Marine and Petroleum Geology 23 (2006) 317–335
www.elsevier.com/locate/marpetgeo
Top seal development in the shale-dominated Upper Devonian
Catskill Delta Complex, western New York State
Gary G. Lash *
Department of Geosciences, College at Fredonia, State University of New York, Fredonia, NY 14063, USA
Received 29 March 2005; received in revised form 8 December 2005; accepted 4 February 2006
Abstract
The preferential generation of vertical natural hydraulic fractures at the contact of the Upper Devonian Hanover gray shale and overlying
Dunkirk black shale of the Catskill Delta Complex, western New York State, suggests that the latter served as a hydraulic top seal to formation
fluids migrating upward from deeper in the sediment pile. Petrophysical properties and small-scale textural characteristics of these siliceous finegrained rocks confirm the crucial role of depositional environment and sequence stratigraphic position of a shale lithotype in determining its
sealing capacity. The especially high sealing capacity of the basal interval of the Dunkirk shale, inferred early high-stand systems tract (HST)
strata, reflects the anoxic depositional environment of these deposits that favored the preservation of their abundant organic matter and finely
laminated depositional texture. The absence of bioturbation enabled the undisrupted sediment, notably carbonaceous clay-rich laminae, to
undergo rapid mechanical compaction, platy grain reorientation, and porosity reduction. Compaction-induced squeezing of ductile organic matter
into void spaces further reduced pore throat diameters. Immediately underlying heavily bioturbated deposits of the organic-lean Hanover shale,
inferred upper HST or low-stand wedge sediments, accumulated in a dysoxic depositional environment. Disruption of layering and
homogenization of sediment by burrowing organisms produced a more porous and permeable microfabric through which formation fluids moved
only to be arrested by the high capillary entry pressures at the base of the Dunkirk shale. Natural hydraulic fractures, some of which propagated
into the Dunkirk shale, formed when fluid pressure at the top of the Hanover shale reached the fracture gradient. The high sealing capacity of the
basal Dunkirk shale was probably enhanced by its finely laminated nature and the generation of biogenic methane, both of which contributed to the
formation of a near-impermeable gas capillary seal.
q 2006 Elsevier Ltd. All rights reserved.
Keywords: Top seal; Porosimetry; Upper Devonian; Appalachian basin; Gas capillary seal
1. Introduction
The fine grain size, small pore throat diameters, and high
capillary entry pressures of shale and mudstone exert a primary
control on the transmission of formation fluids, including
hydrocarbons, through these deposits (Aplin et al., 1995;
Schlömer and Krooss, 1997; Dawson and Almon, 1999, 2002).
Indeed, some shale lithotypes are especially efficient top seals to
fluid flow, enabling the buildup of overpressure in underlying
deposits (e.g. Krushin, 1997; Luo and Vasseur, 1997; Dawson
and Almon, 1999, 2002). Locally, however, top seals may be
compromised by the generation of natural hydraulic fractures
before capillary leakage takes place (e.g. Watts, 1987; Caillett,
1993; Darby et al., 1996). Such occurrences can have important
* Tel.: C1 716 673 3842; fax: C1 716 673 3347.
E-mail address: "$10#>lash@fredonia.edu
0264-8172/$ - see front matter q 2006 Elsevier Ltd. All rights reserved.
doi:10.1016/j.marpetgeo.2006.02.001
implications for hydrocarbon migration and entrapment as well as
for exploration and production strategies. The study of wellexposed top seals is crucial to gaining a greater appreciation of the
milieu of factors that affect top seal formation and behavior.
Indeed, the unique perspective offered by field exposures (e.g.
close sample spacing, relative ease of analysis of macro-textural
features and stratigraphic relationships) combined with observations gained through investigations of top seals in overpressured producing basins can enhance our understanding of this
most essential element of the petroleum system.
Vertical joints (mode I cracks), pervasive across the
Appalachian Plateau of western New York State and
interpreted to be natural hydraulic fractures (Engelder and
Oertel, 1985; Lacazette and Engelder, 1992; Lash et al., 2004),
provide indirect evidence that the shale-dominated Upper
Devonian clastic succession of the Catskill Delta Complex was
once overpressured. The especially high density of joints in
Upper Devonian organic-rich black shales is due in large part
to the generation of hydrocarbons in these very tight rocks
318
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
during the Carboniferous-Permian Alleghanian orogeny
(Loewy, 1995; Engelder et al., 1998; Lash et al., 2004).
