14 aneu applications of technological & engineering solutions edit

Neuquén, Argentina

10-12 June 2014

Application of Technological & EngineeringSolution in Old Wells to Stimulate Vaca MuertaFormation Using Pinpoint Technique.

SPE Exploration and Development ofUnconventional Reservoirs Conference

Pablo Forni - (Capex)

Juan C. Bonapace - (Halliburton)

Federico Kovalenko - (Halliburton)

Federico Sorenson - (Halliburton)

Mariano N. Garcia - (Halliburton)

Abstract

To control costs and obtain needed design information, it is common for operatorsto begin horizontal exploration-development projects using vertical wells. It has alsobeen the practice for resource shale deposits, to stimulate vertical wells forunderstanding, data, samples and research. This is useful to gain designunderstanding and in many cases to understand how to better direct, drill,complete, and stimulate subsequent horizontal wells.

In Neuquén Basin there exists an important number of producing wells traversingVaca Muerta formation. These wells were constructed for conventional targets andtoday present an opportunity to produce from this shale. Several challenges werenecessary to overcome, mainly related to the well’s construction (wellhead, gradeand type of casing), present condition (existing perforation, cement quality) and thepressure required to fracture stimulate this type of reservoir.

This paper will present the engineering and technological solutions applied in an oldwell (drilled in 1974). Two main objectives are covered, a) recondition the well to bestimulated using a swell-packer and 4.5 casing and b) stimulate the entire sectionof Vaca Muerta with 12 fracturing stages using a Pinpoint stimulation technique.

Presentation outline

• Introduction

• Geographic and Well Location

• Re-Completion & Technical Arguments

• Objective & General Consideration

• Completion Program – 1st Phase– Logging – Swell packer – Stimulation & Design

• Completion Program – 2nd Phase– Layout & Logistic – Pinpoint Technique – Job Execution

• Production History

• Lessons Learned & Conclusion

Stratigraphic Column

Vaca Muerta Fm:

Geochemistry

– Kerogen Type II to IV

– TOC Avg 5%

– Ro Avg 0.8 to 1.2

Mineralogy

– Quarz 12%-42%

– Carbonate 32%-77%

– Clays 8%-26%

Thickness

– 150 to 180 m

Geographic Location

Geographic Location

Geographic Location

Well-A Jun-2012

Well-B Dec-2012

Well-C Apr-2013

WellWellWellWell----DDDD Oct-2013

Geographic Location

Shale Plan

• Previous Studies

- Logs

- Cutting

- Seismic (New Process)

• Old Vertical Wells

• New Wells (¿horizontals?)

Well Location

WellWellWellWell----DDDDWellWellWellWell----XXXX

SeismicSeismicSeismicSeismic

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

ADC-1

ADC-1001

ADC-1009

ADC-15

ADC-19ADC-22

ADC-31

ADC-32ADC-35

ADC-36

ADC-42ADC-43

ADC-44ADC-45ADC-46

ADC-47

ADC-48

ADC-50ADC-51

ADC-10

ADC-1002ADC-1004

ADC-11

ADC-12

ADC-13

ADC-14

ADC-16

ADC-18

ADC-2

ADC-20

ADC-24

ADC-28

ADC-3

ADC-30

ADC-33

ADC-34ADC-37

ADC-38

ADC-39

ADC-4

ADC-40

ADC-5

ADC-6

ADC-7ADC-9

ADC-1008

ADC-1010ADC-1011ADC-1012

ADC-1015

ADC-49

Ce-115

ADC-1007

ADC-1005

ADC-1016

WellWellWellWell----XXXX

WellWellWellWell----DDDD

HydrocarbonHydrocarbonHydrocarbonHydrocarbon WindowWindowWindowWindow

Cross Cross Cross Cross SectionSectionSectionSection

Bonapace, Bonapace, Bonapace, Bonapace, 2013201320132013

• Re-Completion (previous well)

- Infraestructure (location)

- Wellhead

- Well Condition & Cementing

WELL A (complete logs set)

• Stimulation Technique (Texas Schedule)

- Rate – Fluids - Sands

- Pumps – Tubes - Manifolds

- Engineering

• Production

- Oil? – Gas? – Nothing?

