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THE BARNETT SHALE (MISSISSIPPIAN) IN THE CENTRAL MIDLAND
BASIN (ANDREWS, ECTOR, MARTIN, AND MIDLAND COUNTIES)
By
CLARK H. OSTERLUND
Bachelor of Science, 2010 Baylor University
Waco, Texas
Submitted to the Graduate Faculty of The College of Science and Engineering
Texas Christian University In partial fulfillment of the requirements for the degree of
MASTER OF SCIENCE
August, 2012
Copyright By Clark Harrison Osterlund
2012
ii
ACKNOWLEDGEMENTS
First, I would like to thank Stonnie Pollock, Dexter Harmon, and the entire
exploration and IT department of Fasken Oil and Ranch Ltd., whose financial backing
made this project possible. I truly appreciate your interest in fostering my development
as a petroleum geologist and your generous help throughout the last couple of years.
I would also like to thank my parents for motivating me throughout this process
and for instilling in me the will to pursue my educational goals. In addition, I would like
to thank all of my friends that I have made at TCU these past two years for putting up
with me and for all the fun shenanigans we enjoyed. I have really had a blast here at
TCU.
Also, I would like to thank Dr. Donovan, whose teaching style stimulated my
desire to learn. I would like to thank Dr. Breyer for his initial help in getting this project
off the ground. Finally, a tremendous thanks to Dr. Helge Alsleben of TCU. Your
guidance and supreme editing skills has been a tremendous asset throughout this process.
Your willingness to make yourself accessible to students and unwavering motivational
support has made you an invaluable resource in the department.
iii
TABLE OF CONTENTS
Acknowledgements……………………………………………….….……………………ii
List of Figures…………………………………………………….………………………iv
List of Tables………………………………………………………………………...…...vi
Introduction…………………………………………………..……………………………1
Previous Work…………………………………………………………….………………3
Geographic and Geologic Setting…………………………………………………………4
Study Area and Methods………………………………………………………………….9
Division of Mississippian Strata…………………………………………………………12
Lithology…………………………………………………………………………………16
Geochemistry………………………………………………………………….…………22
TOC Estimation………………………………………………………………………….27
Age of Strata…………………………………………………………………….……….29
Sediment Accumulation…………………………………………………………….……33
Regional Context…………………………………………………………….…………..46
Structure of Study Area………………………………………………………………….48
Discussion………………………………………………………………..………………53
Production History……………………………………….………………………..……..54
Conclusions and Recommendations…………………………………..…………………57
References……………………………………………………………..…………………59
Appendix I. Geochemical Report……………………………………....……………….61
Appendix II. Paleontological Reports…………………………………………………..64
Vita
Abstract
iv
LIST OF FIGURES
1. Major geologic features of the Permian Basin region 2
2. Late Mississippian paleogeographic map 7
3. Location of Study area within the Midland Basin 10
4. Type log showing stratigraphic subdivisions 13
5. Synthetic seismogram for Mississippian section 14
6. Photomicrograph of the U.B.5 18
7. Photomicrograph of the U.B.3 18
8. Photomicrograph of the U.B.2 20
9. Photomicrograph of the U.B.2 20
10. Photomicrograph of the basal U.B.2 21
11. Photomicrograph of the L.B.3 23
12. TOC wt. % vs. Depth 24
13. Oil potential (S2) 26
14. TOC estimation 28
15. Palynological results for the Fasken Fee BM #1 SWD 30
16. Palynological results for the Fasken Fee BL #1 SWD 31
17. Palynological results for the Amoco David Fasken BS #1 32
18. Gross isopach map of the Mississippian section 34
19. Gross isopach map of Mississippian Lime 35
20. Cross section A-A’ 36
21. Gross isopach map of lower Barnett 37
22. Type log showing >14 Ωm cutoff 39
v
23. Gross isopach map for the upper Barnett 40
24. Net isopach map for the upper Barnett 41
25. Cross section B-B’ 42
26. Cross section C-C’ 43
27. Gross isopach map of the U.B.2 44
28. Net isopach map of the U.B.2 45
29. Late Mississippian paleogeographic map of the Permian Basin region 47
30. Structure contour map on top of the Woodford Shale 49
31. Structure contour map on top of the L.B.3 50
32. Structure contour map on top of the U.B.2 51
33. Structure contour map on top of the U.B.6 52
34. Idealized deposition of bioclastic debris 55
35. Regional map of oil fields producing out of the upper Barnett 56
vi
LIST OF TABLES
1. Wells used in the construction of cross section and for palynological analysis 11
2. X-ray diffraction data from the Fasken Fee BM #1 SWD well 17
3. Rock-Eval pyrolysis and TOC data 23
1
Introduction
The Permian Basin of west Texas and southeastern New Mexico covers more than
86,000 mi2 (225,000 km2), and has produced in excess of 38 billion barrels of oil from
over 3,000 fields making it the largest onshore petroleum province in the United States
(Ball, 1995; IHS, 2011). The greater Permian Basin can be divided into various distinct
entities. The Central Basin Platform divides the basin into two separate sub-basins with
the Delaware Basin to the west and the Midland Basin to the east (Fig. 1). Stratigraphic
sections from all systems of the Paleozoic are present within the basin with established
production predominantly found in Pennsylvanian-Permian sections (Ball, 1995).
Mississippian strata constitute one of the least understood successions in the
Midland Basin in West Texas, despite being located in a mature petroleum province.
Increased activity in the “Wolfberry” (Permian) has led to a resurgence of interest in
previously under-evaluated sections including Mississippian units, which have been
successfully exploited for hydrocarbons in the Barnett Shale (Mississippian) in the Fort
Worth Basin. Part of the ambiguity surrounding the Mississippian strata stems from lack
of a general consensus on what constitutes Mississippian aged rocks. The present study
examines the depositional succession and evaluates the hydrocarbon potential of
Mississippian strata, which are constrained by palynology data, in the central portion of
the Midland Basin (Andrews, Ector, Martin, and Midland Counties).
The Woodford, Mississippian Lime, lower Barnett, and upper Barnett formations
were picked on well logs and seismic sections. These picks were incorporated in the
2
Figure 1. Regional map of the Permian Basin showing major geologic features. Yellow star shows approximate location of the study area and former maximum extent of the ancestral Tobosa Basin is shown in red (modified from Frenzel et al., 1988)
3
construction of cross-sections, structure maps and isopach maps, to establish the basic
depositional framework of the section. The upper Barnett was studied in more detail and
was further subdivided into sub-units that were also mapped. Sub-units consist of gravity
flows containing more desirable reservoir properties. The results offer insight into the
late stages of the evolution of the Tobosa Basin as well as late Mississippian
paleogeography.
In addition to palynology data, X-ray diffraction analysis, thin sections,
geochemical data, and well log analysis are used in this study. These data are used to
determine the overall lithology, clay content, and organic matter in the strata. The results
are related to the overall environment of deposition and are used to identify areas that
warrant focus for future exploration.
Previous Work
As a reflection on the historic dearth of production out of Mississippian strata in
the Midland Basin, there is scant literature concerning the overall Mississippian, let alone
Barnett Shale in the subsurface. A USGS study on Mississippian Systems of the United
States presents overviews on formations as well as depositional environments (Craig and
Connor, 1979). A more local study provided a detailed stratigraphic description of the
Mississippian strata in Gaines and Andrews Counties, Texas based on wireline logs and
well cuttings (Bay, 1954). In the Delaware Basin, deposition and subsequent diagenesis
of an upper Mississippian (Chesterian) oolitic shoal in Lea County New Mexico has been
characterized (Hamilton and Asquith, 2000). Driven by the success of the Barnett Shale
in the Fort Worth Basin, Ruppel and Kane (2006) compiled an updated overview for the
4
Barnett succession in the Permian Basin. Their report highlights some of the difficulties
in the interpretation of Mississippian carbonates solely off of wireline logs, specifically
differentiating between shallow- and deep-water facies.
While specific reports of reservoir properties are primarily found in unpublished
field reports, a concise overview on late Mississippian traps in the Midland Basin is
available (Candelaria, 1990). Though the succession was called “Atoka”, its use is
equivocal in the report. Subsequent workers adopted the age constraints as definite
(Wright, 2006), which added to the confusion about the age of the strata. The reservoir
units are described as an abnormally overpressured (7,500-10,000 psi or 50-70 MPa)
succession of units comprised of silty bioclastic constituents within an overall shale
sequence. Faunal components within the bioclastic debris, includes fenestrate bryozoans,
crinoids, ostracods brachiopods, oolites, and sponge spicules. The only published TOC
values range from 1.1-4.7% TOC (Candelaria, 1990).
Geographic and Geologic Setting
The Permian Basin encompasses regions of West Texas and southern New
Mexico, covering a portion of the North American craton. The Permian Basin is bounded
on the north by the Matador Arch, on the east by the eastern shelf and western flank of
the Bend Arch, on the south by the Marathon-Ouachita fold belt, and on the west by the
Salt-Flat graben (Fig. 1) (Frenzel et al., 1988). The basin is divided into the deep
Delaware Basin to the west, and the shallower Midland Basin to the east. Separating the
Delaware and Midland Basins is the Central Basin Platform, which was a platform
capped by carbonate reefs in the Permian (Frenzel et al., 1988). Prior to the formation of
5
the Permian Basin, its predecessor, the Tobosa Basin occupied a larger area. The Tobosa
Basin existed from the Cambrian to the Early Pennsylvanian as a structural depression
(Adams, 1965; Miall, 2008). Over that time span, the Tobosa Basin subsided and
received around 7,000 feet (2,330 meters) of Paleozoic sediment (Adams, 1965).
Scant information is available on Precambrian strata as few wells penetrate
basement rocks. Thus, geophysical and outcrop studies provide limited information on
the nature of basement units (Hills, 1984). A gravity high associated with the Central
Basin Platform is attributed to layered mafic intrusions of Precambrian age (Adams and
Keller, 1996). Subaerial exposure during the early to mid-Cambrian resulted in erosion
and nondeposition prior to the onset of sandstone deposition at the end of the Cambrian
(Miall, 2008). In the Late Cambrian to Early Ordovician a northwestward transgressing
sea occupied the area, depositing strata primarily composed of sandstone and limestone,
which are mostly the carbonates of the Ellenburger Group (Adams, 1965). The
Ellenburger contains limestone and dolomite members and constrains the lateral extent of
the Tobosa Basin (Frenzel et al., 1988). During the Middle Ordovician, the Simpson
Group was deposited. It consists of alternating layers of limestone, sandstone, and dark
green shale, and does not thin over the Central Basin Platform, which was already present
in Early Ordovician time. This lack of thinning has been attributed to either a quiescent
period or increased subsidence of the uplift relative to the Tobosa Basin (Frenzel et al.,
1988). The Simpson Group is overlain by the Montoya Formation, consisting of chert
and finely crystalline carbonates. Clasts at the base of the Montoya are derived from the
Simpson Group indicating an unconformity surface, although the extent of the erosional
surface is unknown (Galley, 1958; Frenzel et al., 1988). During the Silurian and Early to
6
Middle Devonian, carbonate deposition occurred on shelf areas, with shale forming in the
deeper parts of the basin. In the late Devonian-Early Mississippian, the strata that
constitute the Woodford Shale were deposited in shallow anaerobic waters from a
transgressing sea, forming sediments with a high organic content (Hills, 1984).
Overlying the Woodford Shale is a carbonate formation commonly referred to as
“Mississippian Lime” or Lower Mississippian (Broadhead, 2009). This formation was
deposited in early to mid-Mississippian. During the Mississippian, much of the southern
North American continent was covered in a shallow, tropical epicontinental sea with an
extensive carbonate platform (Gutschick and Sandberg, 1983). The northern portions of
the Permian Basin were located on the outer margin of the platform and the southern
extent has been placed in northeastern Andrews County (Fig. 2) (Bay, 1954). Minimal
clastic input, coupled with warm tropical waters promoted carbonate buildups on the
margins, with the extent of these carbonate buildups being largely controlled by the
advancing Gondwana plate (Ruppel and Kane, 2006). In the Midland Basin, upper
Mississippian units were deposited as fine-grained clastic sequences containing
interbedded carbonates. Proximal to the shelf margins, shale comprises the majority of
strata deposited during Osagean-Merameacian time, while carbonate deposition
dominated during the Chesterian (Hamilton and Asquith, 2000). Distal to the shelf
margin, hemipelagic shale predominates the Mississippian units, with carbonate debris
transported episodically to the basin. In the mid-late Mississippian, the outer portions of
the advancing Ouachita trough had been uplifted, resulting in siliciclastic sediment being
shed off northward into the basin (Ruppel and Kane, 2006).
7
New
Mex
ico
Texa
s
CHAVES
EDDY LEA
YOAKUM TERRY
GAINES
ANDREWS
C h e s t e r i a nS h e l f
C h e s t e rS h e l fC. Erosion
C. Erosion
C. E
rosio
n
N
0 5 10
miles
Permian BasinPre-Pennsylvanian
Chester Lm. Subcrop
New Mexico
Texas
WINKLER ECTOR MIDLAND
MARTIN
DAWSON
LOVING
C h e s t e r i a nS h e l f
Chesterian Basin
Absent
104 0’0’’W 103 0’0’’W 102 0’0’’W
104 0’0’’W 103 0’0’’W 102 0’0’’W
33 0
’0’’N
32 0
’0’’N
33 0
’0’’N
32 0
’0’’N
Figure 2. Map showing the approximate location of Late Mississippian (Chesterian) shelf. Subsequent erosion over the Central Basin Platform is shown. Dashed red square outlines the study area. Figure is modified from Hamilton and Asquith (2000).
8
The Tobosa Basin ceased to be a single depositional entity in the Early
Pennsylvanian, a result of uplift of the Central Basin Platform, and the subsequent
subsidence of the Delaware and Midland Basins (Ye et al., 1996). The Strawn, Canyon,
and Cisco Formations are present above the late Mississippian-early Pennsylvanian shale
sequence in the Midland Basin. The dominant feature of the Pennsylvanian geology in
the Midland Basin is the Horseshoe Atoll, formed by sequences of Strawn, Canyon,
Cisco, and early Permian carbonates. An increase in subsidence in the latter stages of the
Pennsylvanian promoted the buildup of carbonates along the basin edges, deterring
clastic sedimentation in the basin and resulting in a starved basin environment (Adams et
al., 1951).
