The follovving text is focused on the rale of
growth faults in trapping hydrocai-bons. Various
kinds of traps involving growth faults have been
discussed along with a brief case study of Niger
Delta and a detailed study and interpretation of
a block in Mumbai offshore-Shelf Margin.
Hydrocarbon
in
Habitat
Growth Fault
Regime
With case study on Mumbai
Offshore and Niger Delta
Vaibhav Singhal
Hydrocarbon Habitat in Growth Fault Regime
Under Mt-. S.N. Mohanty
Vaibhav Singhal
Summer Train, EEPIL
3rd
Year, Int. NA.Sc. Applied Geology
IIT Kharagpur
Hydrocarbon Habitat in Growth Fault Regime
Page 1
Acknowkowleclgement
I take this opportunity to express my gratitude towards my mentor Mr. S.N.
Mohanty, Vice President, EOL-E&P, Mumbai for his consistent guidance and
support.
I am grateful to Ms. Urmi Surve and ail the members of ESSAR Mumbai for their
constant motivation to work positively and for extending a helping hand whenever
in need.
Special thanks to Mr. Saurabh Goyal, Dy. Manager-EOL, for his kind support,
guidance and encouragement throughout the project work
I would also lifte to thank ail those who are knowingiy or unknowingly involved in
completion of my project.
L-Iydrocarbon Habitat in Growth Fault Regiine
Page 2
Table of Contents
1. HYDROCARBON FORMATION AND
ACCUMULATION
1.1. Formation
1.2. Accumulation...
1.3. Migration
1.4. Entrapment
2. PETR_OLEUM SYSTEM
2
.1.
Introduction...
.....
......
...
......
......
.....
.......
...
2.2. Reservoir
Seal. .
2.4. Traps.........
2.4.1. Stratigraphic Traps
2.4.2. Structural Traps
2.5. Trap Evaluation
3. G ROWTH FAULTS
3.1. Introduction
3_2. Formation And Structure
3.3. Geological Settings For Growth Faults
.• ........
3.4. Importance Of Growth Faults
3.5. Limitations
4. INTERPRETATION
4.1, Data Loading
4.2, The Process..... .....
...
4.2.1. Data Loading
MM•b•M
........
.......
Fault Picking
4.2.3. Horizon Picking...
Fault Polygon
4.2.5. Contouring
4.3. Interpretation of Growth Faults .
4.4. Geometry of Growth Faults
5. MUMBAI OFFSHORE
5.1. Introduction
5.2. Tectonic Setup
..
5.3. Stratigraphy
5.4. Petroleurn System
5.5, Data Interpretation
....... Mai MM•ba
......
........
5.5.1. Seismic Data Interpretation
5.5.2. Horizons and Faults
Hydrocarbon Habitat in Growth Fault Regiiiie
Page 3
5.5.3. Tinie Structure rviaps
5.5.4. Isochronopach Map
5.6. Prospect Analysis
6, NIGE RIA DELTA
6.1, Introduction...
6 .2.
...............
....
....
6.2.1. Tectonics
6.2.2. Stratigraphy
6.3. Petroleum System
6.3.1_ Location
...
6.3.2. Reservoir
6.3.3. Entrapment.
6.3.4, Cap Rock
6.4. Conclusion..
7. CONCLUSION
Hydrocarbon Habitat in Growth Fault Regime
Page 4
INTRODUCTION
There has been a lot of study on growth faults w.r.t. subsurface exploration of hydrocarbons. The
main reason for special recognition of growth faults in this field is Their excellent hydrocarbon
trapping capabilities. A schematic diagram of a growth fault has been shown in figure 1.
Gravide' fault
(cross section)
1: Diagram of a commun Growth Fouit
Growth faults are mostly listric Normal faults generally found in extensronal sedimentary regime.
Their dip decreases with depth and fault ends in the decolInnent zone. The thickness of the
hanging wall {which is the clown thrown block) is increased resulting in thickening of both
reservoir and cap making conditions more favorable for industries,
Ambre numbers of Growth faults have been found in both Niger Delta and Mumbai Offshore
(discussed in a case study of this report later). The traps involving growth faults are structural
traps of both Fault dominated (Fault block) and fold dorninated (Rollover anticline).
Hydrocarbon Habitat in Growth Fault Reginie
Page S
CIMPTER 1:
HYDROCARBON FORMATION
AND ACCUMULATION
1.1
FORMATION
Oïl is formed from diatoms, extremely small sized marine organisms. Diatoms float in the
top few meters of the oceans and also happen to be a major source of food for many forms of
ocean swimmers. Their skeletons are chemically vert' similar to sand and are also made of the
silica. Diatoms produce a kind of ail by themselves to store chernical energy from photosynthesis
and ta increase their ability ta float. But this small amount of oil stiil needs to becorne
concentrated and mature before it can be taken from the ground and used as fuel.
Almost ail cil cornes from rocks that were formed underwater, floating ocean Fife (tint'
creatures known as diatoms, foraminifera, and radielarian) that settle to the bottom of the sea
eventually turns into oil. It tales many millions of years to form thick deposits of organic-rich
siudge at the bottom of the ocean. This siudge afterwards undergoes Secliment Maturation. Given
many thousands of years, a stack of mud and organic remains, many kilometers thick may pile up
on the sea fluor, especially in nutrient-rich waters. Given enough tire, the overlying sediments
that are constantly being deposited will bury these organic remains and mud deeply so that they
eventually are turned into solid rock. High heat and intense pressure help Along various chernical
reactions, transforming the soft parts of ancient organisms found in the deep-sea siudge into oïl
and naturai gas. This onze at the bottorn of the ocean turns into Source Rock.
1.2 ACCUMULATION
Reservoirs are the rock in which the oil is actually stored. An effective Reservoir must be of
high porosity and permeability and must allow active exchange of fluids so that existing ouater in
the trap is exchanged with hydrocarbOnS. It is a place that oil migrates to and is held underground.
Sandstone has plenty of room inside itself ta trap oil and acts just like a sponge. lt is fer this reason
Hydrocarbon Habitat in Growth Fault Regime
Page 6
that sandstones are the mort common reservoir rocks. Limestone and dolostones, some of which
are the skeletal remains of ancient coral reefs, are other examples of reservoir rocks.
Figure: 1 Reservoir grade rock
1.3 MIGRATION
'Vs the process when oïl migrates from source rock to reservoir rock, where it displaces
water that was originally present in the formation. If hyclrocarbons hit a trap they get stored there
otherwise continue travelling upwards via different mechanisms e.g. Emulsification with water etc.
