sdasadafsdasa

1. PEMODELAN RESERVOIR
Rizky Ferdiansyah (220 14 326)
Ryan Surjaudaja (220 14 330)
Wanasherpa (220 15 015)

2. Korelasi Sumur
Penentuan Zona Reservoir
Zoning & Layering
Data
Penentuan Net Gross
dan Net Pay
Penentuan Kontak Fluida
Peta Kontak Fluida
Struktur model
(pilar grid)
Peta Isochore
Analisis structural
model
Structural Model dengan
upscaling data sumur
Data Analisis dan
Pemodelan Variogram
Facies Modelling
CarbonateReservoir:
Perbandigan SIS, TGS dan TGS
with trend Modelling
Clastic Reservoir:
Perbandigan SIS dan TGS
Modelling
Data Analysis dan Variogram
NTG Modelling
Porosity Modelling
Analisa Perbandingan Model
NTG dan Porositas
Upscale Permeabilitas
Analisa Model Permeabilitas
Model Permeabilitas
sthocastic
Cross plot dan analisa porositas
dan permeabilitas
Geometrical Model
height above contact
Perhitungan PC
Perhitungan J-Function
Perhitungan SW
Upscale SW, komparasi
dengan hasil J-Function
Penenuan nilai volume factor untuk
minyak (Boi) dan gas (Bgi)
Perhitungan in-place
1P, 2P dan 3P
Uncertainty Analysis
Histogram Probabilitas
Analisis P10, P50 dan P90
Finish
Upscale NTG dan Porositas
Workflow

3. PEMODELAN RESERVOIR KARBONAT
Pendahuluan
Structural Modeling
Data Analysis
Facies dan Property Modeling
Volumetric
Uncertainty Analysis

4. Pendahuluan
Lokasi
Korelasi
Penentuan Kontak
Konsep Pemodelan Karbonat

5. Peta Lokasi dan Data
3 Sumur:
CB-1, CB-2, CB-3
Data:
GR-Res-NPHI-RHOB
Vcl-PHIE-Perm-SW-NTG
Facies
DST

6. CB-1
CB-2 CB-3
Korelasi A-A’
Vcl / GR RD ρb-NΦ-Φe Sw Fac DST
Top
Bottom
LKG
Vcl / GR RD ρb-NΦ-Φe Sw Fac DST Vcl / GR RD ρb-NΦ-Φe Sw Fac DST
A
A’
A A’
• LKG: -2577’ SSTVD, bidang datar

7. Peta Top Carbonate
Peta Top
Carbonate & Isochore
Legend:
LKG -2577’ SSTVD @ main carbonate
LKG -2577’ SSTVD @ all area
Peta Isochore

8. Model Karbonat
• Isolated carbonate platform (?).
• Depositional facies: open lagoon – shoal – reefal.

9. Layer pada Karbonat
Qualman, 2009
Not likely

10. Structural Modeling

11. Structural Modeling
Structural Framework
Define Geometry
• Grid: 50m x 50m
Horizon Modeling
• Upper-Lower Carbonate tied with well tops
• No fault modeling.

12. Structural Modeling
Structural Gridding
• Layering method: Proportional 80 layers.
• Layer thickness: 2.2 – 6.6 (average 4.6 m).
• Total grid cells (I x J x K):
115 x 166 x 80

13. Perbandingan Jumlah Layer
(Metode Proportional)
Facies
PHIE
Jumlah layer 70 Jumlah layer 80 Jumlah layer 90 Jumlah layer 100

14. Upscaled Well Logs
Depositional
Facies
PHIE Perm SW
PHIE SW Perm NTG Facies
NTG
PHIE SW Perm NTG Facies PHIE SW Perm NTG Facies
Top
Base
LKG

15. Data Analysis
Trend
Analisis Variogram

16. Probability Map
Top Carbonate Map Thickness Map
Asumsi:
• Reef akan tumbuh pada lokasi
yang paling tinggi.
• Ditandai dengan ketebalan yang
paling tebal.
Probability Reef=
If(Thickness>=400 & Top Carbonate
>=-2500, 0.9, 0.1)
Probability_Shoal=
If(Thickness<400 & Top Carbonate
<-2500, 0.9, 0.1)
Probability Map Shoal
Probability Map Reef
As 2nd variable

