Pinpoint completion in Argentina

1. SPE-185478-MS
Multipay Well Completion in Argentina: A
Versatile Pinpoint Completion Technology
Applied Through Several Conventional, Tight,
and Shale Reservoirs
Juan C. Bonapace, Halliburton; Federico Sorenson, Pan American
Energy; Pablo Forni, Grupo Capsa; Fernando Barbalace, Pampa
Energía; and Federico Kovalenko, Halliburton
© 2017 Halliburton. All Rights Reserved.

2. Agenda
Introduction
Completion techniques in Argentina
Hydrajet perforating annular-path treatment placement + proppant plug
diversion (HPAP-PPD)
Argentina historical evolution, reservoirs and formation applied, statistics
Case histories
Conventional oil (CO), conventional gas (CG), tight gas (TG), and shale oil
(SO)
Discussions (looking forward)
Conclusions
Slide 2
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

3. Slide 3
Introduction
This paper documents the experiences, lessons learned, and results
achieved using a versatile pinpoint completion technique for several
types of reservoirs in Argentina.
Hydraulic Fracture in Argentina:
• Oil and gas reservoir since 1960
• Conventional, tight, and shale
• Depth: 300 to 4500 m
• Bottomhole temperature: 100 to 350°F
• Reservoir pressure: subnormal to overpressure
• Formation permeability: high, medium, low, and ultralow
permeability
• Complex formation type, various reservoir problems
• Multilayer reservoir and multitarget wells
• Oil- and water-based systems, alcohol-water mixtures, and foams
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

4. Slide 4
Completions Techniques in Argentina
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
McDaniel (2005): documents a scorecard to identify the best completion option based
on the reservoir (or well) characteristics and limitations (or benefits) of the completion
technique.
Argentina Reservoirs: present multilayer reservoirs (small lenticular lenses or
multitarget wells).
Completion Methodologies:
Workover unit operations
Tubing string with a set of packers and mechanical plugs
Tubing string with a set of straddle packer systems
Rigless operations (plug-and-perf)
Through casing, applying limited-entry perforating, isolating by bridge plugs
Through casing, applying limited-entry perforating, isolating by sand plugs

5. Slide 5
Pinpoint Technique (HPAP-PPD)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
HPAP-PPD
USA: Introduced in 2004 in vertical wells (Surjaatmadja et al. 2005) and soon
also applied in horizontal wells (McDaniel et al. 2006).
Argentina: Introduced in 2006 only in vertical wells (Folmer et al. 2008; Favoretti
and Ferrer 2008; Forni 2008; Bonapace et al. 2009; Kovalenko 2009; Barbalace
et al. 2012; Forni et al. 2014, 2015; Bonapace 2016).

6. Slide 6
Pinpoint Technique (HPAP-PPD)
Reservoirs
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Basin GSJ GSJ Neuquén Neuquén Neuquén Neuquén Neuquén
Formation
Comodoro
Rivadavia
Mina del
Carmen
Lotena Lajas Los Molles Vaca Muerta
Punta
Rosada
Reservoir fluid Oil Oil Oil Gas Gas Oil and gas Gas
Reservoir type Conventional Conventional Conventional Conventional
Conventional/
tight
Shale Tight
Depth (m) 1000 to 2250 2250 to 3000 1400 to 2000 1600 to 2400 2350 to 3200 2400 to 3000 3200 to 3900
BHT (°F) 120 to 190 190 to 230 135 to 165 145 to 180 180 to 220 185 to 215 225 to 255
Porosity (%) 12 to 18 14 to 19 12 to 17 8 to 12 6 to 12 2 to 9 4 to 12
Permeability
(md)
10 to 50 5 to 25 10 to 45 0.2 to 0.65 0.08 to 0.2
0.00001 to
0.0001
0.001 to 0.01
Reservoir
pressure (psi/ft)
0.28 to 0.35 0.37 to 0.40 0.32 to 0.38 0.23 to 0.35 0.35 to 0.65 0.75 to 0.90 0.55 to 0.7
Young’s
modulus (Mpsi)
1.3 to 2.2 1.5 to 2.6 1.1 to 2.3 1.8 to 3.0 2.8 to 5.5 3.5 to 6.0 3.8 to 6.3
Table 1—Summary of the main characteristics for each formation.
Basin GSJ GSJ Neuquén Neuquén Neuquén Neuquén Neuquén
Formation
Comodoro
Rivadavia
Mina del
Carmen
Lotena Lajas Los Molles Vaca Muerta
Punta
Rosada
Reservoir fluid Oil Oil Oil Gas Gas Oil and gas Gas
Reservoir type Conventional Conventional Conventional Conventional
Conventional/
tight
Shale Tight
Depth (m) 1000 to 2250 2250 to 3000 1400 to 2000 1600 to 2400 2350 to 3200 2400 to 3000 3200 to 3900
BHT (°F) 120 to 190 190 to 230 135 to 165 145 to 180 180 to 220 185 to 215 225 to 255
Porosity (%) 12 to 18 14 to 19 12 to 17 8 to 12 6 to 12 2 to 9 4 to 12
Permeability
(md)
10 to 50 5 to 25 10 to 45 0.2 to 0.65 0.08 to 0.2
0.00001 to
0.0001
0.001 to 0.01
Reservoir
pressure (psi/ft)
0.28 to 0.35 0.37 to 0.40 0.32 to 0.38 0.23 to 0.35 0.35 to 0.65 0.75 to 0.90 0.55 to 0.7
Young’s
modulus (Mpsi)
1.3 to 2.2 1.5 to 2.6 1.1 to 2.3 1.8 to 3.0 2.8 to 5.5 3.5 to 6.0 3.8 to 6.3
Table 1—Summary of the main characteristics for each formation.

