2D Seismic Data Interpretation and Volumetric Analyis of Dhulain Area, Upper Indus Basin, Pakistan
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Transcript of 2D Seismic Data Interpretation and Volumetric Analyis of Dhulain Area, Upper Indus Basin, Pakistan
2-D SEISMIC DATA INTERPRETATION AND VOLUMETRIC ANALYSIS OF DHULIAN AREA
UPPER INDUS BASIN, PAKISTAN.
FASIH AKHTAR
WASEEM ABBAS
HASNAIN ZAHOOR AWAN
SUPERVISOR: M. FAHAD MAHMOOD
EXTERNAL SUPERVISOR: Mr. SARMAD HASSAN SHARIF
2010-2014
OUTLINE OF PRESENTATION
Introduction Of the Area Objectives Methodology Adopted Overview of Potwar Sub Basin Petroleum System Seismic Interpretation Petrophysical Analysis Conclusions
OBJECTIVES
To carry out the seismic data interpretation and mapping of the area in order to understand the subsurface structural geometry of Dhulian anticline.
Preparation of Time and Depth Sections
Petrophysical Analysis of Dhulian-43 well to understand the reservoir potential of the structure.
Volumetric Analysis of the area to calculate remaining potential of the structure.
AREA OF INVESTIGATION
The Study area of Dhulian is located in the Eastern Potwar basin.
The Dhulian Area is bounded by Latitude 33°12'41“N and Longitude 72°12'00“E.
The Nearest city to the Dhulian study area is Pindi Gheb.
Oil was also discovered for the first time in Indo-Pakistan from Paleocene reservoirs, during further appraisal of Dhulian structure.
LOCATION MAP
A total of 49 wells were drilled in Dhulian oil field
Three wells have been drilled by Attock Oil Company (A.O.C.)
46 wells have been drilled by Pakistan Oilfields Limited (P.O.L)
Seven wells did not reach objective reservoirs and three wells could not be put on production due to various technical reasons.
ACCESSIBILITY MAP
Courtesy: P.O.L. Geologic Bulletin 2004
Dhulian Oil Field
Alluvium, Sandstone, siltstone etc
Siwaliks Group
Thrust Fault
Anticline
SynclineRawalpindi
GroupOil fields
N
Dhulian Oil Field
Kazmi and Abbasi, 2008
GEOLOGICAL MAP
PETROLEUM PLAY
PLAY ELEMENTS
FORMATONS AGE
TRAP Structural Trap
SEAL Murree FormationNammal Formation
MiocenePaleocene
RESERVOIR Chorgali FormationSakesar LimestoneLockhart FormationWargal Formation
Eocene EocenePaleocenePermian
SOURCE Patala Formation Paleocene
TECTONIC MAP OF POTWAR SUB-BASIN
(Kadri, 1995)
GENERAL STRATIGRAPHY OF DHULIAN AREA
(Kazmi and Jan, 1997)
BOREHOLE STRATIGRAPHY
Total Depth 3788m , A.O.C, 22-03-1963Formations Depth (m)
CHINJI 0
RAWALPINDI GROUP 886
MAMI KHEL 2498
CHORGALI 2524
SAKESAR 2590
NAMMAL 2683
PATALA 2741
LOCKHART 2813
HANGU 2869
MIANWALI 2886
CHIDDRU 2932
WARGAL 2987
AMB 3136
SARDHAI 3214
WARCHA 3291
DANDOT 3444
TOBRA 3508
SALT RANGE 3632
STRUCTURE Dhulian fold is flanked by the Soan Syncline to the south and by the
tight Pindi Gheb syncline to the north
The Dhulian structure was originally thought to be a conventional anticline with a fold axis trending northeast southwest.
Based on this new seismic evidence, Dhulian structure was proved to be a thrust-bounded salt-cored anticline,
It is cut across by a major wrench fault that splits Dhulian into two major fault blocks
As a result, the Dhulian structure may be compartmentalized.
3-D VIEW OF DHULIAN STRUCTURE
Courtesy: P.O.L Geologic Bulletin 2004
SEISMIC DATA INTERPRETATION
Depth Contour Maps
Time to Depth Conversion
Velocity Analysis
Time Contour Maps
Time Picking
Marking of Faults
Marking of Prominent Reflectors
T-D Chart
METHODOLOGY
DATA USED
Line
Name
PDK-102 PDK-103 PDK-104 PDK-113WELLDATA
Line Dip line Dip line Dip line Strike line
DHULIAN-43(Gamma ray log, Neutron Log and Resistivity logs)
Line
Direction
North-South North-South North-South East-West
SP Range 108-188 108-218 108-298 108-340
Date
Recorded
1981 1981 1981 1981
BASE MAP
T-D CHART
0 200 400 600 800 1000 1200 1400 1600 1800 20000
250
500
750
1000
1250
1500
1750
2000
2250
2500
2750
3000
3250
3500
3750
4000
T-D Graph
T-D Graph
Lockhart Formation
Wargal Formation
Chorgali Formation
Dep
th
Time
SEISMIC SEQUENCES & REFLECTION FEATURES
In the study area four sets of seismic sequence are encountered on the basis of seismic reflection features.