Migration is rnainly of two types:
Primary Migration involves release of petroleum compounds from solid organic particles
(Kerogen) in source beds and their transport within and through the capillaries and narrow pores
of fine grained source bed.
Secondary migration, on the other hand, involves expulsion of the oil from source rock into
the reservoir, which has rocks with lager pore spaces and permeability through which it is passed
to traps
1,4 ENTRAPMENT
Hydrocarbons once formed, being Iighter than surroundings have a strong tendency to rire
above until they reach the surface of the earth, after which they are Iost in the environment. This
is what happens at oil seeps (once common in Pennsylvania, California, Texas and Louisiana).
Therefore, it is mandatory for exploration purposes that the hydrocarbon reserve is
contained in some way in the subsurface so that it can be explored and exploited. The geological
structures that act as barriers are called Traps. Traps are geological settings that with the help of
low porosity and perméable rocks trap the hydrocarbons_ Shale, limestone (with low
perrneability), etc. act as good seal.
Hydrocarbon Habitat in Growth Fault Reginie
Page 7
In Figure 2 the yellow particles are clay particles and Pink areas are pore spaces. As we can
notice vert' ciearly that clay particles are packed very tightly, Therefore, due to lack of pore spaces
the movement of oll through these rocks becomes extremely difficult,
PORE SPACE
SAND GRAINS
Figure: 2 Seal
Peculiar case of lime tore: Limestone can act as either a seal or a source rock depending
upon the pressure temperature conditions it has faced. The lirnestone which has undergone
higher pressures is likely to have a Iow permeability and is likely to end up as a Trap whereas the
one that has seen fewer pressures rnight act as a reservoir.
Hydrocarbon Habitat in Growth Fault Reginie
Page B
Chapter 2:
PETROLEUM SYSTEM
2.1 INTRODUCTION
Traps are the features that prevent ail from escaping from earth's surface. Ta be a viable trap, a
subsurface feature must be capable of receiving hydrocarbons and storing them for some
significant length of fine. This requires two fundamental components: a reservoir in which to
store the hydrocarbons, and a seal (or set of seals) ta keep the hydrocarbons from rnigrating out
of the trap. The presence of hydrocarbons is net a critical component of a trap, although this 15 a
requirement for economic success. The absence of hydrocarbons may be the result of failure of
other play or prospect parameters, such as the lacé of an active source rock or migratïon conduits,
and it may have nothing to do with the ability of an individua[ feature ta act as a trap.
2.2 RESERVOIR
The reservoir within a trap provides the storage space for the hydrocarbons. This requires
adequate porosity within the reservoir interval. The reservoir must aise be capable of transmitting
and exchanging fluids. This requires sufficient effective permeability within the reservoir interval
and also along the migration conduit that connects the reservoir with a source rock. Because must
traps are initially water filled, the reservoir rock must be capable of exchanging fluids as the
original formation water has ta be displaced by hydrocarbons. Trap with only one hornogeneous
reservoir rock are rare. lndividual reservoirs commonly include lateral and/or vertical variations in
porosity and permeability. Such variations may be caused either by primary depositional processes
or by secondary diagenetic or deformational effects and can lead to hydrocarbon saturated but
nonproductive waste zones within a trap. Variations in porosity and permeability can also create
transitions that occur over sortie distance between the reservoirs and the major seals of a trac'.
These intervals may contain a significant amount of hydrocarbons that are difficult to produce
effectively. Such intervals are regarded as uneconornic parts of the reservoir and net part of the
seal, or otherwise, trap spill points may be mis-identified. Many traps contain several discrete
reservoir rocks with interbedded impermeable units that forrn internai seals and segment
hydrocarbon accumulations into separate compartments with separate gas-oil-water contacts and
différent pressure distributions.
Hydrocarbon Habitat in Growth Fault Regiine
Page 9
wydrocarbon eccumdation
lepration paithway
Figure I
2.3 SEM
The seal is the most critical component of a trap. Without effective seals, hydrocarbons will
migrate out of the reservoir rock with tirne and the trap will lack viability. Effective seals for
hydrocarbon accumulations are formed by relatively thick, laterally continuous, ductile rocks with
high capillary entry pressures, but other types of seals may be important parts of individuel traps
(e.g., fault zone material, volcanic rock, asphalt, and permafrost). Ali traps require some four of
top seal. When the base of the top seal is convex upward in three dimensions, no other seal is
necessary to form an adequate trap. Many traps are more complicated and require other effective
seals. These are called the poly -seal traps. Lateral seals impede hydrocarbon movernent from the
sides of a trap and are a common element of successful stratigraphic traps. Fades changes from
porous and permeable rocks to rocks with higher capillary entrer pressures can form lateral seals,
as can lateral diagenetic changes from reservoir to tight rocks. Other lateral seals are created by
the juxtaposition of dissimilar rock types across erosional or clepositiona I bounda ries. Stratigraphie
variability in lateral seals poses a risk of leakage and trap iimitation. In thinly interbedded intervals
of porous and permeable rock in a potentiel lateral seal can destroy an otherwise viable trap. Base
seals are present in many traps and are most cornmonly stratigraphie in nature. The presence or
absence of an adequate base seal is rot a general trap requirement, but it can play an important
rote in deciding how a field will be developed. Faults can be important in providing seals for a trap,
and fault leak is a common trap limitation. Faults can create or modify seals by juxtaposing
dissimilar rock types across the fault (Figure 1), by smearing or dragging less permeable material
into the fault zone, by forming a less permeable gouge because of differential sorting and/or
cataclasis, or by preferential diagenesis along the fault. Fault-induced leakage may result from
juxtaposition of porous and permeable rocks across the fault or by formation of a fracture
network along the fault itself.
Hydrocarbon Habitat in Growth Fault Reghne
Page 10
2.4 TRAPS
Traps as discussed a bove are nnainly of three types:
•
•
Stratigraphie Traps
Structural Traps
•
Conibination Traps
These traps and there types are briefly discussed below.
2.4.1 STRATIGRAPHIC TRAPS
Stratigraphic traps are those in which the requisite and reservoir seal(s) combination were formed
by any variation in the stratigraphy that 15 independent of structural deformation, except for
regional titting
They are mainty of 2 types:
> Primary Stratigraphie Traps
Secondary Stratigraphic Traps
2.4.1.1 PRIMARY STRATIGRAPHIC TRAPS
They are formed by syn depositional processes by changes in conternporaneous deformation.
Theses traps are generally characterized by lateral depositional change e.g. depositional
pinchouts and facies change.
2.4.1.2 SECONDARY STRATIGRAPHIC TRAPS
They are formed by post depositional pressure on the underlying strata due to deposition of
sedinnents.
