formation evaluation pete 663 - tamu … evaluation pete 663 ... interpretation -2 ... evaluate...
TRANSCRIPT
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FORMATION EVALUATION
PETE 663
Summer 2010
ACOUSTIC LOGS
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POROSITY TOOLS
• Sonic (acoustic)• Density• Neutron
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APPLICATIONS OF SONIC LOGS
• Determine porosity and lithology• Determine Rwa• Determine formation mechanical
properties, like poisson’s ratio• Evaluate fractures and permeability• Evaluate overpressure in basin• Combined with density logs to produce
seismic traces (synthetic seismograms)• Evaluate cement bond
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SONIC PRINCIPLE
• Generate sound: “click”• Detect sound: hearing / recording• Analyzing sound
– How fast ?– What type of wave ?– How strong / attenuated ?
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SONIC TOOLOPERATION
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P-WAVES
• Travels thru mud & rock• Velocity depends on
– Lithology– Porosity/Pore fluid(s)
• Fastest mode– mud 5,200 ft/sec (190 μsec/ft)
– rock 18,000-25,000 ft/sec (55 – 40 μsec/ft)
• Weakest mode– Fracture insensitive
After Halliburton, 1991
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S-WAVES• Travel thru rock only• Velocity (Vs) depends
on– Lithology (weak)– Shear modulus
• Slower mode– 11,000 –14,000 ft/sec
(90 –70 μsec/ft)
• Stronger mode– Fracture sensitive– Shale sensitive
After Halliburton, 1991
Direction of travel
Mud-filledfracture
Shear wave
Mode conversion
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STONELEY WAVES• Mud + rock mode• Slowest mode (VSt)
– 3,300 – 5,000 ft/sec(300 –200 μsec/ft)
• Strongest mode– Fracture sensitive– Permeability sensitive
After Halliburton, 1991
After Ellis, 1987
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SONIC PRINCIPLE
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SONIC TOOLS
• BHC Sonic– Standard tool 1950’s - late
70’s– 3 ft & 5 ft R-T spacings– 2 ft resolution– Only measures Dtc
– Shallow reading (about 3 or 4 in)
– Damaged zone effects
After Halliburton, 1991
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SONIC PRINCIPLE -WIRELINE
• Non-pad (mandrel) tool• Pulsed transmitters
– Fire alternately– Broadband– All directions (azimuths)
• Multiple receivers– Time window– All directions (azimuths)– Multiple modes
• Borehole compensation (BHC)
After Halliburton, 1991
Transmitter
Transmitter
Receivers
Compression waves
Shear waves
Stoneley waves
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• Note ray paths for the twotransmitter-receiver sets
• Averaging the two Δtmeasurements cancels errorsfrom the sonde tilt and hole-sizechanges
SCHEMATIC OFBHC SONDE
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SONIC TOOLS
• Long spaced sonic– 8 to 13 ft R-T spacings– 1 to 2 ft resolution– Deeper reading (about
6+in)– Reads beyond damaged
zone– Usually Δts and Δ tc
After Schlumberger, 1989
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SONIC TOOLS• Array/full-wave tool
– Long R-T spacings– Deep reading (about 6 to
18 in)– High resolution (6in)– Downhole processing– All modes Δ t’s and
amplitudes• Dipole tool
– As array tool and– Shear in soft formations
After Schlumberger, 1989
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CAUSES OF BAD SONIC LOGS
• Road noise
• Cycle skipping
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• Caused by tool movement along the borehole, generating a high frequency noise component that is superimposed onto the normal acoustic signal
• Far sonic detectors are more affected by road noise than near detectors because of the reduced signal amplitude with increased travel time
ROAD NOISE
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• Attenuation (decreased amplitude) of the compressional acoustic wave is the major cause of poor sonic logs
• Attenuation results in the signal at the receiver crossing the threshold amplitude later than for a stronger signal.
