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Shale & tight reservoir simulation cmg
1. Shale & Tight Reservoir Simulation
Jim Erdle - VP/USA & LA
OCTOBER 2012
2. AGENDA
How CMG’s simulators are being used
oShale/Tight reservoir modelling features
oShale/Tight reservoir modelling workflows
How other simulators are being used
Shale Operators using CMG’s simulators
SPE References
4. MODELLING FEATURES
PVT
oBlack Oil treatment (IMEX)
primary production of dry gas, wet gas, black oil, volatile oil and gas condensate reservoir fluids
oMulti-component EOS Treatment (GEM)
Adds ability to model Multi-Component fluids including non-HC gases (e.g. CO2, H2S, acid gas, Flue Gas & N2) for EOR
5. MODELLING FEATURES
Single vs Dual Porosity
oSingle Porosity if no open natural fractures
oDual Permeability if open natural fractures
6. MODELLING FEATURES
Adsorped Components
oSingle gas component (new in IMEX for 2012)
oMultiple gas or oil components (GEM)
7. MODELLING FEATURES
Diffusion
oMulti-component molecular diffusion (GEM)
Competitive with darcy flow in some very low matrix perm situations
Injection of solvents to aid liquid recovery (e.g. CO2, propane, etc.)
Sequestration of CO2, acid gas, etc.
8. MODELLING FEATURES
Relative Perm & Capillary Pressure
oIndependent curves for matrix, natural fractures & propped fractures
Usually straight line for natural & propped fracs
Matrix can be oil-wet or water-wet (which is it?)
Can include hysteresis if modelling solvent injection
Can also include wettability alteration via relative permeability interpolation (new in GEM for 2012)
9. MODELLING FEATURES
Compaction/Dilation
oPressure-dependent Compaction/Dilation tables for modelling degradation of permeability & porosity
In propped fractures, natural fractures & matrix, including hysteresis for modelling shut-in periods
oEffective Stress-dependent Compaction/Dilation tables when using GEOMECH (GEM)
Barton-Bandis approach for modelling of natural fracture perm vs Effective Stress
11. MODELLING FEATURES
Initial Fluid Saturations
oNon-equilibrium initialization of fluids for modelling presence and flowback of frac fluids in propped & natural fractures
12. MODELLING FEATURES
Explicit Gridding of Propped Fractures
oLS-LR-DK (TARTAN) grids to model propped fracs
oSingle Plane or Complex geometry
oNon-Darcy flow in propped fracs
14. MODELLING FEATURES
Explicit Gridding of Propped Fractures
oAutomatic generation of TARTAN grids (BUILDER)
oSRV delineation (BUILDER)
Import & Filtering of Micro Seismic data
Interactive selection on simulation grid display
oTARTAN grids can be applied to any parent grid geometry
Cartesian & Corner Point Grids
16. MODELLING FEATURES
Time-dependent Propped Fractures
oTARTAN grids can be added when wells are fracked
Don’t have to put all grids in place at beginning of run!
Efficient way to model re-fracs & multi-well models
oCompaction/Dilation Tables (with Hysteresis) can be time-dependent (coming in Dec 2012)
17. MODELLING WORKFLOW
2.Build single well base models
5.Build multi-well models
3.Perform SA & AHM on single well models
4.Forecast EUR for single well models
6.Perform OPT of multi-well models
1.Choose CMG simulator with required physics
18. Base Case Results
Initial model with assumed values does not match historical production data
oToo much gas produced
oNot enough water produced
19. Sensitivity Analysis using CMOST
Reservoir parameter uncertainty
oFracture Permeability
oFracture Width
oPressure Dependent Permeability of Fracture (CROCKTAB)
oLangmuir Adsorption parameters
oDiffusivity
oInitial Water Saturation in Fractures (to model water from the HF fluid)
23. History Match – Final Results
History match error reduction
oOverall HM error reduced from 55% to 1.4%
oFinal Gas Rate Match error = 0.70%
oFinal Water Rate Match error = 2.13%
Total Calendar Time to complete HM
oEngineering Time = 10 hours
oComputing Time = 15 hours (8 concurrent 2-way parallel jobs)
oTotal calendar time = 25 hours
27. ANOTHER APPROACH TO GRIDDING
TARTAN grids = Same Results in 1/10 the time!
0
1000
2000
3000
4000
5000
6000
0 2000 4000 6000 8000 10000 12000
Pressure
Time
Mangum
400 500 600 700 800 900 1,000
400 500 600 700 800 900 1,000
-200 -300 -400 -500 -600
-600 -500 -400 -300 -200
0.00 75.00 150.00 feet
0.00 25.00 50.00 meters
File: cmg_local grid refinement.irf
User: kpatel
Date: 7/27/12
Scale: 1:1148
Y/X: 1.00:1
Axis Units: ft
791
1,193
1,596
1,998
2,401
2,803
3,205
3,608
4,010
4,413
4,815
Pressure (psi) 2039-11-24 K layer: 1
Pressure 40 ft from propped frac is the same!
28. USING CMG FOR SHALE/TIGHT RESERVOIRS
•Anadarko
•Apache
•BG Group
•BHP Billiton
•BP
•Chesapeake
•Chevron
•Devon
•Encana
•EOG
•ExxonMobil
•Marathon
•Matador
•Noble Energy
•Reliance
•Rosetta Resources
•Samson
•Shell
•Statoil
•Talisman
•Total
•Venoco
•Vitruvian
•XTO
29. SPE REFERENCES
CSUG/SPE 148710-PP “Shale Gas Modeling Workflow: From Microseismic to Simulation – A Horn River Case Study”
oJoint paper with CMG and NEXEN
IPTC-14940 “Evaluation in Data Rich Fayatteville Shale Gas Plays – Integrating Physics-based Reservoir Simulations with Data Driven Approaches for Uncertainty Reduction”
oby Yitian Xiao et al (ExxonMobil) presented at 2012 IPTC Bangkok
30. SPE REFERENCES
SPE 147596 “Shale Oil Production Performance from a Stimulated Reservoir Volume”
oby A.S. Chaudhary, C. Economides & R. Wattenbarger (TAMU) presented at 2011 ATCE - Denver
SPE 146975 “Heat Transfer Applications for the Stimulated Reservoir Volume”
oby S. Thoram & C. Economides (TAMU) presented at 2011 ATCE - Denver
31. SPE REFERENCES
SPE 132093 “Accurate Simulation of Non-Darcy Flow in Stimulated Fractured Shale Gas Reservoirs”
oby B. Rubin (CMG) presented at 2010 WRM – Anahiem