SIFAT
FISIKA
BATUAN
dan FLUIDA
1
Sifat Fisik Batuan Reservoir
Sifat fisik Batuan:
Porosity
Pore size distribution
Permeability
Formation compressibilit compressibility y
Sifat statis batuan-fluida (interaksi batuan & fluids di dalam pori):
Wettability & contact angle
Capillary pressure & interf interfacial acial tension
Irreducible & connate water saturation
Residual oil saturation
Sifat Dinamis batuan-fluida (interaksi batuan & fluida):
Relative Relativ e permeability
Mobility
Saturation Satur ation distribution during immiscible fluid displacement
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Sifat Fisik Batuan Reservoir
Sifat fisik Batuan:
Porosity
Pore size distribution
Permeability
Formation compressibilit compressibility y
Sifat statis batuan-fluida (interaksi batuan & fluids di dalam pori):
Wettability & contact angle
Capillary pressure & interf interfacial acial tension
Irreducible & connate water saturation
Residual oil saturation
Sifat Dinamis batuan-fluida (interaksi batuan & fluida):
Relative Relativ e permeability
Mobility
Saturation Satur ation distribution during immiscible fluid displacement
2
Properties of the Rock Material
Porosity or primary porosity - dibentuk bersamaan dgn pengendapan batuan, terkompaksi dan tersemen bersama menjadi matriks
Original
or secondary porosity - berkembang akibat proses geologi yang terjadi setelah pengendapan
Induced
Total
po rosity - total rongga batuan dibagi bulk volume batuan porosity
porosity - ratio rongga yang saling saling berhubungan berhubungan terhadap bulk volume batuan
Effective ctive Effe
3
Properties of the Rock Material
Porosity
Porosity
Void Volume Bulk Volume
Effective Porosity e
Total Porosity T Bulk Volume
Interconnected Pore Volume Bulk Volume
Total Pore Volume Bulk Volume
Rock Volume occupiedby solidgrains
Void volume beween cementedgrains 4
Properties of the Rock Material
Porosity
Pore Space in Packing of Uniform Spheres
Sandstones = 1% - 38% rata-rata = 20%
Limestone & dolomite rata-rata = 10%
5
Properties of the Rock Material
Permeability – Persamaan Darcy’s Persamaan
Darcy’s untuk aliran horizontal linear melalui
media pori Q
dimana: q = volumetric rate (cm3 /sec)
q
k A
p1 p
k = permeability (darcies) 2
L
μ
A = area (cm2)
p2
A
m = viscosity (cp) L p
Q
k
q μ L Ap1 p2
p1
p1 = upstream pressure (atm) p2 = downstream pressure (atm) L = length of porous media (cm)
6
Properties of the Rock Material
Permeability – Persamaan Darcy’s
Batuan
memiliki permeabilitas satu Darcy akan mengalirkan fluida berviskositas satu centipoise melalui luasan satu cm2 dengan laju alir satu centimeter cubic per detik pada gradient tekanan sebesar satu atmosphere per cm.
Biasanya 1 Darcy terlalu besar untuk ukuran batuan reservoir, sehingga millidarcy, merupakan satuan yang biasa digunakan
1000 md = 1 D
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Properties of the Rock Material Permeability – Persamaan Darcy’s
Persamaa
Darcy’s untuk aliran horisontal / linier :
1.1271x103 k A p1 p2 q μ L q = volumetric flow rate of liquid (bbl/day) k = permeability (md) A = flow area (ft2) p1 = upstream pressure (psi) p2 = downstream pressure (psi)
m = fluid viscosity (cp) L = thickness of porous media (ft) 8
Properties of the Rock Material
Permeability – Persamaan Darcy’s
Asumsi
persamaan Darcy’s adalah:
Aliran Incompressible flow
Viskositas konstan
Aliran laminar sangat pelan
Aliran Steady state
Ketika menggunakan persamaan Darcy’s, apakah batasab tersebut sepenuhnya dapat terpenuhi untuk mendapatkan permeability menjadi akurat ? 9
Properties of the Rock Material
Permeabilitas Absolute dan Effective
Permeabilitas Sifat
batuan & bukan fluida yang mengair melaluinya, menyebabkan fluida 100% mensaturasi seluruh pori batuan
Permeabilitas Absolute Permeabilitas Permeabilitas
batuan yang di saturasi satu jenis fluida
Effective
Permeabilitas
batuan bila pada batuan tersebut disaturasi oleh lebih dari satu fluida
Jumlah
dari permeabilitas effective utk fluida yang berlainan selalu < permeabilitas absolute-nya 10
Static Rock-Fluid Properties
Wettability
Wettability - kecenderungan satu fluida ter-adesi di permukaan padatan dibandingkan fluida taktercampur lainnya Forces in Equilibrium at Oilwater Interface
Sudut kontak < 90° (water-wet) Sudut kontak > 90° (oil-wet) Sudut kontak = 90° (neutral)
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Static Rock-Fluid Properties
Wettability Pada
umumnya reservoirs, merupakan:
25%
water-wet
25%
oil-wet
50%
intermediate or mixed wettability Sand Grain
Sand Grain
Water
Oil Water
Oil
Oil Wet
Water Wet
Efficiency
Pendesakan fluida nonwetting mendesak fluida membasahi biasanya lebih kecil dibandingkan fluida wetting terhadap non-wetting 12
Static Rock-Fluid Properties
Wettability
Drainage
- apabila fasa non-wetting displaces fasa wetting
Imbibition –
apabila fasa wetting displaces fasa non-wetting 13
Static Rock-Fluid Properties
Wettability
Wettability
dapat diidentifikasi dengan cara:
Apabila
air produksi memiliki komposisi sama dengan air conat, reservoir bersifat water-wet.
