LEMIGAS
DIREKTORAT JENDERAL MIGAS
SCA-SCB GGR STUDY
BRAVO SATTELITE FIELD
PREPARED BY LEMIGAS GGR TEAM
RESERVOIR ENGINEER
April, 29th 2024
www.lemigas.esdm.go.id
OUTLINE
1. GENERAL WORKFLOW
2. DATA AVAILABILITY
3. ROCK ANALYSIS
4. PVT ANALYSIS
5. PRODUCTION
6. PRESSURE ANALYSIS
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
2
GENERAL WORKFLOW
DATA GATHERING AND QC
Not Started
PVT
Analysis
SCAL-RCAL
Analysis
Production
Analysis
Pressure
Analysis
INTEGRATION
Critical Initialization Results
• Fluid distribution and contacts
• OOIP & OGIP volumes
• Aquifer to HC ratio
• Initial datum pressures and temperatures
Equilibration validation:
• No saturation or pressure changes with time
• No liberated solution gas
• consistent fluid contact, bubble point pressures &
fluid densities
• Stability model validation
Pressure Matching validation :
• Liquid production (Field, Reservoir, and Well basis)
• Pressure profile:
• SFT(RFT), SBHP, PBU, SFL from SWAB Test
Saturation Matching validation (Field, Reservoir, and
Well basis) :
• Water cut
• Oil production
• GOR performance
• Water production
• Gas production
Calibrating to FBHP by adjusting PI multiplier from last
workover
LEMIGAS | DIREKTORAT JENDERAL MIGAS
In-Progress
STATIC
MODEL
Completed
Dynamic Modeling
Initialization
In place?
Match
Not
match
Adjust model
parameters
Equilibration
NO
Stable?
YES
Pressure Matching
NO
Good
Match?
YES
Adjust model
parameters
Saturation Matching
Good
Match?
YES
NO
Adjust model
parameters
Calibration
Production Forecast
• Adjust Capillary pressure
• Fluid Contact
Global Pressure adjustments :
• Transmissibility XYZ multipliers
• Aquifer pore volume factors
• Aquifer strength
• Rock compressibility
• Kv/Kh ratio
• Aquifer transmissibility
• Completion review
Global Saturation adjustments :
• Oil-water relative permeability curve
• Swir and Sorw
• Krw and Krow
• Vertical transmissibility (Tz)
• Adjust layer PIs to change layer
production allocations
• Transmissibility multiplier
• Completion review
End
your excellent partner in oil and gas
3
PROGRESS
Scope of Work
Data Review and Analysis
DST and RFT Analysis, Production History
History Matching Analytical-Based Remaining Oil
Initiallization
History Matching Reservoir Model
Based Production Forecast
Depletion Plan
Precentage (%)
3 from 3
1.5 from 3
-
Remarks
Prelimenary SCAL, PVT
Pressure Analysis, Completion, and Production History
-
Last Week To Do List
-
Pressure SBHP Recap per sand
Menampilkan timeline zona yang dibuka saat produksi
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
2. DATA AVAILABILITY
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
5
DATA AVAILABILITY SB-SC
SB-SC
NO
1
2
DATA
Fluid Data
PVT
Water Analysis
Rock Properties
RCAL
3
4
5
6
7
8
9
SCAL
Pressure Data
Production Data
Production Performance
Well/Workover History
Production Profile
SFL/WFL
Swab Data
Well Completion
Well Diagram
Completion History
Well Test
PBU/PDD
DST
RFT
Well Report
Dynamic Model Data
Grid Model
Property Distribution
Fault
ETC
Completion Log
LEMIGAS | DIREKTORAT JENDERAL MIGAS
CHECK
REMARKS
√
√
SB-1 (DST-1 & DST-2B), SC-1 (DST-1 & DST-3), SC-6 (DST-1 & DST-4)
SB-1, SC-1, SC-2, SC-6
√
√
√
SB-1 (SWC), SBA-2 (Full Diameter Core & Conventional), SB-4 (Conventional core), SC-1 (SWC), SC-2
(SWC), SC-3 (SWC), SC-4 (SWC), SC-5 (Conventional)
Analog (BZ-2, BZZA-7, BZZA-8, BZZA-9)
SBHP SURVEY (SBA-2, SBA-4ST, SBA-5, SCA3L, SCA3S)
√
√
SBA (1, 2, 4ST, 5) ; SCA (1L, 1S, 2L, 2S, 3L, 3S, 5)
SBA (1, 2, 4ST, 5) ; SCA (1L, 1S, 2L, 2S, 3L, 3S, 5)
SBA (1, 2, 4ST, 5, 5ST) ; SCA (1L, 1S, 2L, 2S, 3L, 3S, 5)
√
√
SBA (1, 2, 4ST, 5) ; SCA (1, 2, 3, 5)
SBA (1, 2, 4ST, 5) ; SCA (1L, 1S, 2L, 2S, 3L, 3S, 5)
√
√
√
√
SB-1, SC-1, SC-2, SC-3, SC-4, SC-6
SB (1 & 2) ; SC (1, 2, 3, 4, 5, & 6)
SB-1, SC-1, SC-4, SC-5
ALL WELLS
√
ALL WELLS
WELL NAME EQUAL WELL NAME
SBA-1
SB-1
SBA-2
SBA-3
SBA-4
SB-2
SBA-4ST
SBA-5
SBA-5ST
SCA-1
SC-1
SCA-2
SC-2
SCA-3
SC-3
SC-4
SC-5
SCA-5
SC-6
Required Data :
• SBHP after production for MBAL
• Perforation date for splitting
• Well History, Prod Performance,
Well Diagram SBA-5 ST
Note :
S = Short
L = Long
your excellent partner in oil and gas
6
PVT
DATA AVAILABILITY
PVT = 6
PTA = 14
DST DATA
Explo Wells Prod Well
SB-1
SB-1
SB-1
SB-2
SC-1
SC-1
SC-1
SC-1
SC-1
SC-1
SC-2
SC-2
SC-2
SC-3
SC-3
SC-3
SC-3
SC-3
SC-3
SC-3
SC-4
SC-4
SC-4
SC-4
SC-4
SC-5
SC-6
SC-6
SC-6
SC-6
SC-6
SC-6
SC-6
SC-6
SC-6
SBA-1
SBA-1
SBA-1
SBA-4
SBA-5
SBA-5
SBA-5
SCA-1
SCA-1
SCA-1
SCA-1
SCA-1
SCA-1
SCA-2
SCA-2
SCA-2
DST#
Chk
1
2A
2B
1
#N/A
#N/A
#N/A
1
1 (PERF)
2
1/2"
1/2"
1/2"
3/8"
3A
3A (retest)
1
2
3
1
1A
2
3
4
5
6
1
2
2A
2B
3
#N/A
1
1
1
2
3
4
4
4
5
1/2"
3/8"
#N/A
3/8"
1/2"
1/2"
1/2"
1/2"
1/2"
3/8"
1/2"
1/2"
1/2"
3/4"
3/4"
#N/A
3/8"
3/8"
3/8"
3/8"
3/8"
1/2"
3/4"
1"
3/8"
3/8"
1/2"
1"
5/8"
3/8"
Top Depth Bot Depth Commingle Top Commingle Depth
7933
7724
7724
9838
8438
8095
7784
8110
8139
7846
7654
7600
7600
8566
8215
8002
10634
10634
10582
10382
10134
8992
7848
8562
8362
8450
8362
7591
#N/A
10828
10828
10828
10378
10192
10036
10036
10036
8978
7950
7744
7765
9868
8456
8150
7792
8132
8156
7876
7664
7664
7664
8578
8290
8056
10740
10740
10602
10392
10150
9004
7887
8574
8376
8456
8376
9604
#N/A
10858
10858
10858
10356
10201
10064
10064
10064
8986
LEMIGAS | DIREKTORAT JENDERAL MIGAS
7880
7884
8308
8318
8456
8450
10232
10247
Form
Zone
Lith
TAF
TAF
TAF
#N/A
#N/A
TAF
#N/A
TAF
SB-78
SB-76
SB-76
#N/A
#N/A
SB-76
#N/A
SC-80
Sand
Sand
Sand
#N/A
#N/A
Sand
#N/A
Sand
fluid Remarks
Condensate
Oil
Oil
No Fluid
#N/A
Oil
#N/A
Oil
#N/A
TAF
SC-77B
Sand
No Fluid
TAF
SC-75
Sand
Oil
TAF
SC-76
Sand
Oil
TAF
SC-77
Sand
Oil
TAF
SC-80
Sand
Oil
TAF
SC-77
Sand
Water
TAF
SC-75
Sand
Oil
TAF Intra Talang AkarSand
Gun not Fired
TAF Intra Talang AkarSand
Condensate
TAF
SC-74B
Sand
Condensate
TAF
SC-72
Sand
N2 Lifting
TAF
SC-71
Sand
Condensate
TAF
SC-68
Sand
Condensate
Massive MassiveSand/Limestone
No Fluid
TAF
SC-80
Sand
Oil
TAF
SC-78
Sand
Oil
TAF
SC-78
Sand
Oil
TAF
SC-77B
Sand
Oil
TAF
SC-72
Sand
Wet Gas
#N/A
TAF
SC-77B
Sand
Condensate
TAF
SC-77B
Sand
Condensate
TAF
SC-77B
Sand
Condensate
TAF
SC-76
Sand
N2 Lifting / No Fluid
TAF
SC-75
Sand
N2 Lifting / No Fluid
TAF
SC-74C
Sand
Condensate
TAF
SC-74C
Sand
Condensate
TAF
SC-74C
Sand
Condensate
TAF
SC-69 Limestone
Condensate
API
SG Gas
GOR
BOPD
BWPD
MMCFPD
WC
GOR CALC
57
40.1
33.6
#N/A
#N/A
#N/A
#N/A
35.8
#N/A
#N/A
16
38.5
37.5
44.3
#N/A
43.5
#N/A
55.2
51
#N/A
60.7
68.1
#N/A
30.8
30
#N/A
30.2
64.7
#N/A
52.8
53
53
#N/A
#N/A
60.8
60.8
60.8
69.5
0.971
1.112
1.14
#N/A
#N/A
#N/A
#N/A
1.03
#N/A
#N/A
1.054
1.05
1.048
#N/A
#N/A
0.958
#N/A
0.814
0.843
#N/A
0.838
0.844
#N/A
1.165
1.2
#N/A
1.23
0.964
24033
2402
1051
#N/A
#N/A
1732
#N/A
648
#N/A
#N/A
5763
13629
11350
1622
#N/A
11199
#N/A
#N/A
9939
#N/A
403
15194
#N/A
276
1170
#N/A
970
165500
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
15757
13905
14444
#N/A
64.6
1648
2189
#N/A
#N/A
1624
#N/A
662
#N/A
#N/A
475
510.7491
648
971
0
834
#N/A
660
1090
#N/A
295
1030
#N/A
98.5
345
11.25
325
7
#N/A
391
444
522
#N/A
#N/A
527
1264
816
12
197
0
0
#N/A
#N/A
8
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
586
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
150
153
#N/A
#N/A
67
#N/A
0
52
77
#N/A
#N/A
0
256
18
#N/A
1.552
3.959
2.3
#N/A
#N/A
2.817
#N/A
0.428
#N/A
#N/A
2.737
6.961
7.357
1.578
0
9.34
#N/A
6.56
5.22
#N/A
4.52
15.902
#N/A
0.0277
0.404
#N/A
0.315
1.2
#N/A
6.5
9.1
11.6
#N/A
#N/A
8.304
17.579
11.791
0.6
75.3%
0.0%
0.0%
#N/A
#N/A
0.5%
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
#N/A
100.0%
#N/A
#N/A
18.0%
8.0%
#N/A
10.0%
7.0%
#N/A
60.4%
30.7%
#N/A
#N/A
90.5%
#N/A
0.0%
10.5%
12.9%
#N/A
#N/A
0.0%
16.8%
2.2%
#N/A
24024.8
2402.3
1050.7
#N/A
#N/A
1734.6
#N/A
646.5
#N/A
#N/A
5762.1
13629.0
11353.4
1625.1
#N/A
11199.0
#N/A
9939.4
4789.0
#N/A
15322.0
15438.8
#N/A
281.2
1171.0
#N/A
969.2
171428.6
#N/A
16624.0
20495.5
22222.2
#N/A
#N/A
15757.1
13907.4
14449.8
50000.0
0.89
0.89
0.89
#N/A
#N/A
0.956
0.902
0.956
0.878
•
•
•
•
•
•
SB-1 DST#1 (SB-78)
SB-1 DST#2B (SB-76)
SC-1 DST#1 (SC-80)
SC-1 DST#3 (SC-75)
SC-6 DST#1 (SC-77B)
SC-6 DST#4 (SC-74C)
PTA
•
•
•
•
•
•
•
•
•
•
•
•
•
•
SB-1 DST#1 (SB-78)
SB-1 DST#2B (SB-76)
SC-1 DST#1 (SC-80)
SC-1 DST#2 (SC-77B)
SC-1 DST#3 (SC-75)
SC-1 DST#3A (SC-75)
SC-2 DST#1 (SC-80)
SC-2 DST#3 (SC-75)
SC-3 DST#4 (SC-71)
SC-3 DST#5 (SC-68)
SC-4 DST#1 (SC-80)
SC-4 DST#2 (SC-78)
SC-6 DST#4 (SC-74C)
