Schedule - the Kansas Geological Survey

AAPG Southwest Section Short
Course - Watney
Integrated Approaches to Modeling Late Paleozoic
Petroleum Reservoirs in the Greater Midcontinent,
Midcontinent, U.S.
Part 4 – Lithofacies, Petrophysics, and
Petrofacies
Short Course
AAPG - Southwest Section
December 8, 2008 -- Abilene, Texas
December 9, 2008 -- Ft. Worth, Texas
W. Lynn Watney
Senior Scientific Fellow
Kansas Geological Survey
1930 Constant Avenue
Lawrence, KS 66047
Ph: 785-864-2184
Fax: 785-864-5317
Email: [email protected]
Schedule
9:009:00-10:00 – 1. Approach to Modeling Late Paleozoic Petroleum Reservoirs.
10-12 noon – 2. Regional structural and tectonic framework during the late Paleozoic
and significance to reservoir systems.
–
~10:30~10:30-10:45 -- Break –
NoonNoon-1:00 pm – Lunch
1:00-3:00 pm -- 3. Sequence stratigraphy and reservoir architecture of late Paleozoic
strata in the Midcontinent.
–
~3:00~3:00-3:15 – Break –
3:003:00-4:30 pm -- 4. Reservoir Lithofacies and Petrofacies.
4:304:30-5:00 pm – 5. WrapWrap-up & Summary.
Summary.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
1
AAPG Southwest Section Short
Course - Watney
Take Home Points of Short Course
Basement structures and distal tectonic events affecting them are
are
important in defining location and properties of reservoirs.
ProcessProcess-based field, outcrop, and Recent analogs provide more
appropriate, accurate interpolation of reservoir properties.
Late Paleozoic reservoirs are dominated by depositional fabric
selective diagenesis, both early and late both.
Establishing petrofacies and pore types is essential to accurate
calculations of water saturations, volumetrics, ROIP, establishing
establishing
permeability correlations and predicting fluid flow.
Infill locations and new pays within oil and gas fields remain
significant targets for IOR in mature regions; requires
comprehensive, integrated approach.
ReRe-exploration and exploitation of mature producing areas can be
substantially benefited by access to and mining of large data sets
sets –
digital and electronic data – logs, production, core/samples and
descriptions, in an integrated and quantitative manner.
4. Reservoir Lithofacies and
Petrofacies
Modern ooid shoals – geometries, textures, processes
Example – role of establishing temporal geometries and
importance of texture in permeability and flow unit
designation.
– Hall Gurney CO2 pilot, Central Kansas Uplift, Kansas
(Upper Missourian Plattsburg Limestone)
Petrophysics Overview
– Solving the Archie equation for Sw and establishing the
cementation exponent, m
– Significance of bulk volume water, (BVW = Sw*Ø
Sw*Ø) and pore type
– Examples –
Marmaton Altamont Limestone – volumetrics of an oomoldic reservoir
using varying “m”, the cementation exponent
Waddell Field – San Andres oomoldic and karsted reservoir,
significance of structure and diagenesis
Norcan East Field -- Calibrating pay in a shaly estuarine valleyvalley-fill
sandstone (Atokan, western Ks)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
2
AAPG Southwest Section Short
Course - Watney
Slides on Modern ooid shoals from
the Bahamas provided by
Eugene C. Rankey
University of Kansas
Oolitic Carbonate
Shoals
Conceptual Facies Models
Is this the best we can do?
• Qualitative
• Not predictive
After Handford, 1988
E.C. Rankey, KU
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
3
AAPG Southwest Section Short
Course - Watney
Dunham Carbonate Classification
Moore (1988)
Goals
Examine geomorphology of marine (oolitic)
sand bodies
Explore grain sizes and types within a
hydro-geomorphic framework
Explain patterns in terms of fundamental
processes
Courtesy of Gene Rankey
Department of Geology
The University of Kansas
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
4
AAPG Southwest Section Short
Course - Watney
Marine Sand Belt - Character
Large-scale sand body parallel shelf margin
Parabolic bars superimposed; flood/ebb
Individual sand waves, varied orientation
Cross-laminated – troughs, perhaps wave
rippled
Increase in energy upwards
Lily Bank Marine Sand Belt
Atlantic Ocean
Reef
Reef
Reef
Downdip inactive
Active shoal
Lagoon
10 km
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Little Bahama Bank
5
AAPG Southwest Section Short
Course - Watney
Ramp Fluid Flow
• Lower velocity in troughs
Flow direction
Flood tide
Image Copyright SpaceImaging.com
Ramp Sediments
500 m
1mm
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
6
AAPG Southwest Section Short
Course - Watney
Image Copyright SpaceImaging.com
Ramp Sediments
Relative to troughs,
crests:
more sorted
coarser
– Are coarser
– Are better sorted
Carbonate Tidal Deltas
Mostly from Stacy Reeder PhD
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
7
AAPG Southwest Section Short
Course - Watney
Tidal Deltas - Character
Lobate forms; most commonly flood deltas
Commonly (not always) associated with
bedrock islands
– clasts/rocky bottom
– ‘Fixed’ location
Even if flood-oriented, shaped by both flood
and ebb tides
Not commonly interpreted in geologic record
EbbDominated
Tidal Delta on
Little Bahama
Bank
• Ebb flow over shoal
• Decreasing current
velocity with distance
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
8
AAPG Southwest Section Short
Course - Watney
Tidal Sand Ridges
LBB
100 km
Great Bahama Bank
Miami
Focus area
GBB
Exuma Sound
GBB
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
9
AAPG Southwest Section Short
Course - Watney
Exuma Sound
we
st
Shallow Platform
Channel
1000 μm
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
10
AAPG Southwest Section Short
Course - Watney
Bar Crest
1000 μm
Conclusions from Modern
Feedbacks between bathymetry and
hydrodynamics lead to predictable
geomorphic trends
Ooid sorting improves along crest of
shoals
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
11
AAPG Southwest Section Short
Course - Watney
-Pleistocene ooid shoal
- western side of Bahamian
platform south of Bimini
Ocean Cay
Future LNG Terminal
Dominant Lithofacies of
Pleistocene Oolite
Massive (A) to finely-interbedded (B), fine- to coarse-grained crossbedded oolitic and oolitic/skeletal/peloidal grainstones ranging in
thickness from 0.5-5 m overlying a mottled, bioturbated (C) , vuggy
(D) oolitic/skeletal/peloidal grain- to packstone
Byrnes, Cruse, Eberli, Watney (2006)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
12
AAPG Southwest Section Short
Course - Watney
Permeability vs Porosity
-- indicative of a link between pore development
in the Ancient and Pleistocene oolitic grainstones
-- linked by process, both deposition and early diagenesis
10000
Permeability (md)
1000
100
10
1
Ocean Cay
KS Oomoldic LKC
0.1
0.01
0.001
10
Texture/pore
type &
Permeability vs
Porosity
k=491 md, =37.1%, m=2.56
=39.7%, m=3.08
10,000
Air Permeability (md)
k=191 md,
100
Porosity (%)
Byrnes et al.
(2006)
k=6393 md, =46.4%, m=2.52
1,000
B-300
B-320
B-321
B-322
B-324
B-325
B-326
100
k=4050 md, =43.2%, m=2.62
10
26 28 30 32 34 36 38 40 42 44 46 48
Porosity (%)
k=24 md, =29.7%, m=2.98
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Byrnes et al. (2006)
k=1078 md, =41.7%, m=3.04
13
AAPG Southwest Section Short
Course - Watney
LKC Permeability vs Porosity
In situ Permeability (md)
Insitu Permeability
(md)
10
Cox
Permeability
Bounds vs. Porosity
1000
1
100
0.1
10
0.01
0.001
0
2
16
8 10
0.1
0.001
20 22 24 26 28 30 32 34
0
1
2
3
4
Mold Connectivity Index
Permeability vs. Matrix Archie Porosity
In situ Permeability (md)
100
0.001
0.1
0.0001
0.01
10
1
0.1
0.01
01
0
1
Routine Porosity (%)
1
0.001
10
0.01
0.01
10
Permeability vs. Mold Connectivity
100
Permeability vs. Mold Packing
0.1
100
In situ Permeability (md)
4
Drew s
Dorr
Witt
Oberle
A17W
Boxberger
Leurman
Trembly
Vopat
Gordon
EE Tobias
Hafferman
Michaelis
Soeken
Sellens 2
Sellens 1
Oeser
Princ
Tieperman
Colliver 1
C-C CO2I C
C-C CO2IG
C-C CO2IC WC
Colliver #16
Austin 2-27
OceanCay
28 18
12 S14i 16
In situ Permeability (md)
10000
100
52
103
Mold Packing Index
15 4
0.001
20
25
30
35
40
Porosity (%)Matrix Archie Porosity Index
0
1
2
3
45
4
log10ki = 0.154 – 3.21 (SE=6X)
log10ki = 0.090  + 0.47 MCI – 3.2 (SE=5.5X)
Permeability and
Pore Diameter
Principal Pore Throat Diameter ( m)
100
10
1
Ocean Cay
Ls oomoldic
Ls moldic
Ls interparticle
0.1
Ss lithic
Ls chalk
Ss arkosic
Ss quartzose
0.01
0.00001
0.0001
0.001
0.01
0.1
1
10
100
1000
10000
Insitu Klinkenberg Permeability (md)
Pleistocene cores (light blue) exhibit correlation of permeability and
principal pore throat diameter consistent with trend of other lithologies.
Byrnes et al. (2006)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
14
AAPG Southwest Section Short
Course - Watney
Application of Modern and
Pleistocene to the Pennsylvanian
– Lobate and linear oolitic shoals form complex
geometries
– Granulometric attributes of Modern and Ancient ooid
shoals are comparable
– Oomoldic porosity is extensive in Pleistocene and
older rocks (for
(for aragoniticaragonitic-rich ooid)
ooid)
– Size, sorting, packing of Pennsylvanian and
Pleistocene oomolds are closely related
– Oomoldic pores are closely related to depositional
fabric and near surface subaerial diagenesis,
modified by later burial diagenesis
Pennsylvanian, Bethany Falls Ls.
unstained
Pleistocene, Ocean Cay
w/ alz-r stain
Lansing-Kansas City Production
and CO2 Project Location
Marmaton
200 MMBO (3%)
Morrow
200 MMBO (3%)
All Others
500 MMBO (8%)
1915-2005
Arbuckle
Cherokee
2,300 MMBO (37%)
200 MMBO (3%)
Simpson
250 MMBO (4%)
Viola
370 MMBO (6%)
Mississippian
1,000 MMBO (16%)
LansingKansas City
1,250 MMBO (20%)
Hall-Gurney
Field
CO2 Pilot
Study Area
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
5 Miles
15
AAPG Southwest Section Short
Course - Watney
Total Magnetic Field Intensity
Reduced to Pole
Russell County, Kansas
LKC reservoirs lying on Arbuckle
granite high on the
Central Kansas Uplift
CO2
Project
20
St
ru
ctu
ra
l li
feet
Gross Pay Plattsburg Limestone
ne
am
en
ts
0
C.I. = 1 ft.