Hydrocarbon Habitat in Growth Fault Reginie
Page 11
Top Sul
b
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Figure 3: Seconciory Stratigraphie trop: Trop formed by post deposit!onal differentiai pressures on
the strata
2.4.2 STRUCTURAL
TRAPS
Structurai traps are created by the syn- to post depositional deforrnation of strata into a
geometry (a structure) that permits
the accumulation of hydrocarbons in the subsurface. The
Hydrocarbon Habitat in Growth Fault Reghne
Page 12
resuiting structures involving the reservoir, and usually the seal intervals, are dominated by either
folds, faults, piercements, or any combination, The mort important types of structural traps are:
•
Fold Dominated
Fault Dominated
Piercement
•
•
Combination of Fault-Fold
Subunconformity
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Hydrocarbon Habitat in Growth Fault Regime
Page 13
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Combination trips are formed when both fault and folcling have
important role in formation seal. Most successful structural traps are
cornbination of bath folti and fault
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Subunconformity Traps are formed when the unconformity
surface arts as top seal of the trap
2.5 TRAP EVALUATION
Trap evaluation is concentratecl on placing potentiat traps in the content of the operating
petroleum system. Plate tectonic setting, basin type, and structural evolution (sedimentary basin
study) is used to predict the possible styles of structural and stratigraphie traps that should be
expected in an area. Regional seals and their relation ta potential traps are established early in the
evaivation. Timing of trap formation and its relation to the timing of generation, migration, and
accumulation of hydrocarbon is the key of trap evaluation. Traps that forrn after hydrocarbon
migration has .ceased are not attractive targets unless rernigration out of earlier formed traps has
occurred. Trap is then mapped. Ideally, this would be the sealing surface of the trap. Identification
of the actual sealing surface requires that bath seal and reservoir characterization. A commori flaw
in trap evaluation results from ignoring the transition (or waste) zone, if present, between an
economic reservoir and its ultirnate seal. Before drilling, reservoir and seal characteristics can be
predictecl by combining regiorial and local paleogeographic information, sequence stratigraphie
concepts, and detailed analyses of seismic fades and interval velocities. A detailed log analysis and
incorporation of pertinent drill-stem test data is done for improved predictions. The absence of oil
or gas in a subsurface feature can be the result of failure or absence of other essential elements or
processes of a petroleum system and may have nothing to do with the viability of the trap.
Therefore, although we use the geometric arrangement of key elements to define a trap, trap
Hydrocarbon Habitat in Growth Fault Reginie
Page 14
evaluation must include much more Chan just mapping the configuration of those elements.
Reservoir and seal characteristics and their evaluation must be an integral part of any trap study.
Timing of trap formation is also critical. No trap should be viewed out of context but rather should
be evaluated in concert with all of the other efernents of a petroleurn system. Traps can be
classified as structural, stratigraphie, or combination traps. In addition, hydrodynamic flow can
modify traps and perhaps lead te hydrocarbon accumulations where no conventional traps exist.
The trap classification discussed here is a useful way to consider traps during the early stages of
prospect evaluation. An understanding of end-rnember trap types can help guide data acquisition
strategy and mapping efforts, but there is an alrnost bewildering array of documented and
potentiel hydrocarbon traps, rnany of which may be subtle or unconventional. As more and more
of the world's hydrocarbon provinces reach mature stages of exploration, such traps may provide
some of the best opportunities for future discoveries.
Hydrocarbon Habitat in Growth Fault Reginie
Page 15
Chapter 3:
G ROVVTH FAULTS
3.1 INTRODUCTION
Growth Faults are the type of faults in which there were displacements at the saine time as the
sediments, on either ride of the fault, were accurnulating. Main distinguishing feature of a growth
fault is the greater thickness of horizons, which is distinctly visible, in the downthrown block as
compared to upthrown block. Other important feature of growth fault is the formation of rollover
anticline (rot always seen) on the hanging wall of the fault system. In absence of a rollover
anticline, a tabuiar dip section is seen having contrasting horizon thickness in upthrown and
downthrown blocks,
They are important clans of syn sedimentary fault which have been widely recognized in
the subsurface studies of hydrocarbon-bearing clastic basin successions. They are Listric Normal
faults that affect only a discrete sedimentary interval in which they were active.
3.2 FORMATION AND STRUCTURE
Growth Faults are not directly related to basement tectonics rather are triggered hy gravity slidln
within the sedimentary pile. Whilst active, faults cause the thickness of the successions in
downthrown block to increase. The faults rnostly dip towards basin. This is attributed to the fast
that the rate of deposition increases as we go towards basin. Therefore, the increased Ioad
towards the basin sicle will have a tendency of going clown so, more sediment is deposited there
and therefore we get thickened horizons in basinward direction. Following factors may increase
the rate of the formation of growth faults
1. Ductility of underlying sediments
2.
Overburden of new sediments
Hydrocarbon Habitat in Growth Fault Reginie
Page 16
L
IMiene
=
.
-
L
Fig. 3.1 A Growth Fouit, listric and normal in nature and having thicker horizons on the
downthrown block(right hand skie) and relatively thinner horizons in the footwali wu/1
A ductile sediment succession floues easily and thus faulting occurs more easily, on other hand,
hardi consolidated sediments require much more pressure for faulting.
Figure 3.1 shows a typical growth fault. As we can see the fault is listric normal fault. Two horizons
are marked in the figure showing the increase in throw as we go deep.
The throw of growth fauft increases as we go deep rince the pre deposited successions undergo
faulting for a greater period of Lime as compared to the newly accumulated oves.
Sometimes formation on an anticline is observed on the hanging wall of the fault as shown in
figure 3.2. This roll over anticline aise is caused due to gravity sliding of base sediments ire [ower
parts of the fault
The formation of growth fault leads to cornpaction of shale present in the footwall due ta the
overburden of the sediments in hanging wall sicle. Also, if there is sait dome intrusion below the
fault there is arching in the layers (concave downwards) due the uprising body. This arching breaks
when the sait body exceeds (or rises above) the layer
Hydrocarbon Habitat in Growtli Fault Reghne
Page 17
3.3 GEOLOGICAL SETTINGS FOR GROWTH FAULTS
Since growth faults are generaily restricted to more recent sedimentary successions rather
than basernent they are more commun in extensional sedimentary basins, preferably where the
sediments were loosely packed enabling there decollment or slang at later stages e,g. in de[taic
environrnents where frequently, Ioad of new sedinients is laid over loose older sediments( Niger
Delta)
3.4 IMPORTANCE OF RO TH FAULTS
Growth Faults are given special recognition in study of subsurface exploration of hydrocarbons
because of unique kinds of conditions they form in trapping hydrocarbons.