SC-6 DST#5 (SC-69)
your excellent partner in oil and gas
7
Daily Rate (FIELD)
DATA AVAILABILITY (Production)
SB-1 (SBA-1)
SB-2 (SBA-2)
SBA-4ST
SBA-5
SCA
•
•
•
•
•
•
•
SCA-1L
SCA-1S
SCA-2L
SCA-2S
SCA-3L
SCA-3S
SCA-5
Source : SCA SCB Production.xls
Start
: 01/11/1992
Last date : 01/04/2018
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1992
6000.0
1996
2000
Water Rate (Field)
2004
2008
2012
Gas Rate (Field)
2016
2020
2024
50000.0
45000.0
5000.0
40000.0
35000.0
4000.0
30000.0
3000.0
25000.0
20000.0
2000.0
15000.0
Gas Rate (MSCFD)
•
•
•
•
Oil Rate/Water Rate (BOPD/BWPD)
SBA
Oil Rate (Field)
10000.0
1000.0
5000.0
0.0
1992
1996
2000
2004
2008
2012
2016
2020
0.0
2024
Date
Well List Oil Cummulative (MMBO) Gas Cummulative (MMSCF) Water Cummulative (MMBW)
SBA-1
1.44
8506.95
2.20
SBA-2
0.76
2363.82
0.43
SBA-4ST
0.26
1548.83
0.06
SBA-5
0.50
1349.75
0.18
SBA-5ST
0.23
6346.76
0.11
SCA-1L
0.41
1572.52
0.02
SCA-1S
0.11
4199.87
0.56
SCA-2L
0.15
1962.13
0.05
SCA-2S
0.14
4203.30
0.32
SCA-3L
0.15
3917.82
0.11
SCA-3S
0.15
5015.76
0.07
SCA-5
0.52
5997.90
1.04
SBA
3.18
20115.11
4.03
SCA
1.62
26869.28
2.18
FIELD
4.80
46984.39
your excellent partner 6.21
in oil and gas
8
ROCK
- ANALYSIS -
SCAL
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
9
SCAL Analysis (Sample Oil-Water Selection BZ-2 ANALOG)
Krw
Sw
0.50
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Kro
Kro
Krw
1.0
0.8
0.6
0.4
0.2
0.0
0.00
0.50
Sw
Krw
Kro
Krw
Krw
1.0
0.8
0.6
0.4
0.2
0.0
0.00
0.50
1
0.8
0.6
0.4
0.2
0
1.00
Kro
Krw
Sw
Relative Permeability BZ-2 (36)
Kro
1
0.8
0.6
0.4
0.2
0
1.00
Krw
Kro
Sw
1
0.8
0.6
0.4
0.2
0
1.00
Sw
Relative Permeability BZ-2 (138)
1.0
0.8
0.6
0.4
0.2
0.0
0.00
0.50
Kro
Relative Permeability BZ-2 (60)
Kro
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.00
Krw
Relative Permeability BZ-2 (64)
Kro
Krw
Kro
1
0.8
0.6
0.4
0.2
0
1.00
0.50
1
0.8
0.6
0.4
0.2
0
1.00
Sw
1
0.8
0.6
0.4
0.2
0
1.00
Relative Permeability BZ-2 (33)
Kro
Krw
Kro
0.50
Krw
Sw
Relative Permeability BZ-2 (101)
1.0
0.8
0.6
0.4
0.2
0.0
0.00
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.00
Krw
Sw
0.50
Relative Permeability BZ-2 (124)
1.0
0.8
0.6
0.4
0.2
0.0
0.00
0.50
1
0.8
0.6
0.4
0.2
0
1.00
Krw
Krw
1
0.8
0.6
0.4
0.2
0
1.00
Krw
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.00
Krw
0.50
1
0.8
0.6
0.4
0.2
0
1.00
Relative Permeability BZ-2 (104)
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.00
Krw
Kro
Relative Permeability BZ-2 (131)
Kro
Krw
Sw
*Sample 101, 60,138, and 33 Reversed at the end of Krw Test, caused of fine migration
your excellent partner in oil and gas
10
SCAL Analysis (Sample Oil-Water Selection BZZA-7 ANALOG)
Sw
Kro
1.0
0.5
0.0
0.00
0.50
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Krw
Relative Permeability BZZA-7
(37A)
Kro
Krw
Sw
1.0
0.8
0.6
0.4
0.2
0.0
0.5
0.0
0
0.5
1
Kro
Krw
Krw
Krw
Relative Permeability BZZA-7 (1)
A
K
A
R
1.0
0.8
0.6
0.4
0.2
0.0
1.0
0.8
0.6
0.4
0.2
0.0
0
0.5
Kro
Krw
1
Sw
Relative Permeability BZZA-7 (2)
1.0
0.8
0.6
0.4
0.2
0.0
1.0
0.8
0.6
0.4
0.2
0.0
0
Sw
LEMIGAS | DIREKTORAT JENDERAL MIGAS
0.50
Kro
Sw
Kro
Kro
1.0
Krw
Relative Permeability BZZA-7
(99A)
B
A
T
U
R
A
J
A
1
0.8
0.6
0.4
0.2
0
1.00
Krw
0.50
Krw
1.0
0.8
0.6
0.4
0.2
0.0
0.00
0.5
Krw
0.0
0.00
Kro
T
A
L
A
N
G
Kro
0.5
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Relative Permeability BZZA-7 (3)
Kro
Kro
1.0
Krw
Relative Permeability BZZA-7
(39A)
Kro
Krw
1
Sw
*Sample only taken from Talang Akar Formation
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11
SCAL Analysis (Sample Oil-Water Selection BZZA-8 ANALOG)
0.0
0.00
0.50
Sw
Krw
0.5
0.0
0.00
0.50
1.0
Kro
Krw
Sw
1.0
0.8
0.6
0.4
0.2
0.0
0.5
0.0
0
0.5
Krw
Kro
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Relative Permeability BZZA-8
(120)
Kro
1.0
Kro
0.5
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Krw
Kro
1.0
Relative Permeability BZZA-8
(217)
Krw
Relative Permeability BZZA-8
(229)
Kro
Krw
1
Sw
*Sample 217 and 120 Reversed at the end of Krw Test
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12
SCAL Analysis (Sample Oil-Water Selection BZZA-9 ANALOG)
0.50
0.0
0.00
Krw
0.50
Sw
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.5
0.0
Krw
0
0.5
Sw
0.0
0.00
0.50
Sw
Krw
1
Relative Permeability BZZA-9
(117)
Kro
Krw
Kro
Krw
Kro
0.5
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Kro
Sw
Relative Permeability BZZA-9
(112)
1.0
Krw
0.5
1.0
1.0
1.0
0.5
0.5
0.0
0.00
0.50
0.0
1.00
Krw
0.0
0.00
Kro
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Relative Permeability BZZA-9
(61)
Kro
0.5
1.0
Kro
1.0
0.8
0.6
0.4
0.2
0.0
1.00
Krw
Kro
1.0
Relative Permeability BZZA-9
(65)
Krw
Relative Permeability BZZA-9
(72)
Kro
Krw
Sw
*All sample from BZZA-9 Reversed on Krw Test
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
SCAL Analysis (Normalization)
SCAL Normalization (LET)
SCAL Normalization (Corey)
1
1
0.9
0.9
0.8
0.8
0.7
0.7
0.6
0.6
0.5
0.5
0.4
Kr
Kr
0.4
0.3
0.3
0.2
0.2
0.1
0.1
0
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
Sw
0
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
Sw
Krw
Kro
krw correy MEAN
kro correy MEAN
kro correy MIN
krw correy MIN
Krw
Kro
krw LET MEAN
kro LET MEAN
kro correy MAX
krw correy MAX
Poly. (Krw)
kro LET MIN
krw LET MIN
kro LET MAX
krw LET MAX
Log. (Kro)
Poly. (Kro)
Poly. (Krw)
Log. (Kro)
Poly. (Kro)
BASE
now
nw
LEMIGAS | DIREKTORAT JENDERAL MIGAS
4
1.5
MIN
BASE
MAX
9
2.3
1
0.95
Low
Eow
Tow
Lw
Ew
Tw
1
10
1
1.2
2.8
1.5
MIN
3
15
0.7
1.8
2
1
MAX
MIN OIL MAX OIL
1.8
3
1
1.1
15
1.1
1.9
0.8
1
0.6
0.6
1.8
2.7
2.8
2
2
2
1
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14
SCAL Analysis (End Point Correlation - Swc)
y = -0.0217x + 0.2612
R² = 0.6861
0
2
4
6
8
10
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
1.00
y = -2E-05x + 0.1941
R² = 0.3759
10.00
FZI
Krw @Sor
Sor
0.4000
0.6000
Swc
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1000.00
10000.00
y = 0.0946x + 0.2583
R² = 0.0056
0.2000
0.4000
0.8000
1.0000
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
0.0000
RT
1
y = -0.8764x + 0.7301
R² = 0.3006
2
3
4
0.2000
0.4000
0.6000
0.6000
0.8000
1.0000
Swc
kro @Swc vs Swc
y = -1.5537x + 0.5168
R² = 0.2658
0.2000
100.00
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
0.0000
Perm, mD
krw @Sor vs Swc
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
0.0000
Sor vs Swc
Sor
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
Swc vs k
Swc
Swc
Swc vs FZI
0.8000
EP Type
FZI
Swc
FZI
Swc
FZI
Swc
FZI
Swc
swc
0.140
0.140
0.195
0.195
0.229
0.229
0.246
0.246
sor
0.264
0.272
0.285
0.277
0.297
0.280
0.303
0.282
krw @ sor
0.322
0.300
0.189
0.213
0.108
0.160
0.068
0.134
kro @ swc
0.614
0.608
0.552
0.559
0.514
0.529
0.495
0.514
1.0000
Swc
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15
SCAL Analysis (End Point Correlation - FZI)
y = -0.0217x + 0.2612
R² = 0.6861
0
2
4
6
8
10
10
9
8
7
6
5
4
3
2
1
0
y = 0.0014x + 2.7812
R² = 0.8347
Sor
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
1
10
FZI
Krw @Sor
Sor
2
4
6
FZI
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1000
10000
y = -0.008x + 0.3089
R² = 0.058
0
2
4
8
10
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
RT
1
2
3
4
y = 0.0242x + 0.4784
R² = 0.3339
0
2
4
6
8
10
FZI
kro @Swc vs FZI
y = 0.0516x + 0.0326
R² = 0.4259
0
100
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
Perm, mD
krw @Sor vs FZI
1.0000
0.9000
0.8000
0.7000
0.6000
0.5000
0.4000
0.3000
0.2000
0.1000
0.0000
Sor vs FZI
FZI vs k
FZI
Swc
Swc vs FZI
6
8
EP Type
FZI
Swc
FZI
Swc
FZI
Swc
FZI
Swc
swc
0.140
0.140
0.195
0.195
0.229
0.229
0.246
0.246
sor
0.264
0.272
0.285
0.277
0.297
0.280
0.303
0.282
krw @ sor
0.322
0.300
0.189
0.213
0.108
0.160
0.068
0.134
kro @ swc
0.614
0.608
0.552
0.559
0.514
0.529
0.495
0.514
10
FZI
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16
SCAL Analysis (Denormalization)
BASE CASE (Swc End Point Correlation - Corey)
BASE CASE (FZI End Point Correlation - Corey)
BASE CASE (Swc End Point Correlation - LET)
BASE CASE (FZI End Point Correlation - LET)
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17
SCAL Analysis (Sample Oil-Gas BZ-2 ANALOG)
Krg
0.400
0.600
0.800
1.000
Krg
0.200
Sg
Kro/Krg
Kro/Krg
Krg
0.400
0.600
0.800
1.000
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Krg
0.600
0.800
Sg
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1.000
Kro/Krg
Kro/Krg
Krg
0.200
0.400
0.600
1.0
0.8
0.6
