From Anticline Hunting to Petroleum Syst

FROM ANTICLINE HUNTING TO PETROLEUM SYSTEM

Anticline Hunting: Penerapan pertama kali secara ilmiah konsep geologi

dalam explorasi Migas.

Sterry Hunt 1861

Petroleum system: Penerapan konsep geologi paling mutakhir dalam

eksplorasi Migas

Dow, 1974 Oil System,

Perrodon 1980 Petroleum system

Anticline Hunting

Observasi :

1842: Sir William Logan menghubungkan terdapatnya rembesan

minyak dengan struktur antiklin di pulau Gaspe di

mulut sungai St lawrence Canada.

Observasi pertama yg menghubungkan terdapatnya minyak bumi dengan antiklin

1859: Kolonel William Drake membor minyak secara komersial

didekat rembesan. Awal industri migas

1860: Henry D rodgers Akumulasi minyak yang

ditemukan oleh William Drake terdapat pada sumbu antiklin

Anticline Hunting 1861: Sterry Hunt

Ceramah di Montreal Canada

Publikasi di „Montreal Gazette‟ The History of Petroleum

Andrews seorang Guru besar geologi Marrieta College

Menunjukkan keberadaan minyak dan gas sepanjang antiklin

Keduanya percaya bahwa akumulasi minyak pada

puncak antiklin adalah akibat retakan

Anticline Hunting Pendapat Logan, Rogers, Hunt, Andrews dan Winchel

sedikit sekali diperhatikan oleh perusahaan.

I.C White Geologist pertama yang medemonstrasikan kebenaran teori antiklin.

Teori antiklin diterima oleh ahli geologi di zaman itu

dan digunakan dalam pencarian minyak bumi Anticline Hunting

1897 : Pertamakali geologist dipekerjakan oleh perusahaan Migas (Southern Pacific Oil Company)

Anticline Hunting Pada awalnya konsep Antiklin cukup berhasil

Gabungan antara Rembesan dan Atiklin

Lama kelamaan kurang berhasil

Antiklin tanpa rembesan dibor juga

Pemikiran berkembang:

Kenapa ada antiklin yang menjadi tempat akumulasi minyak dan ada pula yang tidak ?

Batuan reservoir

Setelah diteliti ternyata antiklin yang mengandung minyak adalah antiklin yang terdapat batuan yang berpori

Lahirnya konsep batuan reservoir Konsep ini sebetulnya sudah mulai dikemukakan

oleh Alexander Wichel dari Michigan (1860) bahwa batupasir yang terdapat di antiklin cukup mempunyai pori untuk menyimpan minyak tetapi karena keberhasilkan konsep antiklin fenomena ini kurang diperhatikan.

Batuan reservoir

Lahirnya konsep batuan reservoir

Hanya antiklin yang mengandung batuan

reservoir yang dapat mengandung Minyak

Batuan Induk

Pemikiran batuan reservoir tersebut terus berkembang lebih lanjut karena adanya fakta bahwa Ada struktur antiklin

Tetapi antiklin tersebut setelah dibor tidak juga mengandung minyak

Apa penyebab kegagalan konsep tersebut ?

Lahirnya konsep batuan induk Perdebatan origin dari migas

Lebih lanjut Lahirnya konsep Petroleum system

Petroleum system

Sejarah Petroleum system Dow 1972, 1974 menerbitkan tulisan dalam

AAPG ; Oil-Oil, Oil-source rock correlation

Dapat memisah dan menghubungkan minyak

dalam reservoir tertentu dengan batuan sumber tertentu (source rock)

Oil system

Petroleum system

Perrodon 1980, 1983 Pertama kali menggunakan istilah Petroleum system tetapi dalam bahasa Perancis statement utamanya

adalah sebagai berikut: The geologic criteria governing the distribution of

pools, and in particular the combined presence of source rocks, reservoirs and seals, generally exhibit a certain geographic extension which is reflected by the formation of a family of pool or even better, a petroleum system, a structured set of natural elements of the same species or having the same function.

Petroleum system

Demaison 1984

Generative Basin:

Areas underlain by mature source rocks are called “petroleum generative depression” or “hydrocarbon kitchens”

A generative basin is define as a sedimentary basin that contain one or more petroleum generative depression

Petroleum system

Meissner et al 1984

Hydrocarbon Machine

Sequence which contain all of the elements involved in the process of hydrocarbon generation from source rock to consequent migration and accumulation constitute what may be termed natural geologic hydrocarbon machines.