get thicker across a growth fault. Therefore, it is more likely that
The successions in hanging
we will get larger reserves on the hanging wal[ rather than on footwall. This thickening is
important as it restricts more and more cil on one ride of the fault making the extraction much
more economicar. Apart from this, numerous kinds of traps are possible in growth faulted regime
Rollover Anticline
Fig 3.2 Formation of a roi/over antienne in a growth fouit
The hanging wall of the growth fault often forms a roll over anticline can efficiently trap the
hydrocarbons in presence of effective seal present on top. Also, the fault itseff can act as a lateral
seal
Second trap possible in growth fault is a fault block trap, Though this kind of trap might form in
any kind of fault, the growth fault geometry might enhance the tir-apis capacity by virtue of its
Hydrocarbon Habitat in Growth Fault Reginie
Page 18
thickness. Also, the fault leak is significantly hampered due to thinner successions on the other
ride of the fault. Thus if the hydrocarbon reserve 15 foilowed by a reservoir grade rock across the
fault the migration of oil from reserve will be reduced significantly.
Fig 3.3 Growth faults can effective!), foret excellent combination traps as shown
3.5 LIMITATIONS
First of ail a trap may or may not have hydrocarbon trappecl in it. One must know thoroughly the
geological and tectonic history of the block being explored, alors g with the migration history and
patterns of the hydrocarbon from source to reservoir. A trap has a positive chance only if the trap
formation pre-dates the migration. Also a trap loses the viability if it is not in the migration path of
oil.
Also fault plane, due ta sriding of various kinds of layers, may or may not seal the reserve. This
may lead to significant Ioss of ail te atnnosph.ere if the fault trace extends te the surface.
Similarly, if the rollover anticlirie Js net capped by an effective seal the oil will net be trapped.
Nature of the rocks aise plays dominant mile. The reservoir rock must be permeable enough te let
active exchange of fluids and keep the hydrocarbons absorbed for long periods of time.
Hydrocarbon Habitat in Growth Fault Regime
Page 19
CHAPTER 4:
INTERPRETATION
4.1 INTRODUCTION
1nterpretation refers to study of acquisition data and mapping of the subsurface geophysical data
by studying different seismic sections, marking the faults horizons etc. in the most geologically
appropriate way, integrating the well Iog data and then tying the features to get a reasonaWe
subsurface map.
4.2 THE PROCESS
4.2.1 DATA LCADING:
First of all the seisrnic lines are Ioaded on any interpretation software (SMT, Petrel, OpenDtect
etc.). Along with lines well Iog data can also be included at this step. Also a Polygon is defined
which essentially marks the arec in which we orant to restrict our analysis
4.2.2 FAULT PICKING:
Faults are picked by noting the abrupt change in horizons which is more or Iess sanie throughout
the depth of the line (or atleast for a noticeable length). Though, in section fault trace may look
perturbed {may be due to multiples, noise or other technical limitations) but we must mark the
fault trace in the rnost geologically appropriate way (generally it is preferred to have smooth
fault}. Faults are marked on every line available
4.2.3 HORIZON PICKING:
To start horizon picking dip section is well .suited as on a dip section faults are visible and we can
easily take care of the throw of each fault. At preferred time depth level, a suitable and easily
recognizable horizon is chosen and then marked. After we mark one horizon on one section a
point is obtained on d the Unes intersecting the marked section. This helps the interpreter to
Hydrocarbon Habitat in Growth Fault Reginie
Page 20
avoid the misties that might occur, Generally 2 or more horizons are marked for analysis of an
area
4.2.4 FAULT POLYGON:
The fault traces on seismic section appear as a point on the base map. The points corresponding
to a single fault are enclosed in a polygon. The thickness of polygon at a particular place
represents the throw of the fauft at that place. It is important to specify type of fault (whether
normal or reverse), so that it is shown correctly on the contoured ma
4.2.5 CONTOURING:
The Software interpolates the surface from the marked liner for a particular horizon, marked b )'
the interpréter, and prepares a contoured surface for the area.
4.2.5 THICKNESS MAP:
Thickness map is prepared by subtracting higher horizon contour map from lover horizon contour
map. It essentially reflects the thickness of the strata between the selected two layers, throughout
the area.
4.3 INTERPRETATION OF GROWTH FAULTS
Distinguishing features of a growth fault include varying thickness of horizon across a fault, roll
over anticline etc. They are listric normal fault and dip towards the basin though we often see
opposite dipping antithetic faults which are consequence of growth faulting itself, While marking
growth faults it must be kept in mind that the fault must dip in basin ward direction. Also, throw
increases as we do deep Inside the section. Also commonly observed feature in growth fault is
rotation of the hanging wall if there is some kind of geological barrier e.g. a ridge etc.
4.4 GEOMETRY OF GROWTH FAULTS
The dip of growth fault decreases with depth, therefore fault surface map of a growth fault must
show denser contours as we go in the direction opposite to the dip of the fault. Amount of
thickening in the horizon is a matter of the rate of sedirnentation of the succession at the time of
faulting, but a continuous increase in throw must be seen in growth faulting.
Hydrocarbon Habitat in Growth Fault Reginie
Page 21
CASE STUDY ON G ROWTH FAULTS
• Mumbai Cffshore
• Nger Illta
Hydrocarbon Habitat in Growth Fault Regime
Page 22
Chopter 5:
MUMBAI OFFSHORE
5.1 INTRODUCTION
Mumbai offshore is located on the western continental sheif of India between Saurashtra basin in
NNW and Kerela Konkan in the south. The basin has been proven for commercial production of
petroleum and hence falls under category I. It is approx. 116000 Knn2 in arec from coast to 200m
isobath. The age of the basin ranges from late Cretaceous to Holocene with thick sedimentary fiil
ranging from 1100-5000 meters though possibility of occurrence of Mesozoic synrift sequences in
the deep-water basin have been indicated by the recentiy acquired seismic data. The first oil
discovery in this basin %/vas made in the Miocene limestone reservoir of Mumbai High field in
February 1974, Subsequent intensification in exploration and development activities in this basin
have resulted in several significant discoveries including oil and gas fields like Fieera,Panna,
Bassein, Neelam,Mukta, Ratna,Soth tapti, Mid Tapti etc.
5.2 TECTONIC SETUP
Mumbai offshore is a pericratonic rift basin situated on western continental mare of indic.