During the Permian, subsidence continued with average rates of subsidence,
exceeding 200 m/Ma (Scholle, 2006). Permian strata within the Permian Basin are
characterized by an overall progradation of various types of depositional environments
including sabkhas, open marine shelves, and shelf-edge organic buildups (King, 1948;
Frenzel et al., 1988; Miall, 2008; Scholle, 2006). In the Midland Basin, sediment gravity
flow processes and submarine fan systems carried sand, shale, and carbonates into the
basin (Scholle, 2006). The later stages of the Permian (Ochoan) are marked by the
initiation of a barred basin to the west and the subsequent deposition of thick evaporite
deposits (Miall, 2008).
As a result of a sustained oceanic regression following the end of the Permian,
substantial amounts of Upper Permian strata (hundreds of feet/meters) were eroded
(Hills, 1984). Triassic deposition resulted in the formation of continental red beds in both
9
the Midland and Delaware basins. Jurassic and Lower Cretaceous rocks are present in
the basins, presumably the result of subaerial exposure (Hills, 1984). Upper Cretaceous
limestone and sandstone are also present. In the Tertiary, uplift associated with Basin-
and-Range deformation caused the western side of the Permian basin to be exhumed,
resulting in the present exposures along the western margins of the Delaware Basin.
Study Area and Methods
The study area is located in the central portion of the Midland basin, covering
approximately 25 mi2 (65 km2, Fig. 3). The area includes the southeastern portion of
Andrews County, the northeastern portion of Ector County, the northern region of
Midland County, and the southwestern region of Martin County. It extends from the
basin axis to the eastern flank of the Central Basin Platform. 130 well logs from wells
that penetrate all or portions of the Mississippian section were used in this study. Well
logs from the Fasken Fee BM #1 SWD well, located in the southern region of the study
area served as the type log (Fig. 3).
A three-dimensional seismic volume covering a portion of the study area (Fig. 3)
was interpreted to increase control on structure maps. Thirteen wells are present
containing sonic logs (Δt) in the confines of the seismic survey. Synthetic seismograms
were generated using a Δt log, and then paired with the actual seismic trace at the well
location. The synthetics were stretched and squeezed using anchor points to accomplish
as high a correlation match as possible. However, not all subdivisions contained
sufficient acoustic impedance to warrant picking (see below). Horizons that did were
gridded and then converted to depth to be incorporated in the construction of structure
10
Figure 3. Map showing the location of the study area within the Midland Basin. Map also depicts the location of the type log (green star) and cross sections constructed for the study. See table 1 for the wells used in constructing the cross sections. White stars correspond to wells from palynology data was obtained.
11
Table 1. Wells used in the construction of cross sections. Type log highlighted in yellow. Asterisk (*) corresponds to wells with available palynology data. AOIL-Abandoned oil well, SWD-Salt water disposal well.
Well UWI (API Num.) County Well Name Well Number Operator WELL TD Status1 42-003-4006800 ANDREWS MABEE RANCH 14 1 FASKEN OIL AND RANCH LTD 13370 OIL2 42-003-3077900 ANDREWS FASKEN BLK /BB/ 2 MOBIL OIL CORP 13500 AOIL3 42-003-1031100 ANDREWS FASKEN DAVID AZ 1 PAN AMERICAN 13600 DRY4* 42-003-4216900 ANDREWS FEE BM 1 SWD FASKEN OIL AND RANCH LTD 14200 SWD5 42-329-3126400 MIDLAND CASSELMAN 4 1 U S OPERATING INC 13675 AOIL6 42-329-3131700 MIDLAND FASKEN 4015B FASKEN OIL AND RANCH LTD 13520 OIL7 42-329-3128400 MIDLAND SCHARBAUER 2-27 ENDEAVOR ENERGY RESOURCES LIMITED PR13352 OIL8 42-135-1071100 ECTOR SUPERIOR-RATLIFF 1 FASKEN DAVID 13335 AOIL9* 42-135-4134700 ECTOR FEE BL 1 FASKEN OIL AND RANCH LTD 14568 SWD10 42-135-3458900 ECTOR FASKEN 16 1 ANSCHUTZ CORP 13758 DRY11 42-329-0200600 MIDLAND FEE X 1 DAVID FASKEN 12714 AOIL12 42-317-3282600 MARTIN COWDEN 1 L & B OIL CO INC 13570 AOIL13 42-329-3118100 MIDLAND GETTY-FASKEN 1-19 ANSCHUTZ CORP 13697 AOIL14 42-329-3148600 MIDLAND BARRON 414 EXXON CORPORATION 12128 AOIL15 42-329-3151400 MIDLAND FASKEN D 613 EXXON CORPORATION 11700 AOIL
12
maps. Structure contour maps were constructed to show depths to the top of the
Woodford Shale and Mississippian divisions. Isopach maps and cross sections were
constructed to decipher patterns of sediment accumulation in the area.
Cuttings taken from the Fasken Fee BM #1 SWD well were submitted to Gerald
Waanders (Independent Palynologist) for palynological analysis. The ability to assign a
tentative age to the strata aids in the overall depositional interpretation as Late
Mississippian to Early Pennsylvanian paleogeography varied. In addition to cuttings,
GeoSystems LLP. completed X-Ray diffraction analyses and determined the total organic
carbon (TOC) content on nine side wall cores. XRD analyses quantitatively apply weight
percent values to various mineral phases, and offers insight into clay type present in the
strata.
Division of Mississippian Strata
“Mississippian”, as used in this study, corresponds to the strata extending from
the low gamma ray response denoting the top of Silurian-Devonian carbonates to the
lowermost portion of the overlying “Atoka Lime” carbonate (Pennsylvanian) (Fig. 4).
On seismic, the Woodford is expressed as a trough, overlying a sharp peak denoting the
top of the Silurian-Devonian carbonates (Fig. 5). A limestone formation commonly
referred to as the “Mississippian Lime” or “Lower Miss” is present atop the Woodford
Shale Formation (Ruppel and Kane, 2006). The top of the Mississippian Lime is denoted
by an abrupt suppressed gamma ray response, a function of the carbonate present beneath
the overlying shale. On seismic, the Mississippian Lime appears as a basal portion of a
peak. The remaining section between the Mississippian Lime and Atoka Lime is deemed
13
Figure 4. Type log showing stratigraphic subdivisions utilized. Purple triangles denote sidewall core locations
420034216900
FASKENFEE BM1 SWD
TD : 14,200ELEV_KB : 3,009
0 100GR [API]
100 200GR [API]
0.2 2000ILD [ohmm]
1080
011
000
1120
011
400
1160
011
800
1200
012
200
1240
0
M i
s s i
s s i
p p
i a n
Dev
onia
nP
e n
n s y
v a
n i
a n
Barn
ett S
hale
WoodfordShale
Strawn
Devonian Carbonates
P a
l
e
o z
o
i
c
Low
er B
arne
tt
Mississippian Lime
Upp
er B
arne
tt
Upper Penn. Shales
U.B.2
U.B.1
U.B.3
U.B.4
U.B.5
U.B.6
L.B.1
L.B.2
L.B.3
“Atoka Lime”
Formation
Era
Serie
s
14
Figure 5. Synthetic seismogram for the Mississippian section displaying horizons incorporated in the construction of structure maps.
15
Barnett Shale, which can be further subdivided into an upper and lower section.
Extending from the “Mississippian Lime”, the lower Barnett is on average 180 feet (55
meters) thick, is characterized by high gamma ray measurements and is associated with
resistivity spikes (>10 Ωm). The lower Barnett was divided into 3 subdivisions (L.B.1
through L.B.3). L.B.1 lies directly above the Lower Mississippian. The top of L.B.1 is
expressed by a thin (<10 feet, 3 meter) occurrence of a low gamma ray excursion along
with an abrupt decrease in resistivity. L.B.2 is an overall fining upward succession that
culminates with both a sharp increase in gamma ray (>180 API) and resistivity (>150
Ωm) values. The top of the lower Barnett, L.B.3 is expressed as a sharp gamma ray peak
coupled with a resistivity excursion on the order of 90-200 Ωm. The top of the lower
Barnett is shown to have a trough for a seismic signature.
The upper Barnett section is divided into six intervals (U.B.1 through U.B.6) on
the basis of clean gamma ray signatures, representative of an amalgamation of silty
bioclastic debris encased in shale. Overlying the lower Barnett, U.B.1 is comprised of a
calcareous-siliceous shale sequence the top of which is denoted by an excessively high
GR and resistivity excursion of >160 API and 90 Ωm, respectively. U.B.2 and U.B.3
comprise the thickest intervals in the upper Barnett, and display a coarsening upward,
funnel shaped gamma ray electrofacies, along with a spike in resistivity. U.B.2 is
representative of a small trough on seismic. U.B.4 and U.B.5 are thinner, yet still
maintain a pronounced clean gamma ray and associated resistivity spike. U.B.4 contains
a strong peak as a seismic signature. The U.B.6 is picked by a subtle clean kick in the
gamma ray response associated with a resistivity spike and the top of a peak on seismic.
16
Overlying the Barnett is a formation termed “Atoka Lime”, equivalent to the “Bend
Group” (Wright, 2006).
Lithology
Nine sidewall cores from the Mississippian section in the Fasken Fee BM #1
SWD well were submitted to GeoSystems for X-ray diffraction (XRD) analysis (Fig. 4;
Table 2). Eight cores were from the upper Barnett interval, specifically the U.B.5, U.B.3,
and U.B.2 intervals, with the remaining core taken from the lower Barnett. All but one
core from the upper Barnett was taken from the sections coinciding with the cleaner
gamma ray values.
U.B.5 is a light gray, sandy, fossiliferous, coarse-grained dolostone (Fig. 6).
Layering is observed in the form of variations in grain size, and in the semblance of
bioclastic grains. Bioclastic grains are moderately sorted and include fragmented
brachiopods and echinoderms with a size greater than 1.0 mm. Fragmentation of the
carbonate constituents in the U.B.5 as well as the underlying subdivisions supports the
notion that these bioclasts have been transported from their original environment of
deposition. Apatite is present in the sample (9 weight %) in the form of replaced bone
fragments as well as nodular form. Total clay content derived from XRD is around 3
weight %, equally comprised of illite, kaolinite, and chlorite. Quartz comprises 22 weight
% of the sample. Carbonate minerals include ferroan dolomite (52 weight %) and 12
weight % of calcite (Table 2).
The sample taken from U.B.3 is comprised of a dark gray oolitic carbonate
grainstone (Fig. 7). XRD results show that the rock contains 85% carbonate by weight
17
Tabl
e 2.
X-r
ay d
iffra
ctio
n da
ta fo
r the
Fas
ken
Fee
BM
SW
D #
1 sh
owin
g w
eigh
t % o
f var
ious
min
eral
s pr
esen
t. S
ee F
igur
e 3
for l
ocat
ion
of w
ell,
and
Figu
re 4
for i
nter
vals
sam
pled
Geo
Syst
ems L
LP
X-R
AY
DIF
FR
AC
TIO
N A
NA
LY
SIS
Fee
BM
No.
1 S
WD
Wel
l
CL
AY
MIN
ER
AL
S O
TH
ER
MIN
ER
AL
S C
AR
BO
NA
TE
MIN
ER
AL
S D
RIL
LIN
G M
UD
SO
LID
S T
OT
AL
S
SAMPLE DEPTH (Ft)
SMECTITE
ILLITE-SMECTITE
ILLITE
KAOLINITE
CHLORITE
REICHWEITE ORDERING
ILLITE-SMECTITE EXPANDABILITY %
QUARTZ
K-FELDSPAR
PLAGIOCLASE
PYRITE
ANHYDRITE
APATITE
FERROAN DOLOMITE
CALCITE
DOLOMITE
SIDERITE
OTHER CARBONATES
BENTONITE
HALITE
BARITE
OTHER SOLIDS
TOTAL CLAY MINERALS
TOTAL OTHER MINERALS
TOTAL CARBONATES
TOTAL DRILL SOLIDS
SAMPLE NUMBER
1147
7 <
11
11
R0
20
22
<1
29
52
12
333
64
0
003
1162
5
<1
<1
3
R0
25
6
4 1
1
7 75
3
3 12
85
0
006
1166
2 1
21
<1
R0
15
19
21
468
2
422
74
0
008
1166
5
3 5
<1
1 R
0 20
42
2 1
<
1 4
35
7
9
45
46
0 00
9
1166
9 1
41
<1
R0
20
45
31
1<
15
27
12
650
44
0
010
1167
7
6 6
2 3
R0
30
53
<1
1 2
1
5 19
2
17
57
26
0 01
1
1168
3 4
47
6R
020
46
2
2<
12
27
21
50
29
001
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18
Figure 6. Photomicrograph representative of the sample taken from the U.B.5. Components include quartz grains (e.g., D6), and a range of bioclastic fragments. Fragments include brachiopods (e.g., G5), bivalves (e.g., A11), and echinoderms (e.g., F3).
Figure 7. Photomicrograph of the fossiliferous ooid grainstone of the U.B.3. Abundant ooids are present (e.g., E6, H6) as well as brachiopod fragments (e.g., B11).
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Thin Section Description
Plate 1A
Plate 1B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11477Sample No.: G2142-003
Plate A - Low magnification view displaying the range of components in this rock. Terrigenous very fine to medium sand quartz grains (D-6, H-13) are moderately sorted and angular to subangular in shape. Bioclastic fragments were primarily derived from brachiopods (G-5), though bivalve (A-11) and echinoderm (F-3) debris is also present. Phosphatic nodules are common (M-13). Porosity is not observed due to complete cementation. Coarse ferroan dolomite cements the rock and partially to completely replaces bioclasts. The type and degree of replacement is not consistent. Some echinoderm fragments are completely replaced, whereas others are completely unaffected. Partial replacement is observed in some fragments. Where replacement is complete (B-4), ferroan dolomite is commonly observed displaying unit extinction consistent with replacement of a unit calcite crystal in the original grain. Quartz displays similar heterogeneity in type and degree of replacement of brachiopod fragments.
Plate B - High magnification view displaying variations in replacement fabrics of brachiopod debris. Original grain composition is calcite (stained pink, D-5). Quartz cement nucleating on detrital grains (H-10) partially replacing the grain (D-8 to F-13). Ferroan dolomite has replaced the remainder of the bioclast. Retention of original lamellar fabric (F-16, difficult to view at this magnification) confirms the replacement. Etched grain margins of an unknown calcareous bioclast (B-14) are observed locally where replacement is by ferroan dolomite.