- Flowback

• Hard Test - Previous Studies

Re-Completion (previous well)

Shale Oil

9/18/201216:30 17:00 17:30 18:00 18:30 19:00

9/18/201219:30

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CTreating Pressure (psig) Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)

A BC C

4/25/201317:40 18:00 18:20 18:40 19:00 19:20

4/25/201319:40

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CTreating Pressure (psig) Slurry Rate (bpm)Slurry Proppant Conc (lb/gal) BH Proppant Conc (lb/gal)

A BC C

Completion Technique:� Tbg 4 ½”, P-110 + Packer

� Wireline Perforation through tubing

� SandPlug

Stimulation� 150 m Vaca Muerta section with 3 Frac Stages per well

� Hybrid Design (Slickwater + XL Gel)

� 50/150 to 20/40 mesh Proppant

� 360,000 gal Fluid per stage

� 430,000 lb Proppant per stage

� Avg Slurry Rate 60 bpm per stage


• WELL A

- Re-completion OK

- Stimulation OK

- Oil Production (Previous Studies OK)

WELLS HISTORY

• WELL B

- New Mechanical Log (Neuronal Net)

- Stimulation (Texas Schedule)

- Microsismic (1 Monitor)

- Builds Ups (x stage)

• WELL C – (Poor Logs)

- Neuronal Net

- Stimulation (VM Schedule)

- Microsismic (2 Monitors)

Technicians´ Hell

COSTSCOSTSCOSTSCOSTS

PRODUCTIONPRODUCTIONPRODUCTIONPRODUCTION

Objectives

• Stimulate the entire thickness of V.Muerta• See response in production

• Apply a working methodology to achieve the objective

• Should be economic

WELL D - Technical Arguments

• Background – Oil field

• Microseismic on Previous Wells

• Build-Ups

• Oil production & PLT (flowmeters)

• Tracers

Technical Arguments

MicroseismicMicroseismicMicroseismicMicroseismic

WellWellWellWell----BBBB

BuildBuildBuildBuild----UpUpUpUp

WellWellWellWell----AAAA

TracersTracersTracersTracers & PLT& PLT& PLT& PLT

HALL HALL HALL HALL ---- experienceexperienceexperienceexperience

General Considerations

StimulateStimulateStimulateStimulate allallallall Vaca Muerta Vaca Muerta Vaca Muerta Vaca Muerta (thickness)

SeveralSeveralSeveralSeveral HydraulicHydraulicHydraulicHydraulic Fracture Fracture Fracture Fracture StagesStagesStagesStages

PerforationPerforationPerforationPerforation

PinpointPinpointPinpointPinpoint TechniqueTechniqueTechniqueTechnique

(Coiled Tubing Abrasive Hydrajet)

Open perforations at Quintuco

Casing 7”

Packer (full diameter)

Swell Packer

Location & Logistic

Wellhead condition

Type of Stimulation

Infrastructure

Completion Program

1st Phase – Workover Intervention

1st Phase - Operation Schedule 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

Rig Up - Workover

Remove Subsurface Instalation

Milling "N" Plug

Logging - Pulsed Neutron Tool

Logging - CBL-VDL-GR

Set New "N" Plug + 2 Dump Bailers

Integrity Test

Swabb Test - Quintuco

Wellhead Condition

Waiting 3th party Companies

Run in Hole and Set Swell Packer

Swelling Time 1 2 3 4 5 6 7 8 9 10

Seated weight on Swell Packer

Rig Down - Workover

2nd Phase - Operation Schedule 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

Press Test - Swell Packer

Logging CCL

Move - Rig Up Frac-Equipment

Rig Up - Coiled Tubing

Rig Up CT + Wellhead operation

Pinpoint Stimulation 2 3 6 9 12

Coile Tubing - Well Cleaning

Flowback

Total Time = 20 days

1st Phase – Cement Bond Log & Packer

Performed a CBL and was evaluated to set swell packer (depth)

• Good cement qualities, lower part V.Muerta without cement

• Swell packer: was considered, set packer 10m below lower perforation

1st Phase – Cased Hole Log (PNT+SGR)

• Was Performed on a Training Well (Neural Network) and wasapplied in Well-C

• WellWellWellWell----DDDD: Pulsed Neutron + Spectral Gamma Ray (Neural Network)

Open Open Open Open HoleHoleHoleHole LogLogLogLog

� SP

� Resistivity

� Sonic (DTC)

CasedCasedCasedCased HoleHoleHoleHole LogLogLogLog

� Pulsed Neutron

� Spectral Gamma Ray

BullerBullerBullerBuller, 2010 & Pitcher, 2012, 2010 & Pitcher, 2012, 2010 & Pitcher, 2012, 2010 & Pitcher, 2012