17. Analisis Variogram
• Analisis Variogram:
▫ Vertical (cukup data)
▫ Horizontal (asumsi-konsep)
▫ Arah: asumsi utara-selatan
• Analisis dimulai dari facies.
• Property lain condition to facies.
Vertical Variogram Facies
Vertical Variogram PHIE Condition Shoal to Facies
Vertical Variogram PHIE Condition to Reef Facies
Vertical Major Minor
Facies 105 3000 1000
PHIE 105 (shoal)
195 (reef)
3000 1000
NTG 115 (shoal)
500 (reef)
3000 1000
K 125 (shoal)
195 (reef)
3000 1000

18. Facies and Property Modeling
Facies
PHIE
NTG
Perm
SW

19. Facies Model
Deterministic Method
TGS with Trend
Deterministic:
- Manual paint
Stochastic:
- SIS
- TGS
- TGS with trend

20. Facies Model
SIS Method SIS Method with 2nd Variable
TGS Method TGS Method with 2nd Variable

21. Facies Map
SIS Method SIS Method with 2nd Variable
TGS Method TGS Method with 2nd Variable

22. Facies Map Overlaid by Top Carbonate
SIS Method SIS Method with 2nd Variable
TGS Method TGS Method with 2nd Variable

23. Facies Map Overlaid by Thickness
SIS Method SIS Method with 2nd Variable
TGS Method TGS Method with 2nd Variable

24. Facies Model
• Deterministic  lapangan dengan sumur banyak
• Stochastic  lapangan dengan sumur terbatas
• Perbedaan metode-metode pemodelan stochastic:
• Yang digunakan untuk pemodelan selanjutnya: facies model dengan metode TGS.
SIS TGS TGS with Trend
Distribusi
facies
2 facies yang berdekatan bisa
sangat berbeda
perubahan facies
secara berangsur
perubahan facies secara
berangsur
“mosaik” lebih smooth lebih smooth
Variogram Spherical/Exponential/Gaussian
Variogram utk tiap facies
Gaussian
1 variogram utk semua
Gaussian
1 variogram utk semua

25. NTG Model
SGS Method Kriging Method

26. Porosity Model
SGS Method Kriging Method
SGS Method with NTG as 2nd Variable Kriging Method with NTG as 2nd Variable

27. Perm Model
SGS Method Kriging Method
SGS Method with Poro as 2nd Variable Kriging Method with Poro as 2nd Variable

28. Perm Model
SGS Method Kriging Method
SGS Method with Poro as 2nd Variable Kriging Method with Poro as 2nd Variable
Coefficient Correlation:
0.72 (shoal)
0.96 (reef)

29. SW Model
Geometrical Modeling:
Height Above Contact
Pc Model:
Height above contact * (ρw – ρg)
Jfunction: Pc *
𝐾
𝑃𝐻𝐼𝐸
SW J-Function  Equation
ρw = 0.433 psi/ft
ρg =0.03 psi/ft

30. Simple SW J-Function
SW_vs_JFunc
y = 0.822647 - 0.0006053 * x + 1.03205E-7 * x^2

31. SW Well vs SW-J Function
SW SWJ SW SWJ SW SWJ
CB-1
CB-2 CB-3
PHIE K PHIE K PHIE K

32. Volumetric

33. Volumetric Calculation
• OGIP = Bulk Volume x NTG x PHIE x (1-SW) / Bg
• Net Volume = Bulk Volume x NTG
• Pore Volume = Net Volume x PHIE
• HCPV Gas = Pore Volume x SG
• GIIP = HCPV Gas / Bg
from model

34. Bg
• Bg =
0.350958 ∗ 𝑍 ∗ 𝑇
𝑃
• P = 0.433 psi/ft * 2577 m * 3.28 = 3660 psi = 25234.53 kPa
• T = 158°F = 386°K
(assume T surface = 80°F, temp grad 3°F/100ft)
• Z = ???

35. Z (compressibility)
Assume γg = 0.6
• Ppc = 756.8 – 131.07 γg – 3.6γg
2 = 677
• Tpc = 169.2 – 349.5 γg – 74.0γg
2 = 352
• Ppr =
𝑃
𝑃𝑝𝑐
= 5.4 ; Tpr =
𝑇
𝑇𝑝𝑐
= 1.8
• Z = 0.92

36. Bg
• Bg =
0.350958 ∗ 𝑍 ∗ 𝑇
𝑃
• P = 0.433 psi/ft * 2577 m * 3.28 = 3660 psi = 25234.53 kPa
• T = 158°F = 386°K
(assume T surface = 80°F, temp grad 3°F/100ft)
• Z = 0.92
• Bg = 0.004939 rm3/sm3

