ECLIPSE P.F

EOR Modelling within ECLIPSEEOR Modelling within ECLIPSE

David BradleyAbu Dhabi Regional Technology CenterAli Fadili, Mark Wakefield, Abingdon Technology Center

ECLIPSE EORs modelling2

ECLIPSE - EORs

Black-oil (ECLIPSE 100)PolymerSurfactantHigh pH (Alkaline)Brine – Low SalinitySolventFoam

Compositional (ECLIPSE 300)CO2 Injection


ECLIPSE 100 - Polymer

Base case:water flooding

Polymer injection

Water injection

Effective water viscosity

Polymer adsorption

Permeability reduction

Illustrative example


Main Objective decrease the water mobility reduced viscous fingering better sweep of the reservoir(oil mobility unaffected). Water is the polymer carrier

CapabilitiesWater viscosity model (modified Todd-Longstaff)Polymer Adsorption – analytical or tabulated isothermsPermeability reductionDead pore volumeShear thinning – Herschel Bulkley modelSalinity dependent polymer properties (viscosity, adsorption)( Polymer + Solvent ongoing development)

ECLIPSE 100 - Polymer

Newtonian

Shear rate

Shea

r str

ess

Herschel-Bulkley

μ

ECLIPSE EORs modelling

Shear Thinning Effect

5

nrγμττ &+= 0

Standard polymer Shear thinning: n = 1 to 0.6

Log K - layer from SPE10

PAW (Injection of polymer solution slugs alternate with water injection)

Herschel-Bulkley (yield-power-law model):


ECLIPSE 100 – Surfactant

Reduction of the residual oil saturation by injection of a surfactant solution

Residual oil before surfactant injection

Residual oil after surfactant flooding

Extra oil from upwind reservoir



Surfactant Model

Objective: Reduce oil-water surface tension and change wettability towards more water-wet to improve oil mobility.Features:

• Water phase as surfactant carrier – optional partitioning in oil phase• Oil-water surface tension as a function of surfactant concentration• Immiscible to miscible transition on kr as a function of capillary

number and surfactant concentration• Adsorption – analytical (new 2009.1) or tabulated isotherms• Wettability change (oil wet to water wet) depending on adsorption• Salinity dependent properties (adsorption, TPB flash) (new 2009.1)

• DiffusionOngoing development to handle the micro-emulsion (oil/water/surfactant mixture)


Multi-Component Brine

W O

S

1-phase

3-phase

Ion exchangeIon exchangeNa -

---

Ca

Ca Na

Salts: e.g. NaClSalts: e.g. NaCl + CaClCaCl22

Effective salinityEffective salinity

AdsorptionAdsorption Phase behaviourPhase behaviour

• Multiple salts injection• Ions exchange reactions with

rock and surfactant• Effective salinity:

• For surfactant adsorption and surfactant-water-oil phase behaviour

• For polymer adsorption• Ions transport


Surfactant Model – Salinity Effect on Adsorption

Without Salinity Effect (low adsorption)

With Salinity Effect (high adsorption)

Surfactant concentration

Surfactant adsorption

Effective salinity


High pH (Alkaline) Model (new in 2009.1)

Objective: In-situ generation of surfactants and reduction of surfactant and/or polymer adsorption

Features:• Currently a simplified alkaline model available• Alkaline tracer carried in the water phase• Reduction of polymer/surfactant adsorption with alkaline

concentration• Oil-water surface tension as a function of alkaline concentration• Alkaline adsorption – analytical or tabulated isotherms


Alkaline-Surfactant-Polymer (ASP) Flooding

Log K (layer 3 of SPE10)

Surfactant conc. limit

Alkaline conc. limit

Injection sequence simulated using ACTIONXs and UDAs

Alkaline conc.

Surfactant conc.

Polymer conc.

Log perm.


Log K

Alkaline

Surfactant

Polymer

Alkaline-Surfactant-Polymer (ASP) FloodingInjection sequence simulated using ACTIONXs and UDAs

Surfactant conc. limit

Alkaline conc. limit


Low Salinity Model (new in 2009.1)

Objective: Change of wettability towards more water wet resulting in increased waterflood recovery.

Features:• Saturation and rel. perm. end-points as a function of brine salinity• Water-oil capillary pressure as a function of brine salinity• Salinity dependent brine density and viscosity as std. brine option• Based on SPE 102239


Low Salinity Model

Hcw

Lcwcw

Hor

Loror

SFSFS

SFSFS

)1(

)1(

11

11

−+=

−+=

Hcow

Lcowcow

Hro

Lroro

Hrw

Lrwrw

PFPFP

kFkFk

kFkFk

)1(

)1(

)1(

22

11

11

−+=

−+=

−+=

Saturation end-point scaling:

Relative perm. and cap. pressure:

( ) [ ]( ) [ ]1,0

1,0

22

11

∈=∈=

salt

salt

CfFCfF


ECLIPSE 100 – Solvent

Injection of a solvent slug

Solvent slug

Field Oil Production Rate Field Solvent

Production Rate

Oil density decreases due to oil mixing with solvent

Oil viscosity decreases due to oil mixing with solvent



Main Objective To model mechanisms where injected fluids are miscible with the hydro-carbons in the reservoir (e.g. high pressure gas, LPG slug, alcohol slug , CO2)