1st Phase – Swell Packer

Design:

– Requirements:

• Isolation 7”- 4 ½”

• allow 12 Frac Stages (dif press 10k psi)

• anchoring force during Frac (100k lbs)

– Simulations-Design

• Test oil field sample

• 10 days swelling time

• 30k lbs need to apply on packer after swelled/set

• Avg Working Pressure Condition and Max Pressure

1st Phase – Swell Packer

Operation:

– Swabb test Quintuco (500lt/hr 90% water, replace anullar fluid)

– RIH packer, circulate Oil (40m3), set swell packer

– After 4hrs PreTest 2,500 psi

– Completed swelling time (no pressure annular and tubing)

– Apply weight

1st Phase – Stimulation & Completion

CompletionCompletionCompletionCompletion MethodologyMethodologyMethodologyMethodology• Pinpoint Technique & HydraJet Perf

• 12 Stages (130m thickness)

• Max Rate 25 bpm

• Max WHP 9,000 psi

Fracture Fracture Fracture Fracture DesignDesignDesignDesign• Hybrid Job

• Lb/ft and gal/ft shale

• Proppant Mesh sizes

• Fracture Fluid (CMHPG)

• Surfactant

• Clay Stabilizer

AcidAcidAcidAcid ((((typetypetypetype and and and and volumevolumevolumevolume))))• HCL-HF (6.0%-1.5%)

Garcia, 2013Garcia, 2013Garcia, 2013Garcia, 2013

Pinpoint Completion – 12 Stages (130 m thickness)

1st Phase – Stimulation & Completion

Hydra-Jet Fracture Fluid Mesh Proppant WHP Frac Rate HorsePower Frac Fluid Proppant Avg Prop Conc Prop Conc Acid TOTAL Fluid

Tthckness Depth Type Type Volumen Frac Stage Avg Max HCL-HF Volumen

mts m psi bpm HHP gal sks lb/gal lb/gal gal m3

12 2,408.3 2,417.2 9.0 2,409.7 Slickwater + XL Fluid 30/60 - 20/40 7,174 25 4,396 59,000 858 1.45 5.00 1,200 333.6

11 2,418.9 2,426.1 7.3 2,422.0 Slickwater + XL Fluid 30/60 - 20/40 7,196 25 4,409 48,000 693 1.44 4.50 900 292.2



8 2,458.1 2,472.5 14.4 2,464.0 Slickwater + XL Fluid 30/60 - 20/40 7,272 25 4,456 84,000 1,353 1.61 5.00 1,800 429.2

7 2,474.4 2,480.7 6.3 2,476.0 Slickwater + XL Fluid 30/60 - 20/40 7,293 25 4,469 43,000 594 1.38 4.50 800 274.3

2,483.5 2,498.8 15.2 2,489.0 Slickwater + XL Fluid 30/60 - 20/40 6,429 25 3,940 92,000 1,419 1.54 5.00 1,800 460.0

2,494.0


2,516.6 2,529.9 13.4 2,518.0 Slickwater + XL Fluid 30/60 - 20/40 6,469 25 3,964 79,000 1,221 1.55 5.00 1,700 411.3

2,525.0




801,500 12,111 16,500 4,374

ZONE TO STIMULATE

Total

6

4

StageZone to Stimulate

mts

Time

gal bpm Fluid gal bpm Fluid min

Prepad 500 2.5 WaterFrac 10# -2.5 4.76

HydraJet 1,000 2.5 WaterFrac 10# -2.5 9.52

Spacer 1,500 2.5 WaterFrac 10# -2.5 14.29

Acid 300 2.5 HCl 15% -2.5 2.86

Flush 1,200 2.5 WaterFrac 10# -2.5 11.43

Flush 300 1 WaterFrac 10# 0 7.14

Minifrac 144 0.8 WaterFrac 10# 4,500 25 SlickWater 4.29

Acid 0 0 1,500 6 HCL-HF 0.50

Spacer 133 0.8 WaterFrac 20# 1,000 6 SlickWater 3.97

Pad 256 0.8 WaterFrac 20# 8,000 25 SlickWater 7.62

0.25 224 0.8 WaterFrac 20# 7,000 25 SlickWater 6.67

0.50 224 0.8 WaterFrac 20# 7,000 25 SlickWater 6.67

1.00 224 0.8 WaterFrac 20# 7,000 25 XL Fluid 20# 6.67







10.0 10 0.8 WaterFrac 20# 300 25 WaterFrac 20# 0.29

Flush 154 0.8 WaterFrac 20# 4,800 25 SlickWater 4.57

Shut In 30.00

Reverse -3 8,000 3 Water 63.49

Coiled Tubing AnnulusStage

PumpingPumpingPumpingPumping ScheduleScheduleScheduleSchedule

Completion Program

2nd Phase – Rigless Operation

Total Time = 7 days

1st Phase - Operation Schedule 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

