235.29
236.68
3590.94
3601.43
3612.64
3622.77
3633.82
3559.44
3569.93
3581.14
3591.27
3602.32
3257.80
3284.73
3312.98
3338.34
3366.01
-1951.91
-1967.58
-1984.08
-1998.66
-2014.16
-2608.40
-2630.29
-2653.24
-2673.98
-2696.94
1.22
0.76
0.41
0.82
1.30
-0.38
-0.50
-0.21
-0.08
0.11
1.24
-0.61
0.38
0.88
1.40
5418.31
5449.72
5478.05
5507.16
5536.42
68.62
68.91
69.05
68.69
68.80
237.67
237.88
238.62
237.62
239.36
3644.68
3656.06
3666.22
3676.71
3687.32
3613.18
3624.56
3634.72
3645.21
3655.82
3393.45
3422.65
3449.01
3476.07
3503.24
-2029.06
-2044.68
-2058.59
-2072.93
-2087.18
-2720.05
-2744.82
-2767.31
-2790.37
-2813.61
0.99
0.33
0.75
1.03
1.67
0.32
0.28
0.15
-0.37
0.11
1.00
0.20
0.78
-1.03
1.78
5565.13
5581.92
5606.00
68.68
68.50
68.60
239.03
240.82
241.00
3697.73
3703.86
3712.67
3666.23
3672.36
3681.17
3529.87
3545.40
3567.63
-2100.89
-2108.72
-2119.62
-2836.59
-2850.12
-2869.71
0.34
3.00
0.24
-0.13
-0.32
0.12
-0.34
3.20
0.22
Survey Type: Definitive Survey
Survey Error Model: SLB ISCWSA version 24 *** 3-D 95.00% Confidence 2.7955 sigma
Surveying Prog:
MD From ( m )
MD To ( m ) EOU Freq Survey Tool Type
0.00
84.00 Act-Stns SLB_NSG+BATTERY-Depth Only
84.00
1321.84 Act-Stns SLB_NSG+BATTERY
1321.84
5606.00 Act-Stns SLB_MWD-STD
Workover Procedure SV-4P
Borehole -> Survey
SV-4X -> SV-4X Definitive
SV-4X -> SV-4X Definitive
SV-4X -> SV-4X Definitive
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.5 SPM Oil & Gas Tubing Hanger Information
Workover Procedure SV-4P
Page 50
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 43
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.6 Wellhead to Riser Adaptor (From CLJOC)
Workover Procedure SV-4P
Page 44
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.7 Tubing Connection Data
Workover Procedure SV-4P
Page 45
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.8 Completion Equipment Technical Information
Workover Procedure SV-4P
Page 46
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 47
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 48
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.9 Cable Decompression Instructions
Workover Procedure SV-4P
Page 49
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 50
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 54
Well Workover Procedure
Cuu Long Joint Operating Company.
9.10
SV-4P
Gas lift Design
Workover Procedure SV-4P
Page 54
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
9.11 Layout diagram and stack up schematic
Riser stack up:
Workover Procedure SV-4P
Page 54
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Elevation
Workover Procedure SV-4P
Page 54
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 50
Layout schematic
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 50
9.12 Slick line PCE R/U and Tool String Diagram
PCE R/U on HWU
PETROVIETNAM DRILLING AND WELL SERVICES CORPORATION
PETROLEUM WELL LOGGING COMPANY LIMITED
PCE DIAGRAM
10th Floor, Sailing Tower, 111A Pasteur Street, District 1, HCMC, S.R.Viet Nam
Tel: (84) (8) 39105860 - Fax: (84) (8) 39105859
Website: http://www.pvdrilling.com.vn
Customer:
Location:
CUU LONG - JOC
CPP
Operation: Work over
Well No.
STV-7P
Well Type:
Set - Retrieve 2.813 Standing valve_Set 3.813
plug/prong
Created by:
KIM QUY TRONG
(* #1$/
45$6
7". ’3"##* 3$)"#
8 * )1/ $’4916
<;=5$
/01
/01
+!(0*=!
,)!>56
>;=5$
+C(0*=!E426!C!,!"0&=!
*B$-8: ;!F7: 1<
$+!>56
+C(0*=!E426!C!,!"0&=!