ATTENUATION
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CAUSES OF BAD SONIC LOGS
• Low sonic transmitter strength may
result in less than optimal receiver
signal amplitudes
• Under extreme conditions this will
result in cycle-skipping
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CYCLE SKIPS
Occurrences• If the threshold level is set low• If there are washouts• Presence of gas in mud
Cycle skips occurs when only one of a pair of receivers is triggered by an arriving wave, which causes sharp deflections on the log.
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MEASUREMENT PRINCIPLE
Threshold level
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THEORY OF CYCLE SKIPS
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Abrupt spikes in sonic log indicates cycle skips
CYCLE SKIPS
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Ray, 2002
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SONIC AS A POROSITY TOOL
Sonic affected by:Primary1. Lithology2. PorositySecondarily1. Fluids2. Compaction/consolidation
APPLICATIONS -
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Δtc INTERPRETATION - 1
Transit time Δt or slowness• Transit time is the reciprocal of velocity•Unit : Δt = μsec/ft or μsec/m•Two porosity models
– Wyllie time average (clean, consolidated fm)
– Raymer-Hunt-Gardener
matfltmatlogt
s Δ−ΔΔ−Δ
=φ
log
malog7.0s ttt
ΔΔ−Δ
=φ
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Δtc INTERPRETATION - 2
•Wyllie Typical values (μsec/ft)– Matrix Δt: 51-55 SS; 47.5 LS; 43.5 DOL– Fluid Δt: 189 - salt water
218 – fresh water238 – oil626 – methane
•RHG Typical values (μsec/ft)– Matrix Δt: 56 SS; 49 LS; 44 DOL
matfltmatlogt
s Δ−ΔΔ−Δ
=φ
log
malog7.0s ttt
ΔΔ−Δ
=φ
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CHARTPor-3 (S)
Por-11 (H)
φ = 26.7%
From log:Δt = 90 μsec/ ft
Assume:Δt f = 189 μsec/ ft
Matrix isQuartz
(Δt 55.6 μsec/ ft)
matfltmatlogt
s Δ−ΔΔ−Δ
=φ
6.551896.5590
s −−=φ
4.1334.34
s=φ
8.25s=φ WTA
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Δtc INTERPRETATION - 3Estimating Rw: The Rwa Method• Needs porosity and resistivity logs• Assumes
– Archie’s (second) law– Sw < 1 tRm
waRnwS
φ=
wRwaR
wRFtR
FtRwR
Snw
≥
≥
≤=
so
or 1/• Define Rwa = Rt/F
• Calculate Rwa
• Take (Rwa)min = Rw
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RWA EXAMPLE - PROJECT 3 LOGS140 Δt 40
0.2 Rild 20
• SS @ 156 ft:– Rild = 0.32Ω-m– Δt = 83μs/ft
• Chart φ = 23%
• Assume– a = 0.81– m = 2(Tixier)F = 0.81/φ2
• F = 15• Rwa = Rild/F
= 0.32/15= 0.021 Ω-m
0.32 Ω-m
83 μs/ft
F = _a_ φ m
a is a constant;m is cementation factor
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RWA EXAMPLE - 2 140 Δt 400.2 Rild 20
Depth Δt φ Rild Rwa
125 87 25 45 3.5
156 83 23 0.32 0.021
204 90 26 0.30 0.025
Two further points• Works best in clean formations• Applies to flushed zone, too
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SONIC FAMILY TOOLS & APPLICATION
Open Hole Cased Hole
Mechanical Properties
Formation Evaluation
Casing BondCasing Corrosion
Youngs ModulusBulk Modulus
Sheer ModulusPoisson Ratio
Velocities
PorosityGas Identification
Lithology
Cement QualityReservoir Isolation
Casing Quality
Perforation...Reservoir AppraisalFluid Determination
Seismic ParametersSeismic Calibration
Application
Output
Final Use
Borehole
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APPLICATIONS OF SONIC LOGS
• Determine porosity and lithology• Determine Rwa• Determine formation mechanical
properties, like poisson’s ratio• Evaluate fractures and permeability• Evaluate overpressure in basin• Combined with density logs to produce
seismic traces (synthetic seismograms)• Evaluate cement bond
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SONIC LOGS USED FORFRACTUREDETECTION
In fractures, amplitude of stonely waves and shear waves are attenuated.