However, the Upper Devonian shale succession exposed along
the Lake Erie shoreline in western New York State carries a
joint set that shows no affinity for black shale; instead, fractures
of this set, similar in most respects to other vertical natural
hydraulic fractures in Devonian rocks of the Appalachian
Plateau, are confined to the upper third of the organic-lean
Hanover gray shale and the basal few meters of the overlying
Dunkirk black shale. This paper makes the case that the
Dunkirk shale, by virtue of its depositional and early diagenetic
history, served as a top seal to overpressured formation fluids
migrating upward from deeper in the sedimentary pile. At some
point in time, fluid pressure at the top of the Hanover shale
reached the local fracture gradient resulting in the propagation
of vertical natural hydraulic fractures, some of which
penetrated a short distance into the overlying Dunkirk shale.
Downey’s (1984) suggestion that seals be studied at both the
macro- and microscopic scale is followed in this analysis. First,
field evidence for the existence of a top seal above the Hanover
shale is considered; this is followed by discussion of
petrophysical and microscopic parameters that may have
been vital to vertical fluid flow through the Hanover shale–
Dunkirk shale succession. The lack of layer-parallel shortening
strain produced during compressional tectonics of the
Alleghanian orogeny in these rocks (e.g. Hudak, 1992) allows
for detailed analysis of those factors critical to the development
of top seals in basinal marine shale- or mud-dominated
depositional systems.
2. Stratigraphic framework
The Upper Devonian clastic succession of western New
York State comprises a thick interval of marine shales and
scattered siltstone beds that grades upward into shallow
marine or brackish-water deposits (Fig. 1; Baird and Lash,
Fig. 1. Location map of the Walnut Creek section and generalized Upper Devonian stratigraphy of the Lake Erie shoreline region of the Appalachian Plateau, western
New York State. Note the field location of the stratigraphic interval shown in Fig. 2.
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
1990) thus recording progradation of the Catskill delta
across the Acadian foreland basin (Faill, 1985; Ettensohn,
1992). The shale-dominated basinal marine deposits are
arranged in several cycles, each one defined by a basal unit
of black shale that passes upward through a transition zone
of alternating black and gray shale beds into strata
dominated by gray shale and occasional siltstone and thin
black shale beds (Fig. 1). The basal black shale unit of each
cycle has been interpreted as a record of rapid cratonward
movement of the Acadian fold and thrust load followed
by deposition of gray shale (Ettensohn, 1985, 1992).
319
Specifically, each phase of thrust-sheet imbrication was
accompanied by rapid subsidence of the basin and
deposition of clastic-starved, organic-rich black shale.
Overlying gray shale and siltstone reflects tectonic relaxation, establishment of terrestrial drainage systems and delta
progradation (Ettensohn, 1985, 1992). However, the tectonostratigraphic explanation for cyclic deposition of Devonian
black and gray shales in the Appalachian Basin has been
challenged by models involving eustatic oscillations and/or
fluctuations in the productivity of marine organic matter
(Johnson et al., 1985; Werne et al., 2002).
Fig. 2. Stratigraphic log of the Hanover shale, Dunkirk shale, and lower Gowanda shale along Walnut Creek.
320
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
This study focuses on the Upper Devonian Hanover shale–
Dunkirk shale succession (HDS) most completely exposed
along Walnut Creek near the village of Silver Creek, New York
(Figs. 1 and 2). As pointed out below, the Hanover and Dunkirk
shales contain 40–65% detrital silt and comprise both
laminated and non-laminated deposits. According to the shale
classification of Lundegard and Samuels (1980), which is
based on silt abundance and fabric, the laminated shale is
termed mudshale and the non-laminated fine-grained deposits
are classified as mudstone. However, in order to minimize
terminology and because it is ingrained in the literature, the
term shale will be used throughout the balance of this paper.
The Hanover shale comprises w30 m of organic-lean
(0.09%!total organic carbon [TOC]!0.93%) gray shale,
occasional siltstone, thin- to thick-beds of black shale and
horizons of carbonate nodules (Fig. 2). The lack of primary
structures visible in exposed gray shale is testimony to the
heavily bioturbated condition of these deposits (Baird and
Lash, 1990) and/or deposition from muddy gravity flows.