*B$-8: ;!F7: 1<
(!2/
?;=5$
,!"0&=!*B$-8: ;!F7: 1<
&%!>56
’@G<2814A<!*=!*34
*D#,!2/
>=;=5$
,!"0&=!*B$-8: ;!F7: 1<
&%!>56
’@G<2814A<!*=!"#34
*D#,!2/
>=;=5$
,!"0&=!*B$-8: ;!F7: 1<
&%!>56
’@G<2814A<!*=!"#34
*D#,!2/
@
;=5$
,!"0&=!*B$-8: ;!F7: 1<
+*!>56
HI?!*=
*D#,!2/
@
;A5$
,!"0&=!*B$-8: ;!F7: 1<
++*!>56
.EJ!*=!(!K1:
*D#,!2/
>;A5$
,!"0&=!*B$-8: ;!F7: 1<
,&!>56
JL?!*=M!$=CL+#$!N ;8A
*D#,!2/
@
;B5$
,!"0&OO!P2/!Q!,!"0&OO!GAB!
"$#!>56
KR S!.177!T17T;!
*D#,!2/
A;=5$
+!"0$OO!P2/!Q!!,!"0&OO!F7: 1<!
GAB!
&#!>56
QCET;<!+!"0$OO!UVF!,C
"0&=C*B$W*C(0*=X!F7: 1<!
.AB!=!J2/Y!"#Z!N JY![$?
*D#,!2/
’1/]2/5!?4<2/5!C!+!"0$=!Z?C.;1<!.ABD
IA417!7;/54\!W34X
Date:
C<5$
""++!>56
Workover Procedure SV-4P
, * +3%
). $)"#
:;, ;
4)#6
’2342/5!672/5!809 !
: 164;<!<2/5
?4@332/5!.AB!+C(0*=
#D"#&C#D"$+=
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 54
PCE R/U on Wellhead
PETROVIETNAM DRILLING AND WELL SERVICES CORPORATION
PETROLEUM WELL LOGGING COMPANY LIMITED
10th Floor, Sailing Tower, 111A Pasteur Street, District 1, HCMC, S.R.Viet Nam
Tel: (84) (8) 39105860 - Fax: (84) (8) 39105859
Website: http://www.pvdrilling.com.vn
PCE DIAGRAM
Customer:
CUU LONG - JOC
Well No.
SV_7P
Location:
SU TU VANG
Well Type:
Production
Created by:
KIM QUI TRONG
Operation: Drift
(* #1$/
45$6
)D#34
Date:
:;, ;
4)#6
7". ’3"##* 3$)"#
8 * )1/ $’4916
, * +3%
). $)"#
/01
/01
’2342/5!
672/5!
809 !
: 164;<!
<2/5
+C(0*=!
E426!
C*-^R F
,)!
>56
?4@332/5!
.AB!
+C(0*=
#D"#&C#D"$+
"#D#34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
&%!
>56
’@G<2814A<!
*=!
"#34
*D#,!
2/
"#D#34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
&%!
>56
’@G<2814A<!
*=!
"#34
*D#,!
2/
"#D#34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
&%!
>56
’@G<2814A<!
*=!
"#34
*D#,!
2/
"#D#34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
&%!
>56
’@G<2814A<!
*=!
"#34
*D#,!
2/
"D&34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
+*!
>56
HI?!
*=
*D#,!
2/
(D)34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
,++!
>56
.EJ!
*=!
(!
K1:
*D#,!
2/
"D$34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
,&!
>56
JL?!
*=M!
$=CL+#$!
N ;8A
*D#,!
2/
"#D#34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
&%!
>56
’@G<2814A<!
*=!
"#34
*D#,!
2/
#D%34
,C"0&=C*B$W*C(0*=X!
F7: 1<!
"+!
>56
.7;;]!
E33!
?@G!
*=
*D#,!
2/
#D%34
"C"0&=!
C!
*B$W*C(0*=X!
F7: 1<
"+!
>56
QCET;<!
,!
"0$=!
!
C!
,"0&=!
.AB
"D+34
a_0-
&%!
>56
QCET;<!
&C(0&=!
,C
"0$=C*B$W*C(0*=X!
F7: 1<!
.AB!
b!
&C(0&=!
J2/Y!
"#Z!
N JY!
[$?
R -L_!
‘F^Z
: 12/];8>
L_IFK!
‘F^Z
I<;;!
81P
IA417!
7;/54\!
W34X
,)34
"*#&!
>56
Workover Procedure SV-4P
*D#,!
2/
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 54
Tool String for setting standing valve
PETROVIETNAM DRILLING AND WELL SERVICES CORPORATION
PETROLEUM WELL LOGGING COMPANY LIMITED
10th Floor, Sailing Tower, 111A Pasteur Street, District 1, HCMC, S.R.Viet Nam
SLICKLINE STRING DIAGRAM
Tel: (84) (8) 39105860 - Fax: (84) (8) 39105859
Website: http://www.pvdrilling.com.vn
Client
CLJOC
Well
SV-7P
Nominal Specific OD
OD (in)
(in)
Field
Job Reference
HWU
STV-CPP
Set 2.813" Standing
valve by 3.0"SB
(2.75"OD) pulling tool
Fishing
neck (in)
Assembly
Tool length Tool length
(ft)
(m)
Rig
Date
Tool String No.
