From Anticline Hunting to Petroleum Syst
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Transcript of 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
GENERATION of hydrocarbons
EXPULSION from the source
rock
Source Rock Criteria
QUANTITY of organic matter
TYPE of organic matter
MATURITY of organic matter
GENERATION of hydrocarbons
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
Expulsion from the Source Rock
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.
Expulsion from the Source Rock
Rocks that are brittle and overpressured are
likely to fracture
which dramatically enhances
expulsion efficiency.
Expulsion from the Source Rock
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
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.
EXPULSION EFFICIENCY
(Cooles, Mackenzie and Qiugley 1986)
Lean source rocks Rich source rocks
EXPULSION EFFICIENCY
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 TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH 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 TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
RESISTANT FORCE IN
SECONDARY HYDROCARBON
MIGRATION.
HIGHER PRESSURE ARE
NEEDED TO FORCE
PETROLEUM GLOBULES
TROUGH SMALLER PORES
(AFTER PURCELL 1949 IN
SCHOWALTER 1976)
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
PORE SIZES ARE THE MOST IMPORTANT
ON SECONDARY MIGRATION AND
ENTRAPMENT
PORE SIZES CAN BE ESTIMATED
• THIN SECTION
• SEM
• DISPLACEMENT PRESSUREMICP
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
CAPILLARY PRESSURE =2g (1/Rt-1/Rb)
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
Critical petroleum height = Ypc
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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 TROUGH CARRIER BED TO TRAP
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.
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
SECONDARY MIGRATION TROUGH CARRIER BED TO TRAP
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
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