COILED TUBING DRILLING FOR OFFSHORE WELLS

MUHAMMAD SHAHIMI BIN YA’ACOB

A project report submitted in fulfilment o f the

requirements for the award of the degree o f Master

of. Petroleum Engineering Programme

Faculty o f Chemical and Energy Engineering

Universiti Teknologi Malaysia

JUNE 2018

"My wife, fam ily members andfriends ”

Thank you for your support. This is for all o f you

ACKNOWLEDGMENT

I would like to express my sincere thanks and appreciation to my supervisor,

Associate Professor Issham bin Ismail for his guidance in completing this project since

Mid-year 2017. His ideas, suggestions, and accessible to any discussion has made it

easier for me to complete this project.

My sincere thanks to Mr. Azahar Junin, Staff Well Engineer PETRONAS, Mr.

Zaidan bin Khalid, Custodion Completion Engineer, PETRONAS Carigali, and Mr.

Zahidi Ibrahim, Drilling and Completion Superitendent for their inputs, guidance and

valuable ideas during discussion and providing feedbacks. I am also indebted to Mr.

John Jenie, Advisor o f Coiled Tubing Section Schlumberger Office Jakarta for sharing

his experinces with me.

Not to forget, thanks to all lecturers, my friends and staff o f SPS for their

assistance and guidance in completing this documentation.

Last but not least, to all my family members, especially my wife and children

on their support for me to complete this project, this achievement is for you.

V

ABSTRACT

Coiled Tubing Drilling (CTD) is becoming more popular in the oil and gas

industry as an alternative drilling technique to rejuvenate depleting fields. Its cheaper

drilling cost makes CTD viable to be applied for idle wells and brownfields. The in­

depth investigation is carried out to identify the process and workflow o f selection

criteria for suitable wells to be drilled using CTD application. CTD is one of the

enabling technologies in well intervention technique which can offer industry another

option especially in the re-development o f brownfields. It has unique capabilities in

underbalanced drilling which can prevent formation damage and reduce drilling risks.

This technique can be used to replace the traditional sidetracking techniques, i.e.,

rotary rigs to sidetrack wells as it reduces the time taken to make-up and break-out the

joint pipe and also requires a smaller footprint for coil tubing unit which provides an

additional advantage to work on smaller structures. A case study has been detailed out

in this research work to show the importance and applicability o f CTD. Overall, this

technology costs lower than the conventional drilling or hydraulic workover unit

which makes it more attractive to access bypassed oil or untapped reservoirs hence

prolong a field's economic life.

ABSTRAK

Penggerudian tetiub gegelung (CTD) menjadi semakin popular dalam industri

minyak dan gas sebagai satu pilihan teknik penggerudian untuk memberikan nafas

baharu kepada medan susut. Penggerudian jenis ini adalah murah lalu menjadikannya

sebagai suatu teknik boleh jaya yang sesuai untuk digunakan terhadap telaga terbiar

dan medan matang. Projek ini adalah untuk mengenal pasti proses dan aliran keija

untuk memilih calon telaga yang sesuai untuk digerudi menggunakan CTD.

Penggerudian tetiub gegelung memberi pilihan kepada industri untuk membangunkan

semula medan matang. Penggerudian jenis ini mempunyai kemampuan yang unik

dalam penggerudian bawah imbang yang boleh mencegah kerosakan formasi dan

mengurangkan risiko penggerudian. Teknik ini boleh diguna untuk menggantikan

teknik pelencong telaga lazim, misalnya rig berputar yang diguna bagi menggerudi

telaga secara melencong, kerana teknik terbabit mampu mengurangkan masa mengikat

dan menanggalkan sambungan paip. Selain itu, CTD juga memerlukan kawasan keija

yang lebih kecil untuk ditempatkan unit tetiub gegelung dengan keadaan itu

memberikan kepadanya kelebihan untuk beroperasi pada rig atau pelantar yang kecil.