Capabilities4-phase (water, oil, gas and solvent) or 3-phase (solvent fully mixed with oil or gas)Immiscible to miscible transition handling (via user specified miscibility function)Screening of high water saturation (in miscible gas drive residual oil is higher with higher Sw)Viscosities and densities mixing (Todd and Longstaff and 1/4th power mixing rule)PVT, kr and cap pressure as functions of the miscibility pressure (user specified)

ECLIPSE 100 – Solvent


ECLIPSE 100 – FoamIllustrative example

Reduction in gas mobility

Foam decay

Foam concentration

Foam adsorption


Main Objective: To control gas mobility to slow down the breakthrough of injected gas or gas production. Gas is the foam carrier, foam is as an active tracer.

CapabilitiesFoam adsorption: isotherm as a function of foam concentration (similar to surfactant)Foam decay (function of oil and water saturations)Gas mobility reductionShear effect (similar to polymer)

ECLIPSE 100 – Foam


CO2 as an EOR agentReduce crude oil viscosity and increase in water viscositySwelling of crude oil and reduction of oil densityAcid effect on carbonate and shell rocksMiscibility

Main ObjectiveTo model the chemical reactivity between CO2 (as a critical fluid) and the liquid phases (solubility of CO2 in the aqueous phase)

CapabilitiesModelling of the phase equilibrium between CO2 and the aqueous phaseSolubility of CO2 in the aqueous phase (viscosity and density in particular)

ECLIPSE 300 – CO2


CO2SOL/H2SSOL and GASSOL

Objective: Modelling three-phase compositional effects of CO2 behaviour

Features:• CO2SOL/H2SSOL: three-phase models with CO2/H2S solubility in

the water phase• GASSOL: generic three-phase model where any component can

dissolve in the water phase• General gas-oil compositions, but no water in oil/gas phase• Isothermal conditions


CO2SOL/H2SSOL and GASSOL

Assumptions:• Solubility data entered as a function of

– pressure (GASSOL + CO2SOL + H2SSOL)– temperature (CO2SOL)– salinity (CO2SOL)– composition (CO2SOL + H2SSOL)

• Gas phase fugacities calculated from Peng-Robinson EOS• Molecular diffusion of components can be modelled


CO2 Storage: Trapping Mechanisms

22

1: Hydrodynamic Trapping

3: Residual Trapping

2: Solubility Trapping 4: Mineral Trapping

OHHCOOHHCO

OHHHCOOHCOH

COHOHCO

22323

23232

3222

++→+

++→+

→+

+−−

+−+− +++→

++−

KCO

COOH

22H6QuartzMuscovite

22Feldspar3Ke.g.

32

22

)(SiOQuartz))(FOH)O(AlSi(KAl Muscovite

)O(KAlSiFeldsparK

2

21032

83−

√

√

√

In progress


Alkaline:

Modelling to be based on requirements gatheringSurfactant:

Salinity and rock permeability effects on adsorption

Phase behaviour for water/surfactant/oil mixture

Polymer

Salinity and rock permeability effects on adsorptionSolvent

Robustness, and numerical stability

Ali Fadili, Abingdon Technology Centre

ECLIPSE - EORsReducing the residuals

Future EnhancementsE100 - SOLVENT

To model mechanisms where injected fluids are miscible with the hydro-carbons in the reservoir

Capabilities

4-phase or 3-phase (solvent fully mixed with oil or gas)Immiscible to miscible transition handlingScreening of high water saturation Viscosities / densities mixing (T-L and 1/4th )PVT, kr and cap pressure functions of the miscibility pressure.

E100 - FOAMTo control/reduce gas mobility. Gas is the foam carrierCapabilities

Foam adsorption: isotherm as a function of foam concentrationFoam decay (with oil and water saturations)Gas mobility reductionShear thinning effects

E300 - CO2 as an EOR agentTo model the chemical reactivity between CO2 and the liquid

phases (solubility of CO2 in the aqueous phase)Capabilities

Modelling of the phase equilibrium between CO2 and the aqueous phaseSolubility of CO2 in the phases (viscosity and density effects)

0.0

0.2

0.4

0.6

0.8

1.0

0 2,000

Vo

lum

e F

ract

ion

4,000 6,000 8,000 10,000

Oleic Phase

Microemulsion Phase

Salt Concentration12,000 14,000

Aqueous Phase

Type I Type III Type II

Increasing salt concentration

E100 - POLYMERTo decrease the water mobility reduced viscous

fingering better sweep of the reservoirCapabilities

Water viscosity model (Todd-Longstaff)AdsorptionPermeability reductionDead pore volumeShear thinning (with non-Newtonian rheology)