1 mi.
-1148
feet
Structure Top Plattsburg Limestone
CO2 Project
-1204
C.I. = 2 ft.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
CO2 Project
16
AAPG Southwest Section Short
Course - Watney
Rhomaa-umma lithology solution
Shawnee
Group
Oread
Douglas
Group
Cass
Stanton
Muncie Creek
Muncie Creek
depositional
sequence set
Heebner sequence set
Hall-Gurney Field
Plattsburg
Farley/
Argentine
Iola
Nuyaka Creek
Sequence set
Dewey
Cherryvale
Dennis
Gorham Sandstone
Precambrian
/Precambrian granite
Ooid
shoal
Lansing &
Kansas City
Groups
Swope
Sniabar
Base Pennsylvanian transgression
~Lost Branch/Nuyaka Creek Shale
(regional 3rd order boundary)
Willhite (2008)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
17
AAPG Southwest Section Short
Course - Watney
Willhite (2008)
Average Ø in oomoldic carbonate reservoir
Plattsburg Limestone
#1
CO2 I #1
Colliver #16
(core)
Increased oil
production off
flood pattern
attributed to
CO2 flood
from 2005 to
present
#18
0.25 mi (0.4 km)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Outline of CO2 plume
from 4D seismic
during first 2 years of
injection (2004-2005)
18
AAPG Southwest Section Short
Course - Watney
Layer 2 - 2894.2 =34.1% K =113.9md
1 mm
• 6 layer reservoir model,
oomoldic limestone
Murfin CO2I#1
Layer 3 2897’ = 27.7% K= 32.4md
1 mm
Layer 4 2899’ = 22.9% K= 5.6md
1 mm
Layer 5 2902’ = 20.7% K= 1.4 md
1 mm
Dubois et al. (2003)
Colliver #16 core: Bedsets, grain size range
Bed #
2
3
4
5
6
7
2882
vc
Bedset #2:
3-fining up, well sorted
1-coarsening up, well sorted
1-fining up, less well sorted
2884
photo
2886
2
2888
2890
c-m f-vf
mud
Thin bedsets
Better
sorted
strata
on top of
bedsets
Bedset #3:
Top-coarse, well sorted
Lower-poorly sorted
w/bioclasts
3
2892
2894
Bedset #4:
Cap- well sorted
Lower-Poorly sorted
4
2896
5
2898
Thin bedded,
bioclasts in lower
bedset #2
Bedset #5:
Top– 3 cm thick
beds w/bioclast caps
Lower-micritic clasts,
bioclasts, superficial
oolite
Bedset #2
Bedset #3
2900
2902
2904
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Small-scale
beds noted
as breaks
Bedset #6:
Poorly sorted, open
marine bioclastic
packstone to wackest.
Largest to smallest
grain size
Thicker beds,
well-sorted upper
portion of bedset #3
1cm
19
AAPG Southwest Section Short
Course - Watney
Colliver #16 core: Upward increasing in oomoldic content
Bed #
2
3
4
% Moldic
Dip Angle
5
6
7
0
10
20
30 0
10
20
30
2882
vc
c-m f-vf
mud
2884
Better sorted
2
2886
Depth (ft)
2888
3
2890
2892
4
2894
2896
5
2898
2900
2902
Bed #
Dip Angle
Largest-smallest
grain size
% Moldic
2904
Thin, fining upward bedsets comprise overall
coarsening upward ooid shoals (tidal ridges) in the
SE Kansas near-surface and at Hall-Gurney oil field
(wind modified tidal ridges or parabolic bars)
0.1 ft
Bethany Falls Ls.
0.1 ft
Bed thickness (ft)
2 inches
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Grain size (um)
400
800
1200
20
AAPG Southwest Section Short
Course - Watney
• Depth profile of the “C” zone showing gamma ray, maximum
permeability, and Archie cementation exponent, m, compared to various
measures of porosity.
• Note that cementation exponent, m, increases upward from around 2 to
near 3.5. Higher m indicates more tortuous paths for fluid to move as m
increases.
• Higher m in Archie water saturation equation raises Sw
1000
Clean (lower gamma ray),
better-sorted oolite/
oomoldic
K max (md)
100
10
1
0.1
0.01
0
10
20
30
40
50
60
Gamma Ray (API)
35
30
Porosity
25
20
15
10
• Higher permeability,
>10 md
• Correlation with:
better sorting, packing,
and interconnected
oomolds
(microvugs & associated
high Archie cementation
exponent)
• Clean, better sorted
higher porosity in
cycle caps,
porosity highest near
top of shallowing
upward succession
• Better sorted bar crests
in Modern ooid shoals
5
0
0
10
20
30
40
50
60
Colliver #16 core data
Gamma Ray (API)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
21
AAPG Southwest Section Short
Course - Watney
Refined interpretation of seismic similarity & curvature attribute maps
oa
l#
3`
l#
oa
h
S
1`
Sh
oa
l#
2`
Sh
Seismic facies similarity map and
outlines of better quality reservoir
facies “shoals”
• Closely relate to shoal lobes define by
wireline logs
Seismic maximum curvature
attribute map indicating
structural lineaments
• Set of NW & NE trending
fractures (inherited from
fractured basement?)
• Black wavy lines outline
“shoals” defined by seismic
attribute
Area of enhanced oil recovery
Raef et al. (2007)
Left: Average porosity for Layer #2 of the original six-layer
geologic model.
Right: The six-layer geologic model illustrates average porosity
of each layer as used in the original reservoir simulation
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
22
AAPG Southwest Section Short
Course - Watney
Thickness of low GR
Layer #2 (upper Plattsburg)
• low gamma ray map
• 3 separate shoals – defined by seismic and sample & log analysis
• CO2 off pattern migration (after 4D seismic imaging stopped)& incremental oil
appears to follow shoal boundaries/ structural “grain”
Sec 27
?
?
Sh
oa
l#
2
Sh
oa
l#
3
Sec 28
Sh
oa
l#
1
CO2 #1
Sec 33
incremental oil increase
attributed to CO2
Sec 34
Structure Contour Map, Top Plattsburg Limestone
Sec 28
Sec 27
CO2 #1
Sh
oa
l#
1
Sh
oa
l#
3
?
Sh
oa
l#
2
?
Area illustrated in
cross sections
Sec 33
Sec 34
incremental oil increase
attributed to CO2
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
23
AAPG Southwest Section Short
Course - Watney
NW
SE
Colliver #4
GR
Colliver #10
Colliver #7
Colliver #CO2-1
Colliver #16
Shoal #2
Shoal #2
No clean
capping beds,
Shaly
Shoal #3
Shoal #1
Thick low GR cap
=~ better sorted?
20 ft
-1153
Colliver #9
Ø
Shoal #1 older
than shoal #2
Datum: base of Spring Hill Ls.
Structural profile at top Plattsburg Ls.
-1167
Ooid shoal unit
Low GR, high k?
Seismic defined
lineament
Seismic defined
lineament
NW
• Colliver #4 – (cuttings) dominant fine gr. tight ooid
grainstone – elevated GR
SE
• Colliver #7 – (cuttings) bioclastic pkst-grnst. with
some interparticle Ø, forams, crinoids, encrusters;
40% ooid – thin clean GR
• Colliver #CO2-1 and Colliver #16 (upper) – (cored)
oomoldic grainstone, clean porous (shoal #2); Shoal
#1 in well #16; finer grained and less porous, lower
permeability -- #2 lowest GR, youngest shoal
North
edge of shoals
-- #2a against #2
Giese 7
GR
Colliver #2
C. Colliver #CO2-1
Thickness of
low GR interval
1000 ft (300 m)
C. Colliver #18
Colliver #13
T.B Carter #2
T.B Carter #10
Ø
#2a
Higher GR
#2
#1
Lateral migration of shoal?
20 ft
-1130
South
edge of shoals
-- #2 (youngest) overstepping #1
Lower base of shoal #1
on thinner subtidal
Datum: base of Spring Hill Ls. Member
Structural profile at top Plattsburg Ls.
-1150
structurally higher
-1160
Ooid shoal unit
Low GR, higher Ø
N
Up stratigraphic section
- Lateral migration from north?, moving stratigraphically updip to
south?
- Northern-most edge of shoal #2 (at Colliver #2) is overall low GR
and capped by clean Ø.
- Geise #7 has higher GR CO3, located structurally downdip,
possibly lower energy; thus labeled 2a
- Shoal unit #1 on current structural high position; thinner subtidal,
early onset of shoal #1 suggest paleohigh corresponding closely
with current structure
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Sec. 28
S
Sec. 33
24
AAPG Southwest Section Short
Course - Watney
Missourian ooid shoals on
Kansas shelf
• Similar tidal-dominated ridges and
parabolic forms (convex/concave) to
Modern
Modern Analogs Can Help
Exuma Sound
Great Bahama Bank
• In general terms, best sorted sediments
occur at the bar crests
• Grain size may vary - coarsest may be in
troughs or on crests
• Macrotidal sedimentary structures and
bed geometries are clearly important.
Comparison of core analysis from CO2 #1 and #16: Consistent upward increase
in Archie Cementation Exponent, m, which is closely related to increasing porosity.