Rig Up - Workover

Remove Subsurface Instalation

Milling "N" Plug

Logging - Pulsed Neutron Tool

Logging - CBL-VDL-GR

Set New "N" Plug + 2 Dump Bailers

Integrity Test

Swabb Test - Quintuco

Wellhead Condition

Waiting 3th party Companies

Run in Hole and Set Swell Packer

Swelling Time 1 2 3 4 5 6 7 8 9 10

Seated weight on Swell Packer

Rig Down - Workover

2nd Phase - Operation Schedule 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32

Press Test - Swell Packer

Logging CCL

Move - Rig Up Frac-Equipment

Rig Up - Coiled Tubing

Rig Up CT + Wellhead operation

Pinpoint Stimulation 2 3 6 9 12

Coile Tubing - Well Cleaning

Flowback

2nd Phase – Equipment Layout

• DimensionsDimensionsDimensionsDimensions

• ProppantProppantProppantProppant and and and and ChemicalsChemicalsChemicalsChemicals

• WaterWaterWaterWater TransferTransferTransferTransfer

• OperationalOperationalOperationalOperational CampCampCampCamp

2nd Phase – Rig Up

ProppantProppantProppantProppantChemicalChemicalChemicalChemical ProppantProppantProppantProppant Storage & Storage & Storage & Storage & AcidAcidAcidAcid

CoiledCoiledCoiledCoiled TubingTubingTubingTubing Fracture Fracture Fracture Fracture UnitsUnitsUnitsUnitsWellheadWellheadWellheadWellhead

2nd Phase – Water Logistic

Field CampField CampField CampField Camp

Field CampField CampField CampField Camp

WaterWaterWaterWater StorageStorageStorageStorage



WaterWaterWaterWater PumpsPumpsPumpsPumps

WaterWaterWaterWater TransferTransferTransferTransfer

2nd Phase – Pinpoint Technique

1. 1. 1. 1. Hydrajet is positioned at the zone

2.2.2.2. Abrasive Perforate and initiate fracture with Hydrajet

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

4.4.4.4. Move BHA above excess wellbore proppant

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

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



1. 1. 1. 1. Hydrajet is positioned at the zone

2.2.2.2. Abrasive Perforate and initiate fracture with Hydrajet

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

4.4.4.4. Move BHA above excess wellbore proppant

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

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


11/2/201302:00 03:00 04:00 05:00 06:00

11/2/201307:00

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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

1111 2222 3333 4444 5555 6666

< 5 hr


Coiled Tubing UnitCoiled Tubing UnitCoiled Tubing UnitCoiled Tubing Unit

95K CTU, 1 ¾” - QT 1000 - 17200 ft

Surfaces EquipmentSurfaces EquipmentSurfaces EquipmentSurfaces Equipment

Injector 95K Pool capacity

Side Windows Striper

4 11/16” 10K Quad BOP

4 1/16” 10K Lubricator

7 1/16” to 4 1/16” 10K Cross Over

7 1/16” 10K 2 Flow Cross - side inlet 4 1/16” 1502

7 1/16” 10K 1 Flow Cross - side inlet 2 1/16” 1502

7 1/16” 10K Dual Combi BOP

7 1/16” 10K Valve

7 1/16” 10K Valve (CUSTOMER)

Bottom Hole Bottom Hole Bottom Hole Bottom Hole AsamblyAsamblyAsamblyAsambly

CT Conector

CT Desconector

HydraJet TST– (2 Jet 3/16” - 180°)

Ball Sub

Muleshoe

SurjaatmadjaSurjaatmadjaSurjaatmadjaSurjaatmadja, 2008, 2008, 2008, 2008

2nd Phase – Job Execution (Stages1-4)

StageStageStageStage #1#1#1#1




ResultResultResultResult::::