0.4
0.2
0.0
0.000
0.800
1.000
0.600
Sg
1.000
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Relative Permeability BZ-2 (138)
Krg
0.400
0.800
Sg
Kro
0.200
0.600
Relative Permeability BZ-2 (104)
Krg
0.200
0.400
Sg
Relative Permeability BZ-2 (131)
Kro
0.400
Kro
Sg
Relative Permeability BZ-2 (124)
0.200
1.000
Kro
Sg
1.0
0.8
0.6
0.4
0.2
0.0
0.000
0.800
Relative Permeability BZ-2 (101)
Kro
0.200
0.600
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Sg
Relative Permeability BZ-2 (64)
1.0
0.8
0.6
0.4
0.2
0.0
0.000
0.400
Kro/Krg
0.200
Kro
Kro/Krg
Kro
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Relative Permeability BZ-2 (60)
0.800
1.000
Kro/Krg
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Relative Permeability BZ-2 (36)
Kro/Krg
Kro/Krg
Relative Permeability BZ-2 (33)
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
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18
SCAL Analysis (Sample Oil-Gas BZZA-7 ANALOG)
Relative Permeability BZZA-7 (3)
Kro
0.0
0.000
Krg
0.200
0.400
0.600
0.800
1.000
Sw
Relative Permeability BZZA-7
(37A)
Kro/Krg
1.0
0.5
Kro
0.0
0.000
Krg
0.200
0.400
0.600
0.800
1.000
Sw
Relative Permeability BZZA-7
(99A)
Kro/Krg
1.0
0.5
0.0
0.000
Kro
Krg
0.200
0.400
0.600
Sg
LEMIGAS | DIREKTORAT JENDERAL MIGAS
0.800
1.000
B
A
T
U
R
A
J
A
T
A
L
A
N
G
A
K
A
R
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
Relative Permeability BZZA-7 (1)
Kro/Krg
0.5
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
Relative Permeability BZZA-7 (2)
Kro/Krg
Kro/Krg
1.0
Kro/Krg
Relative Permeability BZZA-7
(39A)
1.0
0.8
0.6
0.4
0.2
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
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19
SCAL Analysis (Sample Oil-Gas BZZA-8 ANALOG)
Relative Permeability BZZA-8
(229)
Relative Permeability BZZA-8
(217)
0.5
0.0
0.000
Kro
Krg
0.200
0.400
0.600
Sg
LEMIGAS | DIREKTORAT JENDERAL MIGAS
0.800
1.000
1.0
0.5
0.0
0.000
Kro
Krg
0.200
0.400
0.600
Sg
0.800
1.000
Kro/Krg
1.0
Kro/Krg
Kro/Krg
1.0
Relative Permeability BZZA-8
(120)
0.5
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
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20
SCAL Analysis (Sample Oil-Gas BZZA-9 ANALOG)
Relative Permeability BZZA-9
(72)
Relative Permeability BZZA-9
(65)
0.5
0.0
0.000
Kro
0.400
0.600
0.800
0.5
0.0
0.000
Krg
0.200
1.000
1.0
Kro
0.400
0.600
0.800
0.5
0.0
0.000
Krg
0.200
Sg
1.000
Kro
Krg
0.200
0.400
Sg
1.000
1.0
0.5
Kro
Krg
0.200
0.400
0.600
Sg
0.800
1.000
Kro
Kro
0.800
Relative Permeability BZZA-9
(117)
1.0
0.0
0.000
0.600
Sg
Relative Permeability BZZA-9
(112)
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Kro
1.0
Kro
Kro
1.0
Relative Permeability BZZA-9
(61)
0.5
0.0
0.000
Kro
Krg
0.200
0.400
0.600
0.800
1.000
Sg
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21
SCAL Analysis (Normalization)
The data used are 20 selected Cores from Talang Akar
COREY TA only SCAL Normalization
LET TA only SCAL Normalization
1.0
1.0
0.9
0.9
0.8
0.8
0.7
0.7
0.6
0.6
0.5
0.5
0.4
0.4
0.3
0.3
0.2
0.2
0.1
0.1
0.0
0.0
0.0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1.0
0.0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
Krg
Kro
Kro Base
Krg Base
Kro Min
Krg
Kro
Kro Base
Krg Base
Kro Min
Krg Min
Kro Max
Krg Max
Poly. (Krg)
Poly. (Kro)
Krg Min
Kro Max
Krg Max
Poly. (Krg)
Poly. (Kro)
BASE
nog
ng
LEMIGAS | DIREKTORAT JENDERAL MIGAS
3
2.15
MIN
4.5
3.5
MAX
1.5
0.8
Lo
Eog
Tog
Lg
Eg
Tg
BASE
1.45
3.80
0.98
1.42
2.20
0.95
MIN
1.50
6.00
0.90
2.50
2.50
0.70
1.0
MAX
MIN OIL MAX OIL
0.90
0.9
1.5
5.50
6
3.8
2.40
0.9
2.4
1.30
1.3
2.5
0.65
0.65
2.5
1.30
1.3
0.7
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22
SCAL Analysis (End Point Correlation - Sgcr)
y = 0.0007x + 0.0222
R² = 0.0055
0
2
4
6
8
10
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
y = -1E-06x + 0.0268
R² = 0.0098
1
10
FZI
Kro@Sgi
Krg@Sogcr
0.04
1000
10000
y = -0.9267x + 0.5125
R² = 0.1037
0
0.02
0.04
0.06
Sgcr
LEMIGAS | DIREKTORAT JENDERAL MIGAS
0.08
0.10
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
0.00
RT
1
y = 1.7773x + 0.3393
R² = 0.1233
2
3
4
0.02
0.04
0.06
0.06
0.08
0.1
Sgcr
Krg@Sogcr vs Sgcr
y = 0.6734x + 0.606
R² = 0.0215
0.02
100
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
Perm, mD
kro@Sgi vs Sgcr
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
0.00
Sogcr vs Sgcr
Sogcr
0.1
0.09
0.08
0.07
0.06
0.05
0.04
0.03
0.02
0.01
0
Sgcr vs k
Swc
Sgcr
Sgcr vs FZI
0.08
EP Type
FZI
Sgcr
FZI
Sgcr
FZI
Sgcr
FZI
Sgcr
sgcr
0.0261
0.0261
0.0243
0.0243
0.0232
0.0232
0.0227
0.0227
sogcr
krg @ sogcr
0.4782
0.3660
0.4883
0.3857
0.5021
0.4051
0.4900
0.3825
0.5167
0.4289
0.4910
0.3806
0.5240
0.4408
0.4915
0.3796
kro @sgi
0.6294
0.6236
0.6153
0.6224
0.6066
0.6216
0.6023
0.6213
0.10
Sgcr
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23
SCAL Analysis (End Point Correlation - FZI)
y = 0.0007x + 0.0222
R² = 0.0055
0
2
4
6
8
10
9
8
7
6
5
4
3
2
1
0
10
y = 0.0014x + 2.7479
R² = 0.8329
1
10
FZI
Kro@Sgi
Krg@Sogcr
2
4
6
FZI
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1000
10000
y = -0.0093x + 0.5303
R² = 0.1322
0
2
4
8
10
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
RT
1
y = -0.0152x + 0.4511
R² = 0.1136
2
3
4
0
2
4
6
8
10
FZI
Krg@Sogcr vs FZI
y = 0.0055x + 0.5986
R² = 0.0182
0
100
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
Perm, mD
kro@Sgi vs FZI
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
Sogcr vs FZI
Sogcr
0.1
0.09
0.08
0.07
0.06
0.05
0.04
0.03
0.02
0.01
0
FZI vs k
FZI
Sgcr
Sgcr vs FZI
6
8
EP Type
FZI
Sgcr
FZI
Sgcr
FZI
Sgcr
FZI
Sgcr
sgcr
0.0261
0.0261
0.0243
0.0243
0.0232
0.0232
0.0227
0.0227
sogcr
krg @ sogcr
0.4782
0.3660
0.4883
0.3857
0.5021
0.4051
0.4900
0.3825
0.5167
0.4289
0.4910
0.3806
0.5240
0.4408
0.4915
0.3796
kro @sgi
0.6294
0.6236
0.6153
0.6224
0.6066
0.6216
0.6023
0.6213
10
FZI
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24
Pc Analysis (RT use Conventional only)
J-Function
Model Capillary Pressure
120
HWFL vs Sw
50
1000
45
900
40
800
35
700
30
600
80
RT-2
60
RT-3
Pc, Psi
J(Sw)
RT-1
RT-1
25
RT-2
20
Power
(RT-1)
Power
(RT-2)
Power
(RT-3)
40
20
0
0
0.5
Sw
1
RT-3
HWFL
100
RT-2
400
15
300
10
200
5
100
0
RT-1
500
RT-3
0
0.0
0.2
0.4
0.6
Sw
0.8
1.0
0.0
0.2
0.4
0.6
0.8
1.0
Sw
Only Available for 3 rock type, the samples for the 4th rock type does not exist
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27
PVT
- ANALYSIS -
PVT DATA
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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33
PVT COMPOSITION (SB-SC)
DATA AVAILABILITY (PVT)
•
•
•
•
•
•
Mol (%)
PVT
SB-1 DST#1 (SB-78) – Wet Gas/Condensate
SB-1 DST#2B (SB-76) – Black Oil
SC-1 DST#1 (SC-80) – Black Oil
SC-1 DST#3 (SC-75) – Volatile Oil
SC-6 DST#1 (SC-77B) – Condensate
SC-6 DST#4 (SC-74C) – Condensate
*Fluid Determination Type is based on
Mc Cain Category and PVT Report
description and result
Component
SBA-1 (DST-1)
Well Stream
Mol%
GPM
SBA-1 (DST-2B)
Well Stream
Mol%
Wt %
100.00
90.00
80.00
70.00
60.00
50.00
40.00
30.00
20.00
10.00
0.00
H2S
CO2
N2
C1
C2
C3
iC4
nC4
iC5
nC5
C6
C7+
SBA-1 (DST-1)
0.00
21.35
0.60
52.29
4.57
12.00
2.92
2.22
1.12
0.52
0.57
1.84
SBA-1 (DST-2B)
0.00
17.27
0.23
27.66
4.78
13.80
3.35
3.66
1.68
1.07
3.16
23.34
SCA-1 (DST-1)
0.00
12.82
0.20
27.01
4.80
14.74
3.98
4.27
2.15
1.30
1.79
26.94
SCA-1 (DST-3)
0.00
21.99
0.24
34.41
3.24
10.50
3.56
3.16
2.16
1.21
2.07
17.46
SCA-5 (DST-1)
0.00
40.07
0.08
34.45
5.05
10.19
2.21
1.87
0.62
0.42
0.54
4.50
SCA-5 (DST-4)
0.00
39.34
0.16
39.57
3.06
7.55
2.17
1.66
0.93
0.54
1.08
3.94
SCA-1 (DST-1)
Well Stream
Mol%
Wt %
SCA-1 (DST-3)
Well Stream
Mol%
Wt %
SCA-5 (DST-1)
Well Stream
Mol%
GPM
SCA-5 (DST-4)
Well Stream
Mol%
GPM
H2 S
Hydrogen Sulfide
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
CO2
Carbon Dioxide
21.35
17.27
9.19
12.82
6.17
21.99
16.36
40.07
39.34
N2
Nitrogen
0.60
0.23
0.08
0.20
0.06
0.24
0.11
0.08
0.16
C1
Methane
52.29
27.66
5.36
27.01
4.74
34.41
9.33
34.45
39.57
C2
Ethane
4.57
1.22
4.78
1.74
4.80
1.58
3.24
1.65
5.05
1.35
3.06
0.82
C3
Propane
12.00
3.31
13.80
7.36
14.74
7.11
10.50
7.83
10.19
2.80
7.55
2.07
iC4
Iso-Butane
2.92
0.96
3.35
2.35
3.98
2.53
3.56
3.50
2.21
0.72
2.17
0.71
nC4
N-Butane
2.22
0.70
3.66
2.57
4.27
2.71
3.16
3.11
1.87
0.59
1.66
0.52
iC5
Tso-Pentane
1.12
0.41
1.68
1.47
2.15
1.70
2.16
2.63
0.62
0.23
0.93
0.34
nC5
N-Pentane
0.52
0.19
1.07
0.93
1.30
1.03
1.21
1.48
0.42
0.15
0.54
0.19
C6
Hexanes