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Thin Section Description
Plate 5A
Plate 5B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11625Sample No.: G2142-006
Plate A - Low magnification view of a fossiliferous, ooid-pelletal grainstone. Lacking early marine cement stabilization of sediment fabric, interparticle porosity was reduced as soft, micritic pellets were deformed by early burial compaction. Ooids (aragonitic) exhibit significant micritization of outer rims by marine endolithic algae (H-6). In contrast, brachiopod fragments (B-9) are composed of calcite that resisted micritization.
Plate B - High magnification view displaying allochemical grains (partially micritized ooids, I-3, C-13 and possible ostracode valve, D-10). Very fine calcite spar cement occludes most interparticle voids (C-15, H-6). Locally, dolomite is observed partially replacing grains (H-12, K-14).
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19
(Table 2) that occurs predominantly in the form of calcite present in ooids and as
intergranular cement. A more diverse faunal assemblage is present than in the U.B.5,
including ooids, brachiopods, echinoderms, bryozoans, ostracods, and bivalves (Fig. 7).
Overall the interval is well sorted with grains ranging from 0.08-0.11mm. Terrigenous
material in the cores of the ooids makes up 10 weight % of the rock (6 weight % quartz
silt and 4 weight % plagioclase). Chloritic clays constitute 3 weight % of the rock.
Five samples were chosen from the U.B.2 section, which reveals that the clean
GR response is the result of a fine-grained, dark gray limestone interval (Figs. 8 and 9).
Extensive bioturbation in the interval could have aided in the destruction of any bedding
structures present at time of deposition. Observed faunal elements are similar to the
overlying detrital sections consisting of bivalves, ostracods, echinoderms, and ooids.
Carbonate minerals (by weight %) account for a majority of the rock. Carbonate is
present as calcite, dolomite, and ferroan dolomite. Though abundant, carbonate
decreases with depth from 74% to 29%. Terrigenous mineral phases are also pervasive in
the rock with quartz comprising 19-53% of the rock by weight. Trace amounts of
plagioclase silt (1-3% by weight) are also present. Clay content accounts for 5-21weight
% of the rock and increases with depth. Clay is present in the form of illite-smectite (1-
21%), illite (2-6%), kaolinite (1-7%), and chlorite (1-6%).
The basal portion of U.B.2 is a poorly sorted calcareous and phosphatic shale
(Fig. 10). Compared to the overlying strata, this section contains higher clay content (38
weight %), including illite (20%), chlorite (7%), kaolinite (6%), and some mixed layer
illite-smectite (5%). Terrigenous constituents account for approximately one quarter of
20
Figure 8. Photomicrograph of sample taken from the U.B.2 displaying a large bivalve fragment (D8) as well as siliciclastic grains (e.g., E6).
Figure 9. Photomicrograph of sample taken from the U.B.2 showing a stylolite (C3-C18) separating two distinct textures of rock. An argillaceous texture is found above a more siliciclastic, silt-rich carbonate texture.
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Thin Section Description
Plate 12A
Plate 12B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11665Sample No.: G2142-009
Plate A- Low magnification view displaying abundant siliciclastic and carbonate grains supported by a carbonate mud (micrite) matrix that is now recrystallized to coarser calcite and partially silicified. Locally, incipient stylolites are observed (F-4, K-11). Light bitumen stain occurs throughout, though microporous peloids may be heavily stained (I-3, L-7). A large bivalve fragment lies parallel to bedding (C-8).
Plate B - High magnification view displaying the prismatic structure of a bivalve fragment as well as grain and matrix characteristics. Rounded glauconite grains (I-15, K-17) and framboidal pyrite (black, I-10) are present in trace amounts.
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Thin Section Description
Plate 16A
Plate 16B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11669Sample No.: G2142-010
Plate A - Low magnification view displaying contrasting textures of the rock separated by an incipient microstylolite (C-3 to C-18). Above the stylolite, filamentous kerogen fragments (A-8, A-14) are common and the rock matrix contains more argillaceous material. Below, the rock is a cemented carbonate grainstone. Siliciclastic silt and carbonate grains float in the “micro-grainy” portion of the rock (poikilotopic celestite cement, F-8).
Plate B - High magnification view of the rock. The original carbonate mud (micrite) matrix is now recrystallized to very fine calcite spar. Allochems include glauconite (M-9), kerogen/bitumen stain (brown, F-5), quartz silt (A-10) and poorly preserved biotic debris (L-3). Note the occurrence of framboidal pyrite (small round black specks).
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21
Figure 10. Photomicrograph of sample taken from the basal portion of the U.B.2 displaying a dark clay rich matrix with scattered bioclastic fragments (e.g., A16, B5).
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Thin Section Description
Plate 28A
Plate 28B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11724Sample No.: G2142-015
Plate A - Low magnification view displaying the dark, clay-rich matrix supporting a variety of grains including bivalve fragments (B-5, B-16), agglutinated forams (E-18) and phosphate nodules (brown, E-12, K-9). Though no laminations are observed, bedding is defined by parallel orientation of elongate grains and compacted phosphatic nodules.
Plate B - High magnification view displaying bioclastic fragments (white) and internal components of a phosphatic nodule (H-3). In many nodules, type, size and spatial arrangement of contained fragments is identical to that of the enclosing matrix, indicating nodule enlargement by replacement of matrix clay.
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22
the rock by weight. Quartz comprises 19 % weight and minor amounts of plagioclase
(3%) and potassium feldspar (1%) are present. Carbonate minerals also comprise ~25%
of the rock. Calcite in the form of bioclastic debris and as fossil fragments comprises 17
weight %. Dolomite (3%) and ferroan dolomite (6%) are also present as artifacts of
diagenesis. Other minerals that formed as a result of diagenesis are apatite (9 weight %)
and pyrite (4 weight %). Unpublished mudlogs have previously attributed this portion of
the U.B.2 coinciding with the elevated gamma ray and resistivity response as being a
coal. This interpretation, however, appears unlikely. The bulk density for a coal is
typically 1.2-1.8 g/cm3 (Serra, 1990), whereas in the study area, bulk densities for the
section of interest are on the order of 2.3-2.4 g/cm3.
The sample taken from the lower Barnett is a silty shale (Fig. 11). Clays dominate
the rock and comprise 63 weight %. Illite is the most prevalent clay mineral (46%) with
the remainder comprised of mixed layer illite-smectite (8%), chlorite (5%), and kaolinite
(4%). Terrigenous components account for little of the overall weight percent with only
plagioclase (3%) and potassium feldspar (1%) present. Quartz makes up 28% of the rock
primarily as a result of recrystallization. Carbonates are scarce in the lower Barnett with
ferroan dolomite the sole phase present contributing <1 weight %.
Geochemistry
The same samples subjected to XRD were also analyzed for total organic carbon
(TOC) content. Samples taken from the upper Barnett contain relatively low values (<1
weight % TOC), although an overall increase is seen with depth from 0.04-0.38 weight %
(Table 3) (Fig. 12). The overall dearth of TOC present in the upper Barnett samples is
23
Figure 11. Photomicrograph of sample taken from the L.B.3 showing the overall texture of the rock. Bioclasts (e.g., B17) are scarce. Light horizontal masses are clay probably from the backfill of feeding traces.
Table 3. Rock-Eval pyrolysis data for the Fasken Fee BM #1 SWD well.
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Thin Section Description
Plate 32A
Plate 32B
Company: Fasken Oil and Ranch, Ltd.Well: Fee BM No. 1 SWDCounty: AndrewsState: TexasDepth (Ft): 11946Sample No.: G2142-018
Plate A - Low magnification view displaying textural and fabric elements typical of this rock. Bioclasts (C-17) are locally replaced by phosphatic material. Agglutinated foraminifera (B-13, D-6) are typically recrystallized to chert (microcrystalline) quartz. Some agglutinated foraminifera contain authigenic pyrite in the remnants of the internal chamber (J-10). Light colored lensoid masses are predominantly clay, and represent back fill in horizontal feeding traces.
Plate B - High magnification view displaying the rock matrix and flake-like clay fragments within horizontal burrows (G-10, F-17). Early diagenetic pyrite displays compactional deformation of laminae around the mass (D-15). Agglutinated foraminifera (F-4, I-3) are common.
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24
Figure 12. TOC (weight %) vs. depth (MD)
0 20 40 60 80 100
11,400
11,500
11,600
11,700
11,800
11,900
12,000
12,100
0 2 4 6 8 10
Mea
sure
d D
epth
, MD
(ft)
Total Organic Carbon (wt% HC)
TOC % Carbonate
% Carbonate
GoodPoor Fair Excellent
TOC vs. Depth (MD)
25
expected, in that they were taken from mass gravity deposits comprised of carbonate
debris, not an organic rich mudstone. The basal portion of the U.B.2. contains 4.65
weight %, whereas the lower Barnett contains the highest TOC value among the samples
(5.3 weight %). These values overlap with values ranging from 1.1-4.7 weight % TOC
south of the study area (Candelaria, 1990). In the neighboring Delaware Basin, TOC
values have been found to be on the order of 4.4 weight % (Kinley, 2006).
As part of the Rock-Eval Pyrolysis, samples were heated to determine how much
petroleum has already been generated and how much generation potential is remaining.
At approximately 572°F (300°C) previously generated hydrocarbons in the source rock
are expelled creating a peak and the content of the hydrocarbons coinciding with the
numbers C1-C25 are recorded. The values for S1 correspond to the area beneath the
peak, representative of hydrocarbons that have already been produced in the rock and
failed to migrate out (Bjorlykke, 2010). A subsequent peak (S2) forms as the sample is
subjected to 1022°F (550°C). This second peak represents the samples ability to continue
to generate hydrocarbons.
Samples taken from the gravity flows contained paltry S1 values ranging from
0.04 to 0.29 mg HC/g (Table 3) (Fig. 13). S2 values for the upper gravity-flows are also
low, while increasing with depth from 0.11 to 0.67 mg HC/g. Samples taken from the
U.B.2 and the lower Barnett Shale contain heightened values. The U.B.2 shale sample
has a S1 value on the order of 3.56 mg HC/g, and an S2 value of 5.57 mg HC/g. The
lower Barnett contains the highest S1 value (4.88 mg HC/g) out of all samples and an S2
value of 5.45 mg HC/g.
26
Figure 13. Oil potential (S2) vs. Depth (MD)
11,400
11,500
11,600
11,700
11,800
11,900
12,000
12,1000 5 10 15 20
Mea
sure
d D
epth
, MD
(ft)
Oil Potential S2 (mg HC/g)
Good - ExcellentPoor Fair
Oil Potential S2
27
TOC Estimation
TOC content can be obtained indirectly from the inverse relationship of the
gamma ray (GR) and true resistivity (Rt) curves (Heslop, 2010). This method was used to
estimate TOC rich sections in the study area. The method calls for the curves to be
plotted on the same track with one of the scales reversed. In a non-source shale (TOC
lean) the curves tend to track, whereas in a source shale (TOC rich) separation of the
curves will occur. The separation is achieved because both of the logs increase in value.
A GR scale of 175-50 API units and a resistivity logarithmic scale of 0.5-500 Ωm
were applied to wells containing suitable curves. The results reveal that the upper
Barnett section is relatively TOC lean, whereas the greater separation between the two
curves in the lower Barnett section suggests higher TOC concentrations (Fig. 14).
To apply a quantitative value to the degree of separation the following formula,
modified from Heslop (2010) was used (Fig. 14):
Equation 1: TOC= (ΔGR+ΔRt)*30/(GRTOC + log10(RtTOC)),
where ΔGR and ΔRt are the separation of the curve from the base line, GRTOC is
representative of the respective log values present in the area of separation, and a value of
30 is applied to scale the separation. GRTOC and RtTOC are TOC values originally
calibrated to lab obtained TOC values.
28
Figure 14. Example of TOC estimates using the Heslop method described above. Notice how the curves track each other in the upper Barnett section, whereas separation occurs in the lower Barnett. TOT= Total gas content observed from the mudlog, HTOC= the TOC curve generated from equation 1.
420034216900
FASKENFEE BM1 SWD
TD : 14,200ELEV_KB : 3,009
0 100GR [API]
100 200GR [API]
1120
011
400
1160
011
800
1200
012
200
1240
0
M i
s s i
s s i
p p
i a n
Dev
onia
nP
e n
n .
Barn
ett S
hale
WoodfordShale
Devonian Carbonates
P a
l
e
o z
o
i
c
Low
er B
arne
tt
Mississippian Lime
Upp
er B
arne
tt
U.B.2
U.B.1
U.B.3
U.B.4
U.B.5
U.B.6
L.B.1
L.B.2
L.B.3
“Atoka Lime”
0.2 2000ILD [ohmm]
175 50GR [API]
0.5 500ILD [ohmm]
0 10HTOC
0 1000TOT [GU]
Formation
29
Age of Strata
Historically, fields producing from the bioclastic debris flows within the upper
Barnett have been reported as Mississippian (Chesterian) or Pennsylvanian (Atokan) in
age. R.V. Hollingsworth (Unpublished Paleontological Reports) identified the “Atoka
Lime” on the occurrence of Atoka fusulines. Underlying the “Atoka Lime”,
Hollingsworth placed the top of the Barnett Shale on the basis of a color change in
conjunction with a change in lithology, due to an absence of fusulines. Poor age
constraints promote ambiguity among operators when discussing the formation.
To reduce the uncertainty surrounding the age, samples from three wells were
submitted to Gerald Waanders (consulting Palynologist) for analysis. Cuttings were
collected from the Fasken Fee BM # 1 SWD, Fasken Fee BL#1 SWD, and the Amoco
David Fasken BS #1 wells. The BM and BS wells cuttings were compiled into 50 feet
(15 meters) increments, while the BL well had sample intervals of 60 feet (18 meters).
The occurrences of assemblages were paired with tops picked from logs. For the Amoco
David Fasken BS #1 well, open hole logs were only available through the U.B.2
formation and the remaining tops were picked from the mud log. The results reveal that
the Mississippian section in the study area encompasses the Chesterian, Meramecian,
Osagean, and possibly the Kinderhookian stages (Figs. 15, 16 and 17, Appendix 1).
30
Figure 15. Palynology results tied into the Fasken Fee BM #1 SWD well.
31
Figure 16. Palynology results tied into the Fasken Fee BL #1 SWD well.
32
Figure 17. Palynology results tied into the Amoco David Fasken BS #1 well.
