SPE-172724

SPE-172724-MS

Conditioning Pre-existing Old Vertical Wells to

Stimulate and Test Vaca Muerta Shale

Productivity through the Application of Pinpoint

Completion Techniques

Pablo Forni, CAPEX S.A.; Juan C. Bonapace, Federico Kovalenko, Mariano N. Garcia, and Federico Sorenson, Halliburton

AGENDA

• Introduction

• Geology

• Phase 1• Studies and Pilot Plant

• Phase 2 - (Well.D)

• New Completion

• Well Operation

• Discussion and Conclusion

Slide 2

SPE-172724-MS • Conditioning Pre-existing Old Vertical Wells to Stimulate and Test Vaca Muerta Shale Productivity through the

Application of Pinpoint Completion Techniques • Walter Suzart

INTRODUCTIONSlide 3



Objetive• Development of a project in Vaca Muerta, using existing vertical wells to

evaluate its commercial potential

Location• Argentina – Neuquén Basin – Agua del Cajón block.

• El Salitral field (Los Molles, Tordillo, Lajas Fms – currently producing gas)

• Agua del Cajon field (Tordillo, Lajas, Quintuco Fms – oil producers)

• Aguada del Cajon Field • Drilling and exploitation - very active in the 1970s and 1980• Secondary recovery operation in the 1990s• Currently not in production• 30 existing vertical wells, that crossed the Vaca Muerta Fm.

GEOLOGYSlide 4



Generalities of Vaca Muerta Fm.• Type of rock, mudstones (very sparingly wackestones)

• Age, Tithonian to early Valanginian

• Thickness, 150 to 180 m

Geochemistry• Kerogen, Type II

• TOC, 2%-5%

• Oil Windows (according Max Temp and PI)

Mineralogy• Quarz 8%-30%

• Calcite/Dolomite 20%-80% - 2%-15%

• Clays < 6% (mainly Illite)

2011 - Geology and Resevoir Studies• 3D Seismic reprocessing

• Maturity and TOC maps, (trace elements studies)

• Structural maps, faults, thickness, reservoir pressures

• Reinterpretation of profiles to openhole

2012/13 - Potential Well Interventions (Pilot Plan)• 30 wells in the area

• Only 11 wells with minimum conditions

• Pilot Plant:

• Selected 3 wells (A-B-C)

• Geology and reservoir condition

• Information - (logs, drill cutting, oil evidences in VM)

• Well condition - (mechanical, wellhead, cement quality, existing perforations)

• Infraestructue - (location and surfaces water resources)

Slide 5



0.65 0.70 0.75 0.80 0.85 0.90 0.95 1.00 1.05 1.10 1.15 1.20

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Hydrocarbon Window Map

PHASE 1 – Studies and Pilot Plant

PHASE 1 – Studies and Pilot PlantSlide 6



Well-A• Completion methodology - (Tbg 4 ½ in. – Packer)

• DFIT (only lower zone) and Hydraulic Fracture

• Well produced oil

Well-B• Microseismic – (one monitor-well)

• Build up Test – (individual zones)

• Well produced oil

Well-C• Cased hole log + Neural Network

• Microseismic – (two monitor-wells)

• Hydraulic Fracture - (modify design)

Well produced oil

PHASE 1 – Studies and Pilot PlantSlide 7



Lesson Learned• All stimulated well produced oil

• Completion methodology was proven and successful

Review Pilot Plan • Different petrophysical properties along VM vertical section

• Denotes a greater degree of heterogeneity• Microsesimic, build up, proppant and fluid tracers, PLT log results

Slide 8



PHASE 2 – New Completion (New Approach)

New Completion Approach• More selective and effective

stimulation

• Equal or lower costs • compared with the completion tested

at pilot plan)

• Improve production with respect to

previous wells.