0.57
0.22
3.16
3.21
1.79
1.64
2.07
2.94
0.54
0.22
1.08
0.44
C7+
Heptanes plus
1.84
1.04
23.34
65.74
26.94
70.73
17.46
51.06
100.00
8.04
100.00
100.00
100.00
100.00
100.00
100.00
4.50
100.00
2.23
8.28
3.94
100.00
1.94
7.03
Properties of Heptanes plus:
°API Gravity at 60 °F
Density, gm/cc at 60 °F
Molecular Weight
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SBA-1 (DST-1)
45.6
0.797
142
SBA-1 (DST-2B)
29.3
0.8791
233
SCA-1 (DST-1)
30.5
0.873
240
SCA-1 (DST-3)
36.1
0.8434
173
SCA-5 (DST-1)
46.33
0.7949
124.78
SCA-5 (DST-4)
44.8
0.8018
124.84
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34
DATA AVAILABILITY (PVT)
There are 6 samples of PVT (Gas, Black Oil, Volatile Oil and Condensate)
PVT SB-SC
No
Well Name
Test
Date of
Sampling
1
SBA-1 (SB-1)
DST-1
13/02/1990 Talang Akar
2
SBA-1 (SB-1) DST-2B 18/02/1990
3
SCA-1 (SC-1)
DST-1
04/04/1990
4
SCA-1 (SC-1)
DST-3
07/04/1990
5
SCA-5 (SC-6)
DST-1
31/03/1994
6
SCA-5 (SC-6)
DST-4
15/04/1944
Formation Sampling
Surface
Sampling
Surface
Talang Akar
Sampling
Surface
Talang Akar
Sampling
Surface
Talang Akar
Sampling
Surface
Talang Akar
Sampling
Surface
Talang Akar
Sampling
Zone
SB-78
SB-76
SC-80
SC-75
Interval
Depth (ft)
7933-7950
7863-7880
7724-7765
7654-7695
8152-8156
8110-8132
7654-7664
7584-7594
Pressure
°API @60
Reservoir
Reservoir
Depth (ft
F
Pressure (Psig) Temperature (°F)
SSD)
Saturation Pressure
(Psig)
FVF Oil
@Pb
3297
GOR
@Pb
Density@ Visco Oil
Pb
@Pb
57
7942
3462
280
33.6
7675
3327
265
3122
2.295
1894
0.6288
0.258
35.8
8082
3515
264
2743
2.074
1477
0.6418
0.707
16
7586
3324
247
3324
4.348
4808
0.5663
0.252
SC-77B
10843-10873
52.8
10858
3640
280
3435
SC-74C
10036-10064
60.8
10050
3432
263
3310
ALL
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Dew
Point
(Psig)
SC
23396
SB
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35
PVT
- ANALYSIS -
PVT QUALITY CHECK AND MATCHING
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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36
PVT QUALITY CHECK
Compositional Check
(𝟐)
Sum xi
Sum yi
Sum zi
Mass Balance QC
PVT Samples
Integrated Validity and Consistency Analysis Parameters and Criteria
•
•
•
•
Leakage Check
P Lab vs P
Field
Condition ≤
10 Psi
Yes
No
Integrated Validity and Consistency Analysis
of Qualified PVT samples
LEMIGAS | DIREKTORAT JENDERAL MIGAS
2) GOR MB Plot Vs GOR Reported < 5% Difference
4) Impurities, Original Components, and Pseudo Components Deviation of
Eliminate
Sample
Reference :
Hoffman QC Plot : Plotting Hoffman factor
versus Log k for all the components, nearly
straight line means good quality separation.
2.
3.
4.
Consider to Use
3,5) R-Squared of Mass Balance Plot ≈ 1
Hoffman Quality Plot <5%
• 2) R-Squared Difference of CCE Check <1%
1.
• Compositional Check
• Separator Check (Hoffman Quality Plot)
• CCE/CVD/DLE Check
3) Sum. Mol Fraction = 100 %
5.
Laing, L.K. et.al., “Comprehensive PVT Data Review, Fluid
Characterization and Grouping Study for Block X in Sarawak,
Malaysia”, OTC-31417-MS, Offshore Technology Conference Asia,
Kuala Lumpur, 2022. DOI : https://doi.org/10.4043131417-MS
Ameen, M , “PVT Quality Check", Reservoir Solutions, Egypt, 2021.
https://reservoir-solution.odoo.com
Lawrence, John J. et at, “Quality Assessment and Consistency
Evaluation of Hydrocarbon PVT Data", IPTC 13784, International
Petroleum Technology Conference, Doha, Qatar, 2009. DOI :
https://doi.org/10.2523.IPTC-13784-MS
Hoffman, A. E. et al., “Equilibrium Constants for a Gas-Condensate
Systems, SPE 219-G, Petroleum Transactions, AIME, Houston,
Texas, 1953, Vol 198,1-10. DOI : https://doi.org/10.2118/219-G
Akpabio, J. U. et al, “PVT Fluid Characterization and Consistency
Check for Retrograde Condensate Reservoir Modeling’, SPE-172359MS, SPE Nigeria Annual International Conference and Exhibition,
Lagos. 2014 DOI : https://doi.org/10.2118/172359-MS
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37
OLD ZONE : SB-78
NEW ZONE : fs_3.1
PVT QUALITY CHECK
Checking method
Opening Pressure Vs
Sampling Pressure
Sum xi (Liquid Comp)
Compositional Sum yi (Gas Comp)
Analysis
Sum zi (Wellstream Comp)
Material Balance QC
Separator
Hoffman
Check
Y-function
CCE
Rel. vol. straight untill pb
Liquid Drop out with CCE
Note
Not Valid
22 Psi Difference, Leakage Indication
Valid
Valid
Valid
Not Valid
Y function vs Pressure
7.16%
Valid
1.4000
1.2000
1.0000
0.8000
0.6000
0.4000
0.2000
0.0000
Calc Yfunction
y = 0.0002x + 0.774
R² = 0.9936
0
1000
2000
3000
Linear (Calc
Yfunction)
4000
Pressure
Valid
Valid
Insufficient
Data
Relative Volume
Relative Volume
CVD
Validity
Y Function
Item
Leakage
Check
SB-1 DST#1 (SB-78)
7.000
6.000
5.000
4.000
3.000
2.000
1.000
0.000
y = -0.0001x + 1.3805
R² = 0.9867
Calcualted Rel.
Vol.
Reported Rel.
Vol Above Pb
0
2000
4000
Pressure
6000
Reported
Rel.Vol. Below
Pb
Hoffman Plot
SB-1 (DST-1)
Sampling Condition
T : 84 deg F
P : 187 Psig
R² : 0.9518
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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39
PVT Analysis SB-1 (DST-1)
SB-1 DST#1
Liq Dropout
WELL STREAM
Gas Z Factor
Last Reservoir Pressure/Bubble Point @3462 Psig
Component
H2S
CO2
N2
C1
C2
C3
iC4
nC4
iC5
nC5
C6
C7+
TOTAL
Properties of Heptane +
API gravity @ 60 F
Density,gm/cc at 60 F
Molecular Weight
Mol
Percent
Weight
Percent
0
21.35
0.6
52.29
4.57
12
2.92
2.22
1.12
0.52
0.57
1.84
100
-
45.6
0.7984
144
Sampling Condition
Last Reservoir Pressure
3462
Dew Point Pressure
3297
Reservoir Temperature
280
Prim. Sep. Pressure
187
Prim. Sep. Temperature
84
Field Stock Tank Liq. Gravity
57
Prim Sep Gas Prod Rate
1589
Lab Gas Gravity
Original GOR
Prim. Sep Gas/ Stock Liq Ratio
Lab Gas Liq Ratio
Z init
Bg
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Two Phase Z factor
Separator Condition @187 Psig
1.008
23396
23029
PSIG
PSIG
F
PSIG
F
API @ 60 F
MSCF/day
SCF/STB
SCF/BBL
SCF/BBL
ft3/scf
• As the GOR and the C7+ Composition Shown as Wet Gas Fluid
Type.
• The last reservoir pressure is above the dew point pressure
• The phase envelope still shown as a little bit oily or need to be
improved. Due to matching the liquid dropout, the Gas z factor
didn’t match fairly.
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41
OLD ZONE : SB-76
NEW ZONE : fs_2.3
PVT QUALITY CHECK
Checking method
Opening Pressure Vs
Sampling Pressure
Sum xi
Compositional Sum yi
Analysis
Sum zi
Material Balance QC
Separator
Hoffman
Check
Y-function
CCE
Rel. vol. straight untill pb
Validity
Y function vs Pressure
Note
3.0000
Valid
y = 0.0005x + 0.9182
R² = 0.9895
2.5000
Y Function
Item
Leakage
Check
Valid
Valid
Valid
Not Valid
SB-1 DST#2B (SB-76)
2.0000
Calc Yfunction
1.5000
1.0000
Linear (Calc
Yfunction)
0.5000
Close to 5% Diff
0.0000
Valid
Not Valid
Valid
0
1000
2000
3000
4000
Pressure
Above 1% Very Close
Relative Volume
Relative Volume
6.000
Calculated
Rel.vol
5.000
4.000
3.000
y = -2E-05x + 1.073
R² = 0.9963
2.000
1.000
Reported Rel.vol
Above Pb
Reported Below
Pb
0.000
0
2000
4000
6000
Pressure
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Slope
Oil Density, lb/cuft
Oil MW, lb/lbmol
MB GOR, scf/stb
Lab GOR, scf/stb
Difference, %
0.71
53.45
155
1035.22
962
7.61
Hoffman Plot
SB-1 (DST-2B)
Sampling Condition
T : 90 deg F
P : 155 Psig
R² : 0.8895
R² Without C7+ = 0.9895
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42
PVT Analysis SB-1 (DST-2B)
SBA-1 (DST-2B)
Component
Well Stream
Mol%
Wt%
0.00
0.00
H2S
Hydrogen Sulfide
CO2
Carbon Dioxide
17.27
9.19
0.08
N2
Nitrogen
0.23
C1
Methane
27.66
5.36
C2
Ethane
4.78
1.74
C3
Propane
13.80
7.36
iC4
Iso-Butane
3.35
2.35
nC4
N-Butane
3.66
2.57
iC5
Tso-Pentane
1.68
1.47
N-Pentane
1.07
0.93
Hexanes
3.16
3.21
23.34
100.00
65.74
100.00
nC5
C6
C7+
Heptanes plus
Properties of Heptanes plus:
°API Gravity at 60 °F
Density, gm/cc at 60 °F
Molecular Weight
Sampling Condition
Last Reservoir Pressure
3327
Bubble Point Pressure
3122
Reservoir Temperature
265
Prim. Sep. Pressure
155
Prim. Sep. Temperature
90
Field Stock Tank Liq. Gravity
33.6
Prim Sep Gas Prod Rate
2088.08
Prim Sep Liq Prod Rate
2170
Lab Gas Gravity
1.076
Prim. Sep Gas/ Sep Liq Ratio
962
Boi
2.28123
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SBA-1 (DST-2B)
29.3
0.8791
233
PSIG
PSIG
F
PSIG
F
API @ 60 F
MSCF/day
BBL/day
Reservoir Condition @3122 Psig
Separator Condition @155 Psig
• As the GOR and the C7+
Composition Shown as Black Oil
Fluid Type.