Red – least attenuated
Blue – highly attenuated
Fractures
Fractures
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SONIC AS A POROSITY TOOLSonic affected by:• Lithology• Porosity• Fluids• Compaction/consolidation• Borehole conditions• Gas in drilling mud
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SUMMARY• Sonic physics
– Several modes– Borehole compensation
• Tools and spacings
• Interpretation– Two Δt models for porosity– Rwa method
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SANDSTONE POROSITY
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WATER-WET OIL-WET
Ayers, 2001FREE WATER
GRAIN
SOLID (ROCK)
WATER
OIL
θ
SOLID (ROCK)
WATER
OIL
θ
GRAIN
BOUND WATER
FREE
WAT
ER
OIL
OILRIM
θ < 90° θ > 90°WATER
θθ
OilAir
WATER
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Modfied from Jordan and Campbell, 1984, vol. 1
VARIATION IN PORE PROPERTIES AND PERMEABILITYWITHIN A FORMATION
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GEOLOGICAL AND PETROPHYSICAL DATA USED TO DEFINE FLOW UNITS
FlowUnits
Gamma RayLog
PetrophysicalData
PoreTypesLithofaciesCore
1
2
3
4
5
CorePlugs
CapillaryPressureφ vs k
Modified from Ebanks et al., 1992
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Sedimentary Facies vs. Porosity
0 5 10 15 20 25 30Porosity (%)
S2
S11'
S11
S3
Faci
es
ø= 1
2%
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PRIMARY (ORIGINAL) POROSITY• Developed at deposition
• Typified by• Intergranular pores of clastics or carbonates• Intercrystalline and fenestral pores of carbonates
• Usually more uniform than secondary porosity
SECONDARY POROSITYDeveloped after the sediments were deposited
• More complex and usually less predictable than primaryporosity
• Typified by- Dissolution pores of clastics or carbonates- Cementation (clays)
- Fractures
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FACTORS AFFECTING PERMEABILITY
• Size and shape of grains• Sorting• Rock – fluid interactions
– Dissolution– Cementation
• Fractures• Stress• Formation damage
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FACTORS THAT AFFECT POROSITY
• Particle sphericity and angularity• Packing• Sorting (variable grain sizes)• Texture
• Cementing materials• Overburden stress (compaction)• Vugs, dissolution, and fractures
PRIMARY
SECONDARY (DIAGENETIC)
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PACKING AND SORTINGOF SPHERES (CLASTICS)
Porosity = 48% Porosity = 27 %
COMPARE SIZES OF PORESAND PORE THROATS
Porosity = 14%
Packing of Two Sizes of SpheresPorosity = 14%
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GRAIN-SIZE SORTING IN SANDSTONE
Very WellSorted
WellSorted
ModeratelySorted
PoorlySorted
Very PoorlySorted
SORTING
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Change of Composition Change of Size
Change of Shape Change of Orientation
Change of Packing
Sand
Shale
Eolian
Fluvial
Slow CurrentFast Current
River
Beach
TYPES OF TEXTURAL CHANGES SENSEDBY THE NAKED EYE AS BEDDING
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SANDSTONE COMPOSITION,Framework Grains
Norphlet Sandstone, Offshore Alabama, USAGrains ~0.25 mm in Diameter/Length
PRF KF
P
KF = PotassiumFeldspar
PRF = Plutonic RockFragment
P = Pore
Potassium Feldspar isStained Yellow With aChemical Dye
Pores are Impregnated WithBlue-Dyed Epoxy
Q
Q = Quartz
Photo by R. Kugler
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PORE-SPACE CLASSIFICATION
• Total porosity, φt =
• Effective porosity, φe =
VolumeBulkPoreVolumeTotal
VolumeBulkVolumePorectedInterconne
• Effective porosity – contains the mobile fluid
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DIAGENETIC PROCESSES
Examples 1. Compaction2. Cementation3. Grain dissolution in sandstones or carbonates4. Vugs and solution cavities in carbonates5. Fractures