Towards NIVE it continues into the oniand Cambay basin. It is bounded in the northwest by
Saurashtra peninsula, north by Diu Arch. Its southern limit is marked by east west trending
Vengurla rch, located ait south of Ratnagiri, and to the easten boundary is marked by Indian
craton. The Mumbai Offshore Basin is divided into 5 différent tectonic zones (Figure 2)
•
•
•
•
Surat Depression (Tapti-Daman Block) in the north
Panna-Bassein-Heera Block in the east central part
Ratnagiri in the southern part
Mumbai High-Platform-Deep Continental Shelf (DCS) in the raid-western sicle
•
Shelf Margin adjoing DCS and the Ratnagiri
Hydrocarbon Habitat in Growth Fault Reginie
Page 23
ni
er
14°.
• Tà$9 .
•
SUNA T 1:1EPRESN0ft
olOPTI mu* MI•OCIp
• 6T
•
te
PAN PiA 'LAS SEN r:.
BLOCK
e:1
ir
010
:.I
7
Figure 2: Different tectanic zones in Mumbai Offshore
5.3 STRATIGRAPHIE
Within the Bombay geologic province, the stratigraphic record is incomplete. ln the subsurface,
Mesozoic rocks are known from drilling only in the Kutch area. ln the Depressions (Panna
Formation) were filled with trap wash overlain by carbonates, shales, and interbedded siitstones
from fluvial to transitional environments. In the Kutch area, marine sedimentation occurred oniy
in the western part until the end of the Paleogene. Lover to middle
Eocene rocks are
absent
from
mort of the offshore area, and an erosional unconformity that extends over rnost of the offshore
area truncates the Panna Formation. Eocene marine carbonates and shales of
the Belapur,
Bassien, and Dui Formations extend over mach of the present -day offshore and Eocene -Oligocene
sandstones, siltstones and shales refiect shallow marine taa ll uv i a l
environments in the south
Cambay Graben. Middle to late Eocene tirne in the shelf margin or outer shelf, Bombay High, and
Panna - Bassein areas is represented by sharlow-marine shales and shelf carbonates of the Belapur
and Bassein Formations. Shoreward„ and to the northeast, shallow - marine to lagoonal Dui
Formation shales domi. nate. Stin farther to
the north, in the south Cambay Graben, deltaic and
alluvial sediments of the AnIdeswar Formation dominate late Eocene-Oligocene environments.
Today, the shelf area continues to receive terrestrial sediments, and the Cambay and Narmada
Deltas continue to expand. The Stratigraphic chart of différent zones of Mumbai offshore are
shown in Figure 3
Hydrocarbon Habitat in Growth Fault Reginie
Page 24
BOMBAY
HIGH-DCS
BLOCK
SHELF-MARIN
BLOCK
5
1■4111,r
RATNAGIRI
BLOCK
PANNA.BASSEIN
BLOCK
1
.*
=
1
1
eC
l
/
=
rXere
TAPTI.DAMAh
.■■•
•■•••• e-bi
4■
11. ,•■• .41.•
mi lila .mlm
'O-
IS -
z
M=M Mil
C.,
o
x
MM IM=M
••= a
. 1=. MM M=M
1=
i''
*M M=M
M1
.
■I1 M= -.
MC% = L_J MI=M
' i■M=MM
a 1.',MMWAIMI b=1 l■M=ZM IMMII
-.7
_rM Ma
I=Mi
IM L. :".'
IM.•M M=M 1■. Kilà1 '
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r.1 l■M=Il 11
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—
)
1±
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419à DiariARM
5
•
—1
—I— ,I
•■
•
(iRANITIC COMPLEX
EXPLANATION
Oil production.
le show. or seep
Gas production
Of StIOW
11.
Source rock
potential
Conglomerate
•
Siltstone. shale.
and sandstone
Sandstone
.
Flysch
FLILirnestone
j
7r1
o
Volcanics
Shale. si ltstoi)e.
---- and sandstone
Figure 3: Stratigraphy of Mumbai offshore arec
Hydrocarbon Habitat in Growth Fault Regime
Page 25
5.4 PETROLEUM SYSTEM
5.4.1 SOURCE
The main source in the Mumbai offshore region is the thick Panna shale facies deposits and
Belapur Shale faces deposited between Paleocene and Lower to Mid Eocene
5.4.2 RESERvOIR
Mumbai Offshore has botte carbonate and clastic reservoir facies everywhere between Paleocene
and middle tvliocene. Reservoir grade rocks are frequentry found interlayered between shales in
lower Miocene and Mid Miocene level. Main reservoir successions include Mukta, Ratnagii etc.
Reservoir
Age
Lithology/Location
Comments
Middle
Carbonate sections (Ratnagiri & The uppermost part has been found to be
Miocene
Bandra formations)
hydrocarbon bearing at a few places
A sheet like sand deposited over Mumbai
High is also proved ta be gas bearing in
commercial quantity in Mumbai High
Lower
Represented by a thick pile of Deposited under cyclic sedimentation with
Miocene
carbonates
hosting
quantity of ou and gas
huge each cycle represented by lagoonal, algal
mound, foraminiferai mound and coastal
marsh
facies
The porosity is mainly intergranular,
intragranular, moldic, vuggy and microfissures and the solution cavities
interconnected by micro-fissures provided
excellent permeability.
Oligo— Early
Sancis ( Panvel formation )
Miocene
Hydrocarbon Habitat in Growth Fault Reginie
Deposited
under
prograding
delta
conditions
Page Xi
Proved to be excellent reservoirs
Eocene and
E.Oligocene clastics (Mahuva Proven hydrocarbon bearing reservoirs in
Early
Formation)
Oligocene
Deposition of thicker carbonate Graduai increase of sea level, shielding
Ta pti
area.
fades over the horst blocks from the clastic onslaught from the
(Bassein, Mukta & Heera northern part of the basin.
formations).
The intervening regressive phases have
aideci in developing good porosity in these
rocks rnaking them excellent reservoir
levels in the basin.
Paleocene
Coarser clastic facies developed The clastics of Panna formation are proved
within the upper marine shale to be excellent reservoirs.
(Panna Formation)
5.4.3 CAP ROCKS
tvlan successions acting as cap are also shales deposited later in Pleistocene, also named Chinchini
Shales. It is a thick shale succession that sits over other clastic and carbonate layers.
5.4.4 ENTRAPMENT
Mumbai Offshore has various tectonic settings that show a range of traps for example in
Structural traps litre tilted fault black type, fault closures. Fold dominated traps include anticlines
and also roll over anticlines formed due to growth faulting. A large number of growth faufts also
have enhanced the probability of striking econornic prospects, especially in the basinward
direction of the zone. This study deals with the growth fault reginne located within the shelf
rnargin tectonic block of Mumbai Offshore basin
5.5 DATA INTERPRETATION
Interpretation of the study area located within the Shelf-Margin tectonic block of Mumbai
offshore was done on SMT KINGDOM on Mid Miocene and Lower Miocene level. The seismic time
section of 21 liner was used to interpret these levels and prepare time structure maps and a rnidMiocene isochronopach.