Apabila
air produksi sama dengan air injeksi, ada dua kemungkinan: Reservoir
adalah oil-wet.
Air
injeksi melewati zona porous yang sangat tipis atau fracture, dan karenanya tidak mempunyai kesempatan kontak secara cukup dengan connat water kecuali pada sistem dengan proses water breakthrough yang lama
14
Static Rock-Fluid Properties
Capillary Pressure
pressure - perbedaan tekanan antar muka dua fluida tidak membasahi pada sistem kapiler (porous)
Capillary
15
Static Rock-Fluid Properties
Capillary Pressure
Hubungan
antara saturasi air, Sw, pada setiap titik di media pori dengan tekanan kapiler-nya didefinisikan sebagai capillary-pressure curve
Dua
tipe:
curves - memperlihatkan perubahan saturasi fasa nonwetting mendesak fasa wetting
Drainage
curves - memperlihatkan perubahan saturasi fasa wetting mendesak fasa non-wetting
Imbibition
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Static Rock-Fluid Properties
Capillary Pressure Example of a typical capillary pressure curve and the corresponding vertical fluid distribution in the reservoir
Capillary Pressure Curve menyatakan distribution air di dalam reservoir
Terdapat interval saturation yang secara gradual berubah dari 100% hingga saturasi air konate < 20%
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Static Rock-Fluid Properties
Capillary Pressure
Layer
yang kurang permeabel memiliki zona transisi yang lebih lebar dan Saturasi air konat lebih besar
Kesalahan
dalam menentukan Tekanan Kapiler dapat menyebabkan estimasi OOIP yang optimistik
Capillary
pressure curves menyatakan sifat sample & kehatihatian diperlukan ketika scaling up ke skala reservoir
Untuk
menjamin distribusi saturasi dari data pengukuran tekanan kapiler, saturasi harus dikalibrasi terhadap logs
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Static Rock-Fluid Properties
Capillary Pressure
Sw = Swir
5000
h t p e D
Top of OW Transition Zone
OWC 5800 0
100%
Water Saturation, Swc 19
Irreducible & Connate Water Saturation Irreducible
Minimum saturation pada capillary pressure curve vertical
Maximum saturation tanpa aliran air
Connate
water saturation, Swir
water saturation, Swc
Saturasi air asli dalam reservoir – yang dapat lebih besar atau sama dengan Swir
Jika Swc > Swir berarti fasa mobile
Pada beberapa perhitungan reservoir, irreducible & connate water saturations dapat diasumsikan identik
Dipengaruhi oleh wettability batuan - cenderung lebih rendah pada batuan oil-wet dibandingkan pada water-wet rocks 20
Dynamic Rock-Fluid Properties
Relative Permeability
Relative
permeability - perbandingan permeabilitas effective terhadap
permeabilitas absolute-nya
keff kr kabs
Persamaan Darcy's, aslinya diformulasikan untuk digunakan pada media pori yang disaturasi hanya dengan satu fluida . . yaitu air
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Dynamic Rock-Fluid Properties
Relative Permeability dz ko A dpo = g ρo qo ds μo ds
kro =
ko k
dz kg A dpg qg = ds - ρg g ds μg
krg =
kg k
dz k w A dpw - ρw g qw = ds μw ds
krw =
kw k
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Dynamic Rock-Fluid Properties
Pengaruh Wettability pada Relative Permeability
Examples of relative permeability curves
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Kharakteristik
water-oil relative permeability untuk waterwet & oil-wet reservoirs: n 1.0 o i t c a r 0.8 F y t i l i 0.6 b a e m r 0.4 e P e v i t 0.2 a l e R 0