Petroleum system

Ulsimek 1986

Independent Petroliferous system (IPS)

……….a body of rocks separated from surrounding rocks by regional barriers to lateral and vertical migration of fluid, including oil and gas. Stratigraphically an IPS is essentially homogeneous, it includes source rocks, reservoir rocks, traps and regional seal……………..

Petroleum system

Magoon 1987

The Petroleum system emphasizes the genetic relation between a particular source rock and resulting petroleum accumulation……..

Petroleum system

Definisi Petroleum system

Mangoon and Dow (1994)

Natural system that encompasses pod of active source rock and all related oil and gas and which includes all the geologic element and processes that are essential if a hydrocarbon accumulation is to exist

The events chart showing the relationship between the essential elements and processes as well as the preservation time and critical moment for the fictitious Deer-Boar (.) petroleum system. Neogene (N) includes the Quaternary here. (Time scale from Palmer, 1983.)

Four Levels of Petroleum Investigation

Petroleum system

Didalam definisi dikemukakan semua mengandung dua pernyataan penting yaitu :

1. Element

2. Processes

Petroleum system

Secara garis besar Petroleum system dapat dibagi menjadi 2 sub systems yaitu :

1. Generative sub system

2. Migration and entrapment sub system

Petroleum system

Generative sub system

Element : source rocks Richness, TOC

Kerogen Types : Type I, Type II, Type III

Oil prone, gas prone

Processes : Thermal maturation Rock eval/Pyrolysis, Tmax, Ro, TAI, TTI

Basin Mod, Thermal modeling.

Petroleum system Migration and entrapment sub system

Element : Generated hydrocarbon

Processes :

Expulsion (Primary migration) Source rock Carrier bed

Expulsion model, expulsion and generation, expulsion Effeciency

Secondary migration Within carrier bed to traps

Migration model, driving force, ristricting force, PC

Petroleum system Entrapment sub system Element :

Migrated hydrocarbon Trap geometry Reservoir rocks Seal rock

Processes :

Migration Trapping

GENERATIVE SUB SYSTEM

QUANTITY of organic matter

TYPE of organic matter

MATURITY of organic matter

GENERATION of hydrocarbons

EXPULSION of hydrocarbons

Geochemical Processes

Applied organic geochemistry has

become an essential part of

prospect evaluation.

Few companies would acquire or

relinquish acreage without first

performing a geochemical analysis.

The main concepts or processes

we’ll be interested in are:

Source rock ACCUMULATION

MATURATION upon burial


EXPULSION from the source

rock

Source Rock Criteria

QUANTITY of organic matter

TYPE of organic matter

MATURITY of organic matter


EXPULSION of hydrocarbons

%TOC Grade

< 0.5 Very Poor0.5 – 1.0 Poor

1.0 – 2.0 Fair

2.0 – 4.0 Good

4.0 – 12.0 Excellent

> 12.0 Oil Shale / Coal

Typically, hydrocarbons are generated in a

dark, organic-rich shale.

Criteria that must be considered:

Quantity

Type

Maturity

Generation

Maturation

Quantity usually measured as TOC (Total

Organic Carbon). A TOC = 1.0 means that

organic carbon constitutes 1 percent dry

weight of the rock.

Typical source rocks have TOC values of

above 1%, ideally 2.5 to 5%.

Another modelling consideration is that

PORTION of the source rock that has the

high TOC content.

The entire formation may be hundreds of

feet thick. The portion rich in TOC may

only be tens of feet thick.

Soluble and insoluble organic matter in

sediments

That part of organic matter which is insoluble in organic solvents is called KEROGEN.

Typically comprised of plant remains.

Soluble organic matter = bitumen.

Kerogen TypesAs Determined by Visual Kerogen Analysis, Origin, and HC Potential

DepositionalEnvironment

Other PalynologySystem

KerogenForm

KerogenType

HydrocarbonPotential

Lacustrine LacustrineSapropel

Algal(Plankton)

Alginite I Oil

FluorescingAmorphous

FluorescingAmorphous

I or II Oil

Herbaceous Exinite II Oil/Condensate

Aquatic Marine " Resinite II "

Sapropel " Liptinite II "

(typically " Suberinite II "

marine) " Sporinite II "

" Cutinite II "

Non-fluorescingAmorphous

Non-fluorescingAmorphous

III or IV Gas or None

Terrestrial Humic WoodyCellulose

Vitrinite

III Gas mainly.May have someoil potential,especially inSE Asia if"HI" is > 150.

