This document identifies 16 potential oil and gas leads located in blocks 31-36 in the Norwegian North Sea. The leads are located at various stratigraphic levels from the Triassic to the Upper Cretaceous. No accurate location data is provided. The document discusses the petroleum system of the area, including four potential source rocks and different prospect types like faulted blocks and sand bodies. Critical elements to evaluate the leads include the geometry of potential reservoir sands and migration of hydrocarbons from source rocks into traps.

1. Play
models
in
Quadrants
31-­‐36
in
Norwegian
North
Sea
This
presenta,on
is
made
to
give
some
few
examples
of
tested
and
untested
play
models
in
the
North
Sea.
No
accurate
loca,on
is
given
in
both
stra,graphic
nor
XY
coordinates.
Valioso
Ltd
and
its
authors
is
not
to
be
held
responsible
for
any
inaccuracies
and
errors
in
material
presented
herein,
and
therefore
not
responsible
for
any
ac,ons
by
any
party
based
on
these
ideas
presented
in
this
presenta,on.
8
7
6
5
4
3
2
1
9

2. Valioso
(UK)
Ltd
has
iden,fied
9
lead
opportuni,es.
These
opportuni,es
are
outlined
in
map
on
previous
slide.
Lead
1
is
iden,fied
within
Blocks
31/3
and
32/1
and
is
iden,fied
as
a
large
,lted
fault
block
at
Upper
Jurassic
and
Middle/Lower
Jurassic
levels.
This
lead
could
contain
a
Upper
Jurassic/Lower
Cretaceous
stra,graphic
lead
associated
with
it.
• Lead
2
is
iden,fied
within
Block
36/10,
as
a
Middle/
Lower
Jurassic
,lted
Fault
Block.
• Lead
3
is
iden,fied
within
Block
36/7
as
Upper
Jurassic
and
Lower
Cretaceous
lead.
• Lead
4
is
iden,fied
within
Block
36/7
same
type
as
Lead
3.
• Lead
5
is
iden,fied
within
Blocks
35/8
and
35/9,
mainly
in
laXer
Block.
This
is
a
Lower
Cretaceous
Lead
• Lead
6
is
iden,fied
as
Jurassic
lead
within
Block
35/8
• Lead
7
is
iden,fied
as
Jurassic
lead
within
Block
35/9
• Lead
8
is
a
Jurassic
lead
iden,fied
within
Blocks
35/8
and
35/5,
mainly
the
first
block.
• Lead
9
in
Blocks
36/4
and
36/7
is
assumed
to
be
Ap,an
Sand
wedge
stra,graphic
trap.
Associated
with
this
lead
is
several
other
leads
found
in
same
geographic
area,
although
various
levels
from
Jurassic
and
upwards,
even
poten,al
Basement
traps.
GIIP
approximately
25
x
109
Sm3.
• Lead
10
is
a
Upper
Jurassic
and
Lower
Cretaceous
lead,
which
has
a
fair
to
medium
size,
main
risk
is
trap
integrity
as
Base
Seal
can
be
destroyed
in
these
leads.
Its
believed
to
be
gas
prone.
• Lead
11
is
a
Upper
Jurassic/Lower
Cretaceous
lead,
with
small
to
fair
size,
main
risk
is
source.
The
lead
is
supposed
to
be
gas
prone.
• Lead
12
as
lead
11.
• Lead
13
is
a
Upper
Cretaceous
lead,
with
same
characteris,cs
as
lead
10.
• Lead
14
and
15
are
Triassic
to
Lower/Middle
Jurassic
leads,
with
a
poten,al
for
Upper
Jurassic
in
Lead
15.
Main
risk
is
trap
integrity
due
to
fault
dependency
to
make
medium
to
large
volumes,
otherwise
the
risk
is
moderate
to
small
volumes.
Reservoir
characteris,cs
are
also
a
maXer
of
concern.
• Lead
16
is
a
Triassic
together
with
poten,al
other
levels
in
same
area.
Main
risk
is
reservoir
together
with
trap
integrity.