Archie Cementation Exponent
3.8
1.8 2.0 2.2 2.4 2.6 2.8 3.0 3.2 3.4 3.6 3.8
2890
Archie Cementation Exponent
2892
2894
CO2I#1
CO2#16
2896
Depth (ft)
y = 0.053x + 1.84
2
R = 0.93
3.6
2898
2900
2902
2904
2906
2908
2910
3.4
3.2
3.0
2.8
2.6
2.4
More complex pore type
In uppermost interval
of CO2 #1
2.2
2.0
CO2I#1 2891-2892.4 ft
CO2I#1 2893-2900 ft
CO2I#1 2900.5-2907 ft
CO2#16 2882.2-2892.4 ft
CO2#16 2893-2895.5 ft
CO2#16 2895.5-2897.5 ft
CO2#16 2897.5-2898.7 ft
1.8
am
Sw=( *RR )
w
t
1/n
1.6
0
5
10
15
20
25
30
35
Porosity (%)
Byrnes et al. (2007)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
25
AAPG Southwest Section Short
Course - Watney
Archie
Cementation
Exponent, m
Archie Cementation Exponent (m)
1.5
2.0
2.5
3.0
3.5
4.0
4.5
5.0
0
m≠2
1.8 < m < 5
2
4
Depth (ft)
6
Shoal 1
m varies with depth
mirroring k
Shoal 2
8
• Note CO2#16 stacked
shoals – m pattern starts
from top of each shoal
• Similar pattern for
Woodward #2 Mound
Valley & Bethany Falls
(near-surface analog in
SE Kansas)
10
12
Austin 2-27
CO2I#1
CO2I#16
Woodward #2 BF
Woodward #2 MV
14
am
Sw=( *RR )
16
1/n
w
t
Byrnes et al. (2007)
LKC Pc-Sw is sensitive to height & permeability
krow is sensitive to permeability & Soi
40
5
4
Longer transition
& higher residual
Sw at lower k
30
3
20
2
10
1
0
0
0.0
0.2
0.4
0.6
0.8
Water Saturation (fraction)
1.0
Relative Permeability
0.3 md
1 md
3 md
10 md
30 md
100 md
300 md
50
1
6
Oil-Water Capillary Pressure (psia)
Height Above Free Water (ft)
Lansing-Kansas City
Lansing-Kansas City
60
Kro
0.1
1md
10 md
100 md
300 md
Krw
Rapid decline in
Kro at lower k
0.01
0.001
0.0
0.2
0.4
0.6
0.8
1.0
Water Saturation (fraction)
(after Byrnes & Bhattacharya, 2006; SPE 99736)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
26
AAPG Southwest Section Short
Course - Watney
m = f(,Apore)
m = f(,k)
m = (-0.019
log10k +
0.085) + 1.5
Model for
estimating m in
oomoldic
petrofacies
knowing k and
phi
Archie
Archie Cementation
CementationExponent
Exponent(m)
(m)
m vs 
5.0
4.6
4.6
4.4
4.4
4.5
4.2
4.2
4.0
4.0
4.0
3.8
3.8
High Ø, lower k
= fewer touching
vugs
3.6
3.6
3.5
3.4
3.4
3.2
3.2
3.0
3.0
3.0
2.8
2.8
2.5
2.6
2.6
2.4
2.4
2.2
2.0
2.2
2.0
2.0
1.8
1.5
1.6
1.8
0
1.6
1.0
0
0
5
55
10
15
Woodward
0.001-0.01
md #2 Mound
Woodward
#2 Bethany
0.01-0.1
md
CO2I#1 'C'
0.1-1 md
0.001-0.01 md
CO2I#1 'G'
1-10 md
0.01-0.1 md
CO2#16
10-100Austin
md #2-27 0.1-1 md
100-1000 md
1-10
md= Ocean
OC
OC 100-1000 md 10-100
md
OC 1,000-3,000 md 100-1000
Pleistocene
md
OC 3,000-10,000
20
25 md 30
35
Porosity
(%)
15
20
10 10 15
20
25
3025 35 3040
Cay
35
45
Porosity
Porosity (%)
(%)
Byrnes et al. (2007)
Take home points for
Hall-Gurney CO2 project
Revised geologic model for “C” zone to
incorporate
– Remap effective flow units by delineation of low
gamma ray, high porosity intervals
– Incorporate directional permeability in northwesterly
trend in shoal #3 overlying structural saddle/flexure to
incorporate preferred direction for open fractures
– Open fractures in NWNW-trend consistent with seismic
coherency analysis compared to production in nearby
field
CO2 IOR in West Texas/New Mexico San
Andres indicates that fracture networks are also
very important and vuggy porosity can be very
discontinuous
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
27
AAPG Southwest Section Short
Course - Watney
Petrophysics Overview
Solving for
water saturation ...
the Archie equation
a m Rw
=
Sw  * R t
(
1/n
)
John Doveton
Kansas Geological Survey
1930 Constant Avenue
Lawrence, KS 66047
Phone: 785-864-2100
Email: [email protected]
m in sandstones
Archie (1942) observed the range in value
of m in sandstones:
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
1.3
unconsolidated sandstones
1.4 - 1.5
very slightly cemented
1.6 - 1.7
slightly cemented
1.8 - 1.9
moderately cemented
2.0 - 2.2
highly cemented
28
AAPG Southwest Section Short
Course - Watney
m in carbonates
Interparticle: intergranular and
intercrystalline porosity
m=2
Fracture porosity
m<2
Vug: moldic porosity or vugs that are
larger than the grains
m>2<5
Prediction of fluid
PRODUCTION from
BVW
= Sw x Ø
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
29
AAPG Southwest Section Short
Course - Watney
Reservoir and Transition zones
100
Free oil
Connate Sw
80
Transition
zone (oil &
water)
60
Free water level
100%
40
0
Porosity
20
0
4
8
12
16
Porosity
20
24
Transition
zone
28
Water
zone
Saturation - porosity relationship of Leduc-Woodbend
D-2 “A” Pool (Buckles, 1965)
Zone at Swi
0
Sw
0
100%
Swi = irreducible water saturation
Bhattacharya et al. (1997)
Cumulative frequency plots
of c, Buckles Number (BVWi)
0
nes
IX IG
s an
dst
o
50%
Irreducible bulk
volume water =
BVWi,
water free
production
= constant for
specific pore
type
es
Vug
car
bon
at
Cumulative percentage of occurrence
100%
0
0.02
0.04
0.06
0.08
0.10
"Irreducible" bulk volume water, c
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
30
AAPG Southwest Section Short
Course - Watney
Texas carbonate reservoir data
by formation
The Pickett Plot
Doveton
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
31
AAPG Southwest Section Short
Course - Watney
Using Super Pickett plot to highlight pay “cut-offs”
5428
Depth
5438
Use Gamma
cut-offs to
define gross
sandstone
5443
5448
Transition
zone
Pay
5458
Sw cut off defines gross pay
(zone with economic hydrocarbon
saturation)
Porosity cut off defines
net sandstone
5463
Critical BVW (BVWi) cut off
Sw = 50
K = 1000 md
Sw = 100
POROSITY
Transition
zone
Pay
Sw = 10
1.0
Water
zone
Porosity
Water Saturation
Water Saturation
5453
Transition
zone
Pay
BVW = 0.045
Porosity
Gamma Log
5433
Water
zone
Water
zone
100
Porosity
50
Sw cut off
Porosity cut off
Vshale cut-off
0
Water Saturation
Pay zone survives the
“cut-offs”
K = 100 md
K = 10 md
0.1
K = 1 md
BVWi cut off defines the net pay
that should yield water free
production
4100 - 07
4107 - 14
4114 - 21
RESISTIVITY Ohm-m
4121 - 28
4128 - 36
0.01
1
100
10
RESISTIVITY Ohm-m
Bhattacharya et al. (1997)
Super Picketts of Example Well Logs
Gamma Log
Morrow Sst.
6041 - 72
a=1
m = 1.85
n=2
Rw = 0.04
POROSITY
Sw = 50
Sw = 60
Sw = 80
Sw = 100
0.1
K = 10 md
K = 1 md
K = 0.1 md
6041 - 48
6048 - 54
Lower part has higher phi &
reduced Rt - reflects trend
towards finer pores or transition
zone
20
6041
100
6051
6058
6061
BVW = 0.37 (zone at Swi)
Low porosity causes low K
Zone thus not perforated
6066
6071
6054 - 60
6060 - 66
100
6066 - 72
Sw = 20
Sw = 30
10,000,000
Gas rate
Cum. Gas
100,000
10,000
0
200
400
Days
600
POROSITY
Sw = 50
1,000,000
Sw = 10
BVW = 0.03
10-1 Cockreham
Sw = 15
1.0
Well Performance
Sw = 100
0.1
BVW = 0.025
10
RESISTIVITY Ohm-m
BVW = 0.04
0.01
1
Mcf/d, Mcf
60
6046
Phi increases and Sw falls
BVW = 0.05 (@ Swi)
Pores fining
Zone perforated
Depth
BVW = 0.37
BVW = 0.06
BVW = 0.05
Sw = 10
1.0
BVW = 0.75
1B Perry
Sandstone - upward
coarsening shoreface
5412 - 40
a=1
m = 1.8
n=2
Rw = 0.04
K = 100 md
K = 10 md
5412 - 15
5415 - 22
800
5422 - 29
5429 - 37
0.01
1
5437 - 40
10
RESISTIVITY Ohm-m
100
Bhattacharya et al. (1997)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
32
AAPG Southwest Section Short
Course - Watney
Sw = 10
1.0
Sw = 50
Shale or
fine pores
BVW = 0.045
Common Signatures on Super Pickett plot
POROSITY
Sw = 100
Hypothetical
4100 - 4136
a=1
m = 1.78
n=2
Rw = 0.1
Zone at irreducible Sw
Possibly free oil zone (pay)
0.1
4100 - 07
4107 - 14
4114 - 21
4121 - 28
4128 - 36
0.01
100
10
RESISTIVITY Ohm-m
1
Long transition zone
Possibly low K
Short transition zone
Possibly high K
Inferences from Super Pickett signatures:
Low BVW at low phi - zone may be at Swi but low phi may result low K
Cluster of points hanging around a BVW line - zone at Swi
Phi increasing with decrease in resistivity - finer pores or transition
Bhattacharya et al. (1997)
Constant Phi with decreasing resistivity and increasing Sw - transition zone
From Geomodels to
Engineering Models –
Opportunities for Spreadsheet
Computing
Saibal Bhattacharya, W. Lynn Watney, Willard J. Guy,
John H. Doveton, Geoff Bohling, and Paul M. Gerlach
Kansas Geological Survey
1930 Constant Avenue – Campus West
Lawrence, Kansas 66047
1999 GCSSEPM Foundation Research Conference –
Advanced Reservoir Characterization for the Twenty-First Century
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
33
AAPG Southwest Section Short
Course - Watney
OOIP calculations for estimating waterflood
potential in Pennsylvanian oomoldic reservoir
Terry Field
OOIP calculations for estimating waterflood
potential in Pennsylvanian oomoldic reservoir
after Gerlach (1997)
Terry Field, Finney County
Target:
• Complex stacked carbonate oil reservoirs
•
Field scale
Data:
•
Core, DST, well logs, perfs & IP, production history
Oil properties
Tools:
Rock catalog, production & DST analyst, PVT,
log analysis, well profile (marked log), cross section,
mapping-volumetric analysis,
KHAN (Kansas Hydrocarbon Association Navigator)
Maps from the Digital Petroleum Atlas
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
34
AAPG Southwest Section Short
Course - Watney
Productive wells in Altamont Limestone
Structure Top Altamont Limestone
Oomoldic Lithofacies:
Terry Field, McCoy Six M Farms “A” 3-22
Marmaton B (Altamont Ls.)