Suatu kajian kes telah diketengah bagi menunjukkan tentang kepentingan dan

pengaplikasian CTD. Secara keseluruhan, teknik ini melibatkan kos yang rendah

berbanding penggerudian lazim atau unit keija semula hidraulik, lalu menjadikannya

lebih menarik untuk menggerudi laluan ke dalam reservoir yang terlepas pandang

sebelum ini atau reservoir baharu bagi memanjangkan hayat ekonomik medan.

TABLE OF CONTENT

CHAPTER TITLE PAGE

ACKNOWLEDGMENT iv

ABSTRACT v

ABSTRAK vi

TABLE OF CONTENT vii

LIST OF TABLES xi

LIST OF FIGURES xii

LIST OF ABBREVIATIONS xv

LIST OF APPENDICES xvi

1 INTRODUCTION 1

1

LITERATURE REVIEW 8

2.1 Overview o f Drilling Operation 8

2.2 Horizontal Holes Drilling 9

2.2.1 Horizontal Wells with Smart Completion 11

1.1 Background

1.2 Problem Statement

1.3 Objectives

1.4 Hypotheses

1.5 Scope

1.6 Significance o f Study

1.7 Chapter Summary

2.2.2 Application o f Horizontal hole to Optimize

Field Development 13

2.3 Multilateral Holes Drilling 15

2.4 Sidetracking 17

2.5 Underbalance Drilling 21

viii

2.6 The Use o f Coilde Tuing in Drilling Operations,

Matured Wells 22

2.7 Future o f CTD 24

2.8 Advantages and Disadvantages o f CTD 27

2.9 Surface and Downhole CTD Equipment 28

2.9.1 Surface Equipment 28

2.9.2 Coiled Tubing Equipments 28

2.9.2.1 Coiled Tubing string 29

2.9.22 Injector head 30

2.9.2.3 Reel 30

2.9.2.4 Power pack 32

2.9.2.5 Crane 32

2.9.2.6 Pipe Handling 33

2.10 Downhole Equipment 34

2.10.1 Drilling BHA 34

2.10.1.1 Drilling Head 35

2.10.1.2 Drill Collars

2.10.1.3 Special Downhole Application

35

Tools 36

2.11 CTD Selection Criteria 37

2.11.1 Economy 39

2.11.2 Idles 40

2.11.3 Formation 40

2.11.4 Cost CAPEX and OPEX 40

2.11.5 Trajectory 41

2.11.6 Platform/Space 41

2.11.7 Expertise 41

2.12 CTD Technlogy Under Development 41

2.13 Chapter Sumary 42

3 METODOLOGY 43

3.1 Flow Execution o f the Project 43

3.2 Data Gathering 47

3.2.1 Remaining Recoverable 49

3.2.2 Review o f Reservoir Data 49

3.2.3 Review on Geological Data 50

3.2.4 Review o f Well Test Data 50

3.2.5 Borehole Stability 50

3.2.6 Drilling Data. 51

3.2.7 Well Completion Data and Well History 52

3.2.8 Project Economics 52

3.3 Feasibility Study 56

3.4 Software Analysis 57

3.5 Software Input Data 57

3.5.1 Input Data for Well Data Panel 58

3.5.2 Bottom Hole Assembly (BHA) Input Data 61

3.5.3 Tubing Force Module Input Data Panel 65

3.5.4 Design Aids Module Input Data Panel 68

3.5.5 CoilLIMIT Input Data Panel 69

3.5.6 Wellsite Geometry Input Data Panel 70

3.5.7 Coil Deformation Input data Panel 71

3.5.8 Wellbore Simulator Module Data Panel 72

3.6 Software A nalysis: Output Data 73

3.6.1 Design Aids Module 78

3.6.2 Tubing Forces Module 78

3.6.3 Wellbore Simulator Module 79

3.6.4 CoilLIFE Module 79

3.6.5 Solid Transport and Removal Module 79

3.7 Project Planning and Data Gathering 80

3.8 Summary 83

4.1 Candidates Screening Output 84

4.1.1 Analysis and Results on EUR Screening 85

X

4.1.2 Analysis and Results on Drilling Feasibility

Assesment 86

4.1.3 Discussion and Analysis Results From

Software Output 88

4.1.4 Analyis and Results on Site Visit 96

4.1.5 Candidate Screening Well Data 97

4.2 Completion Diagram Case Study 100

4.3 Cost Comparisons between CTD and Conventional

Workover Wells 101

4.4 Consideration Added in Selection Criteria Process 106

4.5 Summary 107

5.1 Conclusions 108