Coaly Inertinite IV Dead CarbonNo Potential

(after Merril, 1991; Cornford, 1990)

Each kerogen type will accumulate in a particular sedimentary environment.

Each kerogen type is related to a type of plant material.

Each kerogen type has a tendency to product a certain type of hydrocarbon.

In BasinMod, we use the Type I, Type II Type III Classification.

Type IV has no hydrocarbon potential - it is totally burned up.

Modified van Krevelen Diagram

From Waples, 1985

This Modified Van Krevelen diagram is what we can plot in BasinMod.

Rock-Eval Pyrolysis

Attempt to simulate the hydrocarbon generation process in the

laboratory. QUANTIFIES geochemical parameters.

Rock is heated at a much HIGHER TEMPERATURE than in

nature so generation occurs in a much SHORTER TIME than in

nature.

S1 represents hydrocarbons already present in the rock.

Measured as mg HC per grams of TOC.

S2 represents hydrocarbon formed by thermal degradation

during pyrolysis. It is the most important indicator of the

present-day ability of the kerogen to generate hydrocarbons.

TMAX is the temperature at which the S2 peak occurs. It

represents the temperature at peak generation.

S3 represents the amount of carbon dioxide in the kerogen

which is related to the amount of oxygen in the kerogen. High

oxygen contents are related either to woody-cellulosic source

material or to strong oxidation during diagenesis, high oxygen

content of a kerogen is a negative indicator of hydrocarbon

source potential.

Rock-Eval Pyrolysis

After Waples, 1985

250-550°C

S1 = HC already present (250°C)

S2 = HC generated from

the kerogen by thermal

decomposition (420 - 460°C)

S3 = carbon dioxide given

off by the kerogen Tmax

Relationship between TMAX and Organic Matter Type with Oil and Gas Windows

Bordenave, M., 1992, (ed.), Applied Petroleum Geochemistry, Fig. 2-17, p.246

465

430

Rock-Eval Pyrolysis Generalizations

Immature Source Rock

small S1 peak (small amount HC already generated)

larger S2 peak

Mature Source Rock

large S1 peak (more HC already generated)

smaller S2 peak, occurring at a higher temperature than the immature sample due to increased thermal stability of the more mature organic matter

Maturation and Generated Hydrocarbons

Modified from Dow, 1977

The level of source rock maturation can be measured optically by such methods a spore color index and vitrinite

reflectance. Maturity can be calculated given the subsidence history of the rock and the geothermal gradient of the

area.

MIGRATION

PRIMARY MIGRATION (EXPULSION)

SECONDARY MIGRATION

MIGRATION

PRIMARY MIGRATION EXPULSION FROM THE SOURCE ROCK

Migration - Saturation Threshold Theory

1. At present no general methods for establishing the percent

of generated bitument that migrated out of a source rocks

2. Oil to source rocks correlation provide direct indicator of

migration

3. Assume Hc generation drives migration process

need minimum bitument quantity before expulsion occur

Need to saturarate absorbers in the rock and fill the pore

system

Momper (1978) estimate on average requires 850 ppm

Expulsion from the Source Rock

The mechanism of expulsion is still the subject of

debate.

One method is Porosity Saturation:

As Maturation progresses, organic matter is transformed

to oil. The generated oil fills pore spaces created by

the destruction of kerogen.

1. Oil fills the pore spaces, overcomes capillary

resistance and begins to expel.

2. Overpressure caused by the conversion of kerogen to

oil and gas microfractures the rock and expels the

fluid phase.

3. In a lean source rock, not enough oil may be generated

to fill the pore spaces. With continued burial, this

trapped oil may crack to gas


Another controlling factor is the sedimentary

geometry of the source rocks.

The expulsion efficiency is highest when the

source rocks are thin and hydrocarbons have a

short distance to migrate to more permeable

carrier beds (meters, rather than tens of

meters).

Intercalated sandstones and shales would

provide much greater expulsion efficiency than

thicker bedded shales and sands.


