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Lahiri, S.K., 2013. Near surface lateral inhomogeneities and oil
field locations – a strong connection observed in Namrup-
Sapekhati window, Assam. Insignia, V, 12-16
Near surface lateral inhomogeneities and oil field
locations – a strong connection observed in Namrup-
Sapekhati window, Assam
Siddhartha Kumar Lahiri
Department of Applied Geology
Dibrugarh University
River valleys experiencing active tectonic controls bear typical geomorphic signatures. If
incidentally, the valley concerned is highly petroliferous and oil habitat is strongly governed
by tectonic forcings; expectations grow among the explorers from the recently developed
disciplines like remote sensing methods to play a meaningful complementary role. However,
when the rate of sediment influx is very high, a competitive damping effect sets in that
obliterates many important geomorphic signatures. Thus, in spite of highly potential remote
sensing techniques capable of offering different filtering options for suitable image
processing, the anticipated breakthroughs in ‘exploration leads’ might not be achieved. Under
such circumstances, it is observed that shallow subsurface data like uphole and shallow
seismic refraction, which provide a highly representative description of near surface lateral
inhomogeneities, are very useful. Work was done on high density shallow refraction data sets
in Namrup-Sapekhati window, situated in the south bank of the upper reach of the
Brahmaputra valley, Assam. Three parameters namely; lateral variations in the P-wave
velocities of the topmost low velocity layer (LVL) and the layer following immediately,
known commonly as sub-weathered zone and the thickness of the LVL were considered. A
new approach “Multiparametric microzonation” was applied to implement a zonation scheme
based on different combinations of the above said parameters in the GIS based environment
and oil field locations along with some of the geological elements like blind faults were
collated . It was observed that high velocity (both top and bottom layers) and thicker LVL
bearing zones are more closely associated with the oil fields.
Introduction
In the Brahmaputra valley of Assam, the future of oil exploration rests on how efficiently we
relate thrust belt tectonics with the possibilities of generation of petroleum systems in the
light of basin evolution in different stages. Thus, foredeep areas bordering the thrust belts are
definitely the main focus of present attention which will continue to be so in near future as
well. So far, none of the geophysical techniques can contest the outcome of the seismic
reflection methods. Resolution enhancing efforts by populating the energy source at greater
depths with high frequency contents meet tough challenges in practice. Multi component
seismic methods and increasingly wider range of variability in attribute analysis, thanks to the
fast growing computing ability, brings in the domain of subsurface modelling a kind of
‘magic realism’ like thing but increasing simultaneously the I/O (input versus output) cost
ratio. In essence, most of the high-tech current practices are engaged in approaching the
‘object at distance’ as closely as possible. However, if we assume that the ‘object’ due to its
interconnected neighbourhood is bound to cause certain perturbations at remote places as
well, say at the place where the observer stands, then we could have spent some of our
innovative energy to diagnose the disease by monitoring the skin, instead of depending
increasingly and almost exclusively on ‘test-packages’ which never claim of absolute
certainty yet inflict heavy toll on the pocket of the patient than perhaps the disease itself.
Here comes the role of the shallow subsurface geophysical data which might be used in
extending the scope of morphotectonics. The use of shallow refraction data is very old.
Pioneering papers by Barton (1929) and Heiland (1929) established literally the importance
of the refraction method. Muscat (1933) explained in detail the theory of refraction shooting.
Fan shooting technique that was used in the earlier days for shallow structural traps of oil was
mainly based on the refraction method. Later on the method was used for mapping subsurface
structures (Gardner, 1939), water prospecting and rock investigations (Hasserlström, 1969;
Bachrach and Nur, 1998; Grelle and Guadagno, 2009). Besides these, workers have used
this method to map ancient channels (Pakiser and Black, 1957) and in exploring Quaternary
deposits (Burke, 1973). In this paper, first, arguments are forwarded in favour of a
classification system which is based on the assumption that foredeep areas of the outcropping
thrust belt mountain ranges get highly affected due to the advancing leading edges of the
blind thrusts which influence considerably the sites of aggradation-degradation in the valley.
Secondly, in one of the foremost oil provinces of the upper Assam valley, the Namrup-
Sapekhati window, the locations of some of the major producing oil fields are seen to follow
a distinct trend that is in conformity with the trend of the general regional strike direction.