7. Slide 7
Pinpoint Technique (HPAP-PPD)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Conventional oil
Conventional gas
Tight gas
Shale oil
Evolution and Statistics

8. Slide 8
Case Histories—Conventional Oil (CO)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
First Step: “Breaking Paradigms”
• Adapting technology
• Modified casing types, set initial and
intermediate bridge plug
• Develop learning curve
• Rigup and rigdown, water and proppant
logistics
• Validate technology
• Verify location and quality of the perforations
• Improve times
• Achieve the target time and improve
completion times (offset wells)
• Evaluate production
• Higher initial production and stabilized
production compared to offset wells
Hydrajet perforation Gun perforation

9. Slide 9
Case Histories—Conventional Oil (CO)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Data/Type Reservoir Conventional Oil
Avg. fracture stages 9
Well geometry (in.) 5 1/2
Max. pressure (psi) 10,000
CT unit (injector) 60K
CT outer diameter (OD) (in.) 1 3/4
Hydrajet tool Old tool
BHA - N°hole 3
Working time (hours) 12
Fracture depth (m) 1050 to 2500
BHST (°F) 120 to 205
Fracture gradient (psi/ft) 0.53 to 0.85
Pump rate (bbl/min) 16 to 19
Wellhead pressure (psi) 1,100 to 4,300
Fracture fluid (gal/1,000 gal) Guar-borate (25)
Total well fluid (m3
) 500
Total well proppant (lbm) 230,000
Type of proppant Sand - RCP - ISP
Type of mesh proppant 12/20, 16/30, 20/40
Hydraulic horsepower (HHP) 550 to 2,000
Table 2—Summary of primary characteristics

10. Slide 10
Case Histories—Conventional Gas (CG)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Confirming the Technology: “The Right Place”
• Continue validating technology
• Understanding the new technique, evaluating erosive perforations for the
stimulation and production phase, checking proppant flowback with this technology.
• Environmental applications
• Used in sensitive areas (urban/rural), minimizing intervention well times.
• Improving profitability of project
• Completion time reduced, decreased operational costs, improved initial production.
• Tested a new model completion (multitarget well)
• Decided to use this technique to stimulate three formations in a single well
intervention (30 fracture stages).