Laminated black shale beds crop out at intervals throughout the
lower half of the Hanover shale along Walnut Creek, yet only
one carbonaceous shale bed is observed from w20 m above the
base of the unit to within a meter of its contact with the Dunkirk
shale (Fig. 2). Thin- to medium calcareous siltstone beds
become somewhat more abundant in this interval (Fig. 2). The
upper meter of the Hanover shale along Walnut Creek is
characterized by interbedded gray shale and finely laminated
organic-rich (3.4%!TOC!5.5%) black shale (Fig. 2).
The Hanover shale is abruptly overlain by the Dunkirk
shale, w17 m of laminated black and grayish-black shale, thin
gray shale and siltstone beds, and horizons of large (1.5 m
maximum diameter) internally laminated carbonate concretions (Figs. 2 and 3). The Hanover–Dunkirk contact is
erosional and marked by a lag deposit of reworked pyrite,
Hanover shale Dunkirk shale
Fig. 2 (continued)
Fig. 3. Hanover shale–Dunkirk shale contact (dashed white line), Walnut Creek
section. The contact is a marine (maximum) flooding surface that is interpreted
to be the boundary between the Dunkirk high-stand sequence and underlying
transgressive system (condensed sequence?) deposits of the upper Hanover
shale (see Fig. 16). The white arrow in the Hanover shale points to a
NS-trending joint; joints in the Dunkirk shale are younger ENE (065–0728)trending fractures.
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
321
Fig. 4. (A) NS-trending joint cutting shale and medium-bedded calcareous siltstone (tan layers) near the top of the Hanover shale. Photograph taken along the Lake
Erie shoreline near Dunkirk, New York. The estimated position of the Hanover shale–Dunkirk shale contact is indicated by the white line (width of the back pack to
the right of the jointZ30 cm); (B) close-spaced NS joints at the Hanover shale–Dunkirk shale contact (dashed white line), Walnut Creek section.
fish bones, wood debris, and conodonts (Baird and Lash, 1990;
Baird and Brett, 1991). The Dunkirk shale grades upward
through interbedded black and gray shale into the Gowanda
shale (Figs. 1 and 2), w70 m of gray and lesser black shale and
bundles of very thin- to medium-bedded siltstone. The
Gowanda shale is overlain by more than 560 m of shale and
very thin- to thick-bedded siltstone that records the gradual
infilling of the Acadian foreland basin in this region of the
Appalachian Basin (Baird and Lash, 1990).
fluid-driven or natural hydraulic fractures (Lacazette and
Engelder, 1992). Further, the locally large height: orthogonal
spacing ratio of the joints is at odds with their formation as
tensile fractures produced by joint-normal loading or
3. Joints
Inferences regarding fluid pressure generation and seal
development in the Catskill Delta Complex are based largely
on the distribution of several sets of fluid-driven joints (natural
hydraulic fractures) in these rocks (Engelder and Oertel, 1985;
Engelder and Lacazette, 1990; Lacazette and Engelder, 1992;
McConaughy and Engelder, 1999; Lash et al., 2004). Rocks of
the HDS carry four of five regional joint sets recognized in the
Upper Devonian succession of western New York State (Lash
et al., 2004). Of interest here are NS (352–0078)-trending
joints, which are confined to the upper third of the Hanover
shale and the lower w2.5 m of the Dunkirk shale. NS joints are
essentially vertical, very planar and continuous, extending
beyond the limits of exposure (Fig. 4A). The planarity and
continuity of the joints, as well as their straight overlapping
geometries (Fig. 4B), suggest that they formed under
conditions of relatively high (for mode I cracks) differential
stress (Olson and Pollard, 1989). Occasional arrest lines and
plumose structures observed on joint surfaces, especially those
that cut calcareous siltstone beds, suggest that the joints are
Fig. 5. Box-and-whisker diagrams representing orthogonal joint spacing
distribution for NS joints measured at three stratigraphic intervals of the
Hanover shale. The box encloses the interquartile range of the data set
population; the interquartile range is bounded on the left by the 25th percentile
(lower quartile) and on the right by the 75th percentile (upper quartile). The
vertical line drawn through the box defines the median value of the data
population, and the ‘whiskers’ define the extremes of the sample range.