5.2 Recommendations 109

REFRENCES 111

APPENDIX A Borang permohonan atas talian 127

APPENDIXES B 128 - 151

LIST OF TABLES

TABLE NO. TITLE PAGE

Table 2.1 Summary o f CTD Application 25

Table 2.2 Comparison conventional drilling vs. CTD 27

Table 2.3 Comparison basic criterias between conventional and CTD 38

Table 3.1 Data to be considered for case with FDP and without FDP 48

Table 3.2 CTD well cost breakdown 54

Table 4.1 Candidates screening results by EUR 85

Table 4.2 Candidates screening srilling feasibility assessment 86

Table 4.3 Results from Site visit to barge/platform and equipments 96

Table 4.4 Well survey 98

Table 4.5 Well cost comparison between CTD and conventional drilling 102

Table 4.6 Cost optimisation 103

Table 4.7 Detail o f cost breakdown for conventional/infill drilli 104

LIST OF FIGURES

FIGURE NO. TITLE PAGE

Figure 1.1 Worldwide coiled tubing unit count from 1999-2018 (ICoTA, 2017) 3

Figure 2.1 Completion design for VLA-1035 11

Figure 2.2 EUR per well reduced in field development phases 12

Figure 2.3 Net EUR value per well reduced in progressive field development phases

Figure 2.4 CTD horizontal application, (Taggart et a l., 2006) 14

Figure 2.5 Soviet multibranch well 15

Figure 2.6 Coiled tubing drilling stages 18

Figure 2.7 Example o f side-tracking 19

Figure 2.8 Sidetracking and extended eeach CTD, (Ross et al., 2015) 20

Figure 2.9 Equipment layout for UBD operation 22

Figure 2.10 Well X final completion 24

Figure 2.11 U.S Coiled tubing market revenue 2014-2022 (Market research report,

2017) 26

Figure 2.12 Typical example of CT reel 31

Figure 2.13 Typical power pack unit crane 32

Figure 2.14 Bottam Hole Assembly (BHA) 34

Figure 3.1 Simplified candidate screening 44

Figure 3.2 Candidates selection criteria and process 44

Figure 3.3 Screening funnel o f CTD wells 45

Figure 3.4 Flowchart process o f screening technical & economical feasibility of

coiled tubing drilling, (Gary and Doremus, 1995). 46

Figure 3.5 Data gathering 48

Figure 3.6 Analysis on drilling historical data 52

Figure 3.7 Well cost elements 53

Figure 3.8 Data required for economics evaluation 55

Figure 3.9 Well data panel 58

Figure 3.10 Input data for well data panel 58

Figure 3.11 Parameter required for well data Panel 59

Figure 3.12 Well completion input data 60

Figure 3.13 Tubular input data 60

Figure 3.14 Process flow for well data panel 61

Figure 3.15 Coiled tubing and BHA input data 62

Figure 3.16 Coiled tubing and BHA components 63

Figure 3.17 Treatment fluid input data 64

Figure 3.18 Tubing force module, tubing force input data 65

Figure 3.19 Tubing forde module, friction coefficient input data 66

Figure 3.20 Tubing force module module summary 67

Figure 3.21 Design aids module, liquid circulation design 68

Figure 3.22 Design aids module, flow velocity design 68

Figure 3.23 CoilLlMIT input data 69

Figure 3.24 Wellsite geometry input data 70

Figure 3.25 CoilDeformation input data 71

Figure 3.26 Wellbore simulator module input data 72

Figure 3.27 CoilCADE software modules 73

Figure 3.28 Coiled tubing weight indicator load 75

Figure 3.29 Coiled tubing compressive load 75

Figure 3.30 Stress distribution as % o f yield 76

Figure 3.31 Maximum available pull 76

Figure 3.32 Maximum available weight on bit 77

Figure 3.33 CoilCADE - liquid circulation, circulation pressure vs rate for various