37. Volumetric
Keterangan:
1P
2P
3P
1P
CB-1
750m
-2577’
2P

38. Uncertainty Analysis

39. Parameter Uncertainty
• Major – Minor Variogram NTG
• Seed number NTG Model
• Major – Minor Variogram PHIE
• Seed number PHIE Model
• GWC depth

40. Uncertainty Analysis – Using 1P as Base Case
P50:
935 BCF
P10:
952 BCF
P90:
902 BCF

41. Uncertainty Analysis – Using 2P as Base Case
P50:
984 BCF
P10:
1 TCF
P90:
959 BCF

42. Uncertainty Analysis – Using 3P as Base Case
P50:
1.62 TCF
P10:
1.65 TCF
P90:
1.59 TCF

43. TUGAS PEMODELAN RESERVOIR (GL-5251)
Oleh:
EKA NUGRAHA 22014321
REZA ADHYATMA 22015002
IMAM HARUN 22014323

44. PEMODELAN RESERVOIR KARBONAT

45. WORKFLOW

46. PETA LOKASI & DATA

47. A
A’
KORELASI SUMUR DAN RESERVOIR
A A’

48. PETA STRUKTUR KEDALAMAN TOP KARBONAT & ISOCHORE
PETA STRUKTUR KEDALAMAN
TOP KARBONAT
PETA ISOCHORE
KARBONAT
LKG
2577 M TVDSS

49. STRUCTURAL FRAMEWORK

50. Skeleton Modeling
Structural Gridding
STRUCTURAL GRIDING & MODELLING

51. WELL LOGS UP-SCALE
PHIE PERM SW NTG

52. Analisis Variogram
Vertical Variogram Facies
Vertical Variogram PHIE (Shoal)
Vertical Variogram PHIE (Reef)

53. Deterministic method
TGS with trend
FACIES MODEL

54. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
PERBANDINGAN FACIES MODEL METODE SIS VS TGS

55. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP SIS VS TGS

56. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP OVERLAID BY TOP CARBONATE

57. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP OVERLAID BY THICKNESS

58. SGS method
Kriging method
NTG MODEL

59. SGS method
Kriging method
SGS method with NTG as 2nd variable
Kriging method with NTG as 2nd variable
POROSITY MODEL

60. SGS method Kriging method
SGS method with PHIE as 2nd variable Kriging method with PHIE as 2nd variable
PERMEABILITY MODEL

61. PC model:
Height above contact (pw – pg)
J function
SW J- function
SW MODEL

62. VOLUMETRIC CALCULATION

63. VOLUMETRIC CALCULATION

64. PEMODELAN RESERVOIR SILISICLASTIC

65. DATA
Korelasi Stratigrafi dan
penentuan zona Reservoir
Structural Framework
Upscaling data sumur
dalam structural model
Facies Modeling
Properties Modeling
(NTG, Porosity,
Permeability, Sw)
Geometrical Model above
Contact
Perhitungan Hidrokarbon
InPlace
WORKFLOW

66. Skeleton model Fault Pillars
Well Correlation & Corner Point Gridding

67. Fault Modelling
Memperbaiki fault hasil pickingan seismik di Model

68. Segmentasi Kompartemen
Kompartemen 1
Kompartemen 2
Data Test
Sumur CL-1
Interval (MD ft) : 2272 – 2285 Oil
: 2338 – 2343 Oil
Sumur CL-2
Interval (MD ft) : 2313 – 2320 Oil
: 2345 – 2351 Oil
: 2374 – 2378 Water
Sumur CL-3
Interval (MD ft) : 1520 – 1540 Oil
: 1554 – 1561 Dry
Perbedaan depth
Oil-water contact menandakan
adanya kompartemen yang
berbeda

69. Make Horizon, Make Zone & Layering
Make Zones Layering
Make Horizon Korelasi dasar pembuatan Make Horizon dan Make Zone
Proses layering sangat berpengaruh terhadap scale up well log, agar data resolusi
vertical dari log tetap tercover, sehingga well log ~ 2ft (sehingga zone 1 dengan
ketebalan 112 ft, maka layering harus menjadi 56 layer)

70. Scale-up Well Log
Scale NTG
Scale Up Permeability
Scale Up Porosity
Hasil histogram scale-up tidak melebihi 5%
dari data log.