Statistical outliers are represented by data points that fall outside the extremes
of the sample range.
322
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Fig. 6. (A) Three close-spaced NS joints that propagated various distances into the Dunkirk shale. White arrows denote joint tips (white scale barZ30 cm); (B) two
close-spaced NS joints in the Hanover shale that failed to penetrate the Dunkirk shale (white arrows define joint tips). Both images were photographed along the Lake
Erie shoreline, Dunkirk, New York. Dashed white lines in both photographs mark the Hanover shale–Dunkirk shale contact.
stretching. Rather, the close spacing of the NS joints, especially
proximal to the Hanover–Dunkirk contact (Fig. 5), is more
consistent with their propagation as fluid-driven fractures
(Ladeira and Price, 1981; Fischer et al., 1995; Engelder and
Fischer, 1996). All observed abutting relations of NS joints and
joints of other sets indicate that the former are the older
structures.
Especially noteworthy to current considerations is the
restriction of NS joints to a narrow stratigraphic interval
that encompasses the upper third of the Hanover shale and
lower few meters of the Dunkirk shale. The degree of NSjoint saturation, as measured by orthogonal spacing,
increases upward through the Hanover to its contact with
the Dunkirk shale (Fig. 5), yet fewer than one in five
observed joints penetrate more than 20 cm into the black
shale (Figs. 4B and 6A,B). Roughly 50% of NS joints
examined in this study either were arrested at the base of
the Dunkirk shale or failed to reach the black shale
(Fig. 6C). Rarely are NS joints found exclusively in the
Dunkirk shale; indeed, O80% of studied NS joints in the
Dunkirk shale can be traced down into the Hanover shale.
These observations suggest that the bulk of the NS joints
originated within the Hanover shale.
4. Pressure cell model
Confinement of the vertical NS-trending joints to the upper
third of the Hanover shale and lower few meters of the Dunkirk
shale is consistent with pressure-depth profiles and related
in situ stresses documented from modern basins where the
interplay of minimum horizontal stress, Sh, and fluid pressure,
Pp, through a seal has the potential to induce natural hydraulic
fractures (Fig. 7). Industry data, principally in the form of leakoff test and repeat formation test results, from the Central
Graben of the North Sea reveals a multi-layered pressure
system where normally pressured Upper Cretaceous and
overlying deposits serve as a pressure sink for high formation
pressures generated deeper in the sedimentary pile (e.g. Holm,
1996, 1998). Approximately hydrostatic pressure conditions
exist to the depth of the Lower Cretaceous Comer Knoll group
marls and underlying organic-rich upper Jurassic Kimmeridge
claystone formation through which Pp increases at more than
twice the hydrostatic gradient (Holm, 1998). Formation
pressure in overpressured rocks beneath the Kimmeridge
Claystone Formation continues to build with increasing
depth, but at approximately the hydrostatic gradient, indicating
that these deposits are in hydraulic communication (Darby
323
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
overpressure in the pressure cell will dissipate, at least
temporarily.
The Dunkirk shale is analogous to the Kimmeridge claystone
formation in its role as a top seal, though the depth of fluid
retention (i.e. elevation of Pp above hydrostatic pressure at a
given depth) may have been well up into the Gowanda shale
(Fig. 1). Overlying increasingly siltstone-rich deposits of the
Catskill Delta Complex in western New York State are
comparable to the upper cretaceous clastic rocks of the Central
Graben. Concentration of the early formed vertical natural
hydraulic fractures in the upper Hanover shale and lower few
meters of the Dunkirk shale suggests that the latter was a
hydraulic top seal, a barrier defined by such a high capillary entry
pressure that the rock leaked by natural hydraulic fracturing
before its capillary entry pressure was exceeded (Watts, 1987).
Further, the high height: orthogonal spacing ratio of NS joints,
especially at the Hanover–Dunkirk contact, suggests that natural
hydraulic fracturing occurred episodically (e.g. Roberts and
Nunn, 1995). Elevation of Pp to the fracture gradient resulted in
hydraulic fracturing followed by dissipation of Pp and closure of
the crack. When Pp again rose, new fractures formed well within
the stress reduction shadows of early formed, but closed, fractures
and/or older fractures were reopened and lengthened (Roberts
and Nunn, 1995). Below, petrophysical, compositional, and
small-scale or microscopic textural properties of the Dunkirk
shale and Hanover shale that may have contributed to their
respective abilities to transmit or inhibit formation fluids are
considered.
