Enfoque múltiple disciplinario como metodología para el desarrollo de yacimientos

1

metodología para el desarrollo de yacimientos no convencionales.

Federico Sorenson01/09/2011Neuquen

Agenda

� Introduction� Unconventional Process� Unconventional Experiences in Argentina

2

CoalShaleBasin Centered GasTight Gas

Source Rock

Unconventional Gas

% Sorbed Gas0% 100%

San Juan BasinBarnett ShaleRockies & East Texas

50%

SW Wyoming Province

Fick’s LawDarcy’s Law

103 100 10 1 .1 .01 10-3 10-4 10-5 10-6 10-7 10-8 10-9

microdarcyµD

darcy D

10-10 10-11

nanodarcyνD

millidarcymD

Fluid Velocity

What Makes an Asset Unconventional?

103 100 10 1 .1 .01 10-3 10-4 10-5 10-6 10-7 10-8 10-9 10-10 10-11

Effective Area

27000 acres

8 wells

120 acres3 Wells

27000 acres

225 Wells

27000 acres

5400 Wells

Unconventional Gas / Unconventional Thinking

� Uplifts / Tectonics / Traps� Matrix Density� Water Saturation� Shale Volume� Determine Reservoir

Volume

� Continuous / Undisturbed� Brittleness� TOC / RO� Mineralogy (Particle Size)� Stimulate Reservoir Volume

(SRV)

Conventional Reservoirs Shale Source Reservoirs

� Determine Reservoir Volume

� Extended Well Test� Proppant Concentration� 10K to 20K HHP� 35 to 40 bbls / Min� Planar Fractures� Water Conformance

� Stimulate Reservoir Volume (SRV)

� DFIT � Water Volume� 25K to 40K HHP� 35 to 100 bbls / Min� Complex Fracture Networks� Water Management

Rock Variation

•Depth•Thickness•Temperature•Pressure•Stress magnitude and directiondirection•Barrier rock•Hydrocarbon type•Hydrocarbon content•Flow capacity

7

Geology & Data Gathering

Reservoir Evaluation

Economics & Optimization

Reservoir Focused Development

Fracturing Design

Completion Design & Execution

Production Match & Predict

The Unconventional Process

Electric Logs

Planning

WellConstruction

Cores/Cuttings

LabTesting

Design andMonitoring

DFITsShaleLOG

Unconventional Team

Geología

Ing. Perforación Ing. Producción

Petrofísica

Logística

Ing. Lodos

Ing. Reservorios Ing. EstimulaciónIng. Completación

Tight Gas Shale Gas/Oil

Reservoir Understanding

12

Lab Tests Results - X-Ray Diffraction

What do need to do�Evaluate:

� Mineralogy� Acid and water sensitivity� Bulk permeability from each zone� Presence of natural fractures� Vitrinite Reflectance� TOC� Pyrolysis� Gas Content� Search for analogies

√

√

√

√

√

√

Mineralogy Distribution - PL-1010 - Vaca Muerta

Lab Tests Results - X-Ray Diffraction

13

Black Dots present Vaca Muerta formation results

Carbonates Clays

Acid Solubility and Mineralogy (PL-1010 – PL-1051)

Clay < 30%

0

10

20

30

40

50

60

70

80

90

100

8 12 16 19 22 27 32

Samp le Number

Tot Clay

Calcite

Dolomite

Quartz

K Feldespars

Quartz+Carbonate

Well Sample Depth (ft) Clay Calcite Dolomite Quartz Plagioclase K Feldespars PR Lith YM Lith Brit Lith Member