33
The top of the U.B.6 was found to be conformable with the first occurrences of
Chesterian spores present in all three wells. The top of the Meramecian coincided with
the top U.B.3 to the base of the U.B.2. Osagean assemblages of spores were first
recorded around the shale marker denoting the top of the U.B.1 and encompass the
entirety of the U.B.1, lower Barnett section, and the upper portion of the Mississippian
Lime. Due to possible uphole contamination of samples, a tentative Kinderhookian age
was assigned to the basal portion of the Mississippian Lime and the entirety of the
Woodford Shale.
Sediment Accumulation
Isopach maps and cross sections show the patterns of sediment distribution and
accumulation. Thickness presented on maps and cross sections portray the thickness of
units following compaction. The Mississippian section ranges in thickness from
approximately 980 feet (300 meters) in the northwest to 720 feet (220 meters) in the
southeast (Fig. 18). Noticeable thinning of the section to 190 feet (60 meters) is observed
at the McRae Farm #2 well drilled on an anticlinal structure in the southwestern region of
the study area. The Mississippian Lime is thickest in the northwest, where it is 290 feet
(90 meters) thick (Fig. 19). Thickness decreases to approximately 80 feet (25 meters) in
the southeast. This thinning can be readily seen on cross sections along depositional dip
(Fig. 20). Thickness of the lower Barnett varies from 210 feet (65 meters) to 136 feet (20
meters) (Fig. 21). However, a gross isopach map for the entire lower Barnett interval
depicts thickness decreasing to the east, suggesting that a major depocenter was located
to the west.
34
Figure 18. Gross isopach map for the entire Mississippian section. The overall westward thickening, and the thinning over the McRae farm #2 well are readily apparent. Contour interval is 25 ft.
3
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33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
750775
775
800
800
800
825
825
8 25
528
528
52
8
850
850
850
058
850
058
578
875
875
875
578
875
578
900
900
900
900
009009
925
925
925
529
925
529
925
925
950
950
059
059
059
059
950
95
0
904
877
931
910
941
850
930
883
962
951907
845
920
942
885
936
961
932
976
938936
843832
824
722
911
895
862
795
854
779786
842
805899 820
794
830
888
796
871
797
843
830825
813
813
951
939
941
914
936
893
925934
972
965
867
976
756
970
969
32°00'N
102°25'W 102°20'W 102°15'W 102°10'W
32°0
0'N
102°05
32°05'N32
°05'
N32 °1 0'N
32°1
0'N
32 °1 5'N32
°15'
N
02°30'W 102°25'W 102°20'W 102°15'W
32°2
0'N
975950925900875850825800775750
Gross Mississippian
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
GROSS_MISSISSIPPIAN - GROSS_MISS_
CONTOURSGROSS_MISSISSIPPIAN - ISOPACH4/23 - Isopach Thickness
GROSS_MISSISSIPPIANISOPACH423.GRDContour Interval = 25
750
775
800
825
850
875
900
925
950
975
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 23, 2012
PETRA 5/23/2012 8:15:06 PM
35
Figure 19. Gross isopach map for the Mississippian Lime. Notice the overall southeastward thinning, which likely reflects the southward dipping shelf. Contour interval is 10 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
80
09
100
100
110
110
120
120
120
02
1
130
130
031
140
140
140
041
150
15
0
150
051
150
061160
160
160
170
170
170
180
180
180
190
190
190
19
0
200
20 0
200
200
210
210
21021
0
220
220
22022
0
230
230
230
230
240
240
240
240
250
250
250
250
260
260
260
260
270
270
072
280
280
280
266
249
280
246
228
204
223
245
254
221203
278
199
207
290
234
211
222
208
206192
161155
116
78
175
155
141
121
141
112112
127
129166 120
130
122
154
120
134
112
137
120121
122
265
197
238
246
239
251
240
251248
204
242
262
237
95
216
3002802602402202001801601401201008060
GrossLower Miss. Lime
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
LOWER_MISS - ISOPACH
CONTOURSLOWER_MISS - ISOPACH - Isopach Thickness
LOWER_MISSISOPACH.GRDContour Interval = 10
60 80 100
120
140
160
180
200
220
240
260
280
300
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 12, 2012
PETRA 5/12/2012 2:10:11 AM
Andrews
Ector
Martin
Midland102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N32
°15'
N
102°25'W 102°20'W 102°15'W
36
TD
: 1
3,3
70
EL
EV
_K
B :
2,9
58
TD
: 1
3,5
00
EL
EV
_K
B :
2,9
27
TD
: 1
3,6
00
EL
EV
_G
R :
2,9
18
TD
: 1
4,2
00
EL
EV
_K
B :
3,0
09
TD
: 1
3,6
75
EL
EV
_K
B :
2,9
12
TD
: 1
3,5
20
EL
EV
_K
B :
2,8
85
TD
: 1
3,3
52
EL
EV
_K
B :
2,8
80
<3
.41
MI>
<2
.50
MI>
<3
.22
MI>
<5
.16
MI>
<2
.04
MI>
<2
.06
MI>
11200 11400 11600 11800 12000 12200 12400 12600
10800 11000 11200 11400 11600 11800 12000 12200
11000 11200 11400 11600 11800 12000 12200 12400
11200 11400 11600 11800 12000 12200 12400
11000 11200 11400 11600 11800 12000 12200 12400
11000 11200 11400 11600 11800 12000 12200 12400
11000 11200 11400 11600 11800 12000 12200
U_B
_6
U_B
_5
U_B
_4
U_B
_3
U_B
_2
U_B
_1
L_B
_3
L_B
_2
L_B
_1
LO
WE
R
MIS
SIS
SIP
PIA
N
LIM
N
WO
OD
FO
RD
DE
VO
NIA
N
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
12
34
56
7
A’A Fi
gure
20.
Str
atig
raph
ic c
ross
sect
ion
A-A
’ alo
ng d
epos
ition
al d
ip, f
latte
ned
on th
e U
.B.6
show
s the
ove
rall
decr
ease
in M
issi
ssip
pian
lim
e th
ickn
ess w
ith d
ip.
See
Figu
re 3
for l
ocat
ion
of th
e se
ctio
n.
37
Figure 21. Gross isopach map constructed on the lower Barnett. The map shows a westward thickening. Contour interval is 10 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
135
5415
51
155
551
551
551
561
165
165
561
165
571
175
175
175
571
175
581
185
581
591
591
194
168
201
167
183
157
176
174
192
171178
137
172
162
209
195
178
194
173
174161
155153
154
163
158
165
146
157
156143
157
146155 137
152
153
162
156
162
160
153
152
158
154
158
136
192
162
189
189
198
196
193
192193
195
174
170
192
162
176
215205195185175165155145135
Gross Lower Barnett
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
LOWERBARNETT3 - GROSS_LOWER_BARNETT
CONTOURSLOWERBARNETT3 - GROSS_LOWER_BARNETT - Isopach Thickness
LOWERBARNETT3GROSS_LOWER_BARNETT.GRDContour Interval = 10
135
145
155
165
175
185
195
205
215
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 12, 2012
PETRA 5/12/2012 1:07:46 AM
Andrews
Ector
Martin
Midland102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
38
To differentiate between basinal, siliciclastic-rich, shale and bioclastic debris flow
strata in the upper Barnett, a cutoff of 14 Ωm is applied to the deep resistivity log (Fig.
22). Anything reading greater than 14 Ωm is taken to be representative of the more
permeable debris flow units, and anything less is considered “tighter” shale. It should be
noted, that a gamma ray cutoff would have been preferred, but due to various vintages of
gamma ray curves, displaying a wide range of values for the cleaner sections, a gamma
ray cutoff is misrepresentative of the debris flow section. A gross isopach map for the
upper Barnett section shows thickness increasing north to south (Fig. 23), suggesting that
the basin depocenter has slightly migrated to the south when compared with the
underlying lower Barnett. When the cutoff of greater than 14 Ωm is applied to the
section, a striking contrast is observed. With that cutoff, the section decreases from north
to south (Fig. 24), suggesting a northern source for the upper Barnett carbonate debris.
Cross sections along depositional strike also show an overall decrease towards the south
in the electrofacies representative of the carbonate debris (Fig. 25 and 26). Since
established production has been achieved from the U.B.2 bioclastic debris (see below),
gross and net isopach maps were also constructed for the U.B.2 (Fig. 27 and 28). Similar
patterns to the gross and net isopach maps for the upper Barnett emerge for the U.B.2.
While the gross isopach map for U.B.2 shows thickening to the south, the net isopach
map again shows a thick in the north and thin in the south. The pattern of the net isopach
maps suggests a northern source for the mass gravity flows.
39
Figure 22. Type log showing the >14 Ωm cutoff used to differentiate between shales and bioclastic debris flows. Shaded areas coincide with >14 Ωm.
42-003-42169
FASKEN1 SWD
TD : 14,200ELEV_KB : 3,009
0 100GR [API]
100 200GR [API]
0.2 2000ILD [ohmm]
1080
011
000
1120
011
400
1160
011
800
1200
012
200
1240
0
M i
s s i
s s i
p p
i a n
Dev
onia
nP
e n
n s y
v a
n i
a n
Barn
ett S
hale
WoodfordShale
Strawn Formation
Devonian Carbonates
P a
l
e
o z
o
i
c
Low
er B
arne
tt
Mississippian Lime
Upp
er B
arne
tt
Upper Penn. Shales
U.B.2
U.B.1
U.B.3
U.B.4
U.B.5
U.B.6
L.B.1
L.B.2
L.B.3
“Atoka Lime”
40
Figure 23. Gross isopach map for the upper Barnett. The map pattern suggests that the main depocenter has shifted slightly towards the south since the deposition of the lower Barnett. Contour interval is 25 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
004
524
524
524
450
450
054
054
054
574
574
574
475
574
500
500
500
500
500
525525
525
525
525
525
525
525
055
055
5 5 0
055
55 0
055
055
575575
575
575
444
460
450
498
530
489
530
464
517
558526
430
550
573
386
507
572
517
596
558582
527524
554
573
583
557
528
556
510532
558
530578 564
512
555
573
520
576
525
553
559
540
550
533
412
587
592
511
506
477
489
471
483493
573
549
435
547
499
471
558
625600575550525500475450425400
Gross Upper Barnett
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
GROSS_UPPER_BARNETT - GROSS_UPPER_BARNETT
CONTOURSGROSS_UPPER_BARNETT - GROSS_UPPER_BARNETT - U_B_6 [SLP] - L_B_3 [SLP] ISOPACH
GROSS_UPPER_BARNETTGROSS_UPPER_BARNETT.GRDContour Interval = 25
400
425
450
475
500
525
550
575
600
625
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 12, 2012
PETRA 5/12/2012 2:08:28 AM
Andrews
Ector
Martin
Midland102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
41
Figure 24. Net isopach map for the upper Barnett showing a southward thinning of strata. Contour interval is 10 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
20
20
02
03
03
03
04
04
04
04
05
50
50 50
50
06
06
06
06
06
06
07
07
07
07
07
07
07
80 08
08
08
08
08
08
08
08
90
90 90
09
9009
09
90
90
100
001
100
001
73
94
80
94
70
111102
64
67
86
56
34
22
52
5262
90
69
19
41
7545
18 17
36
2918
35
19
49
20
16
56
22
46
11
32
60
47
55
8048
5679
28
74
93
31
77
101
110
1101009080706050403020
Net Upper Barnett
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
GROSS_UPPER_BARNETTCO3 - GROSS>14
CONTOURSGROSS_UPPER_BARNETTCO3 - GROSS>14 - User Footage
GROSS_UPPER_BARNETTCO3GROSS14.GRDContour Interval = 10
20 30 40 50 60 70 80 90 100
110
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 12, 2012
PETRA 5/12/2012 2:35:21 AM
Andrews
Ector
Martin
Midland102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
42
TD
: 1
3,3
35
ELE
V_K
B : 2
,994
TD
: 1
4,5
68
ELE
V_K
B : 2
,969
TD
: 1
3,7
58
ELE
V_K
B : 2
,936
TD
: 1
2,7
14
ELE
V_K
B : 2
,913
TD
: 1
3,5
70
ELE
V_K
B : 2
,902
<4.6
7M
I><
1.8
1M
I><
3.1
8M
I><
4.4
1M
I>
10200 10400 10600 10800 11000 11200 11400 11600
10800 11000 11200 11400 11600 11800 12000 12200
11000 11200 11400 11600 11800 12000 12200
11200 11400 11600 11800 12000 12200 12400
10800 11000 11200 11400 11600 11800 12000
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
Gr
Res.
U_B
_6
U_B
_5
U_B
_4
U_B
_3
U_B
_2
U_B
_1
L_B
_3
L_B
_2
L_B
_1
LO
WE
R M
ISS
ISS
IPP
IAN
LIM
ES
TO
NE
WO
OD
FO
RD
DE
VO
NIA
N
BB’
89
1012
11
Figu
re 2
5. S
tratig
raph
ic c
ross
sect
ion
B-B
’, fla
ttene
d on
the
top
of th
e U
.B.6
,alo
ng
depo
sitio
nal s
trike
. N
otic
e th
e ov
eral
l thi
ckne
ss o
f the
U.B
.2 c
lean
GR
ele
ctro
faci
es.
For
loca
tion
of th
e se
ctio
n se
e Fi
gure
3.
43
Figure 26. Stratigraphic cross section C-C’, flattened on the U.B.6, along depositional strike showing an overall decrease in the clean GR sections for the U.B.2, which represents the bioclastic debris flows, when compared to cross section B-B’ located to the north. For location of the cross section see Figure 3.
TD : 11,700
ELEV_KB : 2,880
TD : 12,128
ELEV_KB : 2,870
TD : 13,520
ELEV_KB : 2,885
TD : 13,697
ELEV_KB : 2,916
<1.14MI> <1.13MI> <3.25MI>
11
000
11
200
11
400
11
600
11
800
12
000
12
200
11
000
11
200
11
400
11
600
11
800
12
000
12
200
12
400
11
000
11
200
11
400
11
600
11
800
12
000
12
200
12
400
11
000
11
200
11
400
11
600
11
800
12
000
12
200
12
400
U_B_6
U_B_5
U_B_4
U_B_3
U_B_2
U_B_1
L_B_3
L_B_2
L_B_1
LOWER MISSISSIPPIAN
LIMESTONE
WOODFORD
DEVONIAN
Gr Res. Gr Res. Gr Res. Gr Res.