71. Facies Model Setting
Scale Up
Facies Untuk
SIS
Scale Up
Facies Untuk
TGS

72. Facies Modelling Using SIS vs TGS
Perbedaan :
a. Sequential Indicator Simulation (SIS): tidak dikontol oleh urutan litological facies,
b. Truncated Gaussian Simulation (TGS): dikontrol oleh fasies sehingga hasil pemodelan lebih
logis secara geological sense.

73. Intersection A-B Menggunakan SIS
A B
A
B
Oil Water Contact
Oil Water Contact
Sumur CL-1 dan CL-2 mempunyai kompartemen yang berbeda dengan sumur CL-3
A
B

74. Intersection A-B Menggunakan TGS
A
B
A B
o Sebaran lateral litological fasies lebih smooth dibanding metode SIS
o Sumur CL-1 dan CL-2 mempunyai kompartemen yang berbeda dengan sumur CL-3

75. Sebaran Porositas dan Permeabilitas
Porositas
Permeabilitas

76. Capillary Pressure
Pc merupakan fungsi dari ketebalan HC colomn dan buoyancy

77. Volume Hidrocarbon
STOIIP = 323,000,000 STB
*) Keterangan
- NTG = Net Volume / Bulk Volume
- Sw = 1 – (HCPV / Pore Volume)
zone1
zone2

78. Pemodelan Lapangan Klastik ‘Assoy'
Almira Bawono (22014319)
Any A. Rachmad (22014333)
David Ontosari (22014322)

79. Workflow
Structural
model
• Stratigraphic & Structure
• Fluid contacts
Reservoir
Model
• Geostatistics
• Facies model
Volumetric
model
• Reservoir properties
• Reservoir volume
DATA

80. Marker reservoir dan kontak fluida
LKO
OWC
LKO

81. Zona reservoir dan non reservoir - Net Gross dan Net Pay

82. Kontak fluida (LTO/LTG, LKO/LKG, OWC/GWC)

83. Peta batas-batas kontak fluida (OWC)

84. Struktural model (pilar grid)

85. Isochore Map for Each Reservoir Zone

86. Upscale data sumur untuk masing-masing facies

87. Fluid kontak
Oil
water

88. Parameter Facies Model
Geostatistics :
- Variogram
Facies- SIS
NTG-SIS

89. Analisis perbandingan antara object based dan pixel based (SIS/TGS)
Object based
SIS
TGS

90. Analisis model
SIS Model yang digunakan :
- SIS Facies model karena perbedaan histogram distribusi
model fasies dari log, upscaled log dan penyebaran secara
geostatistik menunjukkan kesesuaian tertinggi.
shoreline
landward

91. Upscaling Permeability
Permeability-map
Facies A
Facies B
Facies C

92. Geometrical model height above contact
Above OWC Psi
Pc

93. VII. J-function vs Sw
J function
Sw
J-function

94. Upscale data SW dari sumur
(cross plot Sw-perm)
Sw
Facies A Facies B Facies C

95. Por-Perm per facies
Facies A Facies B Facies C
Por-map

96. Volume HC – 3p
Zones A B C D E F G
FS A - FS B 794 446 25 1 1 1 1
FS B - FS C 597 221 28 4 3 3 3
FS C - FS D 452 145 14 1 1 1 1
Total 1843 812 67 6 5 5 5
A Bulk volume[*10^6 m3]
B Net volume[*10^6 m3]
C Pore volume[*10^6 rm3]
D HCPV oil[*10^6 rm3]
E STOIIP (in oil)[*10^6 sm3]
F STOIIP[*10^6 sm3]

97. Resume
 Best reservoir geometry is Facies B (thickness, lateran continuous,
structure ).
 Best Facies model parameter is Facies B (phie, perm)
 Best upscaling model Facies B (por-perm, JFunction – Sw)
 Potensial net oil recoverable : 31.45 MMBO, with contribution of Facies
B is more than 60%.