PL-1010 8 3772.9 16 52 9 14 8 1 0.25 5.4 49.8 Upper

PL-1010 12 3832.0 18 44 12 19 5 2 0.24 5.18 48.9 Upper

PL-1010 16 3891.0 6 80 1 10 4 0 0.25 6.02 53.3 Middle

PL-1010 19 3920.6 7 80 0 9 4 1 0.25 5.97 53.0 Middle

PL-1010 22 3969.8 9 70 2 12 6 1 0.25 5.79 52.2 Middle

PL-1010 27 4048.5 28 50 1 14 6 1 0.25 4.8 45.7 Lower

PL-1010 32 4186.3 28 36 8 21 5 2 0.25 4.64 45.5 Lower

UpperMiddle

Lower

New reservoir view

500

1000

1500

2000

2500

Datos Reales

Simulacion

Petrophysical Model Validated with BU

18.2 21.931.5

128.6

117 psi

400 psi

580 psi

892 psi

0

100

200

300

400

500

600

700

800

900

1000

0

50

100

150

200

250

300

11/02 12/02 13/02 14/02 15/02 16/02 17/02 18/02 19/02 20/02 21/02 22/02

Pre

sión

BP

(ps

i)

Cau

dal-

orifi

cio

(Mm

3/d-

mm

)

Fecha (dd/mm)

Caudal Gas(Mm³/day)Orificio Cia.Open (mm)

Pre-fractura Post-minifract & 1intento de fractura

Post-minifract & 2intento de fractura

Post-fractura

Min

ifrac

t & 1

2in

tent

o de

Fra

ctur

a co

n 13

83

0

500

0 10 20 30 40 50 60

Halliburton Pumping Diagnostic Analysis ToolkitMinifrac - G Function

1 2 3 4

G(Time)

3125

3150

3175

3200

3225

3250

3275

3300

3325

3350

3375

A

0

50

100

150

200

250

300

D

(0.002, 0)

(m = 37.41)

(4.535, 169.6)

(Y = 0)

(Y = 171.3)

Bottom Hole Calc Pressure (psi)

Smoothed Pressure (psi)Smoothed Adaptive 1st Derivative (psi)Smoothed Adaptive G*dP/dG (psi)

A

ADD

21

1

2

End of PDL

Closure

Time

1.85

4.54

BHCP

3230

3130

SP

3231

3131

DP

112.8

212.5

FE

49.33

70.65

0

20

40

60

80

100

120

11/06 02/07 05/07 08/07 11/07 02/08 05/08 08/08

Gas

Mm

3/d

cal

0

20

40

60

80

100

120

140

160

180

200

PD

BP

Kg/

cm2

Caudal Gas VC.GASL

Produccion Simulada Res Fisurado Frac 20ft

QuikLook Prod Reserv Homogeneo Frac 200 ft 50% Cond

QuikLook Prod Reserv Homogeneo Frac 100ft 100% Cond

Presión Boca Pozo VC.PRESS

Evidencies of Secondary Perm Development

On Minifracs While Fracturing During Production

Petrophysical and Reservoir model Calibration

8/19 /201011 :30 12:00 12:30 13:00 13:30 14:00 14:30 15:00

8/19/201 015:30

Time

0

1000

2000

3000

4000

5000

A

0

10

20

30

40

50

60

70

B

0

1

2

3

4

5

6

7

8

9

10

C

Wellhead P ressure (psi )Slurry Rate (bpm)Actual CO2 Rate (bpm)Surface P roppant Conc ( lb /gal)Overall Pumping Rate (bpm)GOHFER Surface P ressure (psi )GOHFER Bottom Hole P ressure (ps i)GOHFER Slurry Rate (bpm)GOHFER Surface P rop Conc ( lb /ga l)GOHFER Bottom Hole P rop Conc ( lb /gal)

ABBCBAABCC

Pressure History Match

Reservoir PropertiesZona Tope Base NPAY Phie Avg Perm Avg kgh

m m ft v/v mD mD-ftSuperior 5027.5 5045.5 18.5 0.1222 0.090 1.12Superior 5048.5 5052.5 4.5 0.0897 0.015 0.02Superior 5056 5099 43.5 0.1287 0.097 4.12

Total 66.5 5.26

Production Hystory Match

Ma-1026 Gas Rate

0

50000

100000

150000

200000

250000

300000

350000

400000

450000

500000

1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61

Days

Gas

Rat

e (s

cm/d

)

-100

100

300

500

700

900

1100

1300

1500

Actual Gas Rate

Logs Review & Gohfer Frac

Prod History Match & Gohfer Frac

Actual WHP (psi)