liquids 77

Figure 3.34 CoilCADE liquid circulation, downhole pressure vs. liquid rate for

various liquids 78

Figure 3.35 Project planning aspects 81

Figure 3.36 Well data 82

Figure 4.1 Coiled tubing weight indicator load 89

Figure 4.2 Compressive load 90

xiv

91

92

93

94

95

97

99

100

101

106

Stress distribution as % o f yield

Maximum available pull when pull out o f hole

Maximum available weight on bit (WOB)

Design aids, downhole pressure vs. liquid rate for various liquids

Design aids, liquid circulation vs. liquid rate for various liquid

CTD equipment layout schematic

Well trajectory

Completion diagram case study

CTD cost breakdown categories

Candidate selection criteria CTD offshore projects

X V

LIST OF ABBREVIATIONS

UTM - Universiti Teknologi Malaysia

BBL - Barrel

BHP - Bottom Hole Pressure

BPD - Barrel Per Day

CTD - Coiled Tubing Drilling

DLS - Dog Leg Severity

GLM - Gas Lift Mandrel

OH - Open Hole

OBD - Overbalanced Drilling

m-MD - Meter-Measured Depth

NPT - Non Productive Time

SSD - Sliding Sleeve Door

SSSV - SubSurface Safety Valve

UBD - Under Balanced Drilling

WOB - Weight On Bit

xvi

LIST OF APPENDICES

APPENDIX TITLE PAGE

Appendix 1 Project gant chart 2017/2018 128

Appendix 2 CTD Pump 129

Appendix 3 CoilCADE coiled tubing design and evaluation software 130

Appendix 4 CoilCADE coiled tubing design and evaluation software 131

Appendix 5 Modular offshore CT unit 132

Appendix 6 Modular offshore CT unit general specifications 133

Appendix 7 Modular offshore CT unit general specifications 134

Appendix 8 Modular offshore CT unit general specifications 135

Appendix 9 Cement mixer 136

Appendix 10 BHA technical data sheet for 2 3/8” modular 137

Appendix 1 1 2 3/8'" Tool specifications 138

Appendix 12 JMC technology drop in drump-CT reel 139

Appendix 13 : Pressure & Fluid Management System (PFMS) 1 o f 2 140

Appendix 14 Pressure & Fluid Management System (PFMS) 2 o f 2 141

Appendix 15 CTD tower injector head and beams (Total Weight 75) 142

Appendix 16 Bit selection 143

Appendix 17 Milling and drilling bit 144

Appendix 18 Coil tubing mechanical set whipstock for monobore applications 145

Appendix 19 Data weight indicator load 146

Appendix 20 Compression load data 147

Appendix 21 Data stress distribution as % o f yiled 148

Appendix 22 Data maximum available pull 149

Appendix 23 Data maximum available WOB 150

Appendix 24 Data liquid circulation downhole pressure vs liquid rate for various

liquids 151

Appendix 25 Data liquid circulation, circulation pressure vs liquid rate for various

liquid 151

CHAPTER 1

INTRODUCTION

1.1 Background

Drilling operation is an important phase in the upstream o f oil and gas industry.

It involves in drilling a conductor, surface, intermediate, and production holes; which

should penetrate the reservoir until its total depth is about 75 ft below the bottom of

the reservoir. All the casing strings should be cemented prior to drilling the next hole

(Dupius, 2007; Brunherotto et al., 2017; Holden et al., 2017).