• Applied in wells having the same

characteristics - (comparative analysis)

PHASE 2 – New Completion (Pre-feasibility)Slide 9



Final Completion Configuration• Tubing: 4 1/2 in., 13.5 lb/ft, P110

• Packer: Swell packer 4 1/2 ´ 7 in. • (6.05-in. swell and 3.958-in. ID)

• CT: 95K unit, 1 3/4 in., QT 1000

• Hydrajet: TST two jets and 3/16-in. ID

New Completion - Limitation • CT Max Pressure: 12,000 psi

• CT Max Flow Rate: 2.7 bbl/min (hydrajetting)

• BHA: Two jets oriented at 180°• Frac Max Pressure: 9,200 psi (swell packer)

• Frac Max Rate: 25 bbl/min • (maximum erosion velocity limit)

PHASE 2 – Well.D (Swell Packer Design)

Requirements• Isolation 7 – 4 ½ in.

• Allow 12 Frac Stages

Results• Max pressure 10,000 psi difference

• 120,000 lb - anchoring strength

• Sweeling time -10 days

• After sweeling time - apply 30,000 lb of weight (slack off).

Slide 10



PHASE 2 – Well.D (Well Condition- Operation)Slide 11



Plug and Integrity Test• Set a plug and isolate VM fm.

• Well integrity test (9,500 psi @ 10 min.)

Swab Test (Quintuco)• Existing perforation at Quintuco

• 0.5 m3/hr of 90% water

• Recomended displace all fluid in annular by Oil

Swell packer operation• RIH swell packer – pump oil – set swell packer – test swell packer (2,500 psi OK)

• Well closed for swelling time (10 days)

• At 80% swelling time• Open wellhead and chek pressure (tubing and annulus , zero pressure)• Apply weight , effective 30,000lbf

PHASE 2 – Well.D (Cased-Hole Logging)

• Incomplete Openhole logs - (SP, Resistivity and sonic compression)

• S.G.Ray - (better estimation of volumen of clays)

• Pulsed Neutron - (Triple combo, reservoir and mechanical rock properties)

• Apply Trained Well – (Neural Networks assembled and trained)

Slide 12



PHASE 2 – Well.D (Infraestructure)

Logistic & Equipment

• Dimensions

• Proppant and Chemicals

• Water Transfer

• Operational Camp

Slide 13



ProppantChemical

Wellsite and layout

PHASE 2 – Well.D (Water Logistic)Slide 14



Field Camp

Field Camp

Water Storage

Water Storage

Water Storage

Water Pumps

Water Transfer

PHASE 2 – Well.D (Stimulation Design)

Stimulation (Hydraulic Fracture)

• Thickness: 130m

• 12 frac stages

• Max WHP 9,000 psi

• Max Rate 25 bpm

• Hybrid Frac (SW 40% - XL 60%)

• XL Fluid: CMHPG-Zr 20gpt, low pH

• Acid Prepad (reactive fluid HCl-HF)

• Proppant: ISP 30/60 (20%) – 20/40 (80%)

• New Clay Stabilizer

Slide 15



PHASE 2 – Well.D (Pinpoint Technique)Slide 16



1. Hydrajet is positioned at the zone

2. Abrasive Perforate and initiate fracture with Hydrajet

3. Pump frac treatment down annulus and place a proppant pack inside wellbore

4. Move BHA above excess wellbore proppant

5. Reverse up CT to wash down to next target (if needed); test plug

6. Hydrajet is positioned at the next zone: repeat step 2 to 5.

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Annulus Pressure (psi) Tubing Pressure (psi) Slurry Rate~Ann (bpm)Slurry Rate~Tbg (bpm) Slurry Proppant Conc~Ann (lb/gal) Slurry Proppant Conc~Tbg (lb/gal)Prop Conc~EOT Ext (lb/gal) BH Proppant Conc (lb/gal) S1 CT Depth (m)

A A BB C CC C D

INSITE for Stimulation v4.4.010-Apr-14 15:01

1 2 3 4 5 6

< 5 hr

PHASE 2 – Well.D (Pinpoint Technique)Slide 17



Coiled Tubing• Injector: 95K pool capacity• CT: OD 1¾ in, QT-1000, 17200ft

Surfaces Equipment - Wellhead• Side Windows Stripper• Quad blowout preventer (BOP): 4 1/16 in., 10,000 psi• Lubricator: 4 1/16 in., 10,000 psi• Crossover: 7 1/16 to 4 1/16 in.• Two flow crosses: 7 1/16 in., side inlet 4 1/16 in. 1502• One flow cross: 7 1/16 in., side inlet 2 1/16 in. 1502• Dual combi BOP: 7 1/16 in., 10,000 psi• Two valves: 7 1/16 in., 10,000 psi