Engineer / Specialist
1
Kim Quy Trong
Weight
(lbs)
Bottom
Connection
Description
1.875
1.875
1.750
1.42 ft
0.43 m
9.70
1 7/8 HDQRJ
1.875" OD Rope Socket (Pear Drop Type)
1.875
1.875
1.750
1.15 ft
0.35 m
8.82
1 7/8 HDQRJ
1.875" OD Swivel Joint
1.875
2.500
1.750
5.00 ft
1.52 m
42.99
1 7/8 HDQRJ
1.875" OD x 5' Long Wireline Roller Stem
1.875
2.500
1.750
3.00 ft
0.91 m
25.60
1 7/8 HDQRJ
1.875" OD x 3' Long Wireline Roller Stem
1.875
1.875
1.750
1.04 ft
0.32 m
8.38
1 7/8 HDQRJ
1.875" OD Knuckle Joint
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
1 7/8 HDQRJ
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
1.875
1.875
1.750
4.50 ft
1.37 m
35.71
1 1/16" - 10 UN
Box
1.875" OD Power Jar (400LBS)
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
1 1/16" - 10 UN
Pin
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
1.875
1.875
1.750
6.92 ft
2.11 m
33.73
1 7/8 HDQRJ
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
15/16" - 10 UN
Box
3.000
2.750
2.313
1.38 ft
0.42 m
18.00
2.813
2.813
2.313
1.50 ft
0.46 m
12.00
27.11 ft
8.26 m
208 lbs
Max OD : 2.813 ins
1.875" OD x 24" tubular Jar
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
15/16" - 10 UN Pin 3.0" SB pulling tool ( 2.75"OD)
Workover Procedure SV-4P
2.813"FB/RB Standing Valve
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Page 54
Tool String for pulling standing valve
PETROVIETNAM DRILLING AND WELL SERVICES CORPORATION
PETROLEUM WELL LOGGING COMPANY LIMITED
10th Floor, Sailing Tower, 111A Pasteur Street, District 1, HCMC, S.R.Viet Nam
SLICKLINE STRING DIAGRAM
Tel: (84) (8) 39105860 - Fax: (84) (8) 39105859
Website: http://www.pvdrilling.com.vn
Client
CLJOC
Well
SV-7P
Nominal Specific OD
OD (in)
(in)
Field
Job Reference
HWU
STV-CPP
retrieve 2.813 standing
valve by 3.0"SB pulling
tool
Fishing
neck (in)
Assembly
Tool length Tool length
(ft)
(m)
Rig
Date
Tool String No.
Engineer / Specialist
2
Kim Quy Trong
Weight
(lbs)
Bottom
Connection
Description
1.875
1.875
1.750
1.42 ft
0.43 m
9.70
1 7/8 HDQRJ
1.875" OD Rope Socket (Pear Drop Type)
1.875
1.875
1.750
1.15 ft
0.35 m
8.82
1 7/8 HDQRJ
1.875" OD Swivel Joint
1.875
2.500
1.750
5.00 ft
1.52 m
42.99
1 7/8 HDQRJ
1.875" OD x 5' Long Wireline Roller Stem
1.875
2.500
1.750
3.00 ft
0.91 m
25.60
1 7/8 HDQRJ
1.875" OD x 3' Long Wireline Roller Stem
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
1 7/8 HDQRJ
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
1.875
1.875
1.750
4.50 ft
1.37 m
35.71
1 1/16" - 10 UN
Box
1.875" OD Power Jar (400LBS)
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
1 1/16" - 10 UN
Pin
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
1.875
1.875
1.750
1.04 ft
0.32 m
8.38
1 7/8 HDQRJ
1.875" OD Knuckle Joint
1.875
1.875
1.750
6.92 ft
2.11 m
33.73
1 7/8 HDQRJ
1.875" OD x 24" tubular Jar
1.875
1.875
1.750
0.40 ft
0.12 m
4.41
15/16" - 10 UN
Box
3.000
2.750
2.313
1.38 ft
0.42 m
18.00
25.61 ft
7.80 m
196 lbs
Max OD : 2.80 ins
1.875" Crossover Adapter 1-7/8" HD QRJ Male
& 1 1/16" - 10 UN Box
15/16" - 10 UN Pin 3.0" SB pulling tool ( 2.75"OD)
Workover Procedure SV-4P
Well Workover Procedure
Cuu Long Joint Operating Company.
SV-4P
Workover Procedure SV-4P
Page 54