Oil
Water
0
20
40
60
80
100
Water Sat., % PV
Typical water/oil relative permeability characteristics - strongly water-wet rock
n 1.0 o i t c a r 0.8 F n o y i t t i l c a i r 0.6 b F a y e i t l i m r b e 0.4 a P e e m v r e i t P 0.2 a l e e i v R t a l 0 e
R 0
Oil Water 20
40
60
80
100
Water Sat., % PV
Typical water/oil relative permeability characteristics - strongly oil-wet rock
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Dynamic Rock-Fluid Properties
Pengaruh Wettability pada Relative Permeability
Craig “rules of thumb” Water-Wet
Oil-Wet
Connate water saturation
Usually greater than 20 -25%PV
Generally less than 15%PV Frequently less than 10%PV
Saturation at which oil and water relative permeabilities are equal
Greater than 50% water saturation
Less than 50% water saturation
Relative permeability to water Generally less than at maximum water saturation 30% (i.e., floodout)
Greater than 50% and approaches 100%
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Dynamic Rock-Fluid Properties
Pengaruh Wettability pada Relative Permeability
Ini adalah oil-water relative permeability plot untuk "T" Sand di lapangan KB
Menggunakan Craig rules of thumb, apa jenis batuan reservoir
“T” sand ?
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Dynamic Rock-Fluid Properties
Pengaruh Wettability pada Relative Permeability
Swir sample Irreducible core dari water lab: saturation
0.20
Sorw
Residual oil saturation to water
0.48
Swc
Connate (initial) water saturation
0.20
Sgc
Critical gas saturation
0.00
Sorg
Residual oil saturation to gas
0.54
ew
Exponent for k rw equation
1.6
eow
Exponent for k row equation
2.0
eg
Exponent for k rg equation
2.0
eog
Exponent for k rog equation
3.0
krwro
Water relative permeability at residual oil (to water)
0.02
krocw
Oil relative permeability at connate water saturation
0.73
k
Gas relative permeability at residual oil (to gas at connate water
0.3
rgro Calculate krw, krog, krow, and kro for the values of Sw listed in the table in saturation) your manual. This is an oil-water system. 27
Dynamic Rock-Fluid Properties
Mobility
Pada
persamaan Darcy’s, mobility sebagai berbanding lurus dengan kecepatan alir fluida dan berbanding terbalik terhadap gradien tekanan kw Jadi water mobility is: μw ko dan
oil mobility is:
μo
- ukuran seberapa mudah satu fluida melalui reservoir pada kondisi batuan dan fluida tertentu
Mobility
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Dynamic Rock-Fluid Properties
Distribusi Saturasi Selama Pendesakan Fluida Tak Tercampur
Miscible displacement - apabila dua fluida dapat bercampur secara proporsional dan tak terpisahkan menjadi dua fasa
Minyak dan Air tidak dapat bercampur, sehingga merupakan fluida tak tercampur.
Immiscible displacement – apabila air mendesak minyak seperti pada water drive atau project injeksi air.
Secara Umum, karena air mendesak minyak, maka akan terjadi distribusi saturasi yang seragam pada suatu daerah diskontinuitas saturasi didepannya setelah pemindahan oleh air. 29
Dynamic Rock-Fluid Properties
Distribusi Saturasi Selama Pendesakan Fluida Tak Tercampur Schematic of Saturation Profile (After Slider)
Penampang
bagian water drive reservoir dengan distrbusi saturasi uniform.
Hubungan
saturasi terhadap jarak distance diperlihatkan pada gambar bawah.
Slider, H. C., “Practical Petroleum Reservoir Engineering 30 Methods”, Petroleum Publishing Corp.