4288.5 ft, thin section photomicrograph
40x transmitted light; core analysis: 25.6% porosity, 28.8 md
Marmaton B
(Altamont)
0.5 mm
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
35
100 md
AAPG Southwest Section Short
Course - Watney
NW-SE Petrophysical Cross Section through
Altamont Limestone in Terry Field
High Phi
Low Sw
Datum: Top Altamont
• Sweet spots of reservoir (high phi, low Sw, low
BVW) likely more permeable, well drained areas
• Waterflood effectiveness include ways to
access oil in marginal areas of reservoir.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
36
AAPG Southwest Section Short
Course - Watney
Petrophysics of the oomoldic
Altamont limestone
Archie Cementation Exponent
Oomoldic limestones from Kansas and globally exhibit extremely high Archie cementation
exponents. This is consistent with the interpretation that the oomoldic pores are similar to
micro-vugs. Modified Archie parameters for the Carter-Colliver Lease rocks are: m=1.36,
a=9.59. Conversely, if m is considered to change with porosity then m can be predicted for the
higher porosity rocks using: m = 0.05*Porosity(%) + 1.9. Cementation exponents are near
2.0 in the bioclastic wackestone overlying the ‘C’ zone. Cementation exponents increase into
the top of the ‘C’ and then decrease with increasing depth to the base. This is associated with
the higher porosity at the top of the ‘C’ zone but is also influenced by pore structure changes
associated with the unconformity surface.
Pay appears to be at
BVWi, suggesting
water free production
Marmaton B
Oomoldic Lithofacies
“ARCHIE ROCK”
Archie Exponents
m=2, n=2
Well Log Cutoffs
Phi =.15
Sw = .25
Vsh = .3
BVW = .04
Case #1
20%
IP 16 BW & 170 BO
Cumulative recovery
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
37
AAPG Southwest Section Short
Course - Watney
Pay has BVW of ~0.08
Marmaton B
Case #2
Log calibration as
defined by
core analysis
of highly
oomoldic LKC
limestones from
CKU
20%
IP 16 BW & 170 BO
Archie Exponents
m=3.5, n=2
Well Log Cutoffs
Phi =.17
Sw = .55
Vsh = .3
BVW = .097
25% less pay
Volumetrics
Case #2
Marmaton B
Marmaton B
Terry Field
Finney County, Kansas
Oomoldic Reservoir
Compare impact of two
sets of cutoffs
Case #1
Marmaton B
Initial log cutoffs
Archie Exponents Archie Exponents
m=2, n=2
m=3.5, n=2
Well Log Cutoffs
Phi =.15
Sw = .25
Vsh = .3
BVW = .04
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Log calibration
utilizing
core analysis
of highly
oomoldic LKC
limestones from
CKU
Well Log Cutoffs
Phi =.17
Sw = .55
Vsh = .3
BVW = .097
38
AAPG Southwest Section Short
Course - Watney
Gross Thickness
Marmaton B
Case #1
Net Pay
Average Sw
Average Phi
Sum (So*phi*ft)
m=2, n=2
Cutoffs
Phi =.15
Sw = .25
Vsh = .3
BVW = .04
Marmaton B
Case #1
Archie Exponents
m=2, n=2
Marmaton B
Case #2
Archie Exponents
m=3.5, n=2
Well Log Cutoffs
Well Log Cutoffs
Phi =.15
Sw = .25
Vsh = .3
BVW = .04
Phi =.17
Sw = .55
Vsh = .3
BVW = .097
OOIP
Case #1
9.7 MM Bbls OOIP
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
OOIP
Case #2
OOIP
4.2 MM Bbls OOIP
(40% less hydrocarbon than Case #1)
39
AAPG Southwest Section Short
Course - Watney
Pennsylvanian
– Lobate and linear oolitic shoals form complex
geometries
– Granulometric attributes of Modern and ancient ooid
shoals are comparable
– Oomoldic porosity is pervasive
– Size, sorting, packing of Pennsylvanian and
Pleistocene oomolds are closely related
– Archie cementation exponent, m, is critical
measurement affecting Sw calculations and OOIP.
– Relative permeability to oil of lower perm oomoldic
rocks is generally defined by steep decline with
increasing Sw
Pleistocene, Ocean Cay
w/ alz-r stain
Pennsylvanian, Bethany Falls Ls.
unstained
Conclusions
Geometries, scales, and facies distributions of Pennsylvanian
oolite shoals suggest analogs to Modern, tidally influenced ooid
tidal ridges and parabolic bars.
Accurate and precise characterization of connected (effective)
oomoldic pores is critical in IOR modeling and prediction:
– Better sorted, cleaner (low GR), highly porous (>17%) oomoldic grainstone
grainstone
appear to be more permeable;
– In Plattsburg Limestone at HallHall-Gurney Field, best sorting noted in upper
portion of shallowing upward high frequency cycles and bedsets, probably
delimiting separate ooid shoal development
– Moldic porosity increases upward in shallowing bedsets and high
frequency cycles
Structural control of oolite reservoirs likely at various scales
augmenting and possibly influencing depositional and diagenetic
fabrics.
Geophysicists, engineers, and geologists needed for model
development and validation
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
40
AAPG Southwest Section Short
Course - Watney
Conclusions
In a oomoldic thin-bed reservoir standard
log analysis is misleading
Equations for k, Pc, kr, m presented provide
improved prediction for oomoldic LKC
Archie m is not 2, m = f(, k)
Many/most LKC are thin-bed reservoirs
– require advanced log analysis
Even if you run DST accurate k, kr, Sw is
needed for waterflood prediction
Proposed log-analysis methodology should
provide improved k and Sw prediction in
LKC
Pennsylvanian Caddo
Limestone, East Texas
Phylloid Algal Mound
Log Analysis of a Producer and
Dry Hole
Using web view of LAS log data
and spreadsheet log analysis
software, PfEFFER
GR
Lithofacies
From n-d-pe
Ø
Microlog
Imaging
>R, darker
ATKINS-TEXACO
3200-3300
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
PERF: 3208-3212
IPP: 70 BOPD, 5 MCF, 512 BWPD
41
AAPG Southwest Section Short
Course - Watney
-0.100
0.1
3200
3210
3210
3220
3220
3230
3230
3230
3240
3240
3240
Depth
GR.
3250
3260
3270
3280
3290
3300
Depth
3200
3210
PHI
3250
10
3250
3260
BVW
3270
3260
3270
RT
DPHZ.CFC
3280
F
3290
NPOR.CFC
F
3300
3280
RWA
3290
3300
Caddo Limestone
(producer), m = 2
-- first pass
Sw=40%
Sw=20%
1.000
6.045
5.703
5.753
5.353 ATKINS-TEXACO
5.053
5.067
4.838
4.639 3300
4.632
4.465
4.383
4.358
4.3
4.232
4.188
0.000
0.500
4.2583200 4.196
4.136
4.379
4.329
4.253
3210
4.827
4.759
4.666
5.92
5.723
5.616
3220
7.648
7.682
7.484
11.041323011.355
11.166
17.934
19.549
19.429
26.202324034.287
33.172
34.514325054.147
50.561
41.66
74.102
70.406
46.182326087.521
96.168
48.939
94.689 128.249
3270
51.432
99.058 152.316
SW
53.9973280
103.941 164.084
PAY
56.919
113.63 162.413
59.4283290
122.878
154.95
62.1413300
129.784 145.198
64.973
135.15 138.044
A
B
C
BVW=0.02
0.150
3203
3203.5
3204
1000
3204.5
3205
3205.5
3206
3206.5
3207
3207.5
3208
3208.5
3209
3209.5
3210
3210.5
3211
3211.5
3212
3212.5
3213
Depth
0.400
3202
- 32003202.5
ATKINS-TEXACO
3300
3200
3220
Depth
200
- 3200-
BVW=0.04
100
ATKINS-TEXACO
3300
BVW=0.06
0
- 3200-
BVW=0.08
ATKINS-TEXACO
3300
3200-3300
Depth: 3200 - 3300
X:
Y:
a: 1
m: 2
n: 2
RW: 0.2
Sw=80%
Sw=100%
A
POROSITY
B
C
0.100
4.505
4.246
4.088
1.000
4.042
4.17
4.572
5.497
7.305
10.764
18.544
32.581
47.662
65.689
93.797
131.02
157.125
164.062
155.107
143.965
132.64
124.123
ATKINS-TEXACO
Sw=60%
• Phylloid algal lithofacies
• Decrease in Rt with depth
• Steady Ø with depth
• Slight increase in BVW with
depth (cutoff BVW <0.05)
• Three clusters of points with
low BVW (0.03) BVW at top, A
• Lowest zone, C, also has
relatively low BVW and may be
pay
• 87% water cut – fractures?