• “Diagenesis” includes all physical and chemicalchanges that affect sediments after deposition
• Diagenetic processes may increase or decreaseporosity and/or permeability
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MECHANICS OF COMPACTION
Modified from Jonas and McBride, 1977
Platy Grains(e.g., clays)
Non-Platy Grains(e.g., qtz., feldspar)
Rotation and CloserPacking
Ductile GrainDeformation
Breakage of Brittle Grains
Pressure SolutionAt GrainContacts
Ductile FrameworkGrain, e.g., Shale RockFragment
ChemicalCompaction -
Styolites
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Influence Of Clay-Mineral DistributionOn Effective Porosity
Dispersed Clay• Pore-filling• Pore-lining• Pore-bridging
Clay Lamination
Structural Clay(Rock Fragments,
Rip-Up Clasts,Clay-Replaced Grains)
φe
φe
φe
ClayMinerals
Detrital QuartzGrains
φe
eφ
Greatest affect - ΔT
Slight affect - ΔT
Little affect - ΔT
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HOW DO SHALES/CLAYS OCCUR? - 2
Laminated Shale– Interlayered with sand– Reduces por., perm.– Common– Example – shale
laminae– Assume composition
similar to nearby shale
Clay Lamination
φe ClayMinerals
Detrital QuartzGrains
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TYPES OF SANDSTONES POROSITY
Intergranular
Dissolution
Micropores
Fractures
Interstitial Void Space BetweenFramework Grains
Partial or Complete Dissolution of
Framework Grains or CementSmall Pores Mainly Between Detrital
or Authigenic Grains (Can Also OccurWithin Grains
Breakage Due to Earth Stresses
Primary
Secondary
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FOUR COMPONENTS OF SANDSTONE
MATRIXFRAMEWORK
(QUARTZ)
FRAMEWORK(FELDSPAR)
CEMENT
PORE
Note different use of “matrix”by geologists and engineers
0.25 mm
1. Framework2. Matrix3. Cement4. Pores
Engineering“matrix”
Geologist’s Classification
Ayers, 2001
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SANDSTONE COMPOSITION,Framework Grains
Norphlet Sandstone, Offshore Alabama, USAGrains ~0.25 mm in Diameter/Length
PRF KF
P
KF = PotassiumFeldspar
PRF = Plutonic RockFragment
P = Pore
Potassium Feldspar isStained Yellow With aChemical Dye
Pores are Impregnated WithBlue-Dyed Epoxy
Q
Q = Quartz
Photo by R. Kugler
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DUAL POROSITY IN SANDSTONE
MATRIX
FRAMEWORK(QUARTZ)
FRAMEWORK(FELDSPAR)
CEMENT
PORE
0.25 mm
Sandstone Comp.• Framework• Matrix• Cement• Pores
DISSOLUTIONPORE
FRACTURE
1. Primary and secondary “matrix” porosity system2. Fracture porosity system3. Diagenesis
Ayers, 2001
CLAY
2nd STAGE CEMENT
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From Laubach et al., 1996
FRACTURECHARACTERISTICS
FROM MICROSCOPICTHIN SECTIONSOF SANDSTONE
Fractures cross grainsand cements
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PORE-LINING MINERALSIN SANDSTONE
Scanning Electron MicrographNorphlet Formation, Offshore Alabama, USA
Pores Provide theVolume to StoreHydrocarbons
Pore Throats RestrictFlow
PoreThroat
Photomicrograph by R.L. Kugler
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CEMENTATION AND ROCK –FLUID INTERACTIONS
Scanning Electron MicrographTordillo Sandstone, Neuquen Basin, Argentina
Pore Throats inSandstone MayBe Lined WithA Variety ofCement MineralsThat AffectPetrophysicalProperties
Photomicrograph by R.L. Kugler
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INTERGRANULAR PORE AND MICROPOROSITY
IntergranularPore
Microporosity
Kaolinite QuartzDetritalGrain
Intergranular PoresContain HydrocarbonFluids
Micropores ContainIrreducible Water
Backscattered Electron MicrographCarter Sandstone, Black Warrior Basin,Alabama, USA (Photograph by R.L. Kugler)
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Secondary Electron Micrograph