Hydrocarbon Habitat in Growth Fault Reginie
Page 27
5.5.1 SEISM1C DATA INTERPRETATION
Figure 4: Base map shawing the study area
Hydrocarbon Habitat in Growtli Fault Regime
Page 2
5.5.2 INTERPRETED HORIZONS AND FAULTS
Figure 5: Seismic section of line as marked in the figure
Figure 6: Seismk section of une as marked in the figure
Hydrocarbon Habitat in Growth Fault Regime
Page 29
Figure 7: Seismic section of line as morkeci in the figure
Figure 8: Seismk section of une os morked in the figure
Hydrocarbon Habitat in Growth Fault Reginie
Page :30
Numerous listric normal faults are seen on the section. This is because large sediment deposition
in the basin has led to formation of growth faults. Especially to be noted is the centrai main
growth fault marked in red in the above sections. A roll over anticline is seen on the east of tris
fault which has been faulted by antithetic faults (Figure 8}. The Green horizon represents Middle
Miocene level and the yellow horizon denotes Lower Miocene level.
5.5.3 TIME STRUCTURE MARS
+LIU
1 1 SI
ro
1 len
1200
1215
12,0
1241
1350
1275
1290
13)5
1»0
1335
Leti
1365
1380
13■15
14.385
Figure 9: Mid Miocene two way tirne structure !pop
Hydrocarbon Habitat in Growtli Fault Regime
gage 3 1
n mas
les
.1 es
les
t_125
tas
1.525
1 575
1 625
1 SIS
I 725
1 375
1112$
I 975
1 925
1 975
CCC
Figure 10: Lower Miocene two way time structure mafia
The faults trend NNW-SSE on the map. A persistent rire is observed in the western part of the
study area. This is because of Laxmi-Laccadive Ridge which is present along the shelf margin in
Murnbai offshore. Due to this ridge the horizons have been raised on the western part of study
area. Eastern hait of the area has homoclinal slope. Main basinal s'ope is towards ouest because of
the presence of growth fault pockets. Sediment depocenters are observed in the eastern half of
tha study area.
Hydrocarbon Habitat in Growtli Fault Regime
Page 32
5.5.4 1SOCHRONOPACH MAP
.0 top
o 100
oi
0 eiso
no
O29)
0.2e8
3t$0
e 3e
0.370
411:0
0.43)
4f30
0 490
0 i20
59)
0U
~~
VO
0 640
/100
0700
0 73)
07W
4 3"00
Figure 11: isochronopoch of Mid Miocene succession
The thickness is reduced sharply from center to west. As shown in (Fig 5-8) the Middle Miocene
level doesn't vary rnuch whereas there is a sud en rire in Louver Miocene Level after main fauFt
(Marked in Red in respective figures).
5.6 PROSPECT ANALYSIS
Interpretation of the area shows that there is rollover anticline on the hanging wall of the main
fault forming an excellent trap (Figure 12).
The anticline marked rn figure 12 corresponds ta '1' in figure 13. Along with this, similar but
srnaller antiennes are also seen in the area e,g. those rnarked in figure 13, The prospect '3' lies on
the same fault as '1'. '2' is another anticline, but the main problem with this region is that it lies on
Hydrocarbon Habitat in Growth Fault Reghne
Page 33
foot rail of the fault in further east decreasing the thickness considerably which might not yield
econornic quantities of oil.
Probable Plyclroiumbon Prospects in SheI Mar en Mumbai Offshore
Inclined Fault Block Type
Rollover Anticline
•-r• •i&Ifty.
• dMig.1.■....0.;11110.ff
- . •
•
•" •
:..
...i■ IrLeFf.
•MILe
•
4,41.
•,
•
Figure 12: Prospect analysis of the arec (lare view)
Hydrocarbon Habitat in Growth Fault Reginie
P age 4
1.155
1 Mi
11 $5
200
1211
1 230
1 24
1.2E0
275
ne
13S
1320
305
■
13!0
1 305
no
1 795
.1. ME
Possible Hydrocarbon
Prospects
Figure 13: Prospect andlysis of the study arec (Plan view- Mid Miocene TINT rnap)
Hydrocarbon Habitat in Growth Fault Regime
Page 35
CHAPTER 6
NIGER DELTA
6.1 INTRODUCTION
Mo-cliern Coasilinie
•t I
t
t
•
UPPer Eofen
Pre-Getaceous
basernent
Cretaceous &
younger secllrnen t
Lowe Tertlary ha sin
èdee axis and 'direction of
&lui( supply
ee'
f
Appro:drnate coastline
positions a t the designated
Lime
Pi tocene- Pleistocere
Figure 1: The changing coostiine of the Niger delta
100 km
(35
Mo History)
The Niger Delta is situated in the Gulf of Guinea (fig. 2) and extends throughout the Niger Delta
Province. The coastal sedirnentary basin of Nigeria has been the scene of three depositional
cycles.
The first began with a marine incursion in the middle Cretaceous and vki a s terminated by a mild
folding phase in Santonian time. The second included the growth of a proto-Niger delta during the
late Cretaceous and ended in a major Paleocene marine transgression. The third cycle, from
Recent, marked the continuous growth of the main Niger delta. A ne w threefold
lithostratigraphic subdivision is introduced for the Niger delta subsurface, comprising an upper
sandy Benin formation, an intervening unit of alternating sandstone and shale named the Agbada
Eocene to
Hydrocarbon Habitat in Growth Fault Reginie
Page 36
formation, and a lower shaly Akata formation. These three units entend across the whole delta
and each ranges in age from early Tertiary to Recent. From the Eocene to the present, the delta
huas shifted southwestward, forming deposition belts that represent the rnost active portion of the
delta at each stage of its development). These depositional belts forrn a regressive delta an area of
some 300,000 km2, a sediment volume of 500,000 km', and a sediment thickness of over 10 km in
the basin deposition center. The Niger Delta Province contains only one identified petroleum
system, the Tertiary Niger Delta (Akata —Agbada) Petroleum System.
Figure 2: Index map of Nigeria and Cameroon
6.2 GEOLOGY
The onshore portion of the Niger Delta Province is Iined by the geology of southern Nigeria and
southwestern Cameroon (fig. 1). The northern boundary is the Benin flank--an east-northeast
trending hinge line south of the West Africa basernent massif. The northeastern boundary is
defined by outcrops of the Cretaceous on the Abakaliki High and further east-south-east by the
Calabar fiank--a hinge line bordering the adjacent Precarnbrian. The offshore boundary of the
province is defined by the Cameroon voicanic line to the east, the eastern boundary of the
Dahomey basin (the eastern-mort West African transform-fault passive margin) to the west, and
the two kilometer sediment thickness contour or the 4000-meter bathymetric contour in arecs
where sediment thickness is greater than two kilometers to the south and southwest. The
province covers 300,000 km2 and includes the geoiogic entent of the Tertiary Niger Delta (AkataAgbada) Petroleum System.