• The last reservoir pressure is
above the bubble point pressure
• The phase envelope still shown as
Black oil
SCF/BBL
rb/stb
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44
PVT Analysis SB-1 (DST-2B)
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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45
OLD ZONE : SB-80
NEW ZONE : fs_3.4
PVT QUALITY CHECK
Checking method
Validity
Opening Pressure Vs
Valid
Leakage Check Sampling Pressure
Sum xi
Valid
Valid
Compositional Sum yi
Analysis
Sum zi
Valid
Material Balance QC
Not Valid
Separator
Hoffman
Valid
Check
Y-function
Valid
CCE
Rel. vol. straight untill pb
Valid
CVD
Liquid Drop out with CCE
DLE
Insufficient Data
MBE check
Y function vs Pressure
Note
19 Psi Difference, Leakage Indication
Different Temperature
9.15%
3.0000
y = 0.0005x + 1.0454
R² = 0.9994
2.5000
Y Function
Item
SC-1 DST#1 (SB-80)
2.0000
Calc Yfunction
1.5000
1.0000
Linear (Calc
Yfunction)
0.5000
0.0000
0
1000
2000
3000
Pressure
Relative Volume
Relative Volume
5
4
Calcualted Rel.
Vol.
3
y = -2E-05x + 1.0551
R² = 0.9943
2
Reported Rel.vol
Above Pb
1
0
0
2000
4000
6000
Pressure
Hoffman Plot
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Slope
Oil Density, lb/cuft
Oil MW, lb/lbmol
MB GOR, scf/stb
Lab GOR, scf/stb
Difference, %
0.71
53.45
155
1035.22
962
7.61
SC-1 (DST-1)
Sampling Condition
T : 102 deg F
P : 246 Psig
R² : 0.9785
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46
PVT Analysis SC-1 (DST-1)
Component
SCA-1 (DST-1)
Well Stream
Mol%
Wt %
H2S
Hydrogen Sulfide
0.00
0.00
CO2
Carbon Dioxide
12.82
6.17
N2
Nitrogen
0.20
0.06
C1
Methane
27.01
4.74
C2
Ethane
4.80
1.58
C3
Propane
14.74
7.11
iC4
Iso-Butane
3.98
2.53
nC4
N-Butane
4.27
2.71
iC5
Tso-Pentane
2.15
1.70
nC5
N-Pentane
1.30
1.03
C6
Hexanes
1.79
1.64
Heptanes plus
26.94
100.00
70.73
100.00
Properties of Heptanes plus:
°API Gravity at 60 °F
Density, gm/cc at 60 °F
Molecular Weight
SCA-1 (DST-1)
30.5
0.873
240
C7+
Sampling Condition
Last Reservoir Pressure
3515
Bubble Point Pressure
2743
Reservoir Temperature
264
Prim. Sep. Pressure
246
Prim. Sep. Temperature
102
Field Stock Tank Liq. Gravity
35.8
Prim Sep Gas Prod Rate
434094
Prim Sep Liq Prod Rate
682
Lab Gas Gravity
1.006
Prim. Sep Gas/ Sep Liq Ratio
637
Boi
LEMIGAS | DIREKTORAT JENDERAL MIGAS
PSIG
PSIG
F
PSIG
F
API @ 60 F
MSCF/day
BBL/day
Reservoir Condition @3515 Psig
Separator Condition @246 Psig
• As the GOR and the C7+
Composition Shown as Black Oil
Fluid Type.
• The last reservoir pressure is
above the bubble point pressure
• The phase envelope still shown as
Black oil
SCF/BBL
rb/stb
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48
PVT Analysis SC-1 (DST-1)
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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49
PVT QUALITY CHECK
Checking method
Opening Pressure Vs
Sampling Pressure
Sum xi
Validity
Sum yi
Valid
Sum zi
Valid
Material Balance QC
Not Valid
17% diff
Hoffman
Valid
Y-function
Valid
C7+ Quite far
1 Outlier at Yfunction @3157 Psig
adjusted
Valid
CVD
Rel. vol. straight untill pb
Liquid Drop out with CCE
DLE
MBE check
Leakage Check
Compositional
Analysis
Separator Check
Y function vs Pressure
Valid
2.0000
Valid
1.5000
Y Function
1.0000
Linear (Y
Function)
0.5000
y = 0.0003x + 0.8166
R² = 0.9973
0.0000
0
1000
2000
3000
4000
Pressure
Relative Volume
Insufficient
Data
6
Relative Volume
CCE
Note
Y Function
Item
SC-1 DST#3 (SC-75)
Calcualted Rel.
Vol.
5
4
Series2
3
y = -5E-05x + 1.1602
R² = 0.9845
2
1
0
0
2000
4000
6000
Reported Below
Pb
Linear (Series2)
Pressure
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Slope
Oil Density, lb/cuft
Oil MW, lb/lbmol
MB GOR, scf/stb
Lab GOR, scf/stb
Difference, %
0.54
59.83
110
2161.93
2615
17.33
Hoffman Plot
SC-1 (DST-3)
Sampling Condition
T : 90 deg F
P : 240 Psig
R² : 0.9864
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51
PVT Analysis SC-1 (DST-3)
Component
H2S
SCA-1 (DST-3)
Well Stream
Mol%
Wt %
Hydrogen Sulfide
0.00
0.00
CO2
Carbon Dioxide
21.99
16.36
N2
Nitrogen
0.24
0.11
C1
Methane
34.41
9.33
C2
Ethane
3.24
1.65
C3
Propane
10.50
7.83
iC4
Iso-Butane
3.56
3.50
nC4
N-Butane
3.16
3.11
iC5
Tso-Pentane
2.16
2.63
nC5
N-Pentane
1.21
1.48
C6
Hexanes
2.07
2.94
Heptanes plus
17.46
100.00
51.06
100.00
Properties of Heptanes plus:
°API Gravity at 60 °F
Density, gm/cc at 60 °F
Molecular Weight
SCA-1 (DST-3)
36.1
0.8434
173
C7+
Sampling Condition
Last Reservoir Pressure
3324
Bubble Point Pressure
3324
Reservoir Temperature
247
Prim. Sep. Pressure
240
Prim. Sep. Temperature
90
Field Stock Tank Liq. Gravity
16
Prim Sep Gas Prod Rate
1103.548
Prim Sep Liq Prod Rate
422
Lab Gas Gravity
1.034
Prim. Sep Gas/ Sep Liq Ratio
2615
Boi
2.074
LEMIGAS | DIREKTORAT JENDERAL MIGAS
PSIG
PSIG
F
PSIG
F
API @ 60 F
MSCF/day
BBL/day
SCF/BBL
rb/stb
Last Reservoir Pressure/Bubble Point @3324 Psig
Separator Condition @240 Psig
• As the GOR and the C7+
Composition Shown as Volatile
Oil Fluid Type.
• The last reservoir pressure is the
same as bubble point pressure
• The phase envelope still shown as
Black Oil/Volatile Oil
• The API reported in PVT and
Completion log is 16 API, minwhile
the zone above on the dst (3A and
3A retest) and completion log
stated the API are 38.5 and 3.75
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53
PVT Analysis SC-1 (DST-3)
Old Completion Log
LEMIGAS | DIREKTORAT JENDERAL MIGAS
New Completion Log
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54
PVT Analysis SC-1 (DST-3)
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
55
PVT QUALITY CHECK
Leakage Check
Compositional
Analysis
Checking method
Opening Pressure Vs
Sampling Pressure
Sum xi
Sum yi
Sum zi
Material Balance QC
Validity
Not Valid
Y function vs Pressure
Note
20 Psi Difference, Leakage Indication.
Different Temperature
Valid
Valid
Valid
Not Valid
30.99%
1.4
1.2
Y Function
Item
SC-6 DST#1 (SC-77B)
1
0.8
Calc Yfunction
y = 0.0001x + 0.7497
R² = 0.9995
0.6
0.4
Linear (Calc
Yfunction)
0.2
Separator
Check
Hoffman
Valid
CCE
Y-function
Rel. vol. straight untill pb
CVD
Liquid Drop out with CCE
Valid
Valid
Insufficient
Data
0
0
1000
2000
3000
4000
Pressure
Relative Volume
Relative Volume
5.000
y = -0.0001x + 1.4767
R² = 0.9826
4.000
Calculated Rel.
Vol
3.000
Reported Rel. Vol.
Above Pb
2.000
1.000
0.000
0
2000
4000
6000
Reported Rel. Vol.
Below Pb
Pressure
OLD ZONE : SC-77B
NEW ZONE : mfs_4
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Slope
Oil Density, lb/cuft
Oil MW, lb/lbmol
MB GOR, scf/stb
Lab GOR, scf/stb
Difference, %
0.12
47.88
81
10199
14779
30.99
Hoffman Plot
SC-6 (DST-1)
Sampling Condition
T : 32 deg F
P : 185 Psig
R² : 0.9069
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56
PVT Analysis SC-6 (DST-1)
SC-6 DST#1
SC-6 DST#1 (SC-77B)
Last Reservoir Pressure/Bubble Point @3432 Psig
WELL STREAM
Component
H2S
CO2
N2
C1
C2
C3
iC4
nC4
iC5
nC5
C6
C7+
TOTAL
Properties of Heptane +
API gravity @ 60 F
Density,gm/cc at 60 F
Molecular Weight
Mol
Weight
Percent Percent
0
40.07
0.08
34.45
5.05
10.19
2.21
1.87
0.62
0.42
0.54
4.5
100
46.33
0.7949
124.78
Separator Condition @3310 Psig
Lab Gas Gravity
Prim. Sep Gas/ Stock Liq
Ratio
Lab Gas Liq Ratio
Z init
Bg
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Gas Z Factor
Two Phase Z factor
Sampling Condition
Last Reservoir Pressure
3432
Dew Point Pressure
3310
Reservoir Temperature
263
Prim. Sep. Pressure
310
Prim. Sep. Temperature
55
Field Stock Tank Liq.
Gravity
60.8
Prim Sep Gas Prod Rate
Liq Dropout
11792
0.956
PSIG
PSIG
F
PSIG
F
API @ 60
F
MSCF/da
y
14444
SCF/BBL
14138
SCF/BBL
0.8346
0.0199674
01
ft3/scf
• As the GOR and the C7+
Composition Shown as
Condensate Fluid Type.
• The last reservoir
pressure is above the
dew point pressure
• The phase envelope still
shown as Condensate.
Due to matching the
liquid dropout, the Gas z
factor didn’t match fairly.
your excellent partner in oil and gas
58
PVT QUALITY CHECK
Compositional
Analysis
Checking method
Opening Pressure Vs
Sampling Pressure
Sum xi
Validity
Not Valid
Sum yi
Valid
Valid
Valid
Not Valid
Separator
Check
Hoffman
Valid
CCE
Y-function
Rel. vol. straight untill pb
CVD
Liquid Drop out with CCE
Valid
Valid
Insufficient
Data
1.4
1.2
42.48%
1
0.8
Calc Yfunction
y = 0.0001x + 0.7341
R² = 0.9991
0.6
0.4
Linear (Calc
Yfunction)
0.2
0
0
1000
2000
3000
4000
Pressure
Relative Volume
5.000
Relative Volume
Sum zi
Material Balance QC
Y function vs Pressure
Note
47 Psi Difference, Leakage Indication
Different Temperature
Y Function
Item
Leakage
Check
SC-6 DST#4 (SC-74C)
y = -0.0001x + 1.4488
R² = 0.9809
4.000
Calculated Rel.
Vol
3.000
Reported Rel. Vol.
Above Pb
2.000
1.000
0.000
0
2000
4000
6000
Reported Rel. Vol.
Below Pb
Pressure
OLD ZONE : SC-77C
NEW ZONE : mfs_3
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Slope
Oil Density, lb/cuft
Oil MW, lb/lbmol
MB GOR, scf/stb
Lab GOR, scf/stb
Difference, %
0.16
45.89
72
8309
14444
42.48
Hoffman Plot
SC-6 (DST-4)
Sampling Condition
T : 55 deg F
P : 310 Psig
R² : 0.9938
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60
PVT Analysis SC-6 (DST-4)
SC-6 DST#4
Component
H2S
CO2
N2
C1
C2
C3
iC4
nC4
iC5
nC5
C6
C7+
TOTAL
Properties of Heptane +
API gravity @ 60 F
Density,gm/cc at 60 F
Molecular Weight
Liq Dropout
Last Reservoir Pressure/Bubble Point @3640 Psig
WELL STREAM
Mol
Percent
Weight
Percent
0
39.34
0.16
39.57
3.06
7.55
2.17
1.66
0.93
0.54
1.08
3.94
100
-
44.8
0.8018
124.84
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Gas Z Factor
Separator Condition @3345 Psig
Two Phase Z factor
Sampling Condition
Last Reservoir Pressure
3640
Dew Point Pressure
Reservoir Temperature
Prim. Sep. Pressure
Prim. Sep. Temperature
3345
280
185
32
PSIG
PSIG
F
PSIG
F
API @ 60
F
MSCF/day
Field Stock Tank Liq. Gravity 52.8
Prim Sep Gas Prod Rate
6596
Lab Gas Gravity
0.89
Prim. Sep Gas/ Stock Liq
Ratio
16852.3 SCF/BBL
Lab Gas Liq Ratio
14779 SCF/BBL
Z init
0.8346
Bg
0.03562 ft3/scf
• As the GOR and the C7+
Composition Shown as
Condensate Fluid Type.