5.547
- 32004.912
M=2
DEPTH
3280 - 3300
3255 - 3280
3235 - 3255
3212 - 3235
3208 - 3212
0.010
1
10
100
1000
RESISTIVITY Ohm -m
ATKINS-TEXACO
3200-3300
PERF: 3208-3212
IPP: 70 BOPD, 5 MCF, 512 BWPD
Vuggy pores typical of algal mound, higher m is likely
resulting in higher calculated water saturation
0.300
0.150
0.000
0.1
3200
3200
3210
3210
3210
3220
3220
3220
3230
3230
3230
3240
3240
3240
3260
Depth
3200
3250
3250
3260
3270
3250
3270
PHI
3280
3300
1.000
BVW=0.04
3300
BVW=0.06
3300
BVW=0.1
3290
BVW=0.08
3290
Sw=20%
Sw=60%
Sw=80%
Sw=100%
POROSITY
RT
3280
BVW
3290
Sw=40%
10
3260
3270
GR.
3280
3202
- 32003202.5
ATKINS-TEXACO
3300
RWA
40
%
3203
3203.5
3204
1000
3204.5
3205
3205.5
3206
3206.5
3207
3207.5
3208
3208.5
3209
3209.5
3210
3210.5
3211
3211.5
3212
3212.5
3213
3213 5
ATKINS-TEXACO
3200-3300
Depth: 3200 3300
X:
Y:
a: 1
m: 2.5
n: 2
Perf in red
0.100
6.045
5.703
5.753
5.353 ATKINS-TEXACO
5.053
5.067
4.838
4.639 3300
4.632
4.465
4.383
4.358
4.3
4.232
4.188
0.000
0.500
4.2583200 4.196
4.136
4.379
4.329
4.253
4.8273210 4.759
4.666
5.92
5.723
5.616
3220
7.648
7.682
7.484
11.041323011.355
11.166
17.934
19.549
19.429
26.202324034.287
33.172
34.514325054.147
50.561
41.66
74.102
70.406
46.182326087.521
96.168
48.939
94.689 128.249
3270
SW
51.432
99.058 152.316
53.9973280
103.941 164.084
PAY
56.919
113.63 162.413
3290
59.428 122.878
154.95
62.1413300
129.784 145.198
64.973
135.15 138.044
67 603
137 39 131 607
5.547
- 32004.912
4.505
4.246
4.088
1.000
4.042
4.17
4.572
5.497
7.305
10.764
18.544
32.581
47.662
65.689
93.797
131.02
157.125
164.062
155.107
143.965
132.64
124.123
117 15
5.462 165.415
ATKINS
ATKINS-TEXACO
4.847
186.822
3300
4.453 206.688
4.209 223.939
4.054 7 232.564
7
8.5
4.01 3200
234.855
3200
4.139 228.354
3210 3210
4.545
207.175
5.45
168.93
3220 3220
7.246 130.758
10.756
90.568
3230 3230
18.329
55.759
3240 3240
31.647
38.166
49.096
28.973
3250 3250
69.32
24.004
3260 3260
91.506
21.653
117.094
20.434
3270 3270
138.529
19.443
HCAL.IN
3280 3280
151.878
18.519
155.72
17.569
3290 3290
150.873
16.827
145.197
16.093
3300 3300
134.517
15.391
122 449
14 792
- 3200-
10
Limited pay
p
200
- 3200-
Depth
100
ATKINS-TEXACO
3300
Depth
Depth
0
- 3200-
Depth
ATKINS-TEXACO
3300
caliper
Using cementation
exponent, m, equals 2.5
- Pass #2
• Reduces pay to very top
where perforated
DEPTH
3250 - 3300
3230 - 3250
3212 - 3230
3208 - 3212
3190 - 3208
0.010
1
10
100
RESISTIVITY Ohm-m
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
1000
• Lower zones have Sw ~ 50%
• Rw used, 0.02, may be
higher
ATKINS-TEXACO
3200-3300
PERF: 3208-3212
IPP: 70 BOPD, 5 MCF, 512 BWPD
42
AAPG Southwest Section Short
Course - Watney
1.000
BVW=0.06
Sw=20%
BVW=0.1
Sw=40%
BVW=0.08
Sw=60%
BVW=.12
Pass #3 -- Adjusted Ro line to fit base of
porosity using Rw now of 0.4 ohm-m,
with m = 2.5
ATKINS-TEXACO
3200-3300
Depth: 3200 - 3300
X:
Y:
a: 1
m: 2.5
n: 2
RW: 0.4
POROSITY
Sw=80%
Sw=100%
Shale points
Perforated interval
0.100
DEPTH
3278 - 3300
Widely varying
points at low Ø
suggest
fracturing
3256 - 3278
3234 - 3256
3212 - 3234
3190 - 3212
0.010
1
10
100
1000
RESISTIVITY Ohm -m
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Nonlinear Microrestivity (MNOR)
Linear Microrestivity (MNOR)
Nonlinear NPHI
Linear NPHI
Linear Microrestivity (MNOR)
Linear NPHI
Rhomma-NPHI
GR
Rhomma-Umma
Pay
indications of
possible
Fracturing?
WebWeb-based tool for
imaging of porosity and
resistivity for indications of
fracturing
AdkinsAdkins-Texaco
Producing Well
43
AAPG Southwest Section Short
Course - Watney
“Watfa-Nurmi chart”
F = Ro/Rw
= a / Øm
Upper zone of
Caddo
STATEX 8 SPEARS
CADDO LIMESTONE
DRY HOLE
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
44
AAPG Southwest Section Short
Course - Watney
200
0.1
10
100
0.300
3250
3270
GR.
Depth
3310
3330
3350
3350
3370
3370
PHI
3290
RWA
3310
3330
0.150
3270
RT
3290
Depth
3290
3251.5
3251.75
0.000
3252
3252.25
3252.5
3252.75
3253
3253.25
3253.5
3253.75
3254
3254.25
3254.5
3254.75
3255
3255.25
3255.5
3255.75
3256
3256.25
3256 5
3250
BVW
3310
3330
3350
Rw ~ 0.2 ohm-m
STATEX 8 SPEARS
CADDO LIMESTONE
DRY HOLE
-- Low porosity,
tight
-- using m = 2.5,
Rw = .05 ohm-m
for best fit of points
with Ro line
Sw=20%
3370
1.000
56.625
28.013
59.521 SPEAR
27.381
63.349
26.814
67.881 0.000
26.561
72.827
3250 26.701
77.91
27.08
82.901
27.441
3270 27.607
87.669
92.215
27.586
96.651
27.498
3290
101.102
27.447
105.62
27.459
110.176
3310 27.479
114.711
27.4
119.137
27.156
3330 26.811
123.271
126.831
26.52
129.56
26.367
3350
131.34
26.297
132.185
26.212
132.167
3370 26.077
131.408
25.912
130 115
25 741
0.28013
8.909
- 3250-3380
0.27381
8.907
0.26814
8.907
0.26561
8.905
0.500
1.000
0.26701
8.905
0.2708
8.905
0.27441
8.903
0.27607
8.903
0.27586
8.905
SW
0.27498
8.905
PAY
0.27447
8.901
0.27459
8.898
0.27479
8.897
0.274
8.894
0.27156
8.887
0.26811
8.88
0.2652
8.879
0.26367
8.881
0.26297
8.882
0.26212
8.881
0.26077
8.881
0.25912
8.882
0 25741
8 884
SPEAR
3250-3380
Depth: 3250 - 3380
X:
Y:
a: 1
m: 2.5
n: 2
RW: 0.05
Sw=40%
Sw=60%
Sw=80%
Sw=100%
POROSITY
3270
Depth
1
3251
- 3250-3380
3251.25
SPEAR
Depth
100
3250
- 3250-3380
BVW=0.06
0
SPEAR
BVW=0.1
- 3250-3380
BVW=0.08
SPEAR
RoWate
r Line
0.100
DEPTH
3364 - 3393
3335 - 3364
3306 - 3335
3277 - 3306
3248 - 3277
0.010
1
10
100
RESISTIVITY Ohm -m
Petrophysical and Geophysical
Characterization of Karst in a Permian
San Andres Reservoir, Waddell Field,
West Texas
by
Susan E. Nissen, John H. Doveton, and
W. Lynn Watney
presented at AAPG Annual Meeting
May 2008
Funded by the Department of Energy
Cooperative Agreement No.: DEDE-FC26FC26-04NT15504
www.kgs.ku.edu/PRS/publication/2008/OFR08_5/
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
45
AAPG Southwest Section Short
Course - Watney
3 mi
Blumentritt et al. (2003)
San Andres Reservoir on the
Central Basin Platform
www.kgs.ku.edu/SEISKARST
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
46
AAPG Southwest Section Short
Course - Watney
Finding in Study
•. Karst impacts reservoir performance
• Highly compartmentalized reservoir and fluid production is
extremely variable.
• Reservoir heterogeneity appears to be related to stratigraphy
and diagenesis, as well as karst features associated with a
subaerial exposure surface at the top of the San Andres
Formation.
• Core data indicate that the uppermost San Andres consists of
sporadically porous “macro” karst, characterized by intense
chaotic brecciation and anhydrite replacement, followed by
isolated, late stage anhydrite dissolution.
• The karst overprints high frequency sequences composed of
gypsiferous oolitic, fusulinid, and skeletal packstone-grainstone
reservoir rock with moldic, vug, and fracture porosity.
Nissen et al. (2008)
Findings (continued)
• Wireline log petrophysical solutions used to quantitatively
discriminate anhydritic karst from the underlying packstonegrainstone strata in uncored wells.
• The base of the karst zone corresponds to a sharp decrease in
seismic impedance, and 3D seismic data are used to map the base of
karst between wells.
• The karst zone exhibits high variability in thickness; however, the
zone is generally thicker on higher portions of a SE-trending anticline
that runs through the study area, suggesting a structural control on
karst development.
• Seismic data show that the karst zone truncates the base of the
porous reservoir in some areas and seismic attributes reveal
potential reservoir compartment boundaries.
• Better understanding of local karst control on fluid flow in this
reservoir can improve reservoir management decisions.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
47
AAPG Southwest Section Short
Course - Watney
Seismic profile A-A’ across shelf margin of CBP
• Interval from Guadalupian 4 (G4) horizon to top of San
Andres is part of a transgressive systems tract (TST).
• Interval from Top San Andres to Grayburg is part of a
high stand systems tract (HST).
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
48
AAPG Southwest Section Short
Course - Watney
2 sq. mile “high volume” area of Waddell Field
• Multi-mineral models are essential for estimating effective porosities that provide good
matches with core.
• Statistical zonation of well logs provides a consistent method for identifying the base of
karst.
• Seismic horizon mapping provides details on the configuration of the reservoir interval.
• Seismic impedance allows us to determine interwell porosity variation.