Hydrocarbon Habitat in Growth Fault Reginie
Page 37
6.2.1 TECTONICS
The tectonic framework of the continental margin along the Niger toast is coritrolled by
Cretaceous fracture zones expressed as trenches and ridges in the deep Atlantic.
Discal Portion of Depobelt
Continental Rise
Lower Continental Slope
Zone of diapir
Toe thnis
2
-
4
-
•
Late Tertiary
6
•
-••.• - _
•
• ..■16
8
Late Cretaceous EarlyTertiary
•••
• ::F F/0-(/
Oceanic Crue
12
so
100
• SO
Distance (kr»i
Figure 2: Seismic section from the Niger Delta continental slope irise showing the rescrits of internai
gravity tectonics on sediments at the lista} portion of the depobelt.
The ridges in the fracture zone livide the margin into different basins and, in Nigeria, foira the
boundary fautts of the Cretaceous Benue-Abakaliki trough, which culs far into the West African
shield. The trough represents a failed aria of a rift triple junction associated with the opening of
the South Atlantic. ln this region, rifting started in the Late Jurassic and persisted into the Middle
Cretaceous. In the region of the Niger Delta, rifting diminished altogether in the Late Cretaceous,
After rifting ceased, gravit y tectonics became the primary deforrnational process.
Shale mobility induced internai deformation and occurred in response to two processes.
First, shale diapirs fornied from loading of poorly cornpacted, over-pressured, prodelta and deltaslope clays (Akata Fm.) by the higher density delta-front sands (Agbada Fm.). Second, slope
instability occurred due to a lack of lateral, basinward, and support for the under-compacted
delta-slope clays (Akata Fm.) (Fig. 2). Shale rnobility induced internai deformation and occurred in
response to two processes. First, shale diapirs formed from loading of poorly compacted, overpressured, prodelta and delta-slope clays by the higher density delta-front sands (Agbada Fm.).
Second, slope instability occurred due ta a lack of laterat, basinward, and support for the underHydrocarbon Habitat in Growth Fault Reginie
Page 38
compacted delta-clope clays (Akata Fm.) (Fig. 2). For any given depobelt, gravity tectonics were
completed before deposition of the Benin Formation and are expressed in complex structures,
including shale diapirs, roll-over anticlines, collapsed growth fault crests, back-to-back features,
and steeply dipping, closely spaced flank faults. These faults mostly offset different parts of the
Agbada Formation and flatten into detachment planes near the top of the Akata Formation.
6.2.2 STRATIGRAPHIE
The Cretaceous section has not been explored beneath Niger Delta Basin, the youngest and
southernmost sub-basin in the Benue-Abakaliki trough. Lithology of Cretaceous rocks deposited in
the Niger Delta basin can only be extrapolated from the exposed Cretaceous section in the next
basin to the northeast--the Anambra basin. From the Campanian through the Paleocene, the
shoreline was concave into the Anambra basin
Niger Delta Basin'
Anambra Basin
B.tonikr,
SB
L u te dan
Agbada Fm
-50
Yenesian
Thatiet
-60
nies n
Aka ta Fm
Mags-r7 <nuiri
-70
?Amin tg Trri
ÇA
C arnpae
41 1
11
111116±:11
Sinter s
SB)
3
C onda
SB Sequence Boundary
Channel
-- Maximum Ficioding Boundare Tidal structure
— Coal
-80
n
-90
Figure 3: Strutigraphic section of Anan-imbra basin
resulting in convergent longshore drift cells that produced tide-dominated deltaic sédimentation
during transgressions and river-dominated sedîmentation during regressions. Shallow marine
clastics were deposited farther offshore and, in the Anambra basin, are represented by the AlbianCenomanian Asu River shale, Cenomanian-Santonian Eze-Uku and Awgu shales, and
CampanianiMaastrichtian Nkporo shale, aniong others (figs. 3 and 6) . The distribution of Late
Cretaceous shale beneath the Niger Delta is unknown in the Paleocene, a major transgression
(referred to as the Sokoto transgression by Reijers and others, 1997) be an with the Imo shale
Hydrocarbon Habitat in Growth Fault Regime
Page 39
being deposited in the Anambra Basin to the norlheast and the Akata shale in the Niger Delta
Basin area to the southwest (fig. 5). In the Eocene, the coastline chape became convexly
curvilinear, the longshore drift cells switched to divergent, and sedirnentation changed to being
wave-dominated (Reijers and others, 1997). At this tirne, deposition of paralic sediments began in
the Niger Delta Basin proper and, as the sediments prograded south, the coastline became
progressively more convex seaward. Today, delta sedimentatiori is stil' wave-dorninated and
longshore drift cells divergent
Tertiary section of the Niger Delta is divided into three formations, representing prograding
depositional facies that are distinguished rnostly on the basic of sand-shale ratios. The Akata
Formation at the base of the delta is of marine origin and is composed of thick shale sequences
(potential source rock), turbidite sand (potential reservoirs in deep water), and minor amounts of
clay and silt (figs. 3, 4, 5 and 6). The Akata Formation formed during [owstands when terrestrial
organic matter and clays were transported to deep water arecs in low energy conditions and
oxygen deficiency. The formation underlies the entire delta, and is typically over pressured.
Turbiciity currents likely deposited deep sea fan sands within the upper Akata Formation during
clevelopment of the delta. Deposition of the overlying Agbada Formation, the major petroleumbearing unit, began in the Eocene and continues into the Recent (figs. 3, 4 and 5), The formation
consists of paralic siliciclastics over 3700 rneters thick and represents the actual deltaic portion of
the sequence. The clastics a ccumulated in delta-front, delta-topset, and fluvio-deltaic
environrnents. ln the louver Agbada Formation, shale and sandstone beds were deposited in equal
proportions, however, the upper portion is mostly sand with only minor shale interbeds. The
Agbada Formation is overlain by the third formation, the Benin Formation, a continental Iatest
Eocene ta Recent deposit of alluvial and upper coastal plain sands that are up to 2000 m thick
(Avbovbo, 1978).