Days

Ma-1026 Cum Gas

0

2000000

4000000

6000000

8000000

10000000

12000000

14000000

16000000

18000000

20000000

1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61

Days

Cum

Gas

(scm

)

Actual Cum GasLogs Review & Gohfer FracProd History Match & Gohfer Frac

Difference in fracture Effectiveness

430 ft EfectiveEfectiveFrac Lenght

75 ft EfectiveFrac Length

Statically analysis

Production

Normalized FracFluid Volume

Normalized Production

Normalized Prop Volume

Long term analysis

2 año 5 años 6 años

8 años 9 años 10 añosK 0.008 mD Distance 400 m2 wells 2 years + 1more wells at 5 year

Completions Volume

Less U$/LB and Gal

Fracture Design

� ShaleEval. Core, Sidewall, Cuttings

� Identify Pay Zones and barriers (ShaleLog)

� Select Frac Initiation Points and Stages

� Determine Job Size (Estimate SRV)

� Select Fluid System

� Select Proppant

� Design pump schedule.

� Pre-Frac Diagnostics (DFIT)

© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 21

� Pre-Frac Diagnostics (DFIT)

� Perform Treatment

© 2011 HALLIBURTON. ALL RIGHTS RESERVED. 22

Halliburton’s Holistic ApproachStimLOG,

SwiftLOOK and

Swift Reservoir

Analysis,

Production

Forecast and Frac

Design

Daily Work Flow Begins Here

Predict

Well

Performa

nce and

Job

Executio

n

Offset Completions

Validate Stimulation Model

Surveillance

of Results

Field Wide

Surveillance

Stimulation Design

Petrophysical and Stimulation

Model Construction

Petrophysical Model

Monthly and Quarterly Model Review

Strategic planning

for future core,

imaging, NMR, and

Dipole Sonic to aid

field wide model

Strategic planning

for future Injection

testing to refine

stress, pore

pressure, system pressure, system

permeability and

frac model

5000 5750 6500 7250 8000 8300

8200

8100

8000

7900

7800

7700

7600

7500

7400

7300

Stress Profile

Closure Stress (psi)

Permeability

Low High

Fracture Conductivity (mD·ft)

0.00 100 200 300 400 500 600 700 800 900 1000

Conductivity of each Fracture (mD·f t)

YELLOW POINT 3-1

0 250 500 750 1000

Length (ft)

Depth (ft)

0

100000

200000

300000

400000

500000

600000

700000

800000

900000

0 5 10 15 20 25 30 35 40

Time Years

Cum

ulativ

e P

rodu

ction

Oil BBL

Gas MSCF

BWPD

DecisionSpace® DesktopWell Planning

Completion Design, Production Profile

Drilling and Formation Evaluation

Fully Integrated Asset Model

Minifrac - G Function

10 20 30 40

G(Time)

2000

3000

4000

5000

6000

7000

8000

A

0

1000

2000

3000

4000

D

(0.0 02, 0 )

(m = 1 87.8)

(18.36 , 344 7)

(Y = 0)

Bottom Hole Calc Pressure (psi )

S moothed Pre ssure (psi)

1st Derivative (psi )

G*dP/dG (psi )

A

A

D

D

1

1 Closure

Time

14. 39

BHCP

5091

SP

5103

DP

2238

FE

88.47

Completion Optimization, Stimulation Executionand Fracture Mapping

Nexus®: Well Test, Production And

Production History Matching

Sub surface model

Petroleum Systems Analysis

Appraisal WellProgram

3 D Seismic Shoot

& Interpretation

© 2011 HALLIBURTON. ALL RIGHTS RESERVED.

Knowledge Network

Geología

Ing. Perforación Ing. Producción

Petrofísica

Logística

Compañías Servicios

Ing. Lodos

Ing. Reservorios Ing. Estimulación

Compañías Operadoras

Compañías Servicios

GraciasPreguntas ?

25

No two shale plays are alike. Experts must understand the“true geology” to develop tailor-made solutions.