E100 - SURFACTANTTo reduce oil-water surface tension so that water can

displace more oilCapabilities

Capillary pressure decreases with surfactant concentrationImmiscible to miscible transition for relative permeability (with Ncap and Cs) Adsorption / de-adsorptionWettability change on kr (oil wet to water wet)Partitioned tracer

Correlated Permeability Field

Polymer

New in 2008.1

Non-Newtonian Rheology: Herschel-Bulkey modelFoam

New functional model, and phase carrier


ECLIPSE Thermal– Introduction to ECLIPSE Thermal– Recent Thermal Projects Involving AbTC– Developments and Future Plans

Mark WakefieldECLIPSE Developer

[email protected]


Continued development including live oil, well models, chemical reactions, solvers …Continued client support and integration into ECLIPSE/Petrel suite

1992 Project started (Paul Naccache)Dead oil + steamFirst client: BEB in Germany

1995 First commercial release E500

2008 Current release 2008.1 (Mark Wakefield & J. Appleyard)

The ECLIPSE THERMAL Project


THERMAL/HO Processes

Foamy oil Non-equilibrium phase behaviour

CHOPS Sand transport, worm holing (Visage)

Hot water injection Viscosity reduction through heating

Cyclic Steam StimulationSteam DriveSAGD

Viscosity reduction through heatingSteam transporting more energyFormation damage


THERMAL/HO Processes

VAPour EXtractionViscosity reduction via solventAsphaltene precipitation

In-Situ Combustion, THAITM

Viscosity reduction through heatingFractional distillation / solvent floodConsumption of heavy endSteam floodCracking?Coke blocking


Some recent thermal projects involving AbTC include:ISC in VenezuelaMulti segment well comparisonsFoamy oil

Thermal Projects


Collaborating with Schlumberger Cambridge (SCR) to develop ISC models

Combustion tubes data for simulation validationOil analysis to determine a suitable reaction set and data (rates, enthalpies)

Modelled using the REACTION feature

ISC in Venezuela

Asphaltene + O2 → Gas + Water

Maltene + O2 → Gas + Water


ISC in Venezuela

Chemical reactions add source and sink terms to component conservation equationsNo additional solution variablesAdditional non-linearities to the system

– Jacobian less well conditioned– More work for the linear solver– A new time scale (fast) which needs resolving

All leads to challenging models!


925112 Temperature, oF

0.0 0.8Oil Saturation

ISC in Venezuela

Move from Lab to field time and length scalesMaintain sufficient predictive power to assess well configurations, air enrichment and run sensitivities studies

Material supplied by Aubrey O’Callaghan, Jean Gossuin & Paul Naccache.

Oxyg

enGr

avity

Reaction Front

Temp.200–725

oF

Oil Sat.

0.0 - 0.9


Multi Segment Well Inflow Control DevicesData supplied by Carlos Damas et al

Inflow

Annulus

tubing

Control Valve

Packer

Annulus Segment

Valve Segment

Tubing Segment

ICD modelled in ECLIPSE as segments with pressure losses (labyrinths, valves)


Conventional Multisegmented

5 years

10 years

Multi Segment Well ‘vs’ Conventional WellData supplied by Carlos Damas et al

Steam Chamber and Drainage Areas


Multi Segment Well Inflow Control Devices

Steam placement No ICDs

Steam Chamber and

Drainage Areas

Data supplied by Carlos Damas et al


Foamy Oil (DBR Edmonton)

Large numbers of persistent gas bubbles trapped in oil. Generated by de-pressurization of live heavy oilsNon-equilibrium behaviour, gas components take time to appearRestricted gas mobilityResults in Oil components with ideal gas-like compressibilityLiquid Vol. ~ 1 – Cp(P-Pref) Gas Volume ~ 1/P

Material supplied by David Law


Foamy Oil

Non equilibrium behaviour modelled with a kinetic model using the reactions feature instead of a flash calculations.

Trapped Gas Free GasDissolved Gas

Non-volatile

non-condensableNon-volatile

Component

VolatilityCompressibility

Liquid Gas Gas

P,T T

Material supplied by David Law

Phase Oil Oil Gas


Recent Developments – JALS Solver

ECLIPSE Thermal 2007.1 included the new JALS solverConstrained Pressure Residual (CPR) algorithm where a reduced pressure equation is additionally solvedThe additional pressure solve increases the CPU cost per linear iteration but can significantly improve the convergence rateSolver initially tested on a variety of heavy oil & thermal cases. Average CPU WARP / CPU JALS ~ 1.7Solver available in parallelThe JALS solver is under development by John Appleyard, a member of the original ECLIPSE team


JALS Solver, SAGD Example

The JALS solver consistently requires less linear iterations leading to a healthy decrease in CPU time ~ 42% reduction.

Linear iterations CPU time

JALS Warp

16,750 active cells2 multi-segmented wells2 hydrocarbon components


The JALS solver powers through the period of poor convergence leading to a substantial reduction in CPU time ~ 9.8 x

Linear iterations CPU time

JALS Warp

11,000 active cells5 multi-segmented wells2 hydrocarbon components

JALS Solver, Steam Flood Example

ECLIPSE P.F

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