Due to lower current global oil prices, oil companies are looking at many

aspects to lower their capital and operating expenditures especially in drilling

operations. Apart from reducing the non-productive time in drilling operations,

another possibility that they can look into is the usage o f coil tubing drilling (Ahmed

et al., 2012; Kruger et al., 2013; Leising and Newman, 1993).

Coiled Tubing Drilling (CTD) is very important in drilling operations as it can

drill a hole with cheaper cost compared to conventional way without compromising

the quality o f the well and safety (Kumar et al., 2011). The technology has been applied

and proven for more than 30 years. It should be re-visited because it can give an

alternative method o f drilling to oil operators to reconsider the by-passed oil in mature

fields. As highlighted earlier, the current downturn in oil price has forced the industry

to find a cheaper alternative compared to conventional way o f using drill pipe. CTD

can drill faster and save drilling time by almost 60% than conventional drilling

2

(Littleton et al., 2010), thus provides a significant impact in getting the revenue and

improve the economic (Liu et al., 2017; Lheure et a.l, 2000; McCarty et al., 2001; Me

Carty et al., 2002).

The current technology enables oil operators to drill slim holes (Ibrahim et al.,

2013) and extended reach horizontal holes (Alimuddin et al., 2012; Burke et al., 2014;

Li et al., 2017) in an underbalanced condition (Tinkham et al., 2000; Khamess et al.,

2013a, Khamess et al., 2013b) using coiled tubing successfully. Advancement in CTD

operation was realized with the successful drilling and completion o f world’s first

multilateral well (Ooi et al., 2016) in Malaysia. But to achieve a high successful rate

in CTD operations, a proper planning on candidate selection criteria is very crucial

(Gary et al., 1995; Ross et al., 2015; Vonthetoff et al., 2009). In fact, CTD has a bright

future especially in lower global oil price environment (Crabtree, 2017).

In field development plan (FDP) and development phases, due to deadline to

achieve the first oil and economic factors, oil operators may optimize the development

plan via bypassing some o f pay zones (Rahman et al., 2012). Once the field matured,

accessing the by-passed oil behind the casing which is normally in a thin reservoir with

low permeability can be economically attractive but is very challenging especially if

it is located offshore compared to onshore environments (Ooi et al., 2016).

As a background drilling using coiled tubing concept started in late 1940’s an

operation used a continuous string and downhole motor for drilling. In 1960’s the

prototypes were developed and commercially introduced in m id-1970s. However, the

modem CTD era started in 1991 with a horizontal sidetrack re-entry drilled by Oryx

Energy in the Austin Chalk o f Texas (Leising and Rike, 1994). Coiled Tubing Drilling

application has been successfully implemented in Canada (Madarapu et al., 2007).

United States o f America, Russia, North Africa, Middle East (Surewaard et al., 1997;

Khamess et al., 2013a; Khamess et al., 2013b), and South-East Asia (Rahman et al.,

2012; Al-Humood and Al-Khamees, 2017). The overwhelming application o f CTD in

North America which focused on ‘shale play’ has spurred many innovative

developments in well design and completion techniques (Misselbrook, 2011; Ortega

et al., 2010). CTD can be described as drilling using seamless tube coil on a reel. The

use of coiled tubing keeps increasing as shown in Figure 1.1 (ICoTA, 2017).

Various geological formations have been successfully drilled with CTD

systems (Peng et al., 201 7). Active area drilling and re-enter the wells with technology

are Canada and United States o f America. Malaysia via Petronas initiated the CTD

study back in 2005 with the pilot projects were carried out in 2011. List o f some CTD

operations are outlined in Chapter 2. The evolution (Kazlov et al., 2010) of CTD

technology is one o f exciting sections in drilling and has become a competitive

advanced drilling method in oil industry (Crouse et al., 2000; Liu et al., 2017). This

new technology has the potential to be applied widely in Malaysia as it is experiencing

an increase in number o f matured fields and idle wells (Hamzah, 2012; McCarty et al.,

2002; Bumbaugh. 2011).