The composition quite
similar with DST-1.
• The last reservoir
pressure is above the
dew point pressure
• The phase envelope still
shown as Condensate.
Due to matching the
liquid dropout, the Gas z
factor didn’t match fairly.
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62
PTA
Analysis from DST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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64
PTA SB-1 DST-1
DST Operation Summary
WET GAS
: 12/Feb/1990 – 14/Feb/1990
: 7933 – 7950 ft
: 17 ft
:
: Wet Gas
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 57 @ 60 F
Gas/Oil Ratio
: 14014 (SCF/STB)
Gas Gravity (SG)
: 1.03
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 277.5 F
: 7 in
: 2.875 in (OD) , 2.441 in (ID)
Available Rate
N2 Only
LEMIGAS | DIREKTORAT JENDERAL MIGAS
No Hydrocarbon Rate in the 1st Build Up, the analysis can’t be
yourdone
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65
PTA SB-1 DST-2B
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
: 12/Feb/1990 – 14/Feb/1990
: 7724 – 7765 ft
: 41 ft
:
: Black Oil
: Gas Rate & Liquid Rate
This DST operation and has 2 build up phase. The phase
can be analyzed is the 2nd Build Up Phase with 417.6 Min
test duration
BLACK OIL
DST Operation Summary
Hydrocarbon Properties
Oil Gravity
: 33.6 @ 60 F
Gas/Oil Ratio
: 989 (SCF/STB)
Gas Gravity (SG)
: 1.11
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 275.83 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
LEMIGAS | DIREKTORAT JENDERAL MIGAS
2nd Build Up Phase
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66
BLACK OIL
PTA SB-1 DST-2B
2nd PBU (4th Periode)
h
K
Skin
Pi
= 41 ft
= 519 mD
= 15.2
= 3223.63 Psi
The Type-curve of the 2nd PBU period represent the response of homogeneous
model. The down phase of the derivative curves suspected as a disturbance during
the test. The 1st Build Up Model doesn’t have the production rate before the well
shut in.
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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67
BLACK OIL
PTA SC-1 DST-1
: 3/Apr/1990 – 5/Apr/1990
: (8110-8132 & 8139-8156) ft
: 39 ft
:
: Black Oil
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
DST Operation Summary
Hydrocarbon Properties
Oil Gravity
: 35.8 @ 60 F
Gas/Oil Ratio
: 669.3 (SCF/STB)
Gas Gravity (SG)
: 1.03
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 275.15 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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68
PTA SC-1 DST-1
2nd PBU (4th Periode)
BLACK OIL
h
K
Skin
Pi
= 39 ft
= 8.14 mD
= 6.01
= 3400.85 Psi
This model build as the shape of
pressure response. We have tried
the dual layers model as the log
and perforation shown, but it’s
difficult to match the graph.
h
K
Skin
Pi
= 39 ft
= 8.38 mD
= 6.33
= 3423.1 Psi
This analysis was suggested by
A.I. as the suspected profile of the
pressure model. The validation
may be required after the structure
map done.
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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69
PTA SC-1 DST-3
VOLATILE OIL
DST Operation Summary
: 6/Apr/1990 – 8/Apr/1990
: 7654-7664 ft
: 10 ft
:
: Volatile Oil
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 16 @ 60 F
Gas/Oil Ratio
: 3156.8 (SCF/STB)
Gas Gravity (SG)
: 1.05
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 253.55 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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70
PTA SC-1 DST-3
VOLATILE OIL
2nd PBU (4th Periode)
h
K
Skin
Pi
= 10 ft
= 12100 mD
= 25.1
= 3244.02 Psi
This model build as the shape of pressure response. No A.I. suggestion for this kind of pressure
responses.The homogeneous reservoir with rectangle boundary choosen. The rectangle boundary
model choosen because of the derivatives curved downwards as the response of the pressure
transient has reached the boundaries.
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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71
PTA SC-1 DST-3a
VOLATILE OIL
DST Operation Summary
: 8/Apr/1990 – 10/Apr/1990
: 7600-7664 ft
: 64 ft
:
: Volatile Oil
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 39.5 @ 60 F
Gas/Oil Ratio
: 11190.3 (SCF/STB)
Gas Gravity (SG)
: 1.05
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 252.32 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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72
PTA SC-1 DST-3a
From the pressure and the derivative profile, there’s two possible model
that should be validated by the structure map. Circle and Rectangle
boundary choosen because the curve downwards as the result of the
pressure transient has reached the boundary.
LEMIGAS | DIREKTORAT JENDERAL MIGAS
VOLATILE OIL
h
K
Skin
Pi
= 64 ft
= 1860 mD
= 24
= 3230.67 Psi
h
K
Skin
Pi
= 64 ft
= 1840 mD
= 24.1
= 3230.6 Psi
your excellent partner in oil and gas
73
PTA SC-2 DST-1
BLACK OIL
DST Operation Summary
: 31/Aug/1991 – 2/Sep/1991
: 8566-8688 ft
: 12 ft
:
: Black Oil
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 39.5 @ 60 F
Gas/Oil Ratio
: 1622 (SCF/STB)
Gas Gravity (SG)
: 0.95
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 278 F
: 7 in
: 3.5 in (OD) , 2.992 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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74
PTA SC-2 DST-1
BLACK OIL
h
K
Skin
Pi
= 10 ft
= 20.3 mD
= -1.04
= 3775.54 Psi
Limited Entry happened when the perforation column is less than total reservoir thickness.
This caused various flow type showed in the picture. 1.) Radial flow 2.) Spherical Flow and 3.)
Back to Radial Flow
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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75
PTA SC-2 DST-3
CONDENSATE
DST Operation Summary
: 4/Sep/1991 – 7/Sep/1991
: 8002-8056 ft
: 54 ft
:
: Condensate
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 43.5 @ 60 F
Gas/Oil Ratio
: 71361 (SCF/STB)
Gas Gravity (SG)
: 0.96
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 264 F
: 7 in
: 3.5 in (OD) , 2.991 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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76
PTA SC-2 DST-3
CONDENSATE
h
K
Skin
Pi
= 54 ft
= 508 mD
= 13.8
= 3259.59 Psi
From the log above, the hydrocarbon comes out from the same
body sand. The boundary needs to be checked later
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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77
CONDENSATE
PTA SC-3 DST-4
: 21/Jul/1991 – 23/Jul/1991
: 10134 – 10150 ft
: 16 ft
:
: Condensate
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
DST Operation Summary
Hydrocarbon Properties
Oil Gravity
: 60.7 @ 60 F
Gas/Oil Ratio
: 16232 (SCF/STB)
Gas Gravity (SG)
: 0.838
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 268 F
: 7 in
: 3.5 in (OD) , 2.992 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
78
PTA SC-3 DST-4
Composite model could be
identified from the double IARF
which rising or decreasing
dependant to its M and D
LEMIGAS | DIREKTORAT JENDERAL MIGAS
CONDENSATE
h
K
Skin
Pi
= 16 ft
= 11.2 mD
= 19
= 3535.21 Psi
h
K
Skin
Pi
= 16 ft
= 11.2 mD
= 19
= 3500.94 Psi
your excellent partner in oil and gas
79
PTA SC-3 DST-5
CONDENSATE
DST Operation Summary
: 21/Jul/1991 – 2/Sep/1991
: 8992 – 9004 ft
: 12 ft
:
: Condensate
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 68.1 @ 60 F
Gas/Oil Ratio
: 15194 (SCF/STB)
Gas Gravity (SG)
: 0.844
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 259 F
: 7 in
: 3.5 in (OD) , 2.992 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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80
PTA SC-3 DST-5
CONDENSATE
Homogeneous
h
K
Skin
Pi
= 12 ft
= 5510 mD
= 7.49
= 3157.27 Psi
Intersecting
Fault
Limited Entry
Limited Entry happened when the
perforation column is less than total
reservoir thickness. This caused various
flow type showed in the picture. 1.) Radial
flow 2.) Spherical Flow and 3.) Back to
Radial Flow
LEMIGAS | DIREKTORAT JENDERAL MIGAS
h
K
Skin
Pi
= 12 ft
= 5100 mD
= 6.56
= 3158.23 Psi
This model also suggested by A.I.
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81
PTA SC-4 DST-1
BLACK OIL
DST Operation Summary
: 31/Dec/1991 – 1/Jan/1992
: 8562-8574 ft
: 12 ft
:
: Black Oil
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 36.5 @ 60 F
Gas/Oil Ratio
: 272 (SCF/STB)
Gas Gravity (SG)
: 1.17
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 282 F
: 7 in
: 2.875 in (OD) , 2.442 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
82
BLACK OIL
PTA SC-4 DST-1
h
K
Skin
Pi
= 12 ft
= 8.59 mD
= -0.648
= 3506.04 Psi
If K1>K2, the pressure drop in
layer 1 will be higher than 2.
Therefore there will be flow from
layer 2 to layer 1
Double permeability model is
identified by the cave before the
total IARF of 2 layer with different
permeability
LEMIGAS | DIREKTORAT JENDERAL MIGAS
h
K
Skin
Pi
= 12 ft
= 8.59 mD
= -1.17
= 4033.96 Psi
your excellent partner in oil and gas
83
PTA SC-4 DST-2
BLACK OIL
DST Operation Summary
: 1/Jan/1992 – 3/Jan/1992
: (8362-8574 & 8450-8456) ft
: 20 ft
:
: Black Oil
: Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 30 @ 60 F
Gas/Oil Ratio
: 1.7 (SCF/STB)
Gas Gravity (SG)
: 1.2
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 280 F
: 7 in
: 2.875 in (OD) , 2.442 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
84
PTA SC-4 DST-2
BLACK OIL
Homogeneous
h
K
Skin
Pi
Homogeneous
h
K
Skin
Pi
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Parallel Faults
= 20 ft
= 7.36 mD
= -0.428
= 3481.87 Psi
One Fault
= 20 ft
= 7.05 mD
= -0.681
= 3452.09 Psi
your excellent partner in oil and gas
85
PTA SC-6 DST-1a
CONDENSATE
DST Operation Summary
: 29/Mar/1992 – 1/Apr/1992
: 10828 – 10858 ft
: 30 ft
:
: Condensate
: Gas Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 52.8 @ 60 F
Gas/Oil Ratio
: 16624 (SCF/STB)
Gas Gravity (SG)
: 0.89
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 259 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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86
PTA SC-6 DST-1A
CONDENSATE
Two Layers
Rectangle
h
K
Skin
Pi
= 12 ft
= 30 mD
= -0.8
= 3526.14 Psi
Double permeability model is
identified by the cave before the
total IARF of 2 layer with different
permeability
If K1>K2, the pressure drop in
layer 1 will be higher than 2.
Therefore there will be flow from
layer 2 to layer 1
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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87
PTA SC-6 DST-4
CONDENSATE
DST Operation Summary
: 14/Apr/1994 – 16/Apr/1994
: 10036 – 10064 ft
: 28 ft
:
: Condensate
: Gas Rate & Liquid Rate
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 60.8 @ 60 F
Gas/Oil Ratio
: 14630 (SCF/STB)
Gas Gravity (SG)
: 0.96
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 268 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
88
PTA SC-6 DST-4
LEMIGAS | DIREKTORAT JENDERAL MIGAS
CONDENSATE
h
K
Skin
Pi
= 28 ft
= 30 mD
= 10.3
= 3432.34 Psi
h
K
Skin
Pi
= 28 ft
= 201 mD
= 9.77
= 3434.41 Psi
your excellent partner in oil and gas
89
PTA SC-6 DST-5
CONDENSATE
DST Operation Summary
: 17/Apr/1994 – 20/Apr/1992
: 8978 – 8986 ft
: 28 ft
:
: Condensate
: Gas Rate only before B.U.