Namrup-Sapekhati window
This is a NE-SW trending window with approximate area 880 km2 and located within the
four points the longitudes and latitudes of which are respectively 94.990/27.17
0;
95.340/27.36
0; 95.44
0/27.20
0; 95.10
0/27.00
0 (Fig.1). This is one of the richest oil-windows of
the upper reach of the Brahmaputra valley (Fig.2A). At least seven major oil fields namely,
Nahorkatiya, Jorajan, Tarajan, Sarojini, Rajgorh, Diroi and Dipling seem to lie one after
another in a belt and two more oil fields, Tinali in the western part of the belt and
Baruanagar is located in the eastern part of the belt. The alignment of the Naga Patkai Thrust
(NPT) belt, direction of flow of the Disang River, the direction of the regional blind faults
(B1-B1´ and B2-B2´) and above all the clusters of oil fields seem to be parts of an integrated
whole. Seismo-tectonic map covering the window and some of the adjacent areas show (Fig.
2B) there is heterogeneity in valley fill; sediment thickness (as inferred from the basement
depth variations) varies from 4.0 – 6.0+
km within the window. Thicker part is observed along
the foredeep adjacent to the accretionary complex and the Schuppen belt belonging together
to the NPT belt. Bouguer gravity anomaly, in conformity with the above situation varies from
-192 to -200 mgal. The window is very rich in palaeo channel marks and the presence of ox-
bow lakes (Fig. 2A). The amplitude and wavelength of the meandering palaeo-channels are
very much comparable to that with the present day channels and this gives a clear clue of
river migration along a specific direction.
Fig.1. Location map of the Namrup-Sapekhati window is shown on the IRS-P6-LISS-3
image in the south bank of the upper reach of the Brahmaputra valley, Assam.
Abbreviated geological elements are HFT-Himalayan Frontal Thrust, MBT-Main
Boundary Thrust, NPT-Naga Patkai Thrust.
Fig.2. (A) The NE-SW trending
Namrup-Sapekhati window has
plenty of palaeochannel marks.
Two major tributary rivers of
the south bank, Brahmaputra
valley, the Burhi Dihing and
the Disang pass through the
window. Two regional blind
faults and some of the major oil
fields of the area are shown.
Total number of oil fields is 9,
out of which seven are located
in a zone bounded by two blind
faults. (B) Seismotectonic map
covering Namrup-Sapekhati
window and the adjacent areas
show the thickness of alluvial
fill along the foredeep more
than 6km.
Data and Methodology
Shallow refraction data coverage for the Namrup-Sapekhati window is uniform and
extensive. In total 1228 points were covered (Fig. 3). For a general estimate, three (3) points
were investigated for every 2 km2 area. The data was collected systematically by Geofizyka
Toruń of Poland during January-February, 2008 field season for the OIL.
Velocity variation in the topmost LVL is 200 - 840 m/s. This shows a wide range of
variation. Velocity variation in the sub-weathered layer is 600 – 2100 m/s; suggesting thereby
a still wider range of lateral inhomogeneity. Thickness range of the topmost LVL is 1-14m. A
generalized approach of two component system was adopted with the assumption that the
channel-fill deposits and the older flood plain deposits have sharp velocity contrast.
Accordingly, after trial and error, ‘high’ and ‘low’ velocity zones are differentiated. For the
V1 values (that is, velocity of the LVL) the threshold was fixed as, V1 (low) = 200 – 383m/s
and V1 (high) = >383 – 840 m/s. For the V2 values (that is, velocity of the sub-weathered layer)
the threshold was fixed as V2 (low) = 600 – 1162m/s and V2 (high) = >1162 – 2100 m/s (Fig. 4).
Fig.3. Shallow refraction data
density in the Namrup
Sapekhati window having
1228 number of stations
covered.
Thickness range 1-5m for the LVL is taken as ‘thin’ and 5+-14m is treated as ‘thick’. Logic of
micro-zonation is developed based on the overlapping of high-low velocities of V1 and V2
and thick-thin characteristics of the LVL thickness. This results into eight type areas (Table
1). The entire exercise was done in the GIS environment that facilitates a comparative study
of the microzonation with the oil field locations as well as some of the well established
structural elements.
