Coiled Tubing - Mustafa Alzaid - Session 3[1]

8/9/2019 Coiled Tubing - Mustafa Alzaid - Session 3[1]

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SPE Applied Technology Workshop:

Coiled Tubing: From Conventional to Advanced Applications

9-11 September 2013Le Meridien Limassol Resort and SpaCyprus


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Dual Lateral Open Hole Coiled Tubing Acid Stimulation in Deep HPHT

Sour Gas Producer WellsField Experience and Lessons Learned fromthe Ghawar Field

Mustafa R. Al-Zaid, Mohammed A. Al-Ghazal, Saad Al-Driweesh, Fadel Al-Ghurairi, Saudi Aramco;Jose Vielma, Alejandro Chacon and Jose Noguera, Halliburton; all SPE


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Outline

SPE Coiled Tubing: From Conventional to Advanced Applications

Brief Background.

Multilateral Well Intervention Challenges in the Ghawar Field:

Corrosion Concerns in Acidic Fluids and Sour Environments.

CT Lockup in the Open Hole Section.

Access to Multilaterals.

Selective Placement of Acid Treatments in Open Hole Completions.

Post Well Intervention Results.

Conclusion.


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Brief Background


Well Architecture:

Drilling open hole multilateral wells

has significantly increased in the

last few years.

Well architecture is a key factor in

determining the type and size of

the CT and downhole tools to be

used during well interventions.

Radial View of an Open Hole Multilateral Gas

Producer Well Construction


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Brief Background

Schematic Examples of Typical Well Diagrams

4 Tubing with

3.688 minimum ID

9 Casing

with 8.535 ID

8.375 Openhole Diameter

7 Liner with

6.094 ID

5.875 Open

Hole Diameter

Maximum dogleg kept

under 10/100 ft

Maximum dogleg kept

under 10/100 ft

4 Tubing with

3.688 minimum ID


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Brief Background

Formation Description:

Consolidated carbonate formation.

The mineralogy is mainly calcite with streaks of dolomites.

Reservoir pressures and temperatures ranging from 4,500 psi to 6,500 psi and

250F to 300F, respectively .

Formation fluids: gas condensate of 40to 45API. Condensate gas ratio from

50 bbl/MMscfd to 150 bbl/MMscfd.

H2S Concentration varies from 1% to 10% and CO2concentration from 1% to 4%.


7/22SPE Coiled Tubing: From Conventional to Advanced Applications

Outline

Brief Background.







Conclusion.



Challenge #1

The Main Challenge:

Dealing with extreme acidic fluid systems, in hot sour wells.

Tubular and CT string corrosion mitigation and prevention.

Introduced Actions:

Loading the well with treated water prior running CT in hole to minimize sour

formation fluid influx.

Circulating treated water loaded with SSC inhibitor while traversing the open hole

section for CT protection.



Challenge #1

Introduced Actions:

Extensive corrosion tests on CT and completion material coupons.

Using a non-acidic solids-free diverter to minimize fluid losses from thief zones.

Loading acid systems with H2S scavenger.

Mixing acid blends before reaching targeted zones to minimize CT exposure to

sour and acidic fluid influx.



Outline Brief Background.



CT Lockup in th e Open Hole Sect ion.




Conclusion.



Challenge #2

The Main Challenge:

Pipe buckling due to higher friction coefficient in the OH section and large liner

and OH diameters.

Reaching the target depth due to CT lockup.

Introduced Actions:

Running larger OD CT.

Using friction reducer.



Challenge #2

Introduced Actions: Using friction reducer, viscoelastic surfactant (VES) commingled with N2was

utilized to reduce the friction and CT weight.

Using dynamic excitation tool.

Friction reducer used in horizontal open hole section







Access to Mult i laterals.



Conclusion.



Challenge #3

The Main Challenge:

Access to the target lateral in a multilateral

open hole completion.

Introduced Actions:

Using the controlled rotational sub.

Using the controlled bent sub.