11. Slide 11
Case Histories—Conventional Gas (CG)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Data/Type Reservoir Conventional Oil
Avg. fracture stages 9
Well geometry (in.) 5 1/2
Max. pressure (psi) 10,000
CT unit (injector) 60K
CT outer diameter (OD) (in.) 1 3/4
Hydrajet tool Old tool
BHA - N°hole 3
Working time (hours) 12
Fracture depth (m) 1050 to 2500
BHST (°F) 120 to 205
Fracture gradient (psi/ft) 0.53 to 0.85
Pump rate (bbl/min) 16 to 19
Wellhead pressure (psi) 1,100 to 4,300
Fracture fluid (gal/1,000 gal) Guar-borate (25)
Total well fluid (m3
) 500
Total well proppant (lbm) 230,000
Type of proppant Sand - RCP - ISP
Type of mesh proppant 12/20, 16/30, 20/40
Hydraulic horsepower (HHP) 550 to 2,000
Table 2—Summary of primary characteristics
Conventional Gas
9
5 1/2
10,000
60K
1 3/4
Old tool
3
12
1400 to 2800
135 to 200
0.55 to 0.80
18 to 24
2,250 to 5,700
CMHPG-Zr (25)
1,510
585,000
Sand - ISP
16/30, 20/40
1,300 to 2,850

12. Slide 12
Case Histories—Tight Gas (TG)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Working in a Difficult Environment
• Reservoir condition
• Deeper wells (avg. 3500 m/11,500 ft), higher pore
pressure (0.65 to 0.7 psi/ft), high fracture gradient (0.85
to 0.9 psi/ft), and low permeability (0.01 to 0.001 md).
• Adjusting the technique
• Bottomhole assembly (BHA): only two holes (delta
pressure), older hydrajet tool had to be changed at least
once per well (erosion), new hydrajet tool did not need to
be changed.
• Improving time and logistics
• Change in working time (12 to 24 hours), proper water and
proppant logistics were necessary (850 to 1500 m3/day
water and 2,800 to 4,500 sks/day proppant).
Old hydrajet tool performing 10 abrasive perforations
New hydrajet tool performing 21 abrasive perforations

13. Slide 13
Case Histories—Tight Gas (TG)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Data/Type Reservoir Conventional Oil
Avg. fracture stages 9
Well geometry (in.) 5 1/2
Max. pressure (psi) 10,000
CT unit (injector) 60K
CT outer diameter (OD) (in.) 1 3/4
Hydrajet tool Old tool
BHA - N°hole 3
Working time (hours) 12
Fracture depth (m) 1050 to 2500
BHST (°F) 120 to 205
Fracture gradient (psi/ft) 0.53 to 0.85
Pump rate (bbl/min) 16 to 19
Wellhead pressure (psi) 1,100 to 4,300
Fracture fluid (gal/1,000 gal) Guar-borate (25)
Total well fluid (m3
) 500
Total well proppant (lbm) 230,000
Type of proppant Sand - RCP - ISP
Type of mesh proppant 12/20, 16/30, 20/40
Hydraulic horsepower (HHP) 550 to 2,000
Table 2—Summary of primary characteristics
Conventional Gas
9
5 1/2
10,000
60K
1 3/4
Old tool
3
12
1400 to 2800
135 to 200
0.55 to 0.80
18 to 24
2,250 to 5,700
CMHPG-Zr (25)
1,510
585,000
Sand - ISP
16/30, 20/40
1,300 to 2,850
Tight Gas
11
4 1/2
10,000
60 to 95K
1 3/4
Old tool / new tool
2
12 / 24
2900 to 3800
210 to 250
0.75 to 0.95
16 to 20
6,800 to 9,300
CMHPG-Zr (25)
2,475
970,000
ISP
30/60, 20/40
3,000 to 4,350

14. Slide 14
Case Histories—Shale Oil (SO)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Challenges Associated with Unconventionals (Vaca Muerta)
• Using existing well for unconventional project
• Reconditioning old well, additional workover operations.
• Technical and operational feasibility
• Multiple well geometry option, pinpoint parameter design for these alternatives.
• Applying experiences
• TG pinpoint experience, engineering solutions, logistics for unconventional
projects, new hydrajet tool.
• Project objectives
• Complete a multifracture well with more selective stimulations, cost projection
equal to or lower than previous wells.