Rocks that are brittle and overpressured are

likely to fracture

which dramatically enhances

expulsion efficiency.


Expulsion efficiency

Temperature 120-150 C strongly dependent of original richness

Minimum petroleum saturation in the source rock (about 40%) is

required before efficient expulsion take place.

Rich source rocks > 5kg/ton, TOC>1.5 very efficient 60-90% of total

petroleum generated being expelled.

Lean source rocks <5kg/ton, TOC<1.5% expulsion efficiency is

much lower most of the generated oil remain in the source rocks.

Raising Temperature cracked to gas and expulsion can be very

efficient

(Cooles, Mackenzie and Qiugley 1986)

EXPULSION EFFICIENCY

Expulsion Efficiency

as a Function of Source Rock Richness

Certain kerogens undergo

generation at earlier maturity

due to lower activation

energies.

These same kerogens can be

expected to undergo earlier

expulsion.

Richer source rocks will

accumulate greater volumes

earlier that lean source rocks

and begin to expel earlier.

(Cooles, Mackenzie and Qiugley 1986)

Lean source rocks Rich source rocks


Lean rich

T=120-150 C

Oil window

Initial Condition

T >150 C

Gas window

Expulsion efficiency

SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP


SECONDARY MIGRATION CONCENTRATES SUBSURFACE PETROLEUM

INTO SPECIFIC SITES (TRAPS) WHERE IT MAY BE COMMERCIALLY

EXTRATED.

THE MAIN DIFFERENCE BETWEEN PRIMARY MIGRATION (OUT OF THE

SORCE ROCK) AND SECONDARY MIGRATION (TROUGH CARRIER BED)

IS THE POROSITY, PERMEABILITY, PORE SIZE DISTRIBUTION TROUGH

WHICH MIGRATION TAKE PLACE.

END POINT OF SECONDARY MIGRATION

TRAPS

SEEPAGES

KNOWLEDGE OF THE MECHANIC OF SECONDARY MIGRATION IS IMPORTANT IN

THE GENERAL UNDERSTANDING OF ACTIVE CHARGE SYSTEM, SPECIALLY IN:

• TRACING AND PREDICTING MIGRATION PATHWAYS

AREA RECEIVING PETROLEUM CHARGE

• INTERPERETING THE SIGNIFICANCE OF SUBSURFACE PETROLEUM

SHOWS AND SURFACE SEEPAGES.

• ESTIMATING SEAL CAPACITY IN BOTH STRUCTURAL AND

STRATIGRAPHIC TRAPS

• MAIN DRIVING FORCE FORCE BEHIND SECONDARY MIGRATION ARE:

BUOYANCY

• PORE PRESSURE GRADIENT: High P Low P

• MAIN RESTRICTING FORCES TO SECONDARY MIGRATION IS THE

CAPILARY PRESSURE

WHICH INCREASE AS PORE SIZE BECOME SMALLER

• ENTRAPMENT WHEN CAPILLARY PRESSURE EXCEEDS THE DRIVING

FORCES.

SECONDARY MIGRATION THROUGH CARRIER BED TO TRAP

BUYANCY AS DRIVING FORCE IN

SCONDARY MIGRATION .

BUOYANCY IS THE PRESSURE

DIFFERENCE BETWEEN A POINT IN

THE PETROLEUM COLOUMN AND

THE SURROUNDING PORE WATER.

IT IS A FUNCTION OF A PETROLEUM-

WATER DENSITY DIFFERENCE AND

THE HEIGHT OF THE PETROLEUM

COLOUMN.

A LARGE BUOYANCY PRESSURE

MAY DEVELOP AT THE TOPS OF

LARGE, LOW DENSITY (GAS)

PETROLEUM COLOUMNS.

PRESSURE MEASUREMENTS AT

POINT TROUGHOUT THE ETROLEUM

COLOUMN DEFINE A PETROLEUM

PRESSURE GRADIENT

THIS INTERSECT THE HYDROSTATIC

GRADIENT AT THE PETROLEUM-

WATER CONTACT.