C’ C1361415
44
Figure 27. Gross isopach map for the U.B.2 showing a northwestward thinning. Contour interval is 20 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
60
60
60 06
80
8 0
80
08
08
08
08
08
001
100
100
100100
10
0
100
001
100
100
021021
021021
021
120
041
041
140
041
0
41
061
160
160
081
71
114
88
108
48
46
58
52
94
8056
6253
99
67
124
73
84
170
157
169
145
159
160
159142
113117106
127
129
110
107
152
112 101
143
117
116
172
125
111114
115102
107
148
111
101105
103
118
91
96
112
101
150
82
90
81
96
77
9387
187
96
100
174
66
100
95154
76
137
32°00'N
102°25'W 102°20'W 102°15'W 102°10'W
32°0
0'N
102°05
32°05'N
32°0
5'N
32 °1 0'N
32°1
0'N
32 °1 5'N
32°1
5'N
02°30'W 102°25'W 102°20'W 102°15'W
32°2
0'N
18016014012010080604020
GrossU.B.2
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
UB2 - FINAL_ISOPACH
CONTOURSUB2 - FINAL_ISOPACH - Isopach Thickness
UB2FINAL_ISOPACH.GRDContour Interval = 20
20 40 60 80 100
120
140
160
180
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 23, 2012
PETRA 5/23/2012 8:12:56 PM
45
Figure 28. Net isopach map constructed for the U.B.2 showing a southward thinning. Contour interval is 10 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
00
10
10
10
01
10
20
20
20
20
20
20
2020
02
02
30
30
30 30
30
30 30
04
19
61
45
44
25
3323
25
28
29
7
21
2519
34
31
14
24
12
1816
5
615
9
2
0
2220
1725
18 21
42313
13
20
13
21
24
11
1616
913
11
22
56
21
22
32
32°00'N
102°25'W 102°20'W 102°15'W 102°10'W
32°0
0'N
102°05
32°05'N32
°05'
N32 °1 0'N
32°1
0'N
32 °1 5'N32
°15'
N
02°30'W 102°25'W 102°20'W 102°15'W
32°2
0'N
50403020100
Net U.B.2
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
MOONLIGHT_GROSS - MOONLIGHT>14
CONTOURSUBS1 - GROSS>14 - User Footage
UBS1net greater14.GRDContour Interval = 10
0 10 20 30 40 50
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 23, 2012
PETRA 5/23/2012 8:01:52 PM
46
Regional Context
Carbonates sourced from a platform in the north and shale deposited in a basin in
the south characterizes the two distinct lithologies present in Mississippian strata (Ruppel
and Kane, 2006) (Fig. 29). Carbonates were deposited up dip on a southwest- to west-
dipping shelf grading into deeper water limestone, progressively thinning basinward into
basinal shale that comprises the Barnett Shale Formation. The southernmost extent of the
carbonate platform is located north of the study area in Gaines and northern Andrews
Counties (Bay, 1954). The shelf has been eroded over the Central Basin Platform, but
remains present in central Lea County, New Mexico (Hamilton and Asquith, 2000).
Elsewhere in the basin, hemipelagic sedimentation dominated resulting in the formation
of siliceous shale. Maximum thickness of shale is recorded in portions of Reeves and
Ward County (Craig and Conner, 1979; Wright, 1979). The positive features of the
Diablo uplift and Pedernal Massif defined the southern and western limits of the basin
(Fig. 29) and provided the bulk of the siliciclastic sediment to the basin. Starting around
the mid-late Mississippian, uplifted portions of the advancing Ouachita trough also
served to provide siliciclastic input in the southern regions of the basin (Ruppel and
Kane, 2006).
Existing isopach maps for the Mississippian in the Permian Basin show a major
depocenter roughly corresponding to the locality of the ancestral Central Basin Platform
with strata thinning eastward (Fig. 29; Wright, 1979). The study area falls just shy of the
1000 feet contour line on the isopach map for Mississippian strata. Observed thickness in
the study for gross Mississippian strata is 975 feet (300 meters). The eastward thinning is
also reflected in the gross Mississippian isopach map for the study area.
47
Figure 29. Paleogeographic map showing the Permian Basin region during the late Mississippian. Isopach map shows a major depocenter corresponding to the western portion of the study area (yellow star). Contour interval is 250 feet. Map is after Wright (1979) and Ruppel and Kane (2006).
48
Structure of Study Area
Accumulation of Mississippian sediment varied minimally from that of the
Devonian, such that the major depocenters of the Tobosa Basin maintained their role
(Wright, 1979). During the Late Mississippian, the Tobosa Basin was subjected to
various structural changes, including the initial pulses of the Marathon-Ouachita orogeny.
The emergence of the Central Basin Platform during this time resulted in the division of
the Tobosa Basin into two separate depositional entities with the Delaware Basin to the
west and the Midland Basin to the east. Regionally, the Midland Basin displays an
asymmetric character, with the basin axis running approximately north-south, deepening
to the west.
Regional dip is steepest in the west along the flanks of the Central Basin Platform
and lessens to the east towards Martin County. Structure contour maps constructed on
the top of the Woodford, the top of the L.B.3.the U.B.2, and U.B.6 all reflect the same
overall geometry (Figs. 30-33). The measured depth to the top of the Mississippian
section in the study area ranges from 9,000 feet (2,750 meters) in the west to 11,500 feet
(3,500 meters) in the east. Locally, anticlinal and synclinal features are recognized in the
southern portion of the study area. These are presumably a by-product of the structural
regime changes associated with deformation along the flanks of the Central Basin
Platform.
49
Figure 30. Structure contour map of the top of the Woodford Shale. The map depicts a post-depositional low that trends north-south throughout the central portion of the study area. Contour interval is 100 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
1617
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
0049-
0039-
0039-- 93
00
0039-
- 9300
- 920
0
0029-
- 9200
0029
-
- 9200
- 9200
- 9 200
002
9 -
0029-
001
9-
- 910
0
- 910
0
- 9100
0019-
- 910
00019-
- 900
0
- 9000
- 900
0
-900
0
0009-
0009-
- 9000
-890
0- 8900
- 890
0- 8
900
0098-
- 8800
- 880
0-8
8 00
- 8700
- 870
0-8
700
- 8600
-860
0
0068
-
- 8500
-850
0
0058
-
- 8400
-840
0
0048
-
- 8300
-830
0
- 8200
-820
0
- 8100
-810
0
-8,124
-8,966
-8,074
-8,978
-9,261
-9,171-9,293
-8,987
-8,192
-9,284-9,251
-9,343
-9,114
-9,348
-9,152
-8,444
-8,976
-8,676
-9,262
-8,927-9,108
-8,931
-8,903
-9,072
-8,917
-9,306
-9,255
-9,174
-9,130-9,159
-8,979-8,987
-9,025
-8,974-9,274 -9,110
-8,970
-9,036
-9,267
-9,026
-9,264
-9,027
-9,220
-9,077-9,028
-9,143
-9,357
-9,094
-8,141
-8,116
-8,218
-8,102
-8,060
-8,188-8,111
-8,785
-9,118
-9,321
-8,433
-9,042
-9,316
-9,021
-8100-8200-8300-8400-8500-8600-8700-8800-8900-9000-9100-9200-9300-9400-9500
Woodford Structure Map
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
FMTOPS - WOODFORD[SLP] (SS) (FEET)
CONTOURSFMTOPS - WOODFORD May 3 - WOODFORD
FMTOPSWOODFORD Final.GRDContour Interval = 100
-950
0
-940
0
-930
0
-920
0
-910
0
-900
0
-890
0
-880
0
-870
0
-860
0
-850
0
-840
0
-830
0
-820
0
-810
0
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 11, 2012
PETRA 5/11/2012 7:54:33 PM
102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
50
Figure 31. Structure contour map of the top of the L.B.3. Folds are present in the eastern and southeastern portion of the area. Contour interval is 100 ft.
102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
- 890
0
- 8900
- 8900
0098-
0098-
0098-0098-
-890
0
- 880
0
0088
-
- 880
0
- 8800
-88 0
0
- 880
0
- 8800
00 88-
- 8800
- 8800
0088-
0088-
- 8800
- 8800
- 870
0- 8
700
0078
-
- 870
0- 8700
0078-
-8700
-870
0
0078
-
- 8600
- 860
0-8
600
- 860
0- 8600
0068-- 8
500
- 850
0-8
5 00
-850
0
- 840
0
- 840
0- 8
400
-840
0
- 830
0
- 830
0- 8
300
-830
0
- 8
200
- 820
0- 8
200
0028
-
- 810
0
- 810
0- 8
100
- 800
0
-800
0- 8
000
- 790
0
-790
0- 7
900
- 7800
-780
0
- 780
0
- 7700
- 770
0
- 770
0
- 760
0- 7
600
0057-
- 750
0
- 750
0
-740
0
- 7
400- 7300
-7,664
-8,550
-7,593
-8,565
-8,849
-8,810-8,894
-8,568
-7,747
-8,892-8,870
-8,928
-8,744
-8,979
-8,654
-8,015
-8,587
-8,261
-8,881
-8,547-8,755
-8,615
-8,595
-8,802
-8,967
-8,943
-8,863
-8,863-8,861
-8,710-8,733
-8,740
-8,699-8,953 -8,853
-8,688
-8,761
-8,951
-8,749
-8,968
-8,755
-8,930
-8,805
-8,871
-8,752
-8,863
-8,956
-8,590
-8,734
-7,714
-7,680
-7,781
-7,655
-7,638
-7,745-7,670
-8,387
-8,702
-8,889
-8,005
-8,784
-8,803
-8,923
-8,637
-7200-7300-7400-7500-7600-7700-7800-7900-8000-8100-8200-8300-8400-8500-8600-8700-8800-8900-9000-9100-9200
L.B.3 Structure Map
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
FMTOPS - L_B_3[SLP] (SS) (FEET)
CONTOURSFMTOPS - L_B_3 [SLP] - Top of Lower Barnett Shale
FMTOPSL_B_3SLP.GRDContour Interval = 100
-920
0
-910
0
-890
0
-870
0
-850
0
-830
0
-810
0
-790
0
-770
0
-750
0
-730
0
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 11, 2012
PETRA 5/11/2012 9:03:21 PM
Andrews
Ector
Martin
Midland
51
Figure 32. Structure contour map atop of the U.B.2 subdivision. Overall geometry is similar to the preceding maps. Contour interval is 100 feet.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
0098-
-880
0
0088-00
88-
- 870
0
- 870
0
007
8-
0078-- 8 700
- 8700
- 8700
-870
0
0078-
- 8700
0078-
0078-00
78-
- 860
0
- 8600
-860
0
- 8600-8
600
- 8
600
0068-
0068-
0 068-
- 8600
- 8600
0068-
006
8-
- 850
0
00
58-
- 8500
- 850
0
-850
0
- 8500
0058-
00
58-
0058-
0058-
- 8500
00
58-
- 8400
- 840
0-8
400
- 8400
0048
-
0048-
0048-- 8
40
0
- 830
0
-830
0- 8
300
0038-
- 820
0
-820
0
- 820
0
0028
-
- 810
0
-810
0
- 810
0
- 800
0
-800
0
- 800
0
- 7900
-790
0
- 790
0
- 7800
-780
0
- 780
0
- 770
0
-770
0
-770
0
- 7600
-760
0
0067
-
- 7500
- 750
0
- 7400
- 740
0
- 7300
- 730
0
- 720
0
- 7200
- 7100
- 7100
-7,350
-8,276
-7,273
-8,291
-8,552
-8,513-8,588
-8,328
-7,440
-8,617-8,633
-8,674
-8,604
-8,710
-8,605
-8,499
-8,688
-8,643
-8,449
-7,678
-8,258
-7,951
-8,565
-8,006
-8,199-7,959
-8,219-8,466
-8,363
-8,368
-8,388
-8,476
-8,697
-8,694
-8,631
-8,647-8,614
-8,484
-8,711 -8,642
-8,446
-8,700
-8,529
-8,689
-8,525
-8,693-8,649
-8,689 -8,637-8,659
-8,503
-8,653
-8,668
-8,638
-8,620
-8,713
-8,543
-8,682
-8,461
-8,663
-8,724
-8,734
-8,436
-8,437
-7,432
-7,395
-7,509
-7,359
-7,377
-7,446-7,396
-8,052
-8,425
-8,641
-8,694
-7,663
-8,736
-8,535
-8,579-8,654
-8,209
-8,642
-8,386
-8,421
-8,229
-8,329
-7100-7200-7300-7400-7500-7600-7700-7800-7900-8000-8100-8200-8300-8400-8500-8600-8700-8800-8900
U.B.2 Structure Map
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
FMTOPS - U_B_2[SLP] (SS) (FEET)
CONTOURSFMTOPS - U_B_2 [SLP] - MISS MOON PAY
FMTOPSU_B_2SLP.GRDContour Interval = 100
-890
0
-880
0
-870
0
-860
0
-850
0
-840
0
-830
0
-820
0
-810
0
-800
0
-790
0
-780
0
-770
0
-760
0
-750
0
-740
0
-730
0
-720
0
-710
0
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 11, 2012
PETRA 5/11/2012 9:49:49 PM
Andrews
Ector
Martin
Midland102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
52
Figure 33. Structure contour map of the top of the U.B.6 subdivision. Various folds are present in the eastern part of the study area. Contour interval is 100 ft.