3. 10
11
12
13
14
15
16

4. Several
par,es
have
studied
the
petroleum
system
of
the
Tampen
Spur
–
Sogn
Graben
area.
The
approaches
used
are
1D
and
2D
analysis
of
seismic
in
the
area
where
various
hypotheses
could
be
tested
and
later
applied
in
a
3D.
The
area
ranges
from
the
deepest
part
of
the
`Tampen
Graben'
across
the
Visund
Ridge
and
the
Marflø
Ridge
to
the
Sogn
Graben
in
the
east.
Four
source
rocks
have
been
taken
into
account,
two
marine
the
Draupne
Forma,on
(the
most
prolific)
and
the
Heather
Forma,on
and
two
deltaic,
the
Brent
and
the
Dunlin
Forma,ons.
Several
different
prospect
types
can
be
defined:
the
Brent
at
the
top
of
the
,lted
blocks
and
several
genera,ons
of
Heather
Forma,on
sand
bodies
at
the
foot
of
the
eroded
,lted
blocks.
In
addi,on
there
are
Lower
and
Upper
Cretaceous
transgressive
and
lowstand
playmodels
to
be
explored.
Cri,cal
elements
are
the
geometry
of
sand
bodies
and
migra,on
of
hydrocarbons
from
the
rich
Draupne
Forma,on
source
rocks
into
the
sands
in
the
various
trap
types.
Matura,on
is
believed
to
have
started
in
the
middle
Cretaceous,
between
100
Ma
in
the
deepest
eastern
part
of
the
sec,on
(Sogn
Graben)
and
80
Ma
for
the
Draupne
Forma,on
on
the
Tampen
Spur
west
graben.
At
this
,me,
the
Cretaceous
shales
already
sealed
the
structures.
Apart
from
the
Visund
Ridge
and
flankal
areas
of
Sogn
Graben,
all
the
prospects
at
Upper
Jurassic
or
deeper
are
currently
in
the
condensate
or
gas
window.
Overpressures
are
compa,ble
with
large
closed
fault
systems.
Possible
sealing
of
minor
faults
before
migra,on
could
be
cri,cal
in
this
region.
There
is
no
easy
migra,on
path
from
the
rich
Draupne
Forma,on
rocks
to
the
reservoirs
and
various
hypotheses
are
found
to
explain
the
regional
petroleum
poten,al.
One
possible
explana,on
for
the
regional
charge
is
the
contribu,on
of
the
other
source
rocks,
the
Heather,
the
Brent
and
the
Dunlin.
Upper
Jurassic
The
Upper
Jurassic
consists
mainly
of
marine
shales
with
coarser
clas,c
sequences
developed
locally.
The
contact
between
Draupne
and
Heather
shales
are
ojen
abrupt.
The
Draupne
Forma,on
is
organic
rich
and
highly
radioac,ve.
The
Viking
Group,
consis,ng
of
both
Heather
and
Draupne
Forma,ons,
has
become
more
complex
due
to
discoveries
of
different
sand
forma,ons
within
the
group.
The
coastal
to
shallow
marine
sandstone
units
named
Sognekord,
Fenskord
and
Krosskord
Forma,on
sands
are
the
most
common
reservoir
units
with
Upper
Jurassic
sequence
Lower
Cretaceous
In
this
interval
at
least
two
separate
sandstone
units
can
be
detected
both
in
wells
and
seismic.
The
Åsgard
and
Agat
Sandstones.
The
Åsgard
sand
Unit
is
intrpreted
as
a
highstand
systems
tract
unit;
as
for
the
Agat
sand
Units,
which
are
stacked,
sandy
units
are
intrepeted
as
lowstand
systems
tract
units.
In
NPD
nomenclature
the
sandstone
units
are
named
Ran
sandstones
for
the
Viking
Graben
system.
Upper
Cretaceous
Kyrre
sandstones
(99),
has
been
penetrated
in
quad
35
by
wells,
and
exhibits
good
reservoir
quali,es
and
found
hydrocarbon
bearing.
This
sandstone
unit,
could
consist
of
several
sub-­‐units,
and
its
distribu,on
together
with
reservoir
quality
is
per,ent
to
know,
in
order
to
understand
its
play
feasibility.

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further
details
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can
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