SECONDARY MIGRATION

HYDROSTATIC CONDITION

BUOYANCY IS THE ONLY DRIVING FORCE

HYDRODYNAMIC CONDITION

1. COULD INHIBIT OR ASSIST SECONDARY MIGRATION

2. AFFECTING THE DIRECTION AND RATE OF MIGRATION

3. INCREASING OR DECREASING THE DRIVING PRESSURES

AGAINST VERTICAL OR LATERAL SEALS

4. TILTING PETROLEUM WATER CONTACTS AND DISPLACING

PETROLEUM ACCUMULATION (OFF THE CREST OF STRUCTURAL

CLOSURE


POTENSIAL PLANE

HYDRODYNAMIC

FORCE

BUOYANCY

FORCE

HYDRODINAMIC

FLOW

HYDRODINAMIC TRAP

TILTING HC CONTACT

RESTRICTING FORCE IN SECONDARY MIGRATION

• CAPILLARY PRESSURE

• DISPLACEMENT PRESSURE

• INJECTION PRESSURE

FUNCTION OF THE SIZE (RADIUS) OF PORE THROAT

INTERFACIAL SURFACE TENSION BETWEEN THE WATER AND PETROLEUM AND

WETTABILITY OF THE PETROLEUM-WATER-ROCK SYSTEM


RESISTANT FORCE IN

SECONDARY HYDROCARBON

MIGRATION.

HIGHER PRESSURE ARE

NEEDED TO FORCE

PETROLEUM GLOBULES

TROUGH SMALLER PORES

(AFTER PURCELL 1949 IN

SCHOWALTER 1976)


INTERFACIAL TENSION

• DEPENDS ON THE PROPERTIES OF PETROLEUM AND WATER, AND

IS INDEPENDENT OF THE ROCK CHARACTERISTIC

• FUNCTION PRIMARY OF THE PETROLEUM COMPOSITION AND

TEMPERATUREDECREASES WITH INCREASING TEMPERATURE

• GAS-WATER INTERFACIAL TENSIONS ARE GENERALLY HIGHER

THAN THOSE FOR OIL –WATER

• FOR THE SAME ROCK DISPLACEMENT PRESSURE

FOR GAS > FOR OIL

• THE BUOYANCY PRESSURES ARE NORMALLY GREATER FOR GAS.

• WETTABILITY IS FUNCTION OF THE PETROLEUM WATER AND ROCK

• MOST ROCK SURFACES ARE WATER WET


PORE SIZES ARE THE MOST IMPORTANT

ON SECONDARY MIGRATION AND

ENTRAPMENT

PORE SIZES CAN BE ESTIMATED

• THIN SECTION

• SEM

• DISPLACEMENT PRESSUREMICP


CAPILLARY PRESSURE =2g (1/Rt-1/Rb)


Critical petroleum height = Ypc


MIGRATION PATHWAYS

1. DRIVING FORCE BUOYANCY

2. PETROLEUM MIGRATION DIRECTION STEEPEST SLOPE

3. PEPENDICULAR TO STRUCTURAL CONTOURS OR TRUE DIP

DIRECTION

4. LINE DRAWN AT RIGHT ANGLES TO STRUCTURAL CONTOURS

OF THE TOP CARRIER BED/BASE SEAL HORIZON ORTHO

CONTOURS

5. ORTHOCONTOUR MAP ILLUSTRATE HYDROCARBONS

MIGRATION PATHWAYS FROM ITS KITCHEN AREA

6. ILLUSTRATE FOCUSING AND DE-FOCUSING EFFECTS OF

STRUCTURAL FEATURES IN PROSPECT DRAINAGE AREA


MIGRATION PATHWAYS

LATERAL MIGRATION

SHORT DISTANCE

LONG DISTANCE

• LONG DISTANCE MIGRATION PROSPECT S REMOTE FROM

AREA OF MATURE SOURCE ROCKS (KITCHENS AREA )

• THE STRUCTURAL EFFECTS MAY STRONGLY INFLUENCE THE

PATTERN OF HYDROCARBON CHARGE

• PETROLEUM FLOW CAN BE SPLIT WHEN ENCOUNTERING A LOW

AND CONCENTRATED ALONG REGIONAL HIGH

• GEOMETRY OF THE KITCHEN EFFECT PETROLEUM CHARGE

VOLUMES


MIGRATION PATHWAYS

• ORTHOCONTOURS ARE CONSTRUCTED FOR THE ACTUAL

TIME OF SECONDARY MIGRATION.

• PRESENT DAY STRUCTURE MAPS MAY BE USED TO

MODEL PRESENT DAY MIGRATION.