»___ Worldwide Coiled Tubing Unit Count1999 - 2016

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• «»%«•.■*<* tu ic IO fO 7R no H O III |f>; 1**. /II 214 22* 2** 2%+ 2 TO /«/»■ t/» V i TO ' i i « IO"* t/*> l/». 1 IS l«.S 2 tS 1*7 17*9 /Ot> i l l 22+ 2 IO■ I O * lO*> IfX i l . “ » I IO I t f J« .* I M 1 4 * | M l t | 2 0 0 /V *

■ » **l * l «*l l o r 107 U S I / I 111 I t l 1 4 / ;< * , 202 /O S 2 M l 2*2 / / 7

■ ( u r c v ^ /A f r . i * l / t l / A 12* i * 4 I4 » \U> I V . J SS I \ 4 I S / S f 2 l * l ’. J / l J 7h ]-*•, ; S I

• UNA 2\y 22** 2 2 4 ; * ) ; s i .»*S W W < l * « S S 1 4 ! I 'M S / * f c u < » ! / S / 7

■ ( f K l l 1 > 0 1V4 K / / I f c ^ rM I I I t TO 444. 4 4 0 l « I * * I /O I I S 111 127 ISO / • f

Figure 1.1 Worldwide coiled tubing unit count from 1999-2018 (ICoTA, 2017)

Coiled tubing drilling can be described as drilling using seamless tube coil on

a reel. The use o f coiled tubing keeps increasing as shown in Figure 1.1 Worldwide

coiled tubing unit count from 1999-2018 (ICoTA. 2017).

The growth of coil tubing from 2014 to 2025 as explained in Section 2.7 also

shows the increases usage particularly in well intervention and CTD. Major factors

4

contributing to the demand are increasing operating cost for extracting oil from

existing wells and regeneration o f matured oil wells. In addition, the rise in shale gas

projects and development in other unconventional resources are also anticipated to

drive the market growth. Current experiences in CTD show there are many advantages

o f CTD especially in saving drilling time, ability to re-enter an integrated coiled tubing

gyro measurement-while-drilling (MWD) instrument (Madarapu et al., 2007; Mix et

al.. 1996) and drill thru-tubing that save the cost for upper completion and the drilling

equipment is light and moveable (Cassee et al., 2006). Lesson learnt from other

projects also outlined the disadvantages o f CTD particularly on the depth limitation to

reach extended reach objectives, people competency and high total day rate cost. These

disadvantages make the drilling team thought that the CTD application is more

expensive and riskier than the conventional drilling. Throughout the experiences with

a lot o f success stories including multi drilling and completion, extended reach, slim

hole drilling and lesson learnt from other projects has made CT D application becoming

more attractive to the oil and gas industry.

Active area drilling and re-enter the wells with CTD technology are mainly

found in Canada and US. Malaysia operation started the CTD study in 2005 and the

pilot projects carried out in 201 1. German, Oman, and United Arab Emirates are also

successful in applying CTD in their operations. A list o f some CTD operations is given

in Chapter 2.

1.2 Problem Statement

CTD development started in 1991 with a horizontal sidetrack re-entry drilled

by Oryx Energy in the Austin Chalk o f Texas. It can be described as drilling using

seamless coil on a reel. This new' technology has the potential to grow further in

Malaysia’s upstream operations as there are many matured fields and depleted wells

w ith difficult or challenging next drilling targets to be accessed from existing wells or

platforms. The implementation o f CTD should be considered because to sidetrack

existing depleted wells is expensive; CTD application is an alternative to reduce the

project cost for fields to remain economic. However not all wells are suitable for CTD.

5

thus selection criteria is required for re-entry the well. It is imperative to have a proper

planning especially on the candidate selection criteria to allow oil operators achieving

a high successful rate in CTD operations.

1.3 Objectives

The objectives o f this project are:

1) To develop CTD selection criteria for re-entry well.

2) To compare the cost between CTD and conventional drilling

1.4 Hypotheses

The hypotheses for this research work are as follow:

1) Technical feasibility study and candidate screening can reduce risk in re-entry

well drilling operation.