3
25
12
21
28
27
22
11
6
1
7
10
23
26
2524
9
16
17
42
41
38
37
34
13
12
11
10
9
8
7
48
7
8
6
5
4
3
2
1
32
1
16
17
32
33
48
1
2
47
3431
18
15
2
43
36
3
14
19
30
35
46
45
36
29
20
4
3528
37
44
15
14
2
1
24
9
16
17
33
32
31
25
26
23
24
5
30
29
28
18
15
3
14
19
27
26
25
13
14
1224
23
22
20
13
4
5
12
21
21
20
191
2118
17
16
15
C5
20
27
22
5
11
2
22
19
17
18
25
26
27
20
21
2223
24
6
5
4
9
8
7
13
14
15
16
17
9
10
11
12
7
8
9
T1S
3
4
5
6
1
2
3
4
39
40
41
42
31
3233
34
27
28
29
30
31
32
33
28
29
30
19
2021
18
19
20
21
17
16
10
9
8
7
18
17
16
8
7
6
5
4
3
5
8
9
12
43
46
45
44
11
10
7
6
5
1
16
17
32
31
36
3231
18
15
2
4
3
14
19
30
33
34
29
2013
4
6
2
6
12
11
10
9
47
6
5
4
7
10
23
26
24
9
8
3
2
1
48
44
45
30
29
1
16
17
18
15
228
27
46
43
37
38
42
26
25
24
3
14
19
13
4
2322
21
41
39
35
40
20
19
18
17
5
12
11
6
47
16
9
841
40
25
32
33
48
1
16
38
37
36
32
31
15
2
4734
31
30
35
46
3
14
30
29
2423
13
4
45
3629
20
21
28
37
44
5
12
22
21
1514
13
9
8
7
22
10
23
6
5
4
12
11
10
3
2
1
3
19
18
13
14
15
16
7
8
9
10
11
12
7
8
5
6
1
2
3
4
5
33
3217
16
137
38
34
35
36
2
15
18
31
34
3530
19
14
3
25
2627
22
23
24
4
13
20
29
2821
12
5
13
1415
11
22
27
12
6
1
2
3
4
5
36
48
33
32
17
100 1/2
16
1
48
47
2
15
18
31
34
47
100
46
35
30
1914
3
46
36
45
4
13
20
29
36
45
4437
28
21
12
5
44
37
38
43
6
11
22
27
38
39
26
23
10
742
3924
25
40
33
28
16
9
110
25
43
2
11
12
1
2
3
4
5
6
1
48
43
4445
46
47
48
37
38
39
40
41
42
37
36
31
32
33
34
35
36
31
30
25
26
27
28
T1S29
30
25
19
20
21
22
23
2417
18
3
4445
46
47
38
39
40
41
42
37
38
35
3631
32
3334
35
26
27
28
29
30
25
26
23
2419
20
21
2223
24
13
14
15
16
17
18
13
12
7
8
9
10
116
1
19
18
13
14
15
16
7
8
9
10
11
12
7
6
1
2
3
4
5
6
43
44
45
46
47
4831
32
29
30
37
38
39
40
41
42
32
33
34
35
3619
28
29
20
21
16
17
8
9
4
5
33
34
27
28
3
10
10
25
13
24
23
13
12
1
9
9
1
8
15
14
11
2
4
3
2
21
22
15
16
3
11
10
10
11
2
35
26
20
4
9
9
3
4
34
22
0068-
0058-
0058-
005
8 -
0048
-
-840 0
0048-
0048-0048-
0048-
- 8400
- 830
0
- 8300
-8300
- 830
0
0038-
0038-
- 8
300
0038-
0038
-
- 8300
- 8200
- 820
0-8
200
- 820
0
0028
-
0028
-
0028-
- 8200
- 8100
- 810
0- 8
100
- 8100
0018-
- 80 00- 8
000
-800
0
-800
0
- 79
00
- 790
0-7
900
- 780
0
- 780
0- 7
800
- 770
0
- 770
0- 7
700
- 760
0
-760
0- 7
600
- 750
0
-750
0- 7
500
- 740
0
-740
0
0047
-
- 730
0
-730
0
0037
-
- 720
0
-72
00
0027
-
- 710
0
-71 0
0
- 700
0
- 7000
- 690
0
- 6900
-680
0
- 6 80
0
-67 0
0
- 6700
- 660
0- 6
500
-7,220
-8,089
-7,143
-8,067
-8,319
-8,321-8,364
-8,103
-7,230
-8,333-8,344
-8,347
-8,272
-8,498
-8,301
-8,194
-8,406
-8,319
-8,267
-7,509
-8,015
-7,744
-8,286
-7,775
-7,964 -8,231-7,744
-7,989-8,173
-8,088
-8,071
-8,073
-8,248
-8,195
-8,394
-8,398-8,360
-8,373
-8,386
-8,307
-8,335
-8,390
-8,305
-8,199-8,200
-8,183
-8,169-8,375
-8,289
-8,176
-8,205
-8,378
-8,229
-8,393
-8,230
-8,377
-8,246
-8,330
-8,368 -8,323-8,355
-8,203
-8,330
-8,325
-8,318
-8,289-8,373
-8,225
-8,365
-8,131
-8,330
-8,416
-8,544
-8,113
-8,002
-8,143
-7,202
-7,174
-7,304
-7,165
-7,167
-7,262-7,176
-7,813
-8,153
-8,454
-8,371-7,457
-8,285
-8,333-8,392
-7,982
-8,225-8,346
-8,105
-8,121
-7,938
-8,464
-8,052
-6500-6600-6700-6800-6900-7000-7100-7200-7300-7400-7500-7600-7700-7800-7900-8000-8100-8200-8300-8400-8500-8600-8700
U.B.6 Structure Map
FEET
0 5,280 10,560 15,840
POSTED WELL DATA
FMTOPS - U_B_6[SLP] (SS) (FEET)
CONTOURSFMTOPS - U_B_6 [SLP] - Top of Barnett Shale
FMTOPSU_B_6SLP.GRDContour Interval = 100
-870
0
-860
0
-840
0
-820
0
-800
0
-780
0
-760
0
-740
0
-720
0
-700
0
-680
0
-660
0
WELL SYMBOLSLocation OnlyOil WellDry HoleService WellAbandoned Oil WellShut In Oil Well
May 12, 2012
PETRA 5/12/2012 12:15:42 AM
Andrews
Ector
Martin
Midland
102°20'W
3°1
'32°0 0'N
32 °0 5'N2
5°1 0' N
102°25'W 102°15'W 102°10'W
32°0
0'N
32°0
5'N
3232° 1
0'N
N
32°1
5'N
102°25'W 102°20'W 102°15'W
53
Discussion
Strata comprising the lower Barnett were deposited in deep-water marine
conditions. The sidewall core sample taken from the lower Barnett interval, coupled with
the overall elevated gamma ray responses for the entire interval suggest hemipelagic
sedimentation exerted strong influence on the accumulation of strata. This is further
suggested by the dearth of terrigenous constituents present in the sample (Table 2). The
high TOC content is a by-product of anoxic conditions persisting throughout deposition,
which also resulted in the formation of pyrite. The thickest accumulations of the lower
Barnett coincide with the present-day location of the Central Basin Platform. High S1
and S2 values from the lower Barnett sample reveals that the interval contains sufficient
properties to have generated hydrocarbons.
The upper Barnett is composed of both calcareous/phosphatic shale and silty
limestones deposited in marine conditions. The presence of phosphate nodules and pyrite
framboids suggest an anoxic environment. The high density of pyrite and phosphate
could potentially affect any density measurements throughout the section.
A gross isopach of the entire upper Barnett section shows the thickest section in
the southeast. This pattern suggests that the main depocenter shifted slightly to the south
following the deposition of the lower Barnett. This shift may reflect early subsidence
related to the emergence of the Central Basin Platform (Fig. 23). The net isopach map,
taken to represent deposition of bioclastic debris, shows the thickest portion in the north,
decreasing in overall thickness to the south. This pattern is opposite to the gross isopach
pattern and suggests a northerly source for the flows. The likely source is the carbonate
54
platform that was present north of the study area during the Chesterian. If this is correct,
the carbonate constituents that comprise the debris flows were likely episodically sourced
from the platform to the basin via mass-gravity flows (Fig. 34).
Production History
Upper Mississippian fields in the Midland Basin are located in both platform and
basin environments. On the platform, trapping mechanisms are either structural or
stratigraphic, with limestone, dolomite, and/or chert providing the reservoir (Wright,
1979). South of the paleo-platform, fields including Moonlight, Lowe, Desperado, and
Bradford Ranch produce from the bioclastic-rich debris flows present in the upper
Barnett (Fig. 35). Not all fields are reported Mississippian, although that may be a
consequence of the aforementioned lack of age consensus. The trapping mechanism is
stratigraphic, which is a result of the detrital units thinning out on the flanks of the
sequence. A fracture network likely provides the means of production viability from the
“tight”, low porosity, low permeability reservoirs. Evidence for this includes a well’s
ability to drain an entire section and the abnormal pressure gradients (Unpublished Field
Reports). One example of the abnormal pressure gradient is a pressure test that was
applied to the Moonlight field. The test consisted of shutting in wells producing from
upper Mississippian units, while a new one was brought online. Wells 8,500 feet (2,590
meters) away recorded a pressure drop in an hour (Jim Henry, Petroleum Engineer,
personal communication, 2012). Well communication in that short time frame strongly
suggests the presence of a fracture network. Additionally, core recovered from the
Fasken 215-B in the Moonlight Field has a five-inch fracture from the U.B.2 bioclastic
55
Figure 34. A) Location of cross section D-D’ in relation to the study area (dashed red rectangle) and the Chesterian shelf. Modified from Hamilton and Asquith (2000). B) Idealized integration of the deposition of bioclastic mass-gravity flows in study area into Bay’s (1954) cross section. Modified from Bay (1954) and Ruppel and Kane (2006).
56
Figure 35. Map of oil fields that have produced hydrocarbons from the upper Barnett. Study area highlighted in yellow. Modified from Anonymous (1986).
57
carbonate section (Al Smith, Independent Geologist, personal communication, 2011).
Upper Mississippian detrital units were actively pursued in the mid seventies to late
eighties until an unfavorable economic climate curtailed activity.
Favorable economic prices have once again shifted focus to the liquids-rich
Midland Basin, with the “Wolfberry” (Permian) play dominating the industry’s focus.
Wolfberry trends overlap areas that were mapped containing thick portions of the upper
Barnett detritus strata. While it would increase well costs to drill deeper and test, the
potential for increased pay warrants exploration. All of the wells drilled in the original
fields were vertical. With the increased expertise of horizontal drilling, the ability to
increase contact to the “tight” reservoir coupled with fracture stimulation completion,
could aid in increasing permeability.
Conclusions and Recommendations
The top of the shale sequence underlying the “Atoka Lime” is presumptively
Chesterian in age, making it equivalent to the Barnett Shale Formation. Depths to the top
of the Barnett section range from ranges from 9,000 feet (2,750 meters) in the west along
the flank of the Central Basin Platform to 11,500 feet (3,500 meters) in the east. It can be
divided into an upper, calcareous unit and a lower, siliceous unit on the basis of
resistivity and GR responses. The upper unit can be further subdivided into six subunits
by log responses, to further aid in deciphering depositional trends. Isopach maps
constructed on the subunits containing carbonate detritus gravity flows suggest a northern
source, which coincides with the late Mississippian platform margin. Future work in
58
delineating the overall geometry and transport mechanics (point vs. line source) will be
crucial to further understand the deposition patterns.
Historically, established production comes from the upper subunits containing
increased porosity and permeability values. The encasing shales are likely to provide the
source. Although fracture detection was not completed in this study, it is likely to exert
significant control on the ability to exploit hydrocarbons. Preliminary analysis suggests
that weight percent TOC values can be estimated from the amount of separation from GR
and Rt curves. The lower Barnett had the highest TOC and gas shows, based on core and
petrophysical analysis.
Future study of the Barnett in the Midland Basin should incorporate
petrophysical, geophysical, geochemical, and core analysis. More age data should be
gathered from palynology and conodonts to better constrain the sequence. With the
benefit of being located in a mature province, old well logs and core reports are readily
available and should be used to further carry out correlations. Azimuthal angle versus
offset analysis and seismic coherency could provide the means to predict natural
fracturing in the sequence, aiding in delineating specific trends that warrant exploration
focus. While historic production has solely come from the upper subunits, the lower
Barnett with its appreciable TOC, S1 and S2 values could prove to be a viable horizontal
prospect.
59
References
Adams, D.C., and Keller, G.R., 1996, Precambrian basement geology of the Permian Basin region of West Texas and Eastern New Mexico: A geophysical perspective: American Association of Petroleum Geologists Bulletin, v.80, p. 410-431.
Adams, J.E., 1965, Stratigraphic-tectonic development of the Delaware Basin: American
Association of Petroleum Geologists Bulletin, v. 49, p. 2140-2148. Adams, J.E., Frenzel, H.N., Rhodes, M.L., and Johnson, D.P., 1951, Starved Pennsylvanian
Midland Basin: American Association of Petroleum Geologists Bulletin, v. 23, p. 1673-1681. Anonymous, 1986, Unraveling the mystery of the Atoka: Search, v. 2, p. 1-5. Ball, M., 1995, Permian Basin Province (044), in Gautier, D.L., Dolton, G.I. Takahashi, K.T., and
Varnes, K.L., eds., 1995 National assessment of United States oil and gas resources-Results, methodology, and supporting data: U.S. Geological Survey Digital Data Series DDS-30.
Bay, T. A., Jr., 1954, Mississippian system of Andrews and Gaines counties, Texas [Unpublished
MS thesis]: The University of Texas at Austin, 56 p. Bjorlykke, K., 2010, Source rocks and petroleum geochemistry, in Bjorlykke, K., ed., Petroleum
geoscience: From sedimentary environments to rock physics: Springer, Berlin, Germany, p. 339-349.
Broadhead, R.F., 2009, Mississippian strata of southeastern New Mexico: distribution, structure,
and hydrocarbon plays: New Mexico Geology, v.31, p. 65-71. Candelaria, M.P., 1990, “Atoka” detrital a subtle stratigraphic trap in the Midland Basin, in Flis,
J.E., and Price, R. C., eds., Permian Basin oil and gas fields; innovative ideas in exploration and development: West Texas Geological Society, v. 90-87, p.104-106.
Craig, L.C., and Connor, C.W., Coordinators, 1979, Paleotectonic Investigations of the
Mississippian System in the United States, U.S. Geological Survey Professional Paper 1010, Part III.
Frenzel, H.N., and 13 others, 1988, The Permian basin region, in Sloss, L.L., ed., Sedimentary
Cover-North American Craton; U.S.: Geological Society of America, The Geology of North America, Boulder, Colorado, v. D-2 p. 261-306.
Galley, J.E., 1958, Oil and geology in the Permian Basin of Texas and New Mexico, in Weeks,
L.G., ed., Habitat of oil: American Association of Petroleum Geologists, Tulsa, Oklahoma, p. 395-446.
Gutschick, R., and Sandberg, C., 1983, Mississippian Continental Margins on the Conterminous
United States, in Stanley, D.J. and Moore, G.T., eds., The Shelf break: Critical Interface on Continental Margins: Society of Economic Paleontologist Mineralogists, Tulsa, Oklahoma, Special Publication 33, p. 79-96.