Using the isolation sleeve to be able to use

orienting tools in tandem with the dynamic

diversion jetting tool.

Isolation sleeve system on dynamic diversion toll



Challenge #3

Item Tool Schematic

Client:

Rig/Platform: 1

Field/Well Number:

Minimum Well Restriction:

Top of Cement/Fill/HUD:

Bottom Hole Temperature: 2

Bottom Hole Pressure:

Wellhead Pressure:

Quote Number: 3

Job Number:

BHA Name:

Date Drawn:

4

Tool O/D Tool I/D T-Length

in Inches in Inches in Inches

5

6

7

8

9

10

Maxiumum Tool-String OD: 3.125 11

Minimum Tool-String ID: 1

Total Length of BHA in Feet: 25.17

6

20N/A2.1251.5 AMMT Box

1.5 AMMT Pin

Controlled Bent

Sub9

N/A2.875

3.688"

2.388 PAC Box

2.388 PAC Pin

Dynamic

Excitation Tool

Hydrajetting + Dynamic Excitation Tool +

steering Tools

331.12.8752.388 PAC Box

2.388 PAC Pin

1

262 F

5,000 psi

BHA SCHEMATIC

Operator

2.375" CT Unit

X

1

1

CT Dimple

Connector for

2.375" CT

2.388 PAC Pin 3.125 1.1 5

2.5 - 6

Fish neck

typeTool DescriptionItem Tool Connections

Cross-over3

MHA

11 Nozzle 1.5 AMMT Box

221.23.06

2

12132.388 PAC Box

2.388 EUE Pin

2.388 EUE Box

2.388 EUE Pin

HydraJetting tool

and sleeve

system

4

2.388 EUE Box

2.388 PAC PinCross-over5

6N/A3

613

84

2.388 PAC Box

1.5 AMMT PinCross-over7

481.12.1251.5 AMMT Box

1.5 AMMT PinStraight Bar10

1.5 AMMT Box

1.5 AMMT PinRotational Sub8 60N/A2.125

BHA SCHEMATIC








Select ive Placement of Acid Treatments in Op en Hole Compl etions.

Post Well Intervention Results. Conclusion.



Challenge #4

The Main Challenge:

Selective placement of the acid

treatment across the zone of interest

complex operation when in OH due to

large formation area exposed.

Introduced Actions:

Using the hydrajet acid injection

technique for dynamic divergence.

The technique was usually performed at

a rate of 3 bbl/min and 300 scfm of N2,

and at a speed of 10 ft/min.

5000 psi

4800 psi

6000 psi

7000 psi7600 psi

8000 psi

Stagnation pressure can be up

to 3,000+ psi compared to

pressure at entrance to cavity.

Computational fluid dynamics simulation










Conclusion.



Post Well Intervention Results

Post CT stimulation production results

Well

Pre-stimulation Post-stimulationEstimated Gas

Rate Gain

(MMscfd)Gas Rate

(MMscfd)FWHP (psig)

Gas Rate

(MMscfd)FWHP (psig)

A

7

1,070

18

1,310

11

B 4 1,900 6 2,773 2

C 3 1,300 13.6 1,909 10.6

D Unstable performance 24 1,530 6

E 9 1,087 15.4 1,318 6.4

F 3 1,300 5 1,060 2

G 9 1,230 18 1,200 9

H 6 970 17 1,150 11

I

0

240

12

1,480

12

Total Gas Rate Increased =

70


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Conclusion

Innovative solutions with solid engineering ground work were key to the success

of the interventions.

OH multilateral wells can be effectively stimulated in extremely acidic and sour

conditions without jeopardizing the CT string and well completion integrity.

Pumping the friction reducer yielded additional reach in the horizontal section.

The commingling of nitrogen in the stimulation fluid stream helped increase the

delta pressure across the nozzle as well as reduce treatment fluid flowback times.

The positive effect of the solids-free diverting agent for even distribution of

treatment fluids.


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Coiled Tubing - Mustafa Alzaid - Session 3[1]

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