Bottom Hole Asambly• CT Connector• CT De-connector• HydraJet• Ball Sub• Mule shoe

PHASE 2 – Well.D (First Operations)Slide 18



Stage #1

Stage #2

Stage #3

Stage #4

PHASE 2 – Well.D (First Operations)Slide 19



Stage #1

Stage #2

Stage #3

Stage #4

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Annulus Pressure (psi) Tubing Pressure (psi)

Slurry Rate~Ann (bpm) Slurry Rate~Tbg (bpm)

Slurry Proppant Conc~Ann (lb/gal) Slurry Proppant Conc~Tbg (lb/gal)

Prop Conc~EOT Ext (lb/gal) BH Proppant Conc (lb/gal)

CT Depth (m) Backside Pressure (psi)

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191817161514131211

INSITE for Stimulation v 4.4.009-Nov -13 15:54

Results:• SO-43% Prop Fm• 2.5 ppg 20/40

Changes for Stage #2:• Higher % XL Fluid• Sweep between 30/60 – 20/40 mesh• Maximize Fracture Rate

Etapa N° 2 - Fractura : 626 sks mezclados - 563 sks en formación

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Results:• 1 additional H.Jet• SO-63% Prop Fm• 2.6 ppg 20/40

Changes for Stage #3:• 90% XL Fluid and Higher Load 25gpt• Slow proppant increment 0.5 ppg• Increase mesh (50%) - 30/60

Etapa N° 3 - Fractura : 1124 sks mezclados - 1018 sks en formación

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Results:• 1 additional HyJet• SO-96% Prop Fm• 2.0 ppg 20/40

Changes for Stage #4:• Target - 80% Proppant on Fm• Same of Stage#3

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Results:• 1 additional HyJet• SO-95% Prop Fm• 3.0 ppg 20/40

Slide 20



Stage#1 – 43% Prop Fm












Lesson Learned and New Considerations

HydraJet• Evaluate number cuts and i dentify better location

Fracture Design• Target 85% proppant on formation• Clean fluid sweep as contingency

Fracturing Fluid• Use XL gel for 90% of the treatment• Gel loading 25 lb/mgal• Sweep between mesh

Flow Rate• Maximized according wellhead pressure

Proppant:• Modify mesh percentages (50%-30/60 + 50%-20/40)• Slow increment 0.5 ppg between step

PHASE 2 – Well.D (Operation)

PHASE 2 – Well.D (Operations Summary)Slide 21



Hydrajets Hydraulic Fractures

PHASE 2 – Well.D (Operations Summary)Slide 22



• Frac Gradient

• % Proppant in Fm

• % XL Fluid

• % 30/60 mesh

• Max Prop Conc

DISCUSSION AND CONCLUSIONSlide 23



Discussion• Addition Fricction

• Hydrajet (Abrasive Perforation)

• Variation along the Well

Conclusion• Cased-hole logging methodology

• Isolation element (swell packer)

• Performance new hydrajet tool• Higher energy to initial fracture

• Completion technique (HJAF process)• Adapting fracturing treatments• Reduction completion time

• Less resources (horsepower)

• Detailed work plant (logistic, execution)

• Team Work (technical and operational)

Acknowledgements

CAPEX • Gabriel Irazuzta

• Jorge Ferraris

• Daniel Huenuehueque

• Nicolas Fumagalli

• Marcelo Beliera

• Carlos Gomez

Halliburton• German Rimondi

• Esteban Patch

• William Harbolt

• Dustin Holden

• Mattew Sharp

Slide 24

The authors are grateful to the Management of CAPEX and Halliburton for permission to publish this work, in particular

Thanks you for your attention

Slide 25

Engineering

SPE-172724