2) A good feasibility study and planning can increase the chances o f achieving

100% success rate.

3) A reliable technical feasibility study and candidate screening can improve

project economics.

4) Coiled tubing drilling enables oil operator to drill sidetrack wells in challenging

depleted existing wells at lower cost.

6

1.5 Scope

The scope o f this research works are as follow:

1) To identify the criteria and elements which help to increase success rate o f CTD

application.

2) To develop the selection criteria for CTD by analyzing the current situation of

the well, i.e., completion type, angle, technical capabilities, impact o f time,

platform capacity (such as deck space and people onboard capacity), and

history of the well for re-enter to develop the by-passed hydrocarbon zone(s)

(Lheure eta l., 2000).

3) To study the cost elements between CTD and conventional drilling in order to

outline the cost reduction initiatives for sidetracking holes using CTD in

underbalance drilling environment (Venrooy et al., 1999).

1.6 Significance of Study

This study provides a guideline and candidate selection procedures in helping

the engineers and oil operators to re-enter an idle well in a very competitive cost with

high success rate. Thus, it will increase commercial value o f a mature/depleted field

and prolong the field's life. The findings from the project can provide invaluable

information on the process o f selecting the right matured/depleted well to be

rejuvenated using CTD which will subsequently improve the success rate in the CTD

project executione.

7

1.7 Chapter Summary

This chapter discusses the importance o f CTD in drilling operation especially

in re-visiting brown fields. The application o f CTD requires simple unit components,

less manpower, less time usage, and is lighter which makes it mobile and perfectly

suited for drilling matured fields using underbalance drilling method. In fact, CTD is

another method o f drilling which allows oil operators to drill cheaper to reach untapped

hydrocarbon. Based on recent technology development and experiences worldwide, it

is proven that CTD drilling's objectives are achievable with proper selection criteria

and planning. For this research project execution, three scopes have been identified to

satisfy the objectives o f developing CTD selection criteria for re-entry well and outline

its cost reduction initiatives.

I l l

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Abdul Rahman, A. A., Hamzah. N. E., Ahmad Fauzi, N. A., Safiin. N., Khalid, M. Z..

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Abdul Rahman, A. A., Ahmad Fauzi, N., Hamzah, N. E., Chaari. Y.. Sorman, Y. I., Jenie,

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112

Ahn. J. (2015). Achieving Economically Successful Coiled Tubing Composite Plug Drillouts

in Extended Reach Wells. This SPE 173665 paper was presented at SPE/ICoTA Coiled

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Aliniuddin. S.. Shah, N., Das. A., Kumar. N„ Pandey, A., Abhishek, K , and Deendayal. P.

(2012). Synchronization of Coiled Tubing Drilling (CTD) in Extended Reach Drilling

(ERD). This SPE 150910 paper was presented at North Africa Technical Conference and

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Al-Omair. A., Al-Jamaan. H., Rahim, Z., Al-Malki, B., and Al-Kanaan. A. (2011). Enhanced

Sustained Production from Successful Underbalanced Coiled Tubing Drilling in Saudi

Arabian Deep Tight Gas Sandstone and Carbonate Formations. This SPE 142363 paper

was presented at SPE Middle Eust Oil and Gas Show and Conference. Manama, Bahrain.

25-28 September.

Bayati. M., Mostofi. M., Sarmadivaleh. M.. and Evans, B. (2017). Wellbore Stability

Analysis Due to Turbulent Flow in Coiled Tubing Drilling. American Rock Mechanics

Association, 51st U.S. Rock Mechanics/Geomechanics Symposium. California, USA. 25­

28 June..

Beaton. T.. Neyrfor, S., Seale. R., and Neyrfor. S. (2004). The Use of Turbodrills in Coiled

Tubing Applications. This SPE 89434-MS paper was presented at SPE/ICoTA Coiled

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125

presented at SPE/ICoTA Coiled Tubing and Well Intervention Conference and

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