Fig.4. Velocity differentiation of layers into two-component systems
like high velocity (older flood plains, more consolidated) and low
velocity (incised valley deposits, newer flood plains, less
consolidated). (A) Topmost LVL, (B) second layer (sub-weathered).
Discussion
Lateral variability in the geophysical properties of the layers below the ground surface is
apparently contradictory to the Steno’s principles (1669) regarding original lateral continuity
and original horizontality and the superposition principle whereby older layers are
superposed by the younger layers. However, the fact of the matter is, in the ideal source-sink
relationship, say particularly in the deep marine environment (excluding of course the sea
floor spreading zones), these principles are very much valid and for falling sea level and
regressive conditions, when these marine depositional successions (without the intervention
of any structural modifiers) become part of the continents, the outcrop study is bound to
endorse Steno’s principles. Thus Steno’s observations are valid for most of the continental
stratigraphy which are genetically related directly to the marine depositional environments.
Table 1
A schematic description of tri-parametric micro zonation model
However, in the high elevation continental basins with huge mass transfer of sediments, the
landscape is mostly constituted of older floodplains incised by channels having different
stream power. Recently deposited sediments within the channels and floodplains are usually
poorly consolidated and are having lesser seismic velocities compared to the older flood
plains. But there are situations where tectonic controls are forcing the older rocks from deep
inside to rise up and subsequently become a member of the shallow subsurface family, say a
‘high’ having more compact sedimentary rock units and obviously this part of the shallow
subsurface will show much higher velocities and we will get a drastic lateral variation
change. Then, there can be regional ‘lows’ having much thicker low velocity depositions.
Thus, we are bound to get (i) different types of lateral discontinuity, (ii) lack of horizontality
of recently deposited strata and, (iii) a number of complex associations of older strata with
the younger ones. This apparent deviation from Steno’s principles has tremendous influence
on surface landform evolution for the present study window.
Fig.5. Tri-parametric micro-zonation based on the velocity discrimination of the top two layers and the
thickness variation of the top LVL. (A) V2-high, V1-high, H1-thick, (B) V2-high, V1-high, H1-thin,
(C) Both the situations described in (A)-(B) juxtaposed with the locations of the oil fields and the blind
faults. Most of the discovered oil fields seem to be situated on the V2-high, V1-high belt.
The microzonation of the study window shows very clearly a closer affinity of the Type-I and
Type-II zones with the oil fields of the area (Fig. 5). In contrast, Type-VII and Type-VIII
areas in general do not have that kind of affinity (Fig. 6). The observation suggests further
that in the Namrup-Sapekhati window, oil fields have strong structural control.
Moreover, the microzonation shows it clearly that in the foredeep areas of the frontal thrust
belts, thicker LVL does not indicate necessarily the sites of recent aggradation. Similarly, the
sites of thinner LVL do not stand for degradation. Sites of aggradation-degradation are to be
identified principally on the basis of the velocity combinations (as shown in Table 1).
Fig.6. Tri-parametric micro-zonation based on the velocity discrimination of the top two layers
and the thickness variation of the top LVL. (A) V2-low, V1-low, H1-thick, (B) V2-low, V1-
low, H1-thin, (C) Both the situations described in (A)-(B) juxtaposed with the locations of the
oil fields and the blind faults. The oil fields seem to avoid the low velocity zones.
Conclusion
Mapping lateral inhomogeneities of the LVL in the foredeep areas and ‘multiparametric
microzonation’ can provide useful information about late Quaternary sites of aggradation-
degradation and a means for comparing the same with the present day preferential sites.
Subsequently, the nature of changes can be modelled in terms of the structural controls
determining the probable sites of oil entrapment. The findings of known windows like
Namrup-Sapekhati can be applied to the new areas where the reliability of seismic data is
questionable.
Acknowledgement
The author is highly thankful to OIL, Duliajan for sharing the shallow subsurface geophysical
data for research purpose. The cooperation and encouragement extended by Dr. Rahul
Dasgupta, President SPG Duliajan Chapter, in promoting industry-academia relationship is
highly commendable.
References
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