Sequence 1: Continuous and Dark reflectors at the bottom of Seismic Section
stands for the basement of Pre-Cambrian age.
Sequence 2: Strong to medium continuous reflections, great change in thickness, it is Infra Cambrian aged Salt Ranges Formation composed of salt and evaporates. A great decollement plane is development.
Sequence 3: Parallel and continuous reflections high amplitude and frequency. It stands for Paleocene –Eocene ages formation. The traditional reservoirs in Potwar were developed in this sequence.
Sequence 4: Parallel and weak to continuous reflections. It stands for Miocene aged Mollasse architecture.
REFLECTORS MARKING
In total three horizons have been mapped throughout the study
1. Chorgali Formation (Eocene)2. Lockhart Formation (Paleocene)3. Wargal Formation (Permian)
These three horizons comprise the target horizons for hydrocarbon exploration in the study area.
Chorgali Formation was picked as it is a very strong reflector beneath the Kohat Formation i.e. Eocene
Lockhart Formation (Paleocene) was picked in the base of decreasing acoustic impedance from Nammal Formation to Patala Formation and then increasing peak of Lockhart Formation.
Wargal Formation was picked below to Lockhart Formation. The reflection continuity is fair to good.
PDK-102
PDK-103
PDK-104
PDK-113
PDK-102
Time Section
PDK-103
Time Section
PDK-104
Time Section
PDK-113
Time Section
TIME CONTOUR MAPS
Contouring the time structure maps and finding structural traps are one of the basic goals of Seismic data interpretation.
In this respect three time contour maps have been prepared on three different horizons in the whole area at the scale of 1:50, 000.
1. Time Contour Map of Chorgali Formation (Eocene) 2. Time Contour Map of Lockhart Formation (Paleocene) 3. Time Contour Map of Wargal Formation (Permian)
TWT Map on Top Chorgali of Dhulian D & P Lease
TIME CONTOUR MAP OF CHORGALI FORMATION
TWT Map on Top Lockhart of Dhulian D & P Lease
TIME CONTOUR MAP OF LOCKHART FORMATION
TWT Map on Top Wargal of Dhulian D & P Lease
TIME CONTOUR MAP OF WARGAL FORMATION
DEPTH CONTOUR MAPS
The following depth maps have been prepared at the scale of
1:50,000 with respect to mean sea level.
1. Depth Structure Map of Chorgali Formation
2. Depth Structure Map of Lockhart Formation
3. Depth Structure Map of Wargal Formation
These maps have been prepared mainly using the drilling well tops available on different wells in Dhulian area.
DEPTH CONTOUR MAP OF CHORGALI FORMATION
C.I. 20 ftS.R.D 400 m
DEPTH CONTOUR MAP OF LOCKHART FORMATION
DEPTH CONTOUR MAP OF WARGAL FORMATION
PETROPHYSICAL ANALYSIS
Well Dhulian-43.
Located on:
Lattitude 33°12'41“N
Longitude 72°12'00“E.
Total Depth:
3788 meters
Interpretation is done on Chorgali and Lockhart Formation.
WORK FLOW
Marking of Zone of Interest
Lithology Identification
Volume of Shale
Effective Porosity
Total Porosity
Saturation of Water Saturation of
Hydrocarbon
Summation
MARKING ZONE OF INTEREST
Formatio
n
Starting
depth
(m)
Ending depth
(m)
Total thickness
(m)
Chorgali
Fm2494m 2560m 66m
Lockhart
Fm 2783m 2839m 56m
PETROPHYSICAL ANALYSIS
Logs used
• Gamma Ray Log
• Neutron Log
• Density Log
• Resistivity Log
GAMMA RAY LOG
Amount of radioactivity.
Differentiate between shale and sand content.
To calculate shale volume
Volume of Shale (Vsh) = GRlog – GRmax / GRmax – GRmin
0 10 20 30 40 50 60 70 808100
8150
8200
8250
8300
8350
8400
8450
Depth Vs Shale Volume
Depth Vs Shale Volume
Dep
th (
ft)
DENSITY & NEUTRON LOG
Delineation of porous formation and their porosity.
Density Porosity = Densitymatrix – Densitylog / Densitymatrix – Densityfluid
Neutron Porosity = Value of Neutron Log
Average Porosity = (Density Porosity + Neutron Porosity) / 2
Effective Porosity = Porosityavg *
(1- Vsh)
4 6 8 10 12 14 16 188100
8150
8200
8250
8300
8350
8400
8450
Depth Vs Average Porosity
Depth Vs Average Porosity
Dep
th (
ft)
0 2 4 6 8 10 12 148100
8150
8200
8250
8300
8350
8400
8450
Depth Vs Effective Porosity
Depth Vs Effective Porosity
Dep
th (
ft)
RESISTIVITY LOG
Use for determination of resistivity of
formation.