Fig. 7. Idealized pressure–depth plot from normally pressured deposits, through
a top seal and into a pressure cell showing changes in pore pressure from
(Pp) and resultant changes in effective
hydrostatic (Phyd) to overpressured
minimum horizontal stress Sh0 and, therefore, rock strength. Inferred position
of the Hanover–Dunkirk–Gowanda succession within the pressure cell-top seal
system is also shown. This figure should not be taken to mean that hydrostatic
pressure conditions existed down to the top of the Dunkirk shale. Rather, the
departure from Phyd probably occurred within the Gowanda shale. SvZ
overburden stress; ShZminimum horizontal stress and an approximation of the
fracture gradient (modified from Gaarenstroom et al., 1993).
5. Methodology
et al., 1996). Thus, the pressure transition zone defined by the
Comer Knoll Group and Kimmeridge Claystone Formation is a
top seal to overpressured formation fluids in the underlying
pressure cell (Baird, 1986; Gaarenstroom et al., 1993; Leonard,
1993; Holm, 1996, 1998). The most critical interval of this
system is found at the base of the seal, the Kimmeridge
Claystone Formation, and top of the pressure cell where, as
predicted by the Terzaghi effective stress relationship, effective
minimum horizontal stress, Sh0 , approaches zero placing the
rocks in a state of incipient vertical natural hydraulic fracture
generation (Fig. 7; e.g. Gaarenstroom et al., 1993; Leonard,
1993; Caillett, 1993; Holm, 1998). The integrity or retention
capacity of the top seal under these conditions, then, is
predetermined by Sh, which controls the level of maximum
sustainable Pp (Gaarenstroom et al., 1993). That is, if Sh0 Z 0,
(i.e. ShZPp), the rocks near the top seal–pressure cell contact
will fail by fracturing, the seal may be compromised and
Shale samples of the HDS were collected for analysis by
mercury injection capillary porosimetry (MICP), X-ray
diffraction (XRD), thin section and scanning electron
microscopy (SEM), and Rock-Eval pyrolysis. All samples
were collected from O5 cm into exposures to minimize the
effects of weathering. Analytical results are summarized in
Table 1.
5.1. Mercury injection capillary pressure
The sealing capacity of six shale samples collected over a
w35 m interval of the HDS spanning the Hanover–Dunkirk
contact, three each of the Dunkirk and Hanover shales (see Fig. 2
for MICP sample locations), was determined by mercury
injection capillary pressure measurement (refer to Jennings,
1987; Almon and Thomas, 1991; Vavra et al., 1992; and Krushin,
Table 1
Summary table of major characteristics of the Dunkirk shale and Hanover shale
Dunkirk shale
Hanover shale
10% Hg
saturation (psia)
Permeability (m2)
Porosity (%)
Silt (%)
Cement (%)
TOC (%)
Median pore
throat diameter
(nm)
Fabric
10,890–14,200
920–4850
2.6!10K21
2!10K18
3.24
5.97
51
54
1.9
8.9
2.3–4.7
0.1–0.9
7.1
23.9
Strongly oriented
Random to
moderately oriented
324
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
1997, for discussion of porosimetry methodology). Samples
selected for porosimetry analysis were recovered from polished
slabs (typically O50 cm2) in order to assess, as best possible,
sample heterogeneity. Each sample collected from a polished slab
was studied by optical and electron microscopy to rule out the
presence of microfractures. Porosimetry measurements were
made perpendicular to layering on epoxy-jacketed samples by
PoroTechnology, Stafford, Texas. Capillary pressure curves
generated by the step-wise increase in mercury injection pressure
were used to evaluate sealing capacity and pore throat diameter
sorting (e.g. Jennings, 1987). Schowalter (1979) maintains that
compromise of a shale seal by capillary leakage occurs when the
level of hydrocarbon saturation of a water-wet seal falls between
5 and 10%. Similarly, Rudd and Pandey (1973) argue that shale
transmits fluid at mercury saturation levels of less than 10%.