98. TUGAS PEMODELAN RESERVOIR (GL-5251)
Oleh:
EKA NUGRAHA 22014321
REZA ADHYATMA 22015002
IMAM HARUN 22014323

99. PEMODELAN RESERVOIR KARBONAT

100. WORKFLOW

101. PETA LOKASI & DATA

102. A
A’
KORELASI SUMUR DAN RESERVOIR
A A’

103. PETA STRUKTUR KEDALAMAN TOP KARBONAT & ISOCHORE
PETA STRUKTUR KEDALAMAN
TOP KARBONAT
PETA ISOCHORE
KARBONAT
LKG
2577 M TVDSS

104. STRUCTURAL FRAMEWORK

105. Skeleton Modeling
Structural Gridding
STRUCTURAL GRIDING & MODELLING

106. WELL LOGS UP-SCALE
PHIE PERM SW NTG

107. Analisis Variogram
Vertical Variogram Facies
Vertical Variogram PHIE (Shoal)
Vertical Variogram PHIE (Reef)

108. Deterministic method
TGS with trend
FACIES MODEL

109. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
PERBANDINGAN FACIES MODEL METODE SIS VS TGS

110. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP SIS VS TGS

111. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP OVERLAID BY TOP CARBONATE

112. SIS method SIS method with 2nd variable
TGS method TGS method with 2nd variable
FACIES MAP OVERLAID BY THICKNESS

113. SGS method
Kriging method
NTG MODEL

114. SGS method
Kriging method
SGS method with NTG as 2nd variable
Kriging method with NTG as 2nd variable
POROSITY MODEL

115. SGS method Kriging method
SGS method with PHIE as 2nd variable Kriging method with PHIE as 2nd variable
PERMEABILITY MODEL

116. PC model:
Height above contact (pw – pg)
J function
SW J- function
SW MODEL

117. VOLUMETRIC CALCULATION

118. VOLUMETRIC CALCULATION

119. PEMODELAN RESERVOIR SILISICLASTIC

120. DATA
Korelasi Stratigrafi dan
penentuan zona Reservoir
Structural Framework
Upscaling data sumur
dalam structural model
Facies Modeling
Properties Modeling
(NTG, Porosity,
Permeability, Sw)
Geometrical Model above
Contact
Perhitungan Hidrokarbon
InPlace
WORKFLOW

121. Skeleton model Fault Pillars
Well Correlation & Corner Point Gridding

122. Fault Modelling
Memperbaiki fault hasil pickingan seismik di Model

123. Segmentasi Kompartemen
Kompartemen 1
Kompartemen 2
Data Test
Sumur CL-1
Interval (MD ft) : 2272 – 2285 Oil
: 2338 – 2343 Oil
Sumur CL-2
Interval (MD ft) : 2313 – 2320 Oil
: 2345 – 2351 Oil
: 2374 – 2378 Water
Sumur CL-3
Interval (MD ft) : 1520 – 1540 Oil
: 1554 – 1561 Dry
Perbedaan depth
Oil-water contact menandakan
adanya kompartemen yang
berbeda

124. Make Horizon, Make Zone & Layering
Make Zones Layering
Make Horizon Korelasi dasar pembuatan Make Horizon dan Make Zone
Proses layering sangat berpengaruh terhadap scale up well log, agar data resolusi
vertical dari log tetap tercover, sehingga well log ~ 2ft (sehingga zone 1 dengan
ketebalan 112 ft, maka layering harus menjadi 56 layer)

125. Scale-up Well Log
Scale NTG
Scale Up Permeability
Scale Up Porosity
Hasil histogram scale-up tidak melebihi 5%
dari data log.

126. Facies Model Setting
Scale Up
Facies Untuk
SIS
Scale Up
Facies Untuk
TGS

127. Facies Modelling Using SIS vs TGS
Perbedaan :
a. Sequential Indicator Simulation (SIS): tidak dikontol oleh urutan litological facies,
b. Truncated Gaussian Simulation (TGS): dikontrol oleh fasies sehingga hasil pemodelan lebih
logis secara geological sense.

128. Intersection A-B Menggunakan SIS
A B
A
B
Oil Water Contact
Oil Water Contact
Sumur CL-1 dan CL-2 mempunyai kompartemen yang berbeda dengan sumur CL-3
A
B

129. Intersection A-B Menggunakan TGS
A
B
A B
o Sebaran lateral litological fasies lebih smooth dibanding metode SIS
o Sumur CL-1 dan CL-2 mempunyai kompartemen yang berbeda dengan sumur CL-3

130. Sebaran Porositas dan Permeabilitas
Porositas
Permeabilitas

131. Capillary Pressure
Pc merupakan fungsi dari ketebalan HC colomn dan buoyancy

132. Volume Hidrocarbon
STOIIP = 323,000,000 STB
*) Keterangan
- NTG = Net Volume / Bulk Volume
- Sw = 1 – (HCPV / Pore Volume)
zone1
zone2