• SO-43% Prop Fm

• 2.5 ppg 20/40

ChangesChangesChangesChanges forforforfor StageStageStageStage #2:#2:#2:#2:

• Higher % XL Fluid

• Sweep between 30/60 – 20/40 mesh

• Maximize Fracture Rate


• 1 additional HyJet

• SO-63% Prop Fm

• 2.6 ppg 20/40


• 90% XL Fluid and Higher Load 25#

• Slow proppant increment 0.5 ppg

• Increase mesh (50%) - 30/60



• SO-96% Prop Fm

• 2.0 ppg 20/40


• Target = 80% Proppant on Fm

• Same of Stage#3



• SO-95% Prop Fm

• 3.0 ppg 20/40

2nd Phase – Job Execution (Stages1-4)


• SO-43% Prop Fm

• 2.5 ppg 20/40

10/30/2013

09:00 09:10 09:20 09:30 09:40 09:50 10:0010/30 /2013

10:10

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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)

A A

B B

C C

C C

D A

191817161514131211

INSITE f or Stimulation v 4.4.009-Nov -13 15:54


• Higher % XL Fluid

• Sweep between 30/60 – 20/40 mesh

• Maximize Fracture Rate



• SO-63% Prop Fm

• 2.6 ppg 20/40

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

10/30/2013

17:40 17:50 18:00 18:10 18:20 18:30 18:40 18:5010 /30/2013

19:00

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C C

C C

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• 90% XL Fluid and Higher Load 25#

• Slow proppant increment 0.5 ppg

• Increase mesh (50%) - 30/60

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

10/31/2013

08:00 08:20 08:40 09:00 09:2010/31/2013

09:40

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• SO-96% Prop Fm

• 2.0 ppg 20/40


• Target = 80% Proppant on Fm

• Same of Stage#3

11/1 /2 013

02:40 03:00 03:20 03:40 04:00 04:2011/1/2013

04:40

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• SO-95% Prop Fm

• 3.0 ppg 20/40

2nd Phase – Job Execution (12 Stages)

Stage#1 Stage#1 Stage#1 Stage#1 –––– 43% 43% 43% 43% PropPropPropProp FmFmFmFm











Stage#12 Stage#12 Stage#12 Stage#12 –––– 98% 98% 98% 98% PropPropPropProp FmFmFmFm LessonLessonLessonLesson LearnedLearnedLearnedLearned ---- New New New New DesignDesignDesignDesign::::

HydraJet

• Evaluate number cuts

• Identify better location

Fluid (fracture)

• 85-90% XL Fluid

• 25# Gel Loading

• Sweep between mesh

Proppant:

• Slow increment 0.25/0.5 ppg

• 50% mesh 30/60 + 50% mesh 20/40

Max Rate possible: 25 bpm

Target: 80% Proppant on Formation

2nd Phase – Job Execution

55%55%55%55%

Real 85%Real 85%Real 85%Real 85%

20%20%20%20%

Real 45%Real 45%Real 45%Real 45%

2nd Phase – Job Execution

Max HHP

Max HHP

Max HHP

Max HHP

Max

Max

Max

Max Press

Press

Press

Press

Max

Max

Max

Max Rate

Rate

Rate

Rate

12,000 HHP12,000 HHP12,000 HHP12,000 HHP

AvailableAvailableAvailableAvailable

Max HHP = 9200 psi * 25bpmMax HHP = 9200 psi * 25bpmMax HHP = 9200 psi * 25bpmMax HHP = 9200 psi * 25bpm

> 90%> 90%> 90%> 90%

< 50%< 50%< 50%< 50%

Normal FracGrad

18181818----24 24 24 24 bpmbpmbpmbpmEstimatedEstimatedEstimatedEstimated PressPressPressPress

6500650065006500----7500 psi7500 psi7500 psi7500 psi

Lessons Learned & Conclusions

• Proven as an Engineering solution for Old Wells

• Technical Evaluation

– Generation Synthetic Log (PNT+SGR)

• Completion Design

– Swell packer, Pinpoint Technique, HydraJet Perf

• Logistic

– Location, Water, Wellhead

• Execution

– Adjust Perforation and Fracture Design

• Teamwork (Capex-Halliburton)

Acknowledgements

The authors thank Capex S.A. and HALLIBURTON for permission topresent this paper and for all the support provided during itsdevelopment, as well as the field staff of both companies whocollaborated in the execution of the work.

