Post on 23-Sep-2018
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
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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
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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
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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
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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.