• BVW profile analysis is useful for assessing spatial continuity of the reservoir.
• Multi-trace seismic attributes, such as volumetric curvature, provide added detail in our
interpretation of reservoir compartmentalization.
Enhanced Characterization of
Reservoir Heterogeneity
WADDELL FIELD Permian San Andres
Green = tight negative
curvature (faults, fractures?)
Red outline = tracer survey
outlines prominent flow
areas
Most negative curvature map
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Orange lines = engineering
interpreted permeability
barriers
49
AAPG Southwest Section Short
Course - Watney
Top San Andres Formation
(recognizable on seismic)
AWO: 240 BOPD, 176 MCF, 3610 BW
AWO:7 BOPD, 15 MCF, 782 BW
• Difficult to correlate oolitic shoal
packages
• Guadalupian G4 regional marker
below typical well depth in ‘high
volume” area
Wireline log solution to open vug/oomoldic vs. tight rock
in San Andres reservoir at Waddell Field
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
50
AAPG Southwest Section Short
Course - Watney
Karst thickest
along crest
of current
structural high
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
51
AAPG Southwest Section Short
Course - Watney
Seismic Horizon Analysis and
Reservoir Characterization
Top San Andres
“X” marker
Time structure at base of karst below
top of San Andres Formation
•Karst is thicker over structure
•Base of karst based on seismic
appears consistent
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
52
AAPG Southwest Section Short
Course - Watney
Grayb
urg
Base
tight
anh
yd.
SEISMIC
AMPLITUDE
Grayb
urg
Base
tight
anh
yd.
ACOUSTIC
IMPEDANCE
Acoustic
Impedance
sections
flattened on
Top of
Grayburg
horizon
• “X” marker
truncated by base of
karst horizon at
several locations
• “X” marker appears
to onlap regional
seismic horizon
equated with G4
• Interval part of TST
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
53
Isopach (ft)
AAPG Southwest Section Short
Course - Watney
Isochron (ms)
Mean porosity
seismic impedance
Well log impedance
Mean impedance
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
54
AAPG Southwest Section Short
Course - Watney
Porosity distribution appears to be preserved trend of ooid
shoal or diagenetically enhancement along lineament (e.g.,
dissolution of pore filling gypsum cement)
Reservoir Connectivity &
Compartments
BVW = Sw x Ø
• In principal: Increase
BVW with depth as
approach oil-water contact
in a transition zone
• BVW-depth pattern here
is widely scattered, no
pattern
• Lack of pattern suggests
no common transition
zone among wells, or
widely varying reservoir
properties/pore types
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
55
AAPG Southwest Section Short
Course - Watney
Bubble maps of
BVW at given
elevation (subsea)
superimposed on
top of San Andres
structure map
• BVW values vary
markedly by depth
• Depth slices show no
pattern of BVW variation
with depth
• No strong field-wide
transition zone, but rather
well-scale variations in
reservoir properties
Ø-BVW = ~So
Karst
Karst
• Adjacent wells #1207 and #1228 are at opposite ends of depth plot vs. Ø-BVW.
• Both wells at essentially the same elevation at top of the San Andres Fm.
• #1228 is more tightly clustered with lower elevation wells due to thick karst.
• Base of pay corresponds with lowest Ø-BVW, suggesting proximity to water level.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
56
AAPG Southwest Section Short
Course - Watney
Structure map
on Top San
Andres
Formation
• Bubbles depict
cumulative Phi-BVW
in pay intervals for
each well.
• No clear pattern
including offset wells
• Similar to maps of
cumulative oil and
gas production in
“high volume area”.
Most positive volumetric curvature extracted along a
Devonian horizon superimposed on mean impedance map for
base of karst to “X” marker
Black = positive
(antiformal)
curvature)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
• Significant deepseated structural
control to the
northwest-trending
features in the “high
volume area”.
• Crosscutting north to
northeast-trending
features on the
Devonian surface
appear to have
impacted porosity
development in the San
Andres.
57
AAPG Southwest Section Short
Course - Watney
Most positive volumetric curvature extracted along “X”
marker superimposed on mean impedance map for
base of karst to “X” marker
• Some of the same
structural trends as
the Devonian horizon
but also shows a finer
network of lineaments
that enclose areas
with diameters on the
order of 1500 ft (450
m).
Black = tight
positive
(antiformal)
curvature)
• These features may
indicate reservoir
compartmentalization
at a single-well scale.
Conclusions
• A wide range of fluid recoveries is noted in wells in the “high volume area” of
Waddell Field. Higher production generally comes from:
• 1) the main structural high,
• 2) along the northeast flank of the southeast-trending anticline that runs through
the area, and
• 3) along a narrow northeast-trending area roughly corresponding to a structural
saddle on the anticline.
• In the “high volume area”, tight, anhydritic “macro” karst at the top of the San
Andres Formation cuts down into the underlying porous reservoir.
• The karst zone exhibits high variability in thickness but is generally thicker on
the higher portions of the southeast-trending anticline.
• The porous carbonate reservoir interval below the karst is on the saddle area
of the anticline.
• A seismic horizon corresponding to the ”x” marker (base of porous reservoir)
can be interpreted across the impedance volume. This horizon is truncated by
the base of karst in some areas, suggesting an associated change in reservoir
type/quality in these areas.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
58
AAPG Southwest Section Short
Course - Watney
Conclusions (continued)
• A comparison of mean and center of gravity measures of porosity indicates
that higher porosity is developed lower in the pay interval.
• The mean seismic impedance of the reservoir interval corresponds well
with mean porosity from well logs and allows porosity approximation in areas
of poor well control.
• The impedance maps suggest that the porous San Andres shoals that
comprise the pay appear to have N-NE trends, oblique to the main San
Andres structure. The pattern of shoal development may be controlled by
deep- seated structure.
• Local karst development appears to be at a well scale, greatly reducing
the reservoir quality, which causes variability in oil and gas production, even
within this high volume area.
• A combination of factors appears to be responsible for the pay distribution
in the high volume area of Waddell Field.
Seismic amplitude map showing rectilinear
porosity pattern in San Andres Formation
• another example of
compartmentalization
attributed in part to
structural control
Ax
is
of
pr
e
se
nt
st
ru
ct
ur
e
• amplitude/porosity
pattern believed
controlled by access to
burial fluids migrating
along fractures leading
to anhydrite dissolution
From Lucia (1999)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
59
AAPG Southwest Section Short
Course - Watney
Isopach of number of fracture feet in a 20
ft slice map of the Yates San Andres field
• NW-SE and orthogonal NE-SW fracture and karst trend overprint matrix
porosity accompanied by numerous caves below top of San Andres
• grainstone and grain-dominated packstone have highest porosity
• grainstone concentrated on ramp crest
• 4 Billion bbl reservoir
Tinker and Mruk (1995)
NW-SE cross section across
Taylor-Link San Andres reservoir
• ooid grainstone rock fabric facies and fractured fusulinid wackestone facies
• grainstone dolomitized with interooid porosity, ~60 ft thick, amalgamation of several
shoaling-upward cycles
•50 million bbl reservoir
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Lucia et al. (1992)
60
AAPG Southwest Section Short
Course - Watney
Additional Information for
Part 4 – Lithofacies and Petrofacies
Illustrations that follow provide additional
geological background to this paper
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
61
AAPG Southwest Section Short
Course - Watney
Geo-Engineering Modeling of
Morrow/Atoka Incised-Valley Fill
Deposits Using Web-Based
Freeware for Incremental Field
Exploitation
W. Lynn Watney1,3, Saibal Bhattacharya1, Alan Byrnes1, John Doveton1,
John Victorine1, Rick Brownrigg2
2Electrical
1Kansas Geological Survey
Engineering & Computer Science Department
3KU Energy Research Center
The University of Kansas
Lawrence, KS 66047
Objectives
Regional framework of Pennsylvanian incised
valleys in western Kansas
Sequence stratigraphy of Atokan Stage
Lithofacies and high-frequency cycles controlling
production in Minneola/Norcan East Field
Flow units, waterflood performance, refined
reservoir model
Correlation and mapping
Controls
Summary
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
62
AAPG Southwest Section Short
Course - Watney
The Hugoton Embayment
-- Carboniferous Sea Level History
Study
Area
10 m.y.
Ross & Ross
(after Sonnenberg et al. ,1990)
AtokanAtokan-Age Fields, Cross Section Index
in Context of
Regional Morrow Isopach (ft)
Stewart
Finney
A’
Minneola-Norcan East
Gray
A
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Cross
section
Clark
63
AAPG Southwest Section Short
Course - Watney
Lithofacies-Stratigraphic Cross Section A-A’
with Datum on “V” Shale in Cherokee Group
A’
Desmoinesian
A
Atokan
Upper Atokan
sequence “L”
Ste.Genevive
subcrop
Morrowan
Sequence “L”
Youle et al (1994)
-- Atokan backstepping and forward-stepping 4th-order carbonate-dominated cycles
-- Bundling of “4th-order” cyclothemic-scale sequences into 3rd order sequence sets
Idealized Atoka 4th-Order Depositional Sequence
Along margins of Hugoton Embayment
SW-NE “restored” section, A-A’
Eastern Shelf of Hugoton Embayment
Western Kansas
Kansas Cyclothem
After Youle (1992)
Cycle Turnaround
toplap
Minor cycle B
Location
of incised
valleys
Minor cycle A
“Thirteen Finger Ls.”
Ste. Gen.
subcrop
“fall line”
downlap
Sediment Starved
Relief on shelf ~ 150-200 ft
(46-60 m)
Horizontal distance ~ 70 mi.
(110 km)
Lower shelf
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Mid shelf
Upper Shelf
64
AAPG Southwest Section Short
Course - Watney
Study area
Base map from Clark (1987)
Study area
Norcan East
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
65
AAPG Southwest Section Short
Course - Watney
Waterflood
Began, Jan. ‘95
Cumulative Oil Production: 814,000 bbls
Projections: Estimated remaining reserves: 21k bbls
Economic limit at 5 BOPD reached: ~2008…
Cumulative Gas Production: 2.7 BCF
Projections: Estimated remaining reserves: 147 MMCF
Cumulative oil and gas = 1,164 MBOE
Compared to nearby Stewart Field = 9.6 MMbbls
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
66
AAPG Southwest Section Short
Course - Watney
Did the reservoir start production at/above/below
Bubble point?