60
Hamiliton, D.C., and Asquith, G.B., 2000, Depositional, digenetic, and production histories of Chester ooid grainstones in the Austin (Upper Mississippian) Field: Lea County, New Mexico, in DeMis, W., Nelis, M., and Trentham R.C., eds., The Permian Basin: Proving Ground for Tomorrows’s Technologies, West Texas Geological Society, Publication 00-109, p. 95-105.
Heslop, K.A., 2010, Generalized Method for the Estimation of TOC from GR and Rt, AAPG
Datapages/ Search and Discovery, #80117. Hills, J.M., 1984, Sedimentation, tectonism, and hydrocarbon generation in Delaware basin, West
Texas and southeastern New Mexico: American Association of Petroleum Geologists Bulletin, v. 68, p. 250-267.
IHS Energy, 2011, Permian Basin Production Data, accessed from PI Dwight, (July, 2011). King, P.B., 1948, Geology of the southern Guadalupe Mountains, Texas: U.S. Geological Survey
Professional Paper 251, 183 p. Kinley, T.J., Geology and hydrocarbon potential of the Barnett shale (Mississippian) in the
northern Delaware Basin, West Texas and Southeastern New Mexico [M.S. thesis]: Texas Christian University, Ft. Worth, 81 p.
Miall, A.D., 2008, The southern midcontinent, Permian Basin, Ouachitas, in Miall, A.D., ed., The
sedimentary basins of the United States and Canada: Elsevier B.V., Amsterdam, The Netherlands, p. 297-327.
Ruppel, S.C., and Kane, J., 2006, The Mississippian Barnett Formation: A source-rock, seal, and
reservoir produced by early Carboniferous flooding of the Texas craton: http://www.beg.utexas.edu/resprog/permianbasin/PBGSP_members/writ_synth/Mississippian_chapter.pdf (September, 2011).
Scholle, P., 2006, An introduction and virtual field trip to the Permian reef complex, Guadalupe
and Delaware Mountains, New Mexico-West Texas: http://geoinfo.nmt.edu/staff/scholle/guadalupe.html (October 2011).
Serra, O., ed., 1990, Element, Mineral, Rock Catalog, Schlumberger.
Wright, W.F., 1979, Petroleum geology of the Permian Basin: West Texas Geological Society,
Midland, TX, 98 p. Wright, W., 2006, Depositional history of the Atokan Succession (Lower Pennsylvanian) in the
Permian Basin: http://www.beg.utexas.edu/resprog/permianbasin/PBGSP_members/writ_synth/Atoka.pdf (August, 2011).
Ye, H., Royden, L., Burchfiel, C., and Schuepbach, M., 1996, Late Paleozoic deformation of
interior North America; the greater ancestral Rocky Mountains: American Association of Petroleum Geologists Bulletin, v. 80, p. 1397-1432.
61
Appendix I. Geochemical Report From the Fasken Fee BM #1 SWD
Figure I 1. Geochemical logs for BM SWD #1 well
Figure I 2. Kerogen quality relative to TOC Vs. hydrocarbon potential for the BM SWD well
Client: GeoSystemsField / Well: File # G2142Contact: Chuck Segrest
GeoMark ID#: RGES-110602Source Rock Analyses
GeoMark Source Rock Services218 Higgins StreetHumble, TX 77338 1
(832) [email protected]
June 20, 2011
GeoSystems - Chuck Segrest G2142,
Norm. Oil Content, S1/TOC Production Index, S1/(S1+S2) Maturity Indicators
11,400
11,500
11,600
11,700
11,800
11,900
12,000
12,1000.00 0.25 0.50 0.75 1.00
Me
as
ure
d D
ep
th,
MD
(ft
)
Production Index, S1/(S1+S2)
Gas Generation
Imm
atur
e
Oil Gen.
415 435 455 475 495 515 53511,400
11,500
11,600
11,700
11,800
11,900
12,000
12,1000.2 0.8 1.4 2.0 2.6 3.2
Me
as
ure
d D
ep
th,
MD
(ft
)
Vitrinite Reflectance (or VR Equivalent)
Measured %Ro
PyGCMS - Z Maturity
Tmax
Gas Generation
Imm
atur
e Oil Generation
Tmax (°C)
SOURCE ROCK ANALYSES
GEOMARK GEOMARK RESEARCH, LTD.
0 20 40 60 80 10011,400
11,500
11,600
11,700
11,800
11,900
12,000
12,1000 50 100 150 200
Measu
red
Dep
th, M
D (
ft)
Normalized Oil Content, S1/TOC
S1/TOC
% Carbonate
% Carbonate
Low
Mat
urity
or
Exp
elle
d
Early
Mat
ure
Sour
ce R
ock
Mature / Stained Source Rock
Oil / Gas Production or Contamination
Client: GeoSystemsField / Well: File # G2142Contact: Chuck Segrest
GeoMark ID#: RGES-110602Source Rock Analyses
GeoMark Source Rock Services218 Higgins StreetHumble, TX 77338 1
(832) [email protected]
June 20, 2011
GeoSystems - Chuck Segrest G2142,
Kerogen Quality Plot
0
10
20
30
40
50
60
0 2 4 6 8 10 12 14 16
Rem
aini
ng H
ydro
carb
on P
oten
tial,
S2 (m
g H
C /
g R
ock)
Total Organic Carbon, TOC (wt %)
Type I: Oil ProneUsually Lacustrine
Type III: Gas Prone
Mixed Type II / III:Oil / Gas Prone
Type II: Oil ProneUsually Marine
Dry Gas Prone
HI = 50
HI = 200
HI = 350
HI = 700
SOURCE ROCK ANALYSESGEOMARK GEOMARK RESEARCH, LTD.
62
Figure I 3. Kerogen type and maturity based on hydrogen index and Tmax.
Client: GeoSystemsField / Well: File # G2142Contact: Chuck Segrest
GeoMark ID#: RGES-110602Source Rock Analyses
GeoMark Source Rock Services218 Higgins StreetHumble, TX 77338 1
(832) [email protected]
June 20, 2011
GeoSystems - Chuck Segrest G2142,
Kerogen Type and Maturity
0
200
400
600
800
1000
400 410 420 430 440 450 460 470 480 490 500
Hyd
roge
n In
dex
(mg
HC
/ g
TOC
)
Tmax (°C)
TYPE I KEROGEN
TYPE II KEROGEN
TYPE III KEROGEN
SOURCE ROCK ANALYSESGEOMARK GEOMARK RESEARCH, LTD.
~ 0.6 % Ro ~ 1.4 % Ro
Immature Oil Generation Gas Generation
63
Client: GeoSystemsField / Well: File # G2142Contact: Chuck Segrest
GeoMark ID#: RGES-110602Source Rock Analyses
GeoMark Source Rock Services218 Higgins StreetHumble, TX 77338 1
(832) [email protected]
June 20, 2011
GeoSystems - Chuck Segrest G2142,
Kerogen Quality Plot
SOURCE ROCK ANALYSES
GEOMARK GEOMARK RESEARCH, LTD.
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
0.80
0.90
1.00
380 400 420 440 460 480 500 520 540 560 580 600
Ke
ro
ge
n C
on
ve
rs
ion
, P
I (S
1/(
S1
+S
2)
Tmax (C)
Immature Dry Gas ZoneOil Zone CondensateWet Gas
Zone
Stained or Contaminated
Low Level Conversion
Figure I 4. Kerogen quality plot for the BM SWD #1 well
64
Appendix II. Palynological Reports
Ger
ald
Waa
nder
s, C
onsu
lting
Pal
ynol
ogis
t14
75 R
anch
o E
ncin
itas
Driv
e, E
ncin
itas,
Cal
iforn
ia 9
2024
-703
1P
hone
: (8
58) 7
59-0
180,
Em
ail:
waa
npal
y@ro
adru
nner
.com
Figu
re 1
Age
Dep
th
Convolutispora sp.
Cordaitina sp.
Calamospora breviradiata
Nuskoisporites crenulatus
Punctatisporites spp.
Thymospora sp.
Tsugaepollenites jonkeri
Verrucosisporites pergranulus
Acanthotriletes spp.
Aculeisporites varibilis
Punctatosporiotes rotoundus
Wilsonites sp.
Direticuloidospora sp.
Disaccites spp.
Striatites limpidus
Limitisporites monstruosus
Potoniesporites bharadwaji
Potoniesporites novicus
Sphaeripollenites elphinstonei
Apiculatisporis spp.
Florinites spp.
Cordaitina bractea
Hamiapollenites saccatus
Cirratriradites ornatus
Latensina trileta
Florinites visendus
Leiotriletes spP.
Ibrahimisporites brevispinosus
Endosporites formosus
Laevigatosporites vulgaris
Laevigatosporites minimus
Llundbladispora gigantea
Angulisporites splendidus
Crassispora kosankei
Cyclogranisporites pergranulus
Laevigatosorites maximus
Lycospora pusilla
Raistrickia macra
Vestispora profunda
Densosporites annulatus
Granulatisporites microgranifer
Lophotriletes pseudoaculeatus
Microrticulatisporites nobilis
Verrucosisporites verrucosus
Vestispora laevigata
Dictyotriletes bireticulatus
Cristatisporites solaris
Cirratriradites saturni
Densosporites tenuis
Endosporites globiformis
Endosporites ornatus
Lycospora pseudoannulatus
Reticulatisporites reticulatus
Camptotriletes superbus
Lophotriletes microsaetosus
Punctatisporites sinuatus
Schopfites dimorphus
Cirratriradites rarus
Discernisporites micromanifestus
Kraeuselisporites ornatus
Waltzispora planiangulata
Calamospora pallida
Pilosisporites venustus
Spelaeotriletes aranaceus
Ahrensisporites duplicatus
Crassispora maculosa
Raistrickia saetosa
Remysporites magnificus
Schopfites claviger
Raistrickia nigra
Aurororaspora solisortus
Densosporites spitzbergensis
Verrucosisporites nodosus
Convolutispora mellita
Auroraspoora macra
Grandispora echinata
Murospora dupla
Verrucosisporites papulosus
Anaplanisporites sp.
Diatomozonotriletes saetosus
Cyclogranisporites paleophytus
Rotaspora fracta
Knoxisporites cinctus
Microreticulatsporites hortonensis
Tripartites vetustus
Vellatisporites ciliaris
Schulzospora rara
Raistrickia clavata
Knoxisporites literatus
Knoxisporites stephanophorus
Spelaeotriletes pretiosus
Anaplanisporites baccatus
Auroraspora hyalina
Hymenozonotriletes parvimammatus
Hymenozonotriletes pusillites
Tasmanites sp.
Scolecodont sp.
9700
-975
097
50-9
800
RQ
9800
-985
0R
Q98
50-9
900
RR
R99
00-9
950
RR
RR
9950
-10,
000
RQ
10,0
00-1
0,05
0R
RR
RR
R10
,050
-10,
100
RR
RR
10,1
00-1
0,15
0R
RR
R10
,150
-10,
200
RR
RR
RR
10,2
00-1
0,25
0R
RR
RR
RR
R10
,250
-10,
300
RR
RR
RR
R10
,300
-10,
350
RR
RR
RR
RR
10,3
50-1
0,40
0R
RR
10,4
00-1
0,45
0F
RR
R10
,450
-10,
500
RR
RR
RR
10,5
00-1
0,55
0R
R10
,550
-10,
600
RR
RF
RR
10,6
00-1
0,65
0R
RR
RR
10,6
50-1
0,70
0R
RR
R10
,700
-10,
750
RR
RR
RR
10,7
50-1
0,80
0R
RR
10,8
00-1
0,85
0R
R10
-850
,10,
900
RR
RR
R10
,900
-10,
950
RR
RR
RR
R10
,950
-11,
000
RR
RR
RR
RR
RR
RR
11,0
00-1
1,05
0F
RR
FF
RR
RR
RR
RR
RQ
11,0
50-1
1,10
0R
RR
RR
RR
FR
RR
R11
,100
-11,
150
RF
RF
RR
RR
CR
RR
RR
11,1
50-1
1,20
0R
RR
FR
RR
AR
RR
RR
RR
RR
RR
11,2
00-1
1,25
0R
RR
RR
RA
RR
RR
RQ
RR
R11
,250
-11,
300
RR
CR
RR
RR
R11
,300
-11,
350
CR
RR
AR
RR
RR
RR
RR
11,3
50-1
1,40
0R
RR
AA
RR
RF
RR
RR
RR
R11
,400
-11,
450
RR
RA
AR
RR
AR
RR
RR
RR
11,4
50-1
1,50
0A
AQ
RR
RF
RR
RR
R11
,500
-11,
550
RR
RA
AR
RR
RR
RR
R11
,550
-11,
600
RA
AR
RR
RR
RR
R11
,600
-11,
650
RF
AA
AR
RR
11,6
50-1
1,70
0R
RA
AR
RF
RR
RR
RR
R1,
700-
11,7
50F
RA
AR
FR
RR
RR
RR
11,7
50-1
1,80
0R
RA
AR
RF
RR
RR
R11
,800
-11,
850
RR
RA
AR
RR
RR
RR
RR
11,8
50-1
1,90
0R
RR
AA
RF
RR
FR
R11
,900
-11,
950
CR
RA
AR
FR
RF
RR
R11
,950
-12,
000
RR
AA
RR
RR
RR
12,0
00-1
2,05
0R
RA
AR
RR
RR
QR
12,0
50,-1
2,10
0R
RA
RR
RC
RR
RR
12,1
00-1
2,15
0F
RA
FR
RR
RR
RR
R12
,150
-12,
200
FF
RR
FR
RR
R12
,200
-12,
250
RR
RR
CF
RR
FR
QR
RR
RR
12,2
50-1
2,30
0A
FA
RR
QR
RR
QR
RR
RR
12,3
00-1
2,35
0R
RA
RR
RR
RR
RR
12,3
50-1
2,40
0R
RR
RR
RR
R12
,400
-12,
450
RR
AA
RR
RR
RFa
men
nian
12,4
50-1
2,50
0F
RR
AA
RQ
RR
RR
RR
RR
R
Fask
en O
il &
Ran
chR
= R
are,
less
than
6 s
peci
men
s/sl
ide
Fee
BM
#1
SW
DF
= Fr
eque
nt, 6
-15
spec
imen
s/sl
ide
Sec
. 15,
Blk
. 40,
T-1
-N, T
& P
RR
Com
pany
Sur
vey
C =
Com
mon
, 16-
30 s
peci
men
s/sl
ide
And
rew
s, C
o. T
exas
A =
Abu
ndan
t, ov
er 3
0 sp
ecim
ens/
slid
eQ
= Q
uest
iona
ble
Iden
tifac
tion
Dar
k O
rang
e =
Pro
babl
e U
p-ho
le C
onta
min
atio
n
Spo
res
Mic
r.3/
22/1
1
Leon
ardi
an o
r Old
er
Wol
fcam
pian
Kin
derh
ooki
an?
