16 MEDT SPE-178228-MS Presentation
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Transcript of 16 MEDT SPE-178228-MS Presentation
SPE-178228-MS
Successful Use of Abrasive Tubing Punch
Technology for Highly Deviated Wells in Saudi
Arabia Syed Muhammed Danish and Faisal Zubair Khan, Halliburton
Introduction
SPE-178228-MS
presentation
Abstract
Workover operations
Candidate well
Planned execution
Challenges and
solutions
Conclusions
Slide 2
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Summary
Objective:
The operator wanted to identify, isolate, and eliminate downhole tubing casing annulus (TCA) communication by
changing the existing internally plastic coated (IPC) completion.
Candidate well and formation:
• Deep, horizontal, and highly deviated wellbore with openhole production section
• Low pressure, permeable carbonate reservoir having high gas oil ratio (GOR) and H2S percentage Challenge:
• Clean the wellbore of fallen down plastic coating.
• Kill the well without using any loss circulation material (LCM).
• Isolate and identify TCA communication with a mechanical barrier.
• Punch tubing by jetting abrasive sand blend by means of specifically designed carbide nozzles and
circulate kill fluid in the TCA before well recompletion. Execution:
• First run was performed to mill plastic bridges and circulate coating residue using coiled tubing (CT).
• Second run placed a mechanical barrier in the horizontal section to isolate/identify point of leakage.
• Third run was performed to punch tubing and circulate kill fluid through the TCA.
Slide 3
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Workover Operations
In an unrelenting pursuit to increase field productivity, a variety of
remedial workover rig activities are necessary, including:
• Wellbore cleanout.
• Repairing tubing, liner, and/or casing.
• Well recompletion
• Sidetracking.
• Plug-back.
To reduce CAPEX (capital expenditure), time associated with these
activities should be reduced by exploring new innovative
technologies that can:
• Cut unnecessary trips in and out of the wellbore.
• Reduce reliance on multiple intervention techniques.
Slide 4
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Candidate Well
• 6.5-in. Openhole horizontal oil bearing formation
• 12% H2S
• 8.5-in. Section was directionally drilled to 8,746 ft measured depth
(MD) with maximum inclination of 90.86°; 7-in. casing was run and
cemented.
• 13,005 ft MD/7,276 ft total vertical depth (TVD)
• The well was completed with 7-in. packer on 4.5-in. IPC tubing set in
the packer at 8,497 ft MD with 89° inclination angle.
• Before rig move, TCA exhibited 800-psi buildup in 10 minutes
Slide 5
Reservoir Depth* (ft TVD) BHP (psi) BHT
(°F) GOR EMW (PCF)
Reservoir A 7,122 to 7,248 3,100 230 905 61.6
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Tubular From (ft MD) To (ft MD) ID (in.)
9 5/8-in., 40.0 lb CSG ±0 5,277 8.835
7-in., 26 lb CSG ±0 8,746 6.276
4 1/2-in., 12.6 lb TBG ±0 ±8,654 3.958
Planned Execution
1
•Bleed TCA pressure to zero. Bullhead kill fluid (68 PCF NaCl brine) from surface with maximum injection pressure of 1,500 psi. If TCA pressure builds up, communication is confirmed.
-
•If no losses are observed, circulate the kill fluid through the tubing and TCA. Pump marker die to confirm the leakage point depth in the tubing.
-
•If the wellbore is not supporting the column of the kill fluid, isolate the reservoir by setting mechanical plug in the lower most horizontal section of the tubing.
2 •Run in hole (RIH) with slick line and retrieve the sub surface safety valve (SSSV) at 290 ft.
3
•RIH CT with a downhole cleanout tool assembly, mill/circulate the debris from the IPC tubing beyond the plug setting depth to 8,724 ft.
4
•RIH CT with a 3.625-in. gauge cutter and memory casing collar locator (CCL) to drift the wellbore and perform depth correlation to 8,654 ft.
Slide 6
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Planned Execution
5 •RIH CT with a 4 1/2-in. medium expansion (ME) plug and set it at 8,430 ft.
6
•RIH CT with an abrasive jet tool and perforate two 1-in. holes in 4 1/2-in. tubing using sand laden fluid at 8,402 and 8,406 ft respectively, with inclination of 90° at this depth.
7
•First circulate the tubing and then the TCA with kill fluid in an overbalanced state through CT, observe the well for any pressure build up at surface.
8 •RIH with slickline to set a two-way check valve in the SSSV and a back pressure valve (BPV) in the tubing hanger.
9 •Proceed with wellhead tree nipple down (N/D) and rig BOP nipple up (N/U).
10 •Retrieve the BPV, two way check valves with slickline and ME plug with CT, continue with the well de-completion.
Slide 7
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Challenges and Solutions
Wellbore isolation challenges
Formation was not supporting kill fluid column, LCM pill was not an option
because of 4,259 ft open hole
Setting a mechanical plug was not possible because of residual plastic
and metal debris.
Precise depth correlation for accurate plug/barrier setting and abrasive
tubing punch was necessary.
ME plug failed to set in the horizontal section of the wellbore.
Radial cutting torch (RCT) had limitations in terms of reliability and
number of shots per run.
Solutions designed/executed
Isolate the reservoir by setting a ME retrievable bridge plug by means of CT at
90° deviation.
Cleanout the tubing before well killing operation by means of 3.625-in. junk mill
and 2.875-in. hydraulic motor.
Memory CCL was run in the cleanout run to accurately measure the downhole CT
stretch observed.
Slickline mono lock plug equipped with a time activated downhole power unit (DPU)
was run and set by means of CT.
3.06-in. Abrasive jet tool with two carbide jets at 180° phase was run.
Slide 8
Client : Well No : Well Type :
Client Rep : Platform/Rig : Temp :
Contact : Field : Rev :
Location : Prepared By : Date :
OD ID Length
(in) (in) (ft)
2.875 0.9 0.4
2.875 0.563 2.75
3.5 1 1.25
2.875 13.9
3.75 1.25
Total BHA Length: 19.55
SERIAL
NUMBER
1
QATIF Muhamad Kartiman Muda 03/08/14
Operation : Clean out BHA#1 Run#2
ARAMCO QTIF 293
PA 785
QATIF
2" CT Connector 2-3/8" PAC Box
BHA Description Connection
Motorhead Assembly (MHA) 2-3/8" PAC Box x Pin
Double Flapper check valve
3/4" Ball size
Burst Disc (5000psi)
Disconnect Sub (4 x 1000psi)
7/8" Ball disconnect
Circulating Sub (3 x 1400psi)
Fluted Centralizer 2-3/8" PAC Box x Pin
E-CTD Motor 2-3/8" PAC Box x Pin
Dressed with m/jet nozzle 0.2"
MacJet Mill 2-3/8" PAC Pin
Please note that all OD's & ID's are approximate, and are given as guidance only.
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Conclusions
Complex wellbore challenges were solved with many firsts in terms of technology and innovation.
The operation took more than the planned number of runs, but still saved 40 rig operating hours.
Slide 9
First time slickline lock mandrel was run and retrieved by means of CT in this field
First time mono lock plug was set by means of DPU and retrieved on CT in KSA
First time abrasive tubing punch assembly was used during a workover rig operation in KSA
SPE-178228-MS . Successful Use of Abrasive Tubing Punch Technology for Highly Deviated Wells in Saudi Arabia . Syed Danish
Acknowledgements / Thank You / Questions
The author and coauthor thank Halliburton and Saudi Aramco
management for support during the execution of this operation.
Slide 10