Dynamic Rock-Fluid Properties
Distribusi Saturasi Selama Pendesakan Fluida Tak Tercampur Minyak
bergerak kearah sumur produksi dan air masuk dari aquifer atau sumur injeksi, distibusi saturasi akan berubah terhadap : Fluid Displacement Characteristics with Initial Distribution (After Slider)
31
Dynamic Rock-Fluid Properties
Perhitungan Saturasi Selama Pendesakan
Example oil-water relative permeabilities
Fraksi
fluida pendesak dibelakang front akan meningkat terhadap jarak
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Dynamic Rock-Fluid Properties
Penentuan Kurva Fractional Flow Example of Fraction Flow Curve (After Slider)
Fraksi
air f w disebut water cut
Dasar
fractional flow :
Metode
Analitis didasarkan pada material balance dari 2 fasa fluida incompressible
Assumsi
system reservoir homogeneous 33
Dynamic Rock-Fluid Properties
Penentuan Kurva Fractional Flow Fractional
flow untuk air mendesak minyak: qw f w qw qo
Sesuai
persamaan, asumsi aliran horizontal & tekanan kapiler diabaikan : f wNO
1
kro μw 1 krw μo
If
gravity effects (densities of the fluids) & non-horizontal flow (dip of the reservoir) are significant: 1 f w
0.000488kroKA Δγ sina μo q t
kro μw μ k
1
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Penentuan Kurva Fractional Flow
A water drive reservoir is of such size & shape that water encroachment to first line of producers can be treated as linear flow. The water drive is sufficiently active that fluid flow is steady state. The withdrawal rate from the reservoir averages 2,830 reservoir BPD. Reservoir data are as follows: Item Average formation dip, Average “width” of reservoir, feet Reservoir thickness, feet 2 Average cross-sectional area, feet Permeability, mD Connate water (irreducible water) saturation, % Reservoir oil specific gravity Reservoir oil viscosity, cps Reservoir water specific gravity Reservoir water viscosity, cps
Symbol
A K Swc o mo w mw
Value 15.5 8000 30 240,000 108 16 1.01 1.51 1.05 0.83 35
Penentuan Kurva Fractional Flow
Relative Permeability Data: Sw, % 79 (1 – Sorw ) 75 65 55 45 35 25 16 (Swc)
krw 0.63 0.54 0.37 0.23 0.13 0.06 0.02 0.00
kro 0.00 0.02 0.09 0.23 0.44 0.73 0.94 0.98
Calculate the fractional flow for this reservoir corresponding to the saturations listed above for: Inclusion of dip and gravity effects Excluding dip and gravity effects Use oil viscosity of 8.6 cps & exclude dip/gravity effects 36
Welge Method 1. 2. 3. 4. 5.
Estimate OOIP Plot relative permeability curves Estimate average reservoir dip Calculate & plot fractional flow curve, f w Determine water saturation at breakthrough, S wbt, from fractional flow curve 6. Determine average Sw behind the flood front at time of breakthrough 7. Calculate the slope of the fractional flow curve for each water saturation on the relative permeability table 8. Calculate the pore volumes of cumulative injected water required to obtain each water saturation 9. Calculate the cumulative water injection (BBLS) required to obtain each water saturation 10. Calculate the time needed to obtain each water saturation 11. Calculate oil & water production rates for each water saturation 12. Plot oil & water rate versus time 37 Ch 2 - 37 13. Calculate mobility ratio (favorable or adverse?)
Penentuan Kurva Fractional Flow
1. Estimate OOIP 2. Plot relative permeability curves 3. Estimate average reservoir dip 4. Calculate and plot fractional flow curve, f w 5. Determine water saturation at breakthrough, Swbt., from fractional flow curve 6. Determine average Sw behind the flood front at time of breakthrough 7. Calculate the slope of the fractional flow curve for each water saturation on the relative permeability table 38
Penentuan Kurva Fractional Flow
8. Calculate the pore volumes of cumulative injected water required to obtain each water saturation 9. Calculate the cumulative water injection (BBLS) required to obtain each water saturation 10. Calculate the time needed to obtain each water saturation 11. Calculate oil and water production rates for each water saturation 12. Plot oil and water rate versus time 13. Calculate mobility ratio (favorable or adverse?)
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Dynamic Rock-Fluid Properties
Penentuan Kurva Fractional Flow
qw
Average saturation behind the flood front is always greater than S w at the front
qo, qw
Key points about fractional flow curves
sw x Same Sbt for all fronts
Sharp front Saturation ahead of the flood front is S wc 40
Dynamic Rock-Fluid Properties
Penentuan Kurva Fractional Flow
Sw should be as close to 1 as possible for best sweep efficiency
Fractional Flow Curves
1
Sw behind the front
0.9
Key points
10.0
w 0.8 f , about fractional flow curves w 0.7 o Sw at breakthrough l F 0.6 l a n 0.5 o i t c 0.4 a r F 0.3
2.0 0.5
w=
0.5
o
w=
10
o
w=
2
0.2 0.1 0 0
0.2
0.4
0.6
0.8
1
Water Saturation, Sw 41
Dynamic Rock-Fluid Properties
Penentuan Kurva Fractional Flow
At breakthrough:
f w bt Maximum slopeof f w (tangent) Sw
f w f w f w S S w w Key points about fractional flow Sw Sw Sw 2
Behind the flood front:
2
curves At the flood front::
1
bt
1
f w Sw Sw 0.0 Sw bt
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