Date
Perforation Interval
Net Pay
Zone
Major Phase
Available Rate
Hydrocarbon Properties
Oil Gravity
: 69.5 @ 60 F
Gas/Oil Ratio
: 16624 (SCF/STB)
Gas Gravity (SG)
: 0.88
Well Properties
Hole Temperature
Hole/Casing Size
Tubing
: 234.7 F
: 7 in
: 2.875 in (OD) , 2.441 (ID)
Available Rate
2nd Build Up Phase
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
90
CONDENSATE
PTA SC-6 DST-5
h
K
Skin
Pi
= 28 ft
= 1.42 mD
= 45.8
= 3130.29 Psi
The Rate data doesn’t inline with the pressure
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
91
PRODUCTION
Production Profile and Splitting Preparation
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
94
PRODUCTION PROFILE SB
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
LEMIGAS | DIREKTORAT JENDERAL MIGAS
3705 BOPD
4/1/1994
734 BOPD
12/1/1992
5%
7 BOPD
4/1/2018
86%
your excellent partner in oil and gas
95
PRODUCTION PROFILE SC
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
LEMIGAS | DIREKTORAT JENDERAL MIGAS
2502 BOPD
8/1/1996
617 BOPD
6/1/1996
11%
12 BOPD
3/1/2017
89%
your excellent partner in oil and gas
96
PRODUCTION PROFILE SBA-1
Min Date 01-Dec-92 Max Date 01-Apr-18
Well
SBA-1
Cum Oil
(MMBO)
1.44
Cum Gas
(BCF)
8.51
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
97
PRODUCTION PROFILE SBA-1
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
1624 BOPD
7/1/1993
450 BOPD
12/1/1992
6%
7 BOPD
4/1/2018
86%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
334 MSCFD
743 SCF/STB
3969 MSCFD
8/1/1993
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
98
PRODUCTION PROFILE SBA-2
Min Date 01-Dec-92 Max Date
Well
SBA-2
01-Jul-07
Cum Oil
(MMBO)
0.76
Cum Gas
(BCF)
2.36
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
99
PRODUCTION PROFILE SBA-2
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
1706 BOPD
9/1/1993
284 BOPD
12/1/1992
2%
31 BOPD
7/1/2007
87%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
967 MSCFD
3407 SCF/STB
8788 MSCFD
6/1/1993
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Multilayer Channeling
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
0
PRODUCTION PROFILE SBA-4st
Min Date 01-Sep-99 Max Date 01-Jun-07
Well
SBA-4ST
Cum Oil
(MMBO)
0.26
Cum Gas
(BCF)
1.55
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
1
PRODUCTION PROFILE SBA-4st
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
751 BOPD
8/1/2000
188 BOPD
5/1/2000
26%
145 BOPD
6/1/2007
51%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
2530 MSCFD
13476 SCF/STB
3062 MSCFD
11/1/1999
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
2
PRODUCTION PROFILE SBA-5
Min Date 01-Nov-93 Max Date 01-Sep-95
Well
SBA-5
Cum Oil
(MMBO)
0.49
Cum Gas
(BCF)
1.35
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
3
PRODUCTION PROFILE SBA-5
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
1540 BOPD
9/1/1994
273 BOPD
11/1/1993
0%
5 BOPD
9/1/1995
50%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
576 MSCFD
2108 SCF/STB
4549 MSCFD
3/1/1995
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
4
PRODUCTION PROFILE SBA-5st
Min Date 01-Mar-00 Max Date 01-Oct-13
Well
SBA-5ST
Cum Oil
(MMBO)
0.23
Cum Gas
(BCF)
6.35
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
5
PRODUCTION PROFILE SBA-5st
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
419 BOPD
4/1/2000
316 BOPD
3/1/2000
20%
1 BOPD
10/1/2013
86%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
3391 MSCFD
10722 SCF/STB
6399 MSCFD
6/1/2000
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
6
PRODUCTION PROFILE SCA-1L
Min Date 01-Jun-96 Max Date 01-Feb-08
Well
SCA-1L
Cum Oil
(MMBO)
0.41
Cum Gas
(BCF)
1.57
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
7
PRODUCTION PROFILE SCA-1L
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
651 BOPD
2/1/2005
53 BOPD
6/1/1996
4%
61 BOPD
2/1/2008
6%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
85 MSCFD
1614 SCF/STB
4344 MSCFD
2/1/1997
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
8
PRODUCTION PROFILE SCA-1S
Min Date 01-Jun-96 Max Date 01-Jun-98
Well
SCA-1S
Cum Oil
(MMBO)
0.11
Cum Gas
(BCF)
4.20
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
10
9
PRODUCTION PROFILE SCA-1S
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
465 BOPD
12/1/1996
84 BOPD
6/1/1996
6%
1 BOPD
6/1/1998
96%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
804 MSCFD
9532 SCF/STB
10629 MSCFD
1/1/1997
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
0
PRODUCTION PROFILE SCA-2L
Min Date 01-Jun-96 Max Date 01-Dec-00
Well
SCA-2L
Cum Oil
(MMBO)
0.15
Cum Gas
(BCF)
1.96
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
1
PRODUCTION PROFILE SCA-2L
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
335 BOPD
7/1/1996
35 BOPD
6/1/1996
17%
11 BOPD
12/1/2000
3%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
87 MSCFD
2499 SCF/STB
5124 MSCFD
7/1/2000
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
2
PRODUCTION PROFILE SCA-2S
Min Date 01-Jun-96 Max Date 01-Dec-00
Well
SCA-2S
Cum Oil
(MMBO)
0.14
Cum Gas
(BCF)
4.20
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
3
PRODUCTION PROFILE SCA-2S
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
458 BOPD
7/1/1996
109 BOPD
6/1/1996
6%
9 BOPD
12/1/2000
10%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
1043 MSCFD
9604 SCF/STB
10449 MSCFD
7/1/1997
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Normal Displacement with High WOR
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
4
PRODUCTION PROFILE SCA-3L
Min Date 01-Jun-96 Max Date
Well
SCA-3L
01-Jan-06
Cum Oil
(MMBO)
0.15
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Cum Gas
(BCF)
3.92
SCA-3L
your excellent partner in oil and gas
11
5
PRODUCTION PROFILE SCA-3L
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
531 BOPD
10/1/1996
257 BOPD
6/1/1996
17%
1 BOPD
1/1/2006
90%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
1754 MSCFD
6823 SCF/STB
11232 MSCFD
10/1/1996
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Multilayer Channeling with Production
Changes
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
6
PRODUCTION PROFILE SCA-3S
Min Date 01-Aug-96 Max Date 01-Mar-17
Well
SCA-3S
Cum Oil
(MMBO)
0.15
Cum Gas
(BCF)
5.02
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
7
PRODUCTION PROFILE SCA-3S
WATER DIAGNOSTIC PLOT
Water Control Diagnostic Plot (K.S. Chan, 1995)
GOR
Multilayer Channeling with Production
Changes
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
8
PRODUCTION PROFILE SCA-5
Min Date 01-Jun-96 Max Date 01-Mar-17
Well
SCA-5
Cum Oil
(MMBO)
0.52
Cum Gas
(BCF)
6.00
WELL PRODUCTION TEST
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
11
9
PRODUCTION PROFILE SCA-5
PEAK OIL PROD
PEAK OIL DATE
INITIAL OIL RATE
INITIAL PROD. DATE
INITIAL WC
LAST OIL PROD
LAST PROD. DATE
LAST WC
1106 BOPD
12/1/2003
79 BOPD
6/1/1996
0%
11 BOPD
3/1/2017
86%
INITIAL GAS RATE
INITIAL GOR
PEAK GAS RATE
PEAK GAS DATE
1216 MSCFD
15356 SCF/STB
12595 MSCFD
7/1/1996
WATER DIAGNOSTIC PLOT
Water Control Diagnostic
Plot (K.S. Chan, 1995)
GOR
Multilayer Channeling with Production
Changes
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
12
0
PRESSURE
SBHP Pressure Profile
LEMIGAS | DIREKTORAT JENDERAL MIGAS
your excellent partner in oil and gas
12
1
SBHP Pressure
Structure
PF
WELL
1
SB
SB
SB
SB
SB
SB
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SBA
SBA
SBA
SBA
SBA
SBA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SBA-2
SBA-2-BHP SB-73A/74
SBA-2
SBA-2-BHP SB-73A/74
SBA-4ST SBA-4ST-BHP B-28BC
SBA-4ST SBA-4ST-BHP B-28BC
SBA-4ST SBA-4ST-BHP B-28BC
SBA-4ST SBA-4ST-BHP B-28BC
SCA-1S SCA-1S-BHP
SCA-1S SCA-1S-BHP
SCA-2L SCA-2L-BHP
SC-80
SCA-2S SCA-2S-BHP
SC-75
SCA-3L SCA-3L-BHP
SCA-3L SCA-3L-BHP
SCA-3L SCA-3L-BHP
SCA-3L SCA-3L-BHP
SCA-3L SCA-3L-BHP
SCA-3S SCA-3S-BHP1
SCA-3S SCA-3S-BHP1
SCA-3S SCA-3S-BHP1
SCA-3S SCA-3S-BHP2
SCA-3S SCA-3S-BHP3
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
SCA-5L SCA-5L-BHP
B-28BC
2
3
4
5
6
7
8
9
10
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Old Zone New Zone
FS
SC-73
fs_2.1
SC-75
fs_2.3
SC-75
fs_2.2
SC-77B
mfs_3
SC-78
SB-1_BSAT
SC-77C SB-1_BSAT
SC-74B
fs_2.1
SC-75
fs_2.3
SC-80A
fs_3.4
SC-75
fs_2.3
SC-75
fs_2.3
SC-76B
fs_3.2
SC-77C
fs_3.4
SC-79
mfs_3
SC-80B SB-1.2_BSAT
SC-69
fs_2.2
SC-69B
mfs_1
SC-74B SB-1_BSAT
SC-69
mfs_1
SC-69
mfs_1
SC-70
fs_1.3
SC-71
fs_2.2
SC-71B
fs_2.3
SC-72
fs_2.4
SC-74B
mfs_2
SC-75
mfs_3
SC-76B
mfs_4
SC-77B SB-1_BSAT
SC-81
SB-1_BSAT
Remarks
Date of Test
Type of
test
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Single
Single
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Single
Single
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
Commingle
9/5/2005
9/5/2005
9/4/2005
9/4/2005
9/4/2005
9/4/2005
6/19/2007
6/19/2007
7/13/2002
5/27/2002
6/18/2006
6/18/2006
6/18/2006
6/18/2006
6/18/2006
6/18/2007
6/18/2007
6/18/2007
7/2/2002
7/2/2002
9/1/2005
9/1/2005
9/1/2005
9/1/2005
9/1/2005
9/1/2005
9/1/2005
9/1/2005
9/1/2005
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
SBHP
TEST
DEPTH
MD
7950.00
7950.00
6800.00
6800.00
6800.00
6800.00
5935.00
5935.00
8566.00
6000.00
10000.00
10000.00
10000.00
10000.00
10000.00
8942.00
8942.00
8942.00
8950.00
8950.00
9993.00
9993.00
9993.00
9993.00
9993.00
9993.00
9993.00
9993.00
9993.00
TEST
DEPTH
TVD
7273.89
7273.89
6341.78
6341.78
6341.78
6341.78
5865.00
5865.00