Clay Minerals in Sandstone Reservoirs,Authigenic Chlorite
Jurassic Norphlet SandstoneOffshore Alabama, USA (Photograph by R.L. Kugler)
Occurs as ThinCoats on DetritalGrain Surfaces
Occurs in SeveralDeeply BuriedSandstones WithHigh Reservoir Quality
Iron-Rich Varieties ReactWith Acid
~ 10 μm
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Clay Minerals in Sandstone Reservoirs,Authigenic Kaolinite
Secondary Electron Micrograph
Carter SandstoneNorth Blowhorn Creek Oil UnitBlack Warrior Basin, Alabama, USA
Significant PermeabilityReduction
High Irreducible WaterSaturation
Migration of FinesProblem
(Photograph by R.L. Kugler)
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Electron Photomicrograph
Clay Minerals in Sandstone Reservoirs,Fibrous Authigenic Illite
Jurassic Norphlet SandstoneHatters Pond Field, Alabama, USA (Photograph by R.L. Kugler)
Illite
SignificantPermeabilityReduction
Negligible PorosityReduction
Migration ofFines Problem
High IrreducibleWater Saturation
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DISSOLUTION POROSITY
Thin Section Micrograph - Plane Polarized LightAvile Sandstone, Neuquen Basin, Argentina
Dissolution ofFramework Grains(Feldspar, for Example) and Cement may Enhance theInterconnected Pore System
This is SecondaryPorosity
Pore
Quartz DetritalGrain
PartiallyDissolvedFeldspar
Photo by R.L. Kugler
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DISSOLUTION POROSITY
Scanning Electron MicrographTordillo Formation, Neuquen Basin, Argentina
PartiallyDissolvedFeldspar
Dissolution PoresMay be Isolated andnot Contribute to theEffective Pore System
Photo by R.L. Kugler
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CARBONATE POROSITY
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CARBONATES POROSITY TYPESInterparticle
Intraparticle
Intercrystal
Moldic
Pores between particles or grains
Pores within individual particles or grains
Pores between crystals
Pores formed by dissolution of anindividual grain or crystal in the rock
Fenestral
Fracture
Vug
Primary pores larger than grain-supportedinterstices
Formed by a planar break in the rock
Large pores formed by indiscriminatedissolution of cements and grains
Generally, porosity in carbonates is lower thanin clastics, and its occurrence is more complex
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Interparticle Intraparticle Intercrystal Moldic
Fenestral Shelter Growth-Framework
FabricSelective
Fracture Channel Vug
Non-FabricSelective
Breccia Boring Burrow Shrinkage
Fabric Selective or Not Fabric Selective
Idealized Carbonate Porosity Types
(modified from Choquette and Pray, 1970)
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CARBONATE POROSITY - EXAMPLE
Thin section micrograph - plane-polarized lightSmackover Formation, Alabama (Photograph by D.C. Kopaska-Merkel)
MoldicPores
• Due to dissolutionand collapse of ooids(allochemical particles)
• Isolated pores
• Low effective porosity
• Low permeability
Blue areas are pores.Calcite
Dolomite
MoldicPore
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CARBONATE POROSITY - EXAMPLE
Thin section micrographSmackover Formation, AlabamaBlack areas are pores.
(Photograph by D.C. Kopaska-Merkel)
• Combination pore system
• Moldic pores formed throughdissolution of ooids (allochemicalparticles)
• Connected pores
• High effective porosity
• High permeability
MoldicPore
InterparticlePores
Moldic andInterparticle Pores
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APPLICATIONS OF SONIC LOGS
• Determine porosity and lithology• Determine Rwa• Determine formation mechanical
properties, like poisson’s ratio• Evaluate fractures and permeability• Evaluate overpressure in basin• Combined with density logs to produce
seismic traces (synthetic seismograms)• Evaluate Cement bond