15. Slide 15
Case Histories—Shale Oil (SO)
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace
Data/Type Reservoir Conventional Oil
Avg. fracture stages 9
Well geometry (in.) 5 1/2
Max. pressure (psi) 10,000
CT unit (injector) 60K
CT outer diameter (OD) (in.) 1 3/4
Hydrajet tool Old tool
BHA - N°hole 3
Working time (hours) 12
Fracture depth (m) 1050 to 2500
BHST (°F) 120 to 205
Fracture gradient (psi/ft) 0.53 to 0.85
Pump rate (bbl/min) 16 to 19
Wellhead pressure (psi) 1,100 to 4,300
Fracture fluid (gal/1,000 gal) Guar-borate (25)
Total well fluid (m3
) 500
Total well proppant (lbm) 230,000
Type of proppant Sand - RCP - ISP
Type of mesh proppant 12/20, 16/30, 20/40
Hydraulic horsepower (HHP) 550 to 2,000
Table 2—Summary of primary characteristics
Conventional Gas
9
5 1/2
10,000
60K
1 3/4
Old tool
3
12
1400 to 2800
135 to 200
0.55 to 0.80
18 to 24
2,250 to 5,700
CMHPG-Zr (25)
1,510
585,000
Sand - ISP
16/30, 20/40
1,300 to 2,850
Tight Gas
11
4 1/2
10,000
60 to 95K
1 3/4
Old tool / new tool
2
12 / 24
2900 to 3800
210 to 250
0.75 to 0.95
16 to 20
6,800 to 9,300
CMHPG-Zr (25)
2,475
970,000
ISP
30/60, 20/40
3,000 to 4,350
Shale Oil
12
7 + 4 1/2
10,000
95K
1 3/4
New tool
2
24
2350 to 2900
180 to 210
0.93 to 1.05
15 to 23
6,500 to 8,500
CMHPG-Zr (25)
4,800
1,045,000
ISP
30/60, 20/40
3,400 to 4,600

16. Discussions (Looking Forward)
This technique can be used in the following:
• Geographic areas without workover units.
• By operators with experience, availability, and rigless completion models.
• Projects to optimize completion time and costs.
• Reservoirs (fields) not needing evaluation (testing).
• Well or reservoir revitalization (preconditioning old wells to be applicable to this
technology).
• Nontraditional applications.
• Wells with no nominal internal diameters (obstruction, restriction, or deformation).
• Vaca Muerta formation (evaluated to be completed using HPAP-PPD).
Slide 16
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

17. Discussions (Looking Forward)
Benefit obtained:
• Completion technique with lower costs, less risk, and faster operating times.
• No over-displacement of proppant.
• Higher conductivity in the near-wellbore region.
• More effective at treating multiple closely spaced entry points compared to limited-entry
techniques that are not working efficiently.
• Coiled tubing hydrajetting can be used for remedial applications.
• When fracturing treatments using plug-and-perf or sliding sleeves cannot be performed
because of mechanical issues.
• New style hydrajetting tools help enhance this benefit.
Slide 17
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

18. Conclusions
• Adaptability: various types of reservoirs, coiled tubing units, well geometry, rock
types, and fracture designs
• Logistics and planning: continuous learning with different operators, coordination of
resources (water, proppant, materials, equipment) to help minimize negative impacts to
the projects
• Hydrajet tool:
• Initial old style showed erosion in TG → additional time (change BHA)
• New design was applied for TG and SO → improving completion time
Slide 18
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

19. Conclusions
• Reduced completion time:
• CO reduced up to 65%
• CG reduced 40 to 50%
• TG wells required only 5 hours to complete one stage
• SO required 8 hours for one stage
• Production increase: several authors document production increases and higher
initial production rates compared to offsets wells.
• Results obtained have been attributed to
a) Elimination of the damaged region (stress cage) in the perforation tunnel
b) Creation of a high-conductivity cavity just at the perforation tunnel
c) Shorter residence time of the fluid in the formation
d) Focalized stimulation
e) High conductivity in the near-wellbore area
f) Strong connectivity well-formation (no overflush).
Slide 19
SPE-185478-MS • Multipay Well Completion in Argentina: A Versatile Pinpoint Completion Technology Applied
Through Several Conventional, Tight, and Shale Reservoirs • Juan Carlos Bonapace

20. Acknowledgements
The authors thank the following:
• Pan American Energy, Grupo Capsa, Pampa Energía, and Halliburton for permission to
publish this work.
• Staff of the Production Enhancement PSL, Production Solutions PSL, and Global Pinpoint
Stimulation Group.
• Halliburton personnel Mariano Garcia, Leonardo Canini, and Juan Martin Szklarz and
former Halliburton employees Diego Duran (Pluspetrol) and German Rimondi (CWS).
• Buddy McDaniel for his guidance during the last few years.
Slide 20

21. Slide 21
Thank you for your attention