References

� Bonapace, J., et al: ”Optimization”Optimization”Optimization”Optimization inininin CompletionCompletionCompletionCompletion WellsWellsWellsWells withwithwithwith aaaa PackerlessPackerlessPackerlessPackerless,,,, MultistageMultistageMultistageMultistage FractureFractureFractureFracture----StimulationStimulationStimulationStimulation MethodMethodMethodMethod UsingUsingUsingUsing CTCTCTCT PerforatingPerforatingPerforatingPerforating andandandand AnnularAnnularAnnularAnnular----PathPathPathPath PumpingPumpingPumpingPumping inininin Argentina,”Argentina,”Argentina,”Argentina,”.... Paper SPE 121557presented at the 2009 Latin American and Caribbean Petroleum Engineering Conference, Cartagena,Colombia, 31 May–3 June.

� Bonapace, J.,: ““““CompletacionCompletacionCompletacionCompletacion enenenen VacaVacaVacaVaca MuertaMuertaMuertaMuerta enenenen pozospozospozospozos existentesexistentesexistentesexistentes”. Case Histories presented at theIAPG 2013 Jornadas de Caracterización y Estimulación de Reservorios Shale en la Cuenca Neuquina,Neuquén City, Neuquén, 25-26 June.

� Buller, D., et al: “A“A“A“A NovelNovelNovelNovel ApproachApproachApproachApproach totototo ShaleShaleShaleShale----GasGasGasGas EvaluationEvaluationEvaluationEvaluation usingusingusingusing aaaa CasedCasedCasedCased----HoleHoleHoleHole PulsedPulsedPulsedPulsed NeutronNeutronNeutronNeutron ToolToolToolTool””””.Paper SPWLA 87257 presented at the 2010 SPWLA 51th Annual Logging Symposium, Perth, Australia19-23 June.

� Garcia, M., et al: “Vaca“Vaca“Vaca“Vaca MuertaMuertaMuertaMuerta ShaleShaleShaleShale ReservoirReservoirReservoirReservoir CharacterizationCharacterizationCharacterizationCharacterization andandandand DescriptionDescriptionDescriptionDescription:::: TheTheTheThe StartingStartingStartingStarting PointPointPointPointforforforfor DevelopmentDevelopmentDevelopmentDevelopment ofofofof aaaa ShaleShaleShaleShale PlayPlayPlayPlay withwithwithwith VeryVeryVeryVery GoodGoodGoodGood PossibilitiesPossibilitiesPossibilitiesPossibilities forforforfor aaaa SuccessfulSuccessfulSuccessfulSuccessful ProjetProjetProjetProjet””””. Paper SPE168666 presented at the 2013 Unconventional Resources Technology Conference, Denver, USA, 12-14August.

� Pitcher, J., et al: ““““ExploringExploringExploringExploring ShaleShaleShaleShale BasinsBasinsBasinsBasins usingusingusingusing ExitingExitingExitingExiting WellsWellsWellsWells”. Paper 152579 presented at the 2012European Unconventional Resources Conference, Vienna, Austria, 20-22 March.

� Surjaatmadja, J., et al: “New“New“New“New HydrajetHydrajetHydrajetHydrajet ToolToolToolTool DemostratesDemostratesDemostratesDemostrates ImporvedImporvedImporvedImporved LifeLifeLifeLife forforforfor PerforatingPerforatingPerforatingPerforating andandandand FracturingFracturingFracturingFracturingApplicationsApplicationsApplicationsApplications””””. Paper SPE 113722 presented at the 2008 Coiled Tubing and Well InterventionConference and Exhibition, Woodlands, USA, 1-2 April.

� Wellhoefer, B., et al: ““““UniqueUniqueUniqueUnique SolutionSolutionSolutionSolution totototo RepairRepairRepairRepair CasingCasingCasingCasing FailureFailureFailureFailure inininin aaaa HTHPHTHPHTHPHTHP WellboreWellboreWellboreWellbore AllowsAllowsAllowsAllows forforforforSuccessfulSuccessfulSuccessfulSuccessful MultiMultiMultiMulti----StageStageStageStage StimulationStimulationStimulationStimulation TreatmentTreatmentTreatmentTreatment inininin anananan UnconventionalUnconventionalUnconventionalUnconventional ReservoirReservoirReservoirReservoir””””. Paper SPE 162852presented at the 2012 Canadian Unconventional Resources Conference, Calgary, Canada 30 Oct-1November.

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