Presence of Free Gas from Logs
0.7
0.6
Sw
0.5
0.4
0.3
0.2
0.1
0
-0.05
-0.03
-0.01
0.01
0.03
0.05
0.07
0.09
0.11
0.13
0.15
Dphi (ssd) -Nphi
Stat2-12 85/1
Roony1 87/1
TedB1-10 85/8
Stat1-12 85/1
Schlng 84/1
Goel1-4Mur 85/1
Hind1-3 82/12
Pat1 82/8
Ted4-10 84/2
Ted1-10 84/12
Ted1 83/3
Pat2-3 83/5
Har1-3 82/11
Fag2-3 83/3
Goel1-4Ld Inj 82/12
Pat1-3Inj 83/3
Latz1 82/6
Minneola/Norcan East Study area, Clark-Ford Counties, Kansas
fager1-3
Predominantly Oil
Production
4147000
bouch1-3Afag2-3 fag1-3
roo1-2
hind1-3
nort1-4
1
4146000
goel1-4
goell1-4
alle1-9
nort1
harris1-3
patt2-3
Predominantly Gas
Production
patt1-3
Patton 1-3
ted1
hall2-2
patt2-3
ted4-10
patt1
core
schli1-2
ted1-10
ted2-10
latz1
ted1-10
mcgee1-1
core
roo1 statt2-12
statt1-12
roon1-11
ted3-10
ted2-10
Statton 2-12
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
Wells used in GEMINI database
• Digitized logs (LAS)
• Completion information
• Core data
• Test results
• Lease production
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
1 mile
67
AAPG Southwest Section Short
Course - Watney
Total magnetic field intensity with
oil fields
Minneola Field Complex
Ste. Genevieve
subcrop
HighHigh-Resolution Seismic Survey of the
Minneola Complex
Southwest Kansas
Kansas Geological Survey OpenOpen-File Report OFR 9898-44
Joseph M. Kruger, Kansas Geological Survey
Seismic line index map
Dashed lines = limits of
Atoka sandstone
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
68
AAPG Southwest Section Short
Course - Watney
Acoustic impedance interpolation of sonic and density logs from wells
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
69
AAPG Southwest Section Short
Course - Watney
5316
S1
5318
Top Atoka
Predominantly
Limestone
5320
S1
5316
Vfn.
Gr.
5322
S2
5318
b
a
WTR
INJ.
flow units
b
5320
5322
5324
S2
5326
5328
5324
Fn.
Gr.
a
5326
Shaly ss-siltstone
S3
Top Mississippian
5328
Patton 1-3 Core
(Depths 5 ft. high to log)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
70
AAPG Southwest Section Short
Course - Watney
Coarser, more well sorted qtz sand = greater porosity
Statton 2-12 5322.5 ft, permeability between clay laminae, graded bedding; “a” flow unit of S2 Sand (estuarine)
Statton 2-10, 5316 ft. (top S2 sand)
Statton 2-10 5321 ft. (mid S2 sand)
Statton 2-10 5322.5 ft. (lower S2 sand)
S1
S2
Rhythmic ss-sh lam. & bioturbation
-- flow unit “B” sand of S2
Inner bay, distal tidal bar
SS, with tabular cross stratification
with rhythmic shale laminae,
reactivation surface
-- flow unit “a” sand of S2
tidal bar
Flooding/ravinement surface between
S1 & S2 cycles separating wackestone (top)
from sandstone (lower)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
71
AAPG Southwest Section Short
Course - Watney
Patton 1-3 5321.8 caliche, probably in situ, and dispersed pyrite; lower part of “b” sand (early subaerial exposure)
Patton 1-3 core
5316
Wackestone, gr.
S1
(Marine Ls.)
5318
Sequence
Boundary
5320
Thin
section
S2
Ss-sh., vfn gr., lam, reactivation surfaces
b
Bi-directional ripple cross-lam.
(Distal Estuarine Ss.)
5322
Sh., dk. Gr., lam. w/lenses of ss., cross-lam.,
flaser bedded
(Heterolithic Clastics and
ss., bioturbated top
Carbonates – Inner bay, lagoon)
5324
Ss., fine gr., low-angle planar bedding, reactivation
surfaces
(Proximal Estuarine
a
5326
Thin
section
5328
Ss.)
ss., slightly argil.
Ss., bioturbated, distinct cm-scale smooth burrows,
vertical and horizontal
Sh., dk. gr to blk., mod. Soft, carbonaceous
(Bay to marginal marine Shale)
Flow units “a” and “b” within transgressive-regressive S2 Sand
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
72
AAPG Southwest Section Short
Course - Watney
Lower “a”
Flow unit
“Super Pickett Crossplot”
b
a
Upper “b”
Flow unit
Water Injection zone
“a” flow unit
(Archie solution to
water saturation)
Cutoffs based on production
Density porosity
• Matrix density = 2.647 g/cc
• Gas correction in eastern
most wells
Permeability-porosity relationships – Minneola Field
Permeability vs Porosity by GRI
Insitu Klinkenberg Permeability (md)
1000
100
10-20
20-30
30-40
10
40-50
GRI 15
GRI 25
GRI 35
GRI 45
GRI 55
1
10
12
14
16
18
20
22
24
In situ Porosity (%)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
73
AAPG Southwest Section Short
Course - Watney
Structure Top S2 Sand, Minneola/Norcan East
Sea Level Datum, feet
fager1-3
C.I. = 10 ft.
B’
-2685
bouch1-3A fag2-3 fag1-3
4147000
roo1-2
hind1-3
nort1-4
goel1-4
1
harris1-3
patt2-3
nort1
4146000
-2705
patt1-3
patt1
goell1-4
alle1-9
-2695
hall2-2
patt2-3
ted1
B
-2715
schli1-2
ted4-10
mcgee1-1
ted1-10
ted2-10
ted1-10
roo1 statt2-12
latz1
-2725
statt1-12
roon1-11
-2735
ted3-10
ted2-10
-2745
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
-2755
1 mile
Cross Section Index B-B’
SW-N Structural cross section B-B’
B
B’
Murfin
Patton #2-3
Murfin
Patton #1-3
Injector
Murfin
Tedford #4-10
150 Mbbl
132.9 Mbbl
53.1 Mbbl
Murfin
Fager #2-3
73.6 Mbbl
Datum =
sealevel
Top Ato
ka
“B”
S2
S2
“A”
Water
breakthrough
Jan. ‘98
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Water injection
in flow unit “A”
Plugged before
water injection
No water
breakthrough
Horizontal
Distance =
~ 1 mile
74
AAPG Southwest Section Short
Course - Watney
Isopach of Atoka Stage
feet
105
6000
95
85
4000
75
65
2000
55
45
0
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
35
1 mile
Primary valley incision
N
Gross Thickness of S2 Pay, Minneola/Norcan East
C.I. = 4 ft.
23.5
Patton 1-3
Water injector
4147000 in lower
“A” flow unit
54
21.5
25
nort1-4
22 1
4146000alle1-9
hind1-3
25
goel1-4 15
27.5
11.5
harris1-3
roo1-2
31.5
19
patt2-3
27.5
50
14
bouch1-3Afag2-3 fag1-3
17.5
10.5
58
fager1-3
29
46
18
42
hall2-2
38
patt2-3
32
34
patt1-3
goell1-4
17
13
24.5
nort1
ted1
ted4-10
patt1
13.5
ted1-10
23.5
ted1-10 33.5
11
schli1-2
38.5
ted2-10
26.5
25.5
55.5
48
9
latz1
roon1-11
15.5
59
roo1 statt2-12
30
mcgee1-1
statt1-12
22
18
ted3-10
14
ted2-10
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
• Separation of east and west reservoirs
• Isolation of eastside from waterflood
• Triangulation gridding
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
26
10
1 mile
N
75
AAPG Southwest Section Short
Course - Watney
Net Pay Isopach, S2 Sand, Minneola/Norcan East
C.I. = 1 ft.
0
fager1-3
0
4147000
11.5
11
10
1
0
bouch1-3A fag2-3 fag1-3
0
0
nort1-4
5.5
goel1-44.5
1
0
4146000alle1-9
harris1-3
patt2-3
4
8
hall2-2
7
patt2-3
1
patt1-3
6
patt1
5.5
goell1-4
0
1.5
8
nort1
ted1
ted4-10
10
schli1-2
0
ted1-10
0
3.5
0
latz1
roon1-11
5
10
8
ted2-10
1.5
ted1-10
0
4
hind1-3
6
9
roo1-2
9.5
7.5
5
5
mcgee1-1
4
3
statt1-12
roo1 statt2-12
2
ted3-10
0.5
1
ted2-10
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
Net Pay applying pay cutoffs
phi = 0.1
Sw = 0.5
Vsh = 0.3
BVW (bulk volume water = Sw x phi) = 0.12
0
1 mile
C.I. = 0.2 p-ft
(Storage Potential)
Sum Phi*h for S2 Pay, Minneola-Norcan East
0
fag er1-3
Western bayhead delta
0
47000
2 .487
2.2
0
1.567
bou ch1-3A fa g2 -3 fa g1-3
1.442
1 .30 3
0
nort1-4
01
46000alle 1-9
goel1 -4
0.740 7
goell1
0 -4
n ort1
hin d1 -3
1.742
harris1-3
0.3849
p att1-3
1.5 996 25 46 6764
te d4 -10 0.09 79
ted1
0
ted1 -1 0
0
ted2-10
Sh
1.8
hal l2-2
1.6
pa tt2-3
0.35 6
1.4
patt1
0.8846
ted 1-1 0
ted2-10
0.5 593
2
Sh
0
roo 1- 2
2.49
patt2 -3
1 .47 5
2.4
0
1.2
1.91 6
0
schli1-2
mcgee1 -1
1.4 54
0
latz1
roo n1 -11
r oo1
1.89 1
0.968 3
sta tt2-12
statt1-12
Eastern bayhead delta
ted 3-1 0
406000
406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
Western
lobe:
Source: northern edge of valley
1 mile
2 Flow units:
-- Lower A sandstone thickens in distal (southern) position
-- Upper B sandstone thickens in proximal (northern) position
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
1
0.8
0.6
0.4
0.2
0
76
AAPG Southwest Section Short
Course - Watney
(Flow Potential)
Sum k*h, S2 Pay in Minneola/Norcan East
C.I. = 4 md-ft
fa ger1-3
3600
Western bayhead delta
bo uch 1-3A fag 2-3 fag1- 3
4147000
3200
r oo1-2
patt2-3
hind1- 3
n ort1 -4
1
goe l1-4
p att2-3
ha rris1-3
alle1-9
nort1
2400
Sh
patt1-3
patt1
goell 1-4
4146000
2800
ha ll2-2
ted1
2000
sch li1-2
ted4 -10
mcg ee1-1
1600
ted1 -10
ted2- 10
roo1 statt2-1 2
latz1
ted1 -10
Sh
statt1-1 2
1200
roon 1-11
ted3 -10
Eastern bayhead delta
ted 2-10
800
400
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
0
1 mile
Eastern Lobe:
• Source: southeastern edge of valley
• 3 flow units:
-- Lower A and B sandstones are laterally extensive
before grading into limestone to west
-- Upper C sandstone limited to proximal position
in southeast
Volumetrics of S2 Sand
•
•
OOIP ~8 MMBBLS
Compared to cumulative production of ~1.1
MMBOE (14% of OOIP)
Hydrocarbon Porosity Feet, S2 Pay, Minneola/Norcan East Contours, C.I.
