apogce spe-176060-ms presentation

SPE-176060-MS

Innovative Offshore Stimulation Campaign in

Saudi Arabia

Syed Muhammed Danish and Etna Becerra, Halliburton

© 2015 Halliburton. All Rights Reserved.

SPE-176060-MS • Innovative Offshore Stimulation Campaign in Saudi Arabia • Syed Danish

Abstract

Field X—offshore/onshore footprint • Peripheral matrix water injection as a pressure maintenance scheme.

• More than 80 wells on 13 offshore platforms.

• More than 100 wells on 27 man-made artificial drilling islands interlinked with a 41 km causeway.

• Extended reach, highly deviated with openhole production/injection profile ranging from 3,000 to

9,000 ft

Campaign objective • Stimulate to restore reservoir productivity/injectivity with multiple downhole and offshore challenges.

• Heavy tar mat zone characterizes the field, causing hard mixed deposit bridges.

• Large treatment volumes are necessary: 1,700 to 5,100 bbl for power water injectors (PWIs) and

1,500 to 4,500 bbl for oil producers (OPs).

• Offshore barge/platform weight and space limitations with limited return handling capability.

• Time consuming/costly logistics.

The scope of this presentation is to review: • Remedial coiled tubing (CT) intervention and stimulations performed during the offshore portion of

this project resulting in more than 300% production/injection improvement.

Slide 2


Field Introduction

• Largest carbonate project of the region

with target production: • 900 million B/D heavy crude oil

• 90 MSc/D sour gas

• 65 million B/D condensate

• Unique engineering design: • Water drive mechanism

• Unique placement of both PWI and OP

wells

• Onshore foot print on artificial man-

made islands

• Offshore foot print on shallow platforms

with ~10 m water depth

Slide 3


Offshore Drilling and Stimulation Plan

Planned work on 13 platforms • Offshore rig mobilizes to a pad site, drills and

completes six to seven wells per platform,

consisting of a cutting re injection (CRI) or

reservoir monitoring with permanent

downhole monitoring system (PDHMS) and

the rest either OP or PWI wells.

• Post-drilling/completion rig moves to the next

pad site without stimulating the wells, and a

platform is commissioned with respective

production or injection lines from the gas/oil

separation plant (GOSP).

• Jack up barge/vessel with CT, nitrogen, return

handling package, and a stimulation vessel

follows the rig to the newly commissioned

platform and stimulates the wells.

Slide 4


Challenges

• Downhole challenges • 80% of these wells are extended reach, 90% of the

wells are highly deviated, with maximum deviation

angle reaching 90° for more than 50% of the

openhole region, hydraulic tractor and agitator

assemblies are necessary to reach total depth

(TD).

• 30% of the measured depth coverage is for

openhole production or injection.

• Open hole results in excessive drag while running

in hole (RIH), slick friction reducer is placed in the

45° deviated zone.

• 2% of the wells have multilateral profiles. Lateral

finding technology is necessary to stimulate the

correct lateral.

Slide 5


Challenges

Offshore barge limitations

• Barge deck loading/capacity • Limited in terms of CT string length

• Limited use of other services, including full surface

testing package, stimulation package, slickline, or

wireline

• Crane capacity and length—45 ton port side and 25 ton

starboard side • Limited in terms of lubricator height, tool deployment

is restricted

• Barge technology • Self-propelled barge without dynamic positioning,

weather plays a important role during barge

positioning

• Barge leg lengths—52 ft and barge draft—4.5 m • Cannot perform deepwater or shallow water

operations

Slide 6


Stimulation Vessel

• Vessel specifications • Dynamic positioning system (DP2)

• 3 in. Iron discharge line 15,000 psi

certified

• 50 bbl blender tub—mixes acid-on-

the-fly (AOF)

• 91,300 gal of raw HCl acid/10,000

gal of solvent/12,500 gal of

additives

• 4,200 gal waste tank for fluid for

priming up pumps and lines

• Five pumps; 5,000 HHP; Min rate:

0.5 bbl/min, max rate: 30.0 bbl/min

From 2013 to 2015, 3.7 million gal of

corrosive fluids pumped in more than 60

wells

Slide 7


STIMSTAR (Stimulation Vessel) and KINOA (Jack up Barge)

Slide 8

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Project Execution: 65 Wells (2013 to 2015)

Slide 9

58

7Operations executed

Acid Stimulation

Milling/Cleanout

42

28 Wells executed

Power Water Injector

Oil Producer

Treatment volume gradients

For PWIs:

• Preflush 6 gal/ft

• Carbonate stimulation acid (CSA) 3 gal/ft

• Viscoelastic-based diverting acid (VDA) 3 gal/ft

• Spacer CSA 3 gal/ft

• Carbonate emulsified acid (CEA) 6 gal/ft

• Post-flush 3 gal/ft

For OPs:

• Preflush 3 gal/ft

• CSA 10 gal/ft

• VDA 5 gal/ft

• Post-flush 3 gal/ft


Project Execution: 65 Wells (2013 to 2015)

Slide 10


Conclusions

Slide 11

• Sixty-five interventions, seven milling/cleanouts, and 58 acid stimulations were

successfully completed.

• Injectivity/productivity results post-stimulation revealed a 300% improvement.

• Execution time per well was reduced to 1/4th of the original time.

• Customized CT stack rigup reduced rigup (R/U) and rigdown (R/D) time.

• Provided operational flexibility with regards to use of chemical solvents, dispersants,

tools, tractors, agitators, indexing/knuckle joints, acid compatible motor, and mill

assembly.

• Using the jack up barge and stimulation vessel combination helped improve logistics and

resource availability

Acknowledgements / Thank You / Questions

The authors thank the management of Halliburton and Saudi Aramco for

support during the execution of this project.

Slide 12

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