• ISOPACHING (3-D DECOMPACTION) CAN BE USED TO

PRODUCE PALEOSTRUCTURE MAP AND USED TO

MODEL PALEO MIGRATION


OTHER FACTORS:

SEALING FAULT ; MAY DEFLECT PETROLEUM FLOW LATERALLY.

NON SEALING FAULTS; ALLOWS PETROLEUM TO FLOW ACROSS THE

FAULT INTO JUXTAPOSE PERMEABLE BED AT DIFFERENT

STRATIGRAPHIC LEVEL.

NEEDS A DIFFERENT STRUCTURE MAP FOR SECONDARY

MIGRATION MODELLING.

COMMUNICATION BETWEEN CARRIER BEDS CAUSED BY LATERAL

STRATIGRAPHIC CHANGES BY SANDING OUT OF SHALE SEAL.

THE ORTHOCONTOUR MAP SHOULD BE CONSTRUCTED ONLY AS

FAR AS ASEAL PERSIST


SECONDARY MIGRATION LOSSES

TWO DISTINCT HABITATS:

MINIATUR TRAPSDEAD ENDS ALONG THE MIGRATION

ROUTE PRODUCED BY FAULTED AND DIP CLOSED

GEOMETRIES AND STRATIGRAPHIC CHANGES. TRAP COULD

BE OBSERVABLE BUT NO COMMERCIAL

RESIDUAL PETROLEUM SATURATION IN THE PORE OF

CARRIER BED, TRAPPED BY CAPILLARY FORCES 30% OF

THE PORE VOLUME.


HYDROCARBON TRAP

TRAP

FINAL REQUIREMENT FOR THE OPERATION OF ANN EFFECTIVE

PETROLEUM PLAY IS ATRAPS

REPRESENT THE LOCATION OF A SUBSURFACE OBSTACLE TO

THE MIGRATION OF PETROLEUM TOWARDS THE EARTH’S

SURFACE

PETROLEUM EXPLORATION INDUSTRY IS PRIMARILY

CONCERNED WITH THE RECOGNITION OF THESE SITES

PETROLEUM ACCUMULATION

HYDROCARBON TRAP

HYDROCARBON TRAP

A TRAP IS FORMED WHERE THE

CAPILLARY DISPLACEMENT

PRESSURE OF A SEAL EXCEEDS THE

UPWARD-DIRECTED BUOYANCY OF

PETROLEUM IN THE ADJOINING

POROUS AND PERMEABLE

RESERVOIR ROCK

HYDROCARBON TRAP

TRAP CLASSIFICATION

•ALLOW COMPARISON BETWEEN

PROSPECT OR PLAY

•ALLOW THE DRAWING OF GEOLOGICAL

ANALOGIES

•TO ESTIMATE HC VOLUME

•TO ASSES THE RISK

HYDROCARBON TRAP

THE MAJORITY WORLD,S GIANT OIL FIELDS FOUND IN

ANTICLINAL TRAP

HYDRODYNAMIC TRAPS ARE THOSE FORMED BY THE

MOVEMENT OF INTERSTIAL FLUIDS TROUGH THE BASIN.

A TRAP EXIST WHERE SUBSURFACE CONDITIONS CAUSE

THE CONCENTRATION AND ACCUMULATION OF PETROLEUM

AFTER MATURATION AND EXPULSION

THE HC WILL MOVE FROM SITES OF HIGH POTENTIAL

ENERGY TO SITES OF LOW POTENTIAL ENERGY

HYDROCARBON TRAP

TRAP CLASSIFICATION

STRUCTURAL TRAPS

THOSE CAUSED BY TECTONIC, DIAPIRIC, GRAVITATIONAL AND

COMPACTION PROCESSES

STRATIGRAPHIC TRAPS:

DIVERSE GROUP, TRAP GEOMETRY INHERITAGE FROM THE ORIGINAL

MORPHOLOGY

DISCONTINUITIES IN THE BASIN FILL

DIAGENETIC EFFECTS.

COMBINATION TRAPS

COMBINATION OF STRUCTURE AND STRATIGRAPHY

HYDROCARBON TRAP

Subsurface conditions:

Structural condition

Stratigraphic condition

Reservoir condition

Seal condition

From Anticline Hunting to Petroleum Syst

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