Mis
sour
ian
to
Des
moi
nsia
n (U
ndiff
eren
tiate
d)
Ato
kan
Che
ster
ian
Mer
amec
ian
Osa
gean
?
Figure II. 1. Specimen report for the Fasken Fee BM #1 SWD well
65
Ger
ald
Waa
nder
s, C
onsu
lting
Pal
ynol
ogis
t14
75 R
anch
o E
ncin
itas
Driv
e, E
ncin
itas,
Cal
iforn
ia 9
2024
-703
1P
hone
: (8
58) 7
59-0
180,
FA
X:
(858
) 759
-902
8, E
mai
l: w
aanp
aly@
road
runn
er.c
om
Figu
re 1
Age
Dep
th
Cordaitina sp.
Disaccites sp.
Potoniesporites bharadwaji
Potoniesporites novicus
Schopfipollenites sp.
Punctatisporites spp.
Wilsonites sp.
Calamospora breviradiata
Leiotriletes sp.
Angulisporites sp.
Limitissporites monstruosus
Florinites spp.
Dictyotriletes bireticulatus
Endosporites globiformis
Lycospora pusilla
Crassispora kosankei
Densosporites annulatus
Laevigatosporites vulgaris
Lophotriletes pseudoaculeatus
Vestispora laevigata
Angulisporites splendidus
Punctatosporites rotundus
Densosporites tenuis
Lycospora pseudoannulatus
Vestigisporites sp.
Apiculatisporis aculeatus
Granulatisporites microgranifer
Lundbladispora gigantea
Savitrisporites camptotus
Punctatisporites sinuatus
Lopohotriletes microsaetosus
Schulzospora rara
Spelaeotriletes aranaceus
Convolutispora sp.
Discernisporites micromanifestus
Leiotriletes politus
Cirratriradites rarus
Laevigatosporites maximus
Raistrickia microhorrida
Remysporites magnificus
Endosporites ornatus
Waltzispora planiangulata
Waltzispora polita
Apiculatisporis sp.
Raistrickia nigra
Savitrisporites nux
Schopfites claviger
Cristatisporites bellus
Grandispora spinosa
Convolutispora flexuosa
Latosporites sp.
Raistrickia clavata
Spelaeotriletes pretiosus
Verruretusispora magnifica
Leiosphaera spp.
Tasmanites spp.
Algal Cuticle
Micrhystridium echinosum
9900
-998
0R
RR
RR
9980
-10,
060
RR
RR
10,0
60-1
0,14
0R
RR
R10
,140
-10,
200
RR
RR
10,2
00-1
0,28
0R
R10
,280
-10,
360
RR
R10
,360
-10,
420
RR
R10
,420
-10,
480
RR
10,4
80-1
0,56
0R
RR
10,5
60-1
0,64
0R
FR
10,6
40-1
0,70
0F
RR
RR
RF
10,7
00-1
0,78
0F
FR
RF
RR
RR
R10
,780
-10,
840
RR
RR
RF
RR
10,8
40-1
0,86
0F
RR
AR
RR
RQ
R10
,860
-10,
940
RR
AR
RR
RR
RR
R10
,940
-11,
000
RR
RR
AR
RR
RR
11,0
00-1
1,08
0R
AR
RA
R11
,080
-11,
160
RR
AR
AR
RR
R11
,160
-11,
220
RA
RR
FR
RR
RR
11,2
20-1
1,28
0F
AF
AR
RR
R11
,280
-11,
340
RA
FR
AR
RR
RR
RR
R11
,340
-11,
420
FA
RA
RR
RR
RR
RR
R11
,420
-11,
500
FA
RA
RR
RR
RR
R11
,500
-11,
580
RA
RA
RF
FR
FR
R11
,580
-11,
660
RA
RR
11,6
60-1
1,74
0R
R11
,740
-11,
820
RR
RR
R11
,820
-11,
900
RA
RR
RR
RR
RC
11,9
00-1
1,98
0A
RR
RR
C11
,980
-12,
050
RC
RR
12,0
50-1
2,11
0R
AR
RR
RC
A12
-110
-12,
160
RA
RR
RQ
12,1
60-1
2,20
0R
AR
CR
RR
RR
Fask
enR
= R
are,
less
than
6 s
peci
men
s/sl
ide
"BL"
No.
1 S
WD
F
= Fr
eque
nt, 6
-15
spec
imen
s/sl
ide
C =
Com
mon
, 16-
30 s
peci
men
s/sl
ide
A =
Abu
ndan
t, ov
er 3
0 sp
ecim
ens/
slid
eQ
= Q
uest
iona
ble
Iden
tifac
tion
Dar
k O
rang
e =
Pro
babl
e U
p-ho
le C
onta
min
atio
n
4/12
/12
Mic
ropl
ank.
Inde
term
inat
e
Spo
res
Che
ster
ian
Kin
derh
ooki
an?
Mer
amec
ian
to
Osa
gean
(U
ndiff
eren
tiate
d)
Ato
kan
Wol
fcam
pian
to
Des
moi
nsia
n (U
ndiff
eren
tiate
d)
Figure II. 2. Specimen report for the Fasken Fee BL #1 well.
66
Ger
ald
Waa
nder
s, C
onsu
lting
Pal
ynol
ogis
t14
75 R
anch
o E
ncin
itas
Driv
e, E
ncin
itas,
Cal
iforn
ia 9
2024
-703
1P
hone
: (8
58) 7
59-0
180,
FA
X:
(858
) 759
-902
8, E
mai
l: w
aanp
aly@
road
runn
er.c
om
Figu
re 1
Age
Dep
th
Caiospora magna
Calamospora spp.
Densosporites annulatus
Densosporites sphaerotriangularis
Densosporites spp.
Disaccites spp.
Florinites spp.
Laevigatosporites maximus
Lophotriletes microsaetosus
Lophotriletes pseudoaculeatus
Lycospora pusilla
Potoniesporites spp.
Punctatisporites spp.
Florinites eremus
Savitrisporites camptotus
Schopfipollenites sp.
Verrucosisporites spp.
Angulisporites spendidus
Crassispora kosankei
Cyclogranisporites orbicularis
Endosporites spp.
Raistrickia aculeata
Reticulatisporites polygonalis
Apiculatisporis sp.
Converrucosisporites sp.
Florinites junior
Florinites ovalis
Granulatisporites microgranifer
Punctatisporites sinuatus
Florinites pellucidus
Leiotriletes adnatus
Calamospora pallida
Cyclogranisporites pergranulatus
Laevigatosporites sp.
Lycospora pseudoannulata
Raistrickia fulva
Vestispora irregularis
Reticulatisporites reticulatus
Vestispora cancellata
Cirratriradites saturni
Endosporites ornatus
Granulatisporites granulatus
Vestispora laevigata
Cristatisporites solaris
Raistrickia saetosa
Gravisporites sphaerus
Spelaeotriletes aranaceus
Bellispores nitidus
Crassispora maculosa
Densosporites tenuis
Discernisporites micromanifestus
Reinchospora triangularis
Waltzispora planiangulata
Mooreisporites trigallerus
Schulzospora rara
Verrucosisporites baccatus
Grandispora echinata
Knoxisporites stephanophorus
Knoxisporites cinctus
Convolutispora mellita
Remysporites magnificus
Tricidarisporites magnificus
Knoxisporites triradiatus
Rugospora polyptycha
Schopfites claviger
Cyclogranisporites paleiphytus
Convolutispora spp.
Camptotriletes superbus
Anaplanisporites baccatus
Secarisporites sp.
Verrucosisporites nitidus
Crassispra sp. (Eames)
Geminospora sp.
Hymenozonotriletes lepidophytus
Raistrickia clavata
Spelaeotriletes balteatus
Vellatisporites pusillites
Auroraspora macra
Cyclogranisporites sp.
Lophozonotriletes sp.
Hymenozonotriletes explanatus
Verruretusispora magnifica
Densosporites variomarginatus
Dictyotriletes cancellatus
Microreticulatisporites sp.
Aurospora solisorta
Tasmanites spp.
Scolecodont sp.
Desmochitina sp. ?
Chitinozoan Fragments
Michrhystridium echinosum
Navifusa sp.
Chitinozoan sp.
Mis
sour
ian
10,6
50-1
0,70
0R
RR
RR
FR
RR
RF
FC
R10
,700
-10,
750
RR
RR
FR
FR
RR
R10
,750
-10,
800
RR
R10
,800
-10,
850
RR
RR
CR
RR
RR
RR
R10
,850
-10,
900
RR
RR
RR
RR
RR
RR
R10
,900
-10,
950
RR
RF
RC
FR
FR
RF
RR
10,9
50-1
1,00
0R
FC
FR
RF
RR
RR
RR
11,0
00-1
1,05
0R
RR
AR
RR
RR
RR
11,0
50-1
1,10
0F
AF
RR
RR
RR
RR
RR
RR
11,1
00-1
1,15
0R
RF
RA
FR
RR
RR
RR
11,1
50-1
1,20
0C
CC
RA
RR
RR
RR
RR
RR
R11
,200
-11,
250
AA
RA
FR
RA
RR
RR
AR
RR
11,2
50-1
1,30
0A
FR
AR
RA
RR
RA
RR
11,3
00-1
1,35
0A
RA
RR
AR
RA
RR
RR
R11
,350
-11,
400
AR
AR
RR
AR
RR
RA
RR
RR
11,4
00-1
1,45
0A
AA
FR
RA
RR
RA
RR
RR
11,4
50-1
1,50
0R
RR
AA
RR
RR
RR
RR
RR
11,5
00-1
1,55
0R
RA
RR
RR
RR
RR
11,5
50-1
1,60
0R
FA
RR
RR
AR
R11
,600
-11,
650
FR
RA
RR
RR
R11
,650
-11,
700
CR
AR
RC
RR
11,7
00-1
1,75
0R
FA
RR
RR
FR
11,7
50-1
1,80
0R
RF
RR
RR
11,8
00-1
1,85
0R
RF
FR
RR
R11
,850
-11,
900
RF
RR
RF
RR
11,9
00-1
1,95
0R
FA
FR
FR
R11
,950
-12,
000
RF
AR
RR
RF
RR
12,0
00-1
2,05
0R
RA
FR
RR
AIn
dete
rmin
ate
12,0
50-1
2,10
0R
RF
FR
RF
RK
inde
rhoo
k. to
Fam
enni
an12
,100
-12-
150
RR
FR
FR
RR
R12
,150
-12,
200
RR
RR
RR
RR
RR
RR
RR
RR
AR
12,9
40-1
2,94
5A
AR
RR
RR
RR
RR
13,0
50-1
3,10
0R
AR
RR
RA
RR
RR
RR
13,1
00-1
3,15
0F
AR
RR
RA
RR
RR
RF
RR
13,1
50-1
3,20
0R
AR
AR
RR
RA
R13
,200
-13,
250
RA
FR
AR
RR
RR
AR
13,2
50-1
3,30
0A
RR
AR
RR
R13
,300
-13,
350
RA
RA
R13
,350
-13,
400
RA
RC
RR
R
Dav
id F
aske
nR
= R
are,
less
than
6 s
peci
men
s/sl
ide
"BS
" No.
1 S
WD
Re-
entry
F =
Freq
uent
, 6-1
5 sp
ecim
ens/
slid
eS
ec. 4
1, B
lk. 4
0 T-
1-N
T&
P R
R C
o. S
urve
y C
= C
omm
on, 1
6-30
spe
cim
ens/
slid
eM
idla
nd, C
o. T
exas
A =
Abu
ndan
t, ov
er 3
0 sp
ecim
ens/
slid
eQ
= Q
uest
iona
ble
Iden
tifac
tion
Dar
k O
rang
e =
Pro
babl
e U
p-ho
le C
onta
min
atio
n
Silu
rian
to O
rdov
icia
n U
ndiff
eren
tiate
d
Spo
res
Mic
ropl
ankt
on11
/9/1
0
Che
ster
ian
Ato
kan
Mer
amec
ian
to
Osa
gean
(U
ndiff
eren
tiate
d)
Des
moi
nsia
n
Figure II. 3. Specimen report for the Amoco David Fasken BS #1 well.
Vita
Personal Clark Harrison Osterlund Background Fort Worth, Texas Born May 18, 1988, Midland, TX Son of David and Eve Osterlund Education Bachelors of Science in Geology, 2010 Baylor University, Waco, TX Master of Science in Geology, 2012 Texas Christian University, Fort Worth, TX Experience Intern Geologist, summers 2007-2011 Fasken Oil and Ranch Ltd. Midland, TX Intern Geologist, 2011-2012 BOPCO Ltd., Fort Worth TX Professional American Association of Petroleum Geologists (AAPG) Memberships West Texas Geological Society (WTGS)
ABSTRACT
THE BARNETT SHALE (MISSISSIPPIAN) IN THE CENTRAL MIDLAND BASIN, (ANDREWS, ECTOR, MARTIN, AND MIDLAND COUNTIES)
By Clark H. Osterlund, M.S., 2012 Department of Geology, Energy, and the Environment
Texas Christian University
Dr. Helge Alsleben – Professor of Geology Dr. R. Nowell Donovan – Professor of Geology, and Provost
Stonnie Pollock – Geologist, Fasken Oil and Ranch Ltd.
Fine-grained units underlying the Atoka Lime Formation in the Midland Basin have
historically been interpreted as Pennsylvanian (Atokan) or Mississippian (Chesterian) strata.
Recent palynology data suggest that the shale was deposited during the late Mississippian
(Osagean-Chesterian), making it equivalent to the Barnett Shale. The trend of the Barnett was
studied in a 25-mi2 (~65 Km2) area in the Central Midland Basin.
In the study area, siliceous-calcareous units comprising the Barnett shale can be divided
into an upper and lower unit. The upper unit can be further subdivided into six subunits by log
curve markers, interpreted as gravity-flow deposits consisting of silty bioclastic debris. Isopach
maps of the flow deposits suggest a source to the north. Preliminary TOC analyses suggest that
the upper Barnett section is relatively TOC lean, whereas the lower Barnett has higher values.
Exploration focus can be enhanced by detailed mapping of flows for the upper Barnett.