18 20 22 24 26 28 30 32 34 36 388100
8150
8200
8250
8300
8350
8400
8450
Depth Vs Saturation of Water
Depth Vs Saturation of Water
Dep
th (
ft)
60 80 100 1208100
8150
8200
8250
8300
8350
8400
8450
Depth Vs Saturation of Hydrocarbons
Depth Vs Saturation of Hydro-carbons
COMPOSITE DIAGRAM0 20 40 60 80 100 120
8100
8150
8200
8250
8300
8350
8400
8450
Volume of ShaleAverage PorosityEffective PorositySaturation of WaterSaturation of Hydrocarbons
Dep
th (
ft)
Lockhart Formation
0 20 40 60 80 100 1209000
9050
9100
9150
9200
9250
9300
9350
Depth Vs Volume of Shale
Depth Vs Volume of Shale
Dep
th (
ft)
Dep
th (
ft)
4 6 8 10 12 14 16 189000
9050
9100
9150
9200
9250
9300
9350
Depth Vs Average Porosity
Depth Vs Average Porosity
0 2 4 6 8 10 12 149000
9050
9100
9150
9200
9250
9300
9350
Depth Vs Effective Porosity
Depth Vs Effective Porosity
Dep
th (
ft)
24 26 28 30 32 34 36 38 40 429000
9050
9100
9150
9200
9250
9300
9350
Depth Vs Saturation Of Water
Depth Vs Saturation Of Water
Dep
th (
ft)
58 60 62 64 66 68 70 72 74 769000
9050
9100
9150
9200
9250
9300
9350
Depth Vs Saturation of Hydrocarbons
Depth Vs Saturation of Hy-drocarbons
Dep
th (
ft)
COMPOSITE DIAGRAM
0 10 20 30 40 50 60 70 809000
9050
9100
9150
9200
9250
9300
9350
Volume of ShaleAverage PorosityEffective PorositySaturation of WaterSaturation of HydrocarbonsD
ep
th (
ft)
Formation
Name
Lithology Volume Of
Shale
(%)
Average
Porosity
(%)
Effective
Porosity
(%)
Avg. Water
Saturation
(%)
Avg,
Hydrocarb
on
Saturation
(%)
Chorgali
Formation
Limestone,
Shale
33.80
%
10.81
%
7.34
%
26.33
%
73.66
%
Lockhart
Formation
Limestone,
Marl
32.55
%
9.84
%
7.56
%
42.6
%
57.4
%
RESERVOIR ESTIMATION
The total estimated amount of oil in a reservoir, including both
producible and non-producible oil, is called oil in place.
C.I. 20 ftS.R.D 400 m
N = 7758 * GRV * N/G * Φ * So * 1/Bo
Where
7785 = Conversion factor (acre-ft*7758 =barrels)
GRV = Gross Rock Volume (acre-ft)
N/G = Net to Gross Ratio (decimal)
Φ = Porosity of this net reservoir rock (decimal)
So = Oil Saturation (decimal)
Bo = Formation Volume factor.
VOLUMETRIC RESERVE ESTIMATION
RESULT OF VOLUMETRIC RESERVES
Reserve Calculation
(7758*Area(acre)*Net Pay(ft)*Avg. Porosity(phi)*Sw)/Bg
Formation Case ContourArea
(Acre)Net Pay
(ft)Phi avg.
(fraction)Sw avg.
(fraction)Bo
OIIP (MMBL)
Recovery Factor
Recoverable Reserves
(MMBL)
GOR (scf/stb)
Gas Recovery
(BCF)
Chorgali
P90 2470 3706 130 0.05 0.28 2.047 65 30 19.5 1975 38512.5
P50 2600 6177 130 0.05 0.28 2.047 109 30 32.7 1975 64582.5
P10 2700 9884 130 0.05 0.28 2.047 175 30 52.5 1975 103687.5
CONCLUSIONS
The multifold seismic acquired by OXY and POL demonstrated that Dhulian subsurface structure is more complicated than what was originally thought.
The structure is a three way dip closure bounded by thrust fault.
Based on this new seismic evidence, Dhulian structure was proved to be a thrust-bounded salt-cored anticline.
It is cut across by a major wrench fault that splits Dhulian into two major fault blocks.
RECOMMENDATIONS
For more detailed study and to define potential sites in the area, more
seismic lines are required.
High resolution seismic data and wire line logs should be acquire in future
operations.
3D seismic survey should acquire in future to obtain the maximum
information of subsurface.
REFERENCES
Dolan P., (1990) Pakistan: a history of petroleum exploration and future potential; in Classic Petroleum province edited by Brooks J. Special Publication of The Geological Society London
Iqbal B. Kadri, (1995), Petroleum Geology of Pakistan
Khan M. A. Ahmed R., Raza H. A., and Kemal A., (1986), Geology of Petroleum in Kohat-Potwar depression, Pakistan, AAPG Bulletin, Vol 70, No. 4
Iqbal, M.W.S, and Shah, S.M.I, 1980. A guide to the Stratigraphy of Pakistan.V.53
Thank You
AnnexureStructural Model of Dhulian