A
A'
East
West
Figure 4: AN Section (refer Figure 1)
Hydrocarbon Habitat in Growth Fault Reginie
Page 40
PROVINCE
PRESE NT DAY
DELTA FRONT
BOUNDARY
t ers
M10-P 10CENE
DELTA FRONT
IOCENE
DELTA Fele
«DIE
MITA Ma«
AGAOADA FA OB
de>
MASADA FACIES 0/0/
MATA FADES
Out 1 AC1ES
itEleNfACIES
efe
iesu
RneERCIP
i goe
eior.
-------
e te.>
11000
AEROMAGNETK
r...%
pure
cepirec
BOISEMENT 11000
•11 far ine fartes
11 Conti nental facies
Baser* nt compte'
(Oceanic and continen
Unconformfty
-- 1.$
Facies boundamo
90410A
1
2061
0
100
1
I
1
I
3111 PAL
ji
Figure 5: Bir Section (Refer Figure 1)
Hydrocarbon Habitat in Growth Fault Regime
Page 41
SOUTHWEST
NORTHEAST
•
Ouaternai
••n
I
•Moid d •
•• ••• .• •
Deltaic Facies
Pli0(ene
.e•
I ••
• • „
dry +rr:
(Ag bada Fm.)
mn' •
• n...n
'
•• r
%Me -fr.d...•••••••
.•.••• ••• •••+d• dy••
•
! ,.:•••••%;..::•'...:•....:••;••
•
• .:«.•■ •••••:
•
$.
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nui LA I ly via Sa ncr
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.
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m
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m.
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Extert or erosional truncat on
Figure 6:
Stratigraphic column showing the 3 formations of Niger delta
Hydrocarbon Habitat in Growth Fault Reghne
Page 42
6.3 PETROLEUM SYSTi M
6.3.1 LOCATION
llydrocarbons are present throughout the Agbada Formation of the Niger Delta (Figure 1). Though,
oil rich trends have been found having the lowest gas to oil ratio as shown in Fig. 7
Shate proue areas
Coastline
/Direction of clastic input
Figure 7: The oil rich trend line in the Niger delta province
As shown above, the oil rich trend ruas close to the shore and roughly corresponds to transition
betvveen continental and oceanic trust, and within the axis of maximum thickness.
Source Rocks
Marine Akata shales and interbedded shales cretaceous shale of Agbada along with Cretaceous
shales have been identified. Also Agbada Formation has intervals that contain organic carton
contains in sufficiently high quantifies but the thickness of Chose layers is riot thick enough to
produce a world dass oil province. Also they are immature in various parts of the deltas. The thick
Akata shales, below Agbada, are however are of large volume and produce oil in large quantifies.
Hydrocarbon Habitat in Growth Fault Regime
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6.3.2 RESERVOIR
The main reservoirs are sandstone and unconsolidated sands in Agbada formation. The reservoirs
are often stacked and are show a large variation in thickness ranging from 15 ruts to 10% having
thickness of 45 nits.
6.3.3 ENTRAPMENT
N
Grawthfaults
Giowth fault
V
Strat. trap
Roi lover structure
Clay filled channe
losures
au:T c/oit:te
— —
Rollover çtructure
•
Sand pinçhout
•_
• •
nef Pirktioca
• Akata
-
-
A katie,
g
L
Simple rollover structure with clay filled c hannel
48.
.4
Structure with multiple growth faults
N
Antithetic fault
\\I
Growth fault
ve
Structure with antithetic fault
G rowth fa tilts
Antithetic Mun
Collapseci crestil
f ollapsecl crest structure
Figure 8: Various traps found in the Niger delta province
the Niger delta region are mostly structural mostly involving syn sedirnentary
deformations, rnostly growth faults and rollover structures. The shales, acting as a seal trap
typically either form clay smears a[ong the faufts or provide interbedded sealing units against
which reservoir sands are juxtaposed due to faulting or set a vertical seal and act like lateral seals
to prevent horizontal migration of oil. On the flanks of delta (offshore} the clay filled canyons
provide top seal and foret excellent traps,
The traps in
Hydrocarbon Habitat in Growth Fault Reginie
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6.3.4 CAP ROCK
The primary seal rock in Niger delta is the interbedded shale within the Agbada formation. As
discussed earlier the shale provides three types of seals—clair srnears along faults, interbedded
sealing units against which reservoir sands are juxtaposed due tu faulting, and vertical seals
6.4 CONCLUSION
kis clear from above discussion that the main traps in the Niger Delta province are based on syn
sedimentary structures. The abundance of such traps is increased mainly due to the uncompacted
layers of sand stones being overpressured by the heavy sediment loads of the delta. This has recuit
in gravit y siiding and fracturing of subsurface on a large scale, Thickness of reservoir is selectively
increased at places by growth faults making exploration and extraction very profitable.
Hydrocarbon Habitat in Growth Fault Reginie
Page 45
CONCLUSION
From the study done tilt now following important points have been concluded:
•
oir occurrence in the trap depends on the Urne of formation of trap and the time of
»
migration. The Trap should have formed before migration otherwise the oïl will escape.
If the underlying sediments are not compact enough their ductility increases and pence
theïr tendent y of undergoing gravit y siiding eventually leading to growth faulting (As seen
in the case of Niger Delta)
~~ Interpretation shows that, in the stuclied ares of S'Il& Margin of Mumbai Offshore, there is
a possibility of good quantifies of hydrocarbons due to existing rollover structures and
highly faulted strata.
Hydrocarbon Habitat in Growth Fault Reginie
Page 46
Works Cited
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p.801-15, 32
July 1984, Listric Normal Faults; An Illustrated Summary, AAPGBulletin, v.68,
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G.,
Trevino, Ramon H.,Hammes, Ursula, 2004, Understanding
Growth faulted,intraslope subbasins by applying sequence stratigraphic pririciples: Examples
from the south Texas Oligocene formation, AAPG Bulletin, y. 88, no. 11 ,pp. 1501 —1522
Brown,L. Frank Jr,Loucks„ Robert G., Trevino, Ramon H.,Hammes, Ursula, 2004, Understanding
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from the south Texas Oligocene Frio Formation: Reply, AAPG Bulletin, U. 90, no. 5 (May 2006),
pp. 799-805
Gazes, c_A., December 2004, Oyerlap zones, growth faults, and sedimentation: using high
Resolution gravity data, Livingston Parish, LA, Phd. Theisis, Louisiana State University
Wandrey, C.J , May 2004, Bombay Geologic Province Eocene to Miocene Composite Total
Petroleum System, india, Petroleum Systems and Related Geologic Studies in Region 8, South
Asia, U.S. Geological Survey Bulletin 2208-F, v.1
Jackson, M.P,A, Vendeville, B.C.,July 1991, The rire of diapirs during thin-skinned extension,
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wiNvv.cighindier.rirq
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