So *=phi
*h
So-p-ft
0
fager1-3
Western bayhead delta
0
- mainly oil
4147000
1 .9
2.01
0.18
0.94
0
0
nort1-4
0
1
4146000alle1-9
0.69
hind1-3
0.66
goel1-40.46
goell1-4
0
nort1
harris1-3
0.14
0.44
ted4-10
1 .3
patt2-3
0.09
1 .1
patt1
0.69
0.13
ted1-10
0
0.1
1.72
ted3-10
0.55
schli1-2
0
ted2-10
ted1-10
1 .5
0
hall2-2
patt1-3
1.27
ted1
roo1-2
1.68
patt2-3
0.37
1 .7
0
bouch1-3Afag2-3 fag1-3
1.3
0.36
0
latz1
roon1-11
1.54
roo1 statt2-12
0.88
mcgee1-1
statt1-12
Eastern bayhead delta
- mainly gas
0 .9
0 .7
0 .5
0 .3
0 .1
ted2-10
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
Comparison of this
volumetric map with the
a map of the cumulative
BOE shows a high
degree of correlation.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
-0. 1
1 mile
77
AAPG Southwest Section Short
Course - Watney
Cumulative BOE, Minneola/Norcan East
C.I. = 20 MBOE
0
fager1-3
Western bayhead delta
0
- mainly oil
4147000
73.6
0
46.9
bouch1-3A fag2-3 fag1-3
78
39.9
0
nort1-4
01
4146000alle1-9
hind1-3
105.2
goel1-433.5
harris1-3
nort1
patt2-3
53.1
patt1-3
goell1-4
0
ted4-10
0
patt2-3
26
5.7
ted1-10
ted2-10
6
ted1-10
0
0
hall2-2
Sh
0
ted3-10
200
180
160
140
Sh
patt1
37.5
150
ted1
roo1-2
132.9
Underperforming well:
Perforated flow unit (“B”) is
not connected to flow unit
(“A”), zone of water injection
120
193.8
0
schli1-2
113.5
mcgee1-1
68.5
0
statt1-12
latz1
roon1-11
roo1 statt2-12
Eastern bayhead delta
- mainly gas
ted2-10
406000 406500 407000 407500 408000 408500 409000 409500 410000 410500 411000 411500
100
80
60
40
20
0
1 mile
http://www.suffolkestuaries.co.uk/Blyth/images/Option1-NAI.jpg
• Flow unit speed =
Kcumulative*ft/Ø*ftcumulative
• Inflection points indicative of
different flow speeds (speed
zones)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
78
AAPG Southwest Section Short
Course - Watney
S1
S1
S1
Figure 2 – Cross section on
structure
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
Patton 1-3
79
AAPG Southwest Section Short
Course - Watney
Patton #1-3
Type wireline log
A -Upper flow unit
PEF
0 6
DPHI
0.3 0
Subsea GR NPHI FUS
Depth 0 150 0.3 00.2 2
(ft)
1 cm (slab photos)
2700
Top Atokan
2710
2720
marine
flooding
surface
S1
2730
L2 HFU
2770
2790
2800
S3
vfn
Ss
5322
S2
2760
2780
5318
5320
2740
2750
5316
0.6 FUS cutoff
coincides with
break in slope
on Lorenz plot
Top Mississippian
Lower flow unit
Upper flow unit
5324
B- Middle flow unit
b
S2
fn
Ss
a
5326
5328
Core
Depth
(ft)
C- Lower flow unit
Upper flow unit
Upper flow unit
Thin-section photomicrographs of lower and upper flow units of S2 in Murfin Drilling Company 1-3 Patton well. (A) Patton
5327.3 ft (1623.76 m) (lower flow unit): bivalve in quartz sandstone. (B) Fine-grained sandstone with millimeter-shaly
laminations (Patton 5320.1 ft [1621.56 m], upper flow unit). Blue epoxy impregnated under cross nicols. The scale bar (1 mm;
0.03 in.) is in the lower left. (C) Patton 5321.8 ft (1622.08 m): quartose sandstone (lower upper flow unit). (D) Patton 5321.8 ft
(1622.08 m) (lower upper flow unit): caliche nodule (microcrystalline calcite) containing displaced sand grains suggesting insitu formation. Blue epoxy impregnation under cross nicols. Porosity developed on the right and bottom of the
photomicrograph. Scale bar shown is 1.0 mm (0.03 in.) long.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
80
AAPG Southwest Section Short
Course - Watney
Positive correlation in net pay with
cumulative production
S2 net-pay isopach map of the Norcan East field.
The thickness is expressed in feet, and the square
grid is 1 mi (1.61 km) on a side. The S2 sandstone
is limited to confines of the incised valley, and two
discrete sandstone accumulations (an eastern and
a western lobe) are visible.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
81
AAPG Southwest Section Short
Course - Watney
A
B
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
82
AAPG Southwest Section Short
Course - Watney
Is BVW related to structure or pore characteristics?
BVW Profile
0.12
0.1
BVW
0.08
0.06
0.04
0.02
0
2680
2690
2700
2710
2720
2730
2740
2750
2760
Subsea, ft
Stat2-12
Schlng
Ted1-10
Ted1
Roony 1
Pat2-3
Har1-3
Hall1-2
Stat1-12
Fag2-3
Geol1-4Ld Inj
Norton1-4
Goel1-4Mur
Pat1-3Inj
Latz1
Harris2-3
Ted4-10
Hind1-3
Pat1
McGee1-1
Porosity Profile
0.3
0.25
Phi
0.2
0.15
0.1
0.05
0
2680
2690
2700
2710
2720
2730
2740
2750
2760
Subsea, ft
Stat2-12
Schlng
Ted1-10
Ted1
Roony 1
Pat2-3
Har1-3
Hall1-2
Stat1-12
Fag2-3
Geol1-4Ld Inj
Harris2-3
Goel1-4Mur
Pat1-3Inj
Latz1
McGee1-1
Ted4-10
Hind1-3
Pat1
Log derived Sw vs elevation for S2 pay
• Colors represent saturation profiles of different wells.
• In some wells, the logs stop before saturation gets to or near 1,
whereas at others, the saturation reaches or is close to 1 at different
subsea depths.
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
83
AAPG Southwest Section Short
Course - Watney
• History match of fluid production from the western segment of the
Norcan East field.
• The green circles and line represent the historic oil rate and that
calculated by the simulator.
• History match between simulator-calculated water injection
volumes and historic volumes of injected water in western
segment of the field
• Broken black line = simulator calculated field pressure
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
84
AAPG Southwest Section Short
Course - Watney
Depositional & Petrofacies Model
for Atoka sandstone Reservoirs
The classic tripartite estuary mouth, inner estuary, and alluvial
alluvial plain
depositional model for the IVF systems is modified to accommodate
accommodate reservoir
compartmentalization introduced by multiple, tributary drainage into an estuary at
Minneola Field forming subordinate bayhead estuarine deltas
CyclothemicCyclothemic-scale (4th(4th-order) changes in sea level during the Pennsylvanian
resulted in unconformityunconformity-bounded depositional sequences
–most clearly defined on well logs in this estuarine system by correlatable
correlatable marine flooding surfaces.
A transgressivetransgressive-regressive lithofacies succession in the reservoirreservoir-bearing cycle
often consists of (from bottom to top): 1) baybay-fill shale, 2) tidaltidal-dominated bay
mouth bar to fluvial; 3) heterolithic intertidal central bay muds,
muds, silts,sands, and
carbonates; and 4) fluvial to bay mouth bar lithofacies.
Local depositional conditions vary depending on the local elevation
elevation and
position in the valley, proximity to the sediment source, and the
the mouth of the
valley.
Lithofacies reflect the landward terminus of the Atokan marine cycle
Coarser, better sorted sandstones are better reservoirs:
– reflected by lower GR, higher porosity and permeability, lower Sw and BVW
– in proximal positions in bayfill deltas in Norcan East in Minneola Field complex
Additional example of
Pennsylvanian Ooid Shoal –
Collier Flats, Missourian Swope
Limestone, Comanche County,
Kansas
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
85
AAPG Southwest Section Short
Course - Watney
Collier Flats Field – lower shelf ooid shoal
on structural break
Collier Flats Field
Lebeau (1997)
Collier Flats – Bethany Falls Ooid Shoal
Incremental oil
• 11 wells (62 max in 1982),
• Cumulative production = 2 MM bbls oil and 7.8 BCF
• Discovered 1970
• Waterflood initiated in 1998
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
86
AAPG Southwest Section Short
Course - Watney
Collier Flats Field
Bethany Falls Ls. Isopach Map
Plunging
anticlinal nose
above structural
break
Lebeau (1997)
thickest
thick
th
i
Galesburg Shale Isopach Map
th
in
ne
st
nn
er
1 mi.
thin
Top Mississippian
th
ic
ke
r
Lebeau (1997)
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
87
AAPG Southwest Section Short
Course - Watney
Lebeau (1997)
East
West
Higher permeability
and porosity beneath
lower perm. upper
half
PART 4.LITHOFACIES,
PETROPHYSICS, AND
PETROFACIES
88