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

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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.

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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.

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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.

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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.

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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.

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