8059.46
5668.24
7955.08
7955.08
7955.08
7955.08
7955.08
7118.27
7118.27
7118.27
7124.43
7124.43
9925.00
9925.00
9925.00
9925.00
9925.00
9925.00
9925.00
9925.00
9925.00
DATUM
6989
FIELD
Pressure Profile
4000
3500
3000
P@ Datum
WELL NAME
PETREL
NO
2500
2000
SBHP
1500
1000
500
0
1987
1990
1993
1995
1998
2001
2004
2006
2009
Date
your excellent partner in oil and gas
12
2
DST Pressure
NO
Structure
PF
WELL
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
SB
SB
SB
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SB
SB
SC
SC
SC
SC
SC
SC
SC
SC
SC
SBA
SBA
SBA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SBA
SBA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SCA
SB-1
SB-1
SB-1
SC-1
SC-1
SC-1
SC-1
SC-2
SC-2
SC-2
SC-3
SC-3
SC-4
SC-4
SC-4
SC-6
SC-6
SC-6
SC-6
SB-1
SB-1
SC-1
SC-1
SC-2
SC-3
SC-3
SC-4
SC-4
SC-6
SC-6
WELL NAME
PETREL
LEMIGAS | DIREKTORAT JENDERAL MIGAS
Old Zone New Zone
SB-78
SB-76
SB-76
SC-80
SC-77B
SC-75
SC-76
SC-80
SC-77
SC-75
SC-71
SC-68
SC-80
SC-78
SC-72
SC-77B
SC-75
SC-74C
SC-69
SB-76
SB-76
SC-75
SC-76
SC-80
SC-71
SC-68
SC-80
SC-78
SC-77B
SC-74C
FS
SC-77B
fs_3.1
SC-75
fs_2.3
SC-75
fs_2.3
SC-80A
fs_3.4
SC-77B
fs_3.1
SC-75
fs_2.3
SC-75
fs_2.3
SC-79B
fs_3.4
SC-75
fs_3.1
SC-73
fs_2.3
SC-76B SB-1.2_BSAT
SC-68
mfs_1
SC-80C
fs_3.5
SC-79B SB-2_BSAT
SC-81
mfs_2
SC-81
mfs_4
SC-78
fs_3.2
SC-77B
mfs_3
SC-70
SB-1_BSAT
SC-75
fs_2.3
SC-75
fs_2.3
SC-75
fs_2.3
SC-75
fs_2.3
SC-79B
fs_3.4
SC-76B SB-1.2_BSAT
SC-68
mfs_1
SC-80C
fs_3.5
SC-79B SB-2_BSAT
SC-81
mfs_4
SC-77B
mfs_3
Remarks
Date of Test
Type of
test
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
Single
12/2/1990
2/14/1990
2/18/1990
4/3/1990
5/4/1990
6/4/1990
8/4/1990
8/31/1991
2/9/1991
4/9/1991
7/21/1991
7/23/1991
12/31/1992
1/1/1992
8/1/1992
3/23/1994
11/4/1994
4/14/1994
4/17/1994
2/14/1990
2/18/1990
6/4/1990
8/4/1990
8/31/1991
7/21/1991
7/23/1991
12/31/1992
1/1/1992
3/23/1994
4/14/1994
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
EO PBU
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
P* PTA
TEST
DEPTH
MD
7933
7724
7724
8110
7846
7654
7600
8566
8215
8002
10134
8992
8562
8362
7591
10828
10192
10036
8978
7724
7724
7654
7600
8566
10134
8992
8562
8362
10828
10036
TEST
DEPTH P @ Depth
TVD
7863
3352.99
7654
3213.73
7654
3220.61
8040
3408.88
7776
3203.05
7584
3229.68
7530
3214.16
8059.46
3395.1
7721.19 3280.81
7517.59 3243.73
8061.42 3484.79
7149
3138.72
8483
3452.75
8283
3389.84
7512
3223.26
8531
3638.19
8060
3489.5
7957.98 3437.59
7171.04
3131.8
7654
3223.63
7654
3400.85
7584
3244.02
7530
3230.67
8059.46
3775.54
8061.42
3535.21
7149
3158.23
8483
3506.04
8283
3481.87
8531
3526.14
7957.98
3434.41
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12
3
Mfs 1 Pressure
PVT & DST Overview
Mfs_1
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SC-3(SCA-3) #DST 5
8992-9004 ft MD / 7156.76-7166.03 ft TVDSS
1030 BOPD, GOR 15438.8 SCF/STB
Fluid Type : Wet Gas
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12
4
SB-1_Bsat Pressure
PVT & DST Overview
SB-1_Bsat
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SC-6(SCA-5) #DST 5
8978-8986 ft MD / 7170.99-7177.37 ft TVDSS
12 BOPD, GOR 50000 SCF/STB
Fluid Type : Wet Gas
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12
5
Fs_1.2 Bsat Pressure
No Pressure Profile
PVT & DST Overview
No Test/DST/PVT
Fs_1.2
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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12
6
Fs_1.3 Pressure
PVT & DST Overview
No Test/DST/PVT
Fs_1.3
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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12
7
Mfs_2 Pressure
PVT & DST Overview
No Test/DST/PVT
Mfs_2
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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12
8
fs_2.1 Pressure
PVT & DST Overview
fs_2.1
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SBA-5
#NA
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12
9
fs_2.2 Pressure
PVT & DST Overview
No Test/No DST/No PVT
fs_2.2
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
0
fs_2.3 Pressure
PVT & DST Overview
SCA-1(SC-1) #DST 3
fs_2.3
7654-7664 ft MD/7584-7594 ft TVDSS
475 BOPD, GOR 5762.1 SCF/STB
Fluid Type : Volatile Oil
PVT DATA AVAILABLE
SCA-1(SC-1) #DST 3A Retest
7600-7664 ft MD / 7530-7594 TVDSS
648 BOPD, GOR 11353.4 SCF/STB
Fluid Type : Volatile Oil
SCA-1(SC-1) #DST 3A
SCA-2(SC-2) #DST 3A
7600-7664 ft MD / 7530-7594 ft TVDSS
7600-7664 ft MD / 7517.54-7793.14 ft
TVDSS
510.749 BOPD, GOR 13629
SCF/STB
Fluid Type : Volatile Oil
834 BOPD, GOR 11199 SCF/STB
Fluid Type : Condensate
SBA-1(SB-1) #DST 2A
7724-7744 ft MD/7654-7674 ft TVDSS
1648 BOPD, GOR 2402.3
SCF/STB
Fluid Type : Volatile Oil
SBA-1(SB-1) #DST 2B
7724-7765 ft MD//7654-7695 TVDSS
SBA-5 DST #NA
2189 BOPD, GOR 1050.7
SCF/STB
Fluid Type : Black Oil
PVT DATA AVAILABLE
8095-8150 ft MD/7859.38-7912.25 ft
TVDSS
LEMIGAS | DIREKTORAT JENDERAL MIGAS
1624 BOPD, GOR 1734.6 SCF/STB
Fluid Type : Black Oil
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13
1
SB 1.2_BSAT Pressure
PVT & DST Overview
SB 1.2_BSAT
SC-3(SCA-3) #DST 4
7654-7664 ft MD/8061.37-8074 ft
TVDSS
475 BOPD, GOR 5762.1
SCF/STB
Fluid Type : Wet Gas
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13
2
Fs_2.4 Pressure
PVT & DST Overview
Fs_2.4
No Test/No DST/No PVT
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
3
PVT & DST Overview
mfs_3
Mfs_3 Pressure
SCA-5(SC-6) #DST 4
Choke 5/8”
10036-10064 ft MD/7957.93-7976.26 ft TVDSS
256 BOPD, GOR 14449.8 SCF/STB
Fluid Type : Condensate
PVT DATA AVAILABLE
SCA-5(SC-6) #DST 4
Choke 1”
10036-10064 ft MD/7957.93-7976.26 ft TVDSS
1264 BOPD, GOR 13907 SCF/STB
Fluid Type : Condensate
PVT DATA AVAILABLE
SCA-5(SC-6) #DST 4
Choke ½”
10036-10064 ft MD
527 BOPD, GOR 15757.1 SCF/STB
Fluid Type : Wet Gas
PVT DATA AVAILABLE
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
4
fs 3.1 Pressure
PVT & DST Overview
fs_3.1
SCA-1(SC-1) #DST 2
SCA-2(SC-2) #DST 2
7846-7876; 7880-7884 ft MD/
7776-7806; 7810-7814 ft TVDSS
8215-8290; 8308-8318 ft MD/
7721.15-7793.14; 7810,44-7820.06
Fluid Type : No Fluid
Fluid Type : Water
SBA-1(SBA-1) #DST 1
7933-7950 ft MD/
7863-7880 ft TVDSS
527 BOPD, GOR 24024.8
SCF/STB
Fluid Type : Wet Gas
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
5
fs 3.2 Pressure
PVT & DST Overview
fs_3.2
SCA-3(SC-3) #DST 3
10382-10392 ft MD
8255.88-8263.68 ft TVDSS
Fluid Type : N2 Lifting
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SCA-6(SC-5) #DST 3
10192-10201; 10232-10247 ft
MD
325 BOPD, GOR 969.2
SCF/STB
Fluid Type : N2 Lifting
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13
6
PVT & DST Overview
SB-2_BSAT Pressure
SB-2_BSAT
SC-4 #DST 2B
8362-8376 ft MD /
8284-8298 ft TVDSS
325 BOPD, GOR 969.2
SCF/STB
Fluid Type : Black Oil
SC-4) #DST 2
8362-8376 ft MD /
8284-8298 ft TVDSS
345 BOPD, GOR 1171
SCF/STB
Fluid Type : Black Oil
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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13
7
Fs_3.4 Pressure
PVT & DST Overview
fs_3.4
SCA-3(SC-3) #DST 1 (3/8”)
10634-10740 ft MD
8450.24-8529.66 ft TVDSS
Note : Gun Not Fired
SCA-1(SC-1) #DST 1
8110-8132 ft MD
8040-8062 ft TVDSS
662 BOPD, GOR 645
SCF/STB
Fluid Type : Black Oil
PVT DATA
AVAILABLE
SC-4 #DST 2A
8450-8456 ft MD /
8450-8372 ft TVDSS
11 BOPD
fluid Type : Black Oil
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SCA-1(SC-1) #DST 1
(PERF)
8139-8156 ft MD
8069-8086 ft TVDSS
Note : Gun not fired
SCA-2(SC-2) #DST 1
8566-8578 ft MD
8059.40-88071.02 ft
TVDSS
971 BOPD, GOR
1625.1 SCF/STB
Fluid Type : Black Oil
SCA-3(SC-3) #DST 1A (1/2”)
10634-10740 ft MD
8450.24-8529 ft TVDSS
660 BOPD, GOR 9939.4
SCF/STB
Fluid Type : Condensate
SCA-3(SC-3) #DST 2
10634-10740 ft MD
8410.68-7820.06 ft TVDSS
1090 BOPD, GOR 4789
SCF/STB
Fluid Type : Condensate
SCA-5(SC-6) #DST 2
10356-10378 ft MD
8171.27-8186.63 ft TVDSS
Note : #NA
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13
8
PVT & DST Overview
fs_3.4
SBA-4(SB-2) #DST 1
9838-9868 ft MD /
8622.61-8651.09 ft TVDSS
Fluid Type : No fluid
LEMIGAS | DIREKTORAT JENDERAL MIGAS
SBA-5(SC-5) #DST N/A
8438-8456 ft MD /
8189.11-8206.41 ft TVDSS
Fluid Type : No fluid
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13
9
PVT & DST Overview
Fs_3.5 Pressure
fs_3.5
SC-4 #DST 1
8562-8574 ft MD/8484-8496
ft TVDSS
98.5 BOPD, GOR 281.2
SCF/STB
Fluid Type : Black Oil
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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14
0
PVT & DST Overview
Mfs_4
Mfs_4 Pressure
SCA-5(SC-6) #DST 1
Choke 1”
10828-10858 ft MD/8531.09-8555.74 ft TVDSS
391 BOPD, GOR 14449.8 SCF/STB
Fluid Type : Wet Gas
PVT DATA AVAILABLE
SCA-5(SC-6) #DST 1
Choke 3/4”
10828-10858 ft MD/8531.09-8555.74 ft TVDSS
444 BOPD, GOR 20495.5 SCF/STB
Fluid Type : Wet Gas
PVT DATA AVAILABLE
SCA-5(SC-6) #DST 1
Choke ½”
10828-10858 ft MD/8531.09-8555.74 ft TVDSS
522 BOPD, GOR 22222.2 SCF/STB
Fluid Type : Wet Gas
PVT DATA AVAILABLE
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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14
1
NEXT TARGET
1. Prelimenary Production Splitting after the marker fix
2.
’ Permeability for validation
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14
2
Terima Kasih
www.lemigas.esdm.go.id
LEMIGAS | DIREKTORAT JENDERAL MIGAS
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