Thus, the mercury intrusion pressure at 10% saturation (the
displacement pressure of Schowalter, 1979) serves as a proxy for
seal efficiency. In addition, to facilitating the calculation of
sealing capacity, porosimetry measurements can be used to
estimate the distribution of pore volume accessible by pore
throats of a given size, pore throat sorting, porosity, and
permeability (Jennings, 1987; Vavra et al., 1992; Boult, 1993;
Krushin, 1997).
5.2. Petrographic (thin section and electron microscopic)
analysis
Thin section analysis provides useful information
regarding macro-textural features, including lamination
type and bioturbation (O’Brien and Slatt, 1990), mineralogy,
and grain shape (i.e. aspect ratios of organic particles) and
orientation (e.g. Sutton et al., 2004). The bulk mineralogy
of the six shale samples analyzed by MICP was carried out
by XRD. Point counts of 300 grains of each sample yielded
results within 5% of the correlative XRD results. Having
established consistency between both analytical methods, an
additional 10 shale samples, seven Hanover and three
Dunkirk samples, were point counted for framework grains
(quartz, feldspar), clay and diagenetic cement. Carbonate,
principally calcite, is the dominant cement, followed in
abundance by quartz. Diagenetic quartz forms elongate or
lobate grains that appear to have filled void spaces,
principally the result of early dissolution of radiolaria by
pore water. Detrital quartz grains, on the other hand, are
angular and roughly equi-dimensional. Quartz silt grains
that could not be positively identified as detrital or
authigenic were not counted.
Fig. 8. Petrophysical and compositional parameters plotted against stratigraphic position within the Hanover–Dunkirk succession.
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Each shale sample studied in thin section was analyzed by
backscattered and secondary electron imaging techniques.
Shale samples, prepared for SEM analysis as per O’Brien and
Slatt (1990), were mounted on double-sided adhesive carbon
tape such that the viewing direction was normal to bedding.
Samples were coated with 20 nm of evaporated carbon to
render the surface conductive and analyzed on a Hitachi
S-4000 Field Emission SEM operating at 30 keV. Digital
secondary electron images were collected with a 4PI digital
imaging system.
5.3. Organic carbon content
Total organic carbon content of 13 shale samples collected
from the HDS was measured in tandem with Rock-Eval
pyrolysis measurements. Analytical work was carried out by
Geochemical and Environmental Analysis, Université de
Neuchâtel, Switzerland.
325
within 3 m of its contact with the Dunkirk shale (Fig. 8).
Dunkirk shale samples are defined by markedly higher seal
capacities; 10% mercury saturation is achieved at 14,200 psia
at the base of the Dunkirk, diminishing to 10,890 psia at the top
of the unit (Fig. 8). The difference between the high and low
10% mercury saturation values for both units is great, yet
variation among the Hanover samples is proportionately
greater than that of the Dunkirk shale samples; i.e. 80 versus
23% of the maximum sealing capacity of the Hanover and
Dunkirk, respectively. Dunkirk shale samples possess a lower
average porosity (Table 1); median pore throat diameters of the
Hanover samples (13.3–44.4 nm) are markedly larger than
those of the Dunkirk shale (6.7–7.3 nm; Fig. 8). Moreover,
MICP curves (Fig. 9) and pore throat size distribution plots
(Fig. 10) illustrate a high degree of pore throat diameter sorting
among Dunkirk samples; Hanover shale samples, on the other
hand, display a more variable and lower degree of pore throat
6. Results
Sealing capacities of the HDS samples vary widely over the
limited stratigraphic interval studied (Fig. 8). The 10%
mercury saturation level of the Hanover shale samples ranges
from a low of 920 psia in the lower third of the unit to 4850 psia
Fig. 9. Mercury injection capillary pressure curves for the Hanover shale and
Dunkirk shale samples. Note the line denoting the 10% mercury saturation
pressure.
Fig. 10. Pore throat size distribution curves for the Hanover shale and Dunkirk
shale samples. The plots are arranged in stratigraphic order within each unit
(refer to Fig. 2 for sample locations).
326
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Fig. 11. Plots of sealing capacity versus selected petrophysical and compositional parameters. Gray arrows indicate younging directions of the samples within their
respective units.
diameter sorting. It is noteworthy that pore throat diameter
sorting of the Hanover shale samples decreases upward; a
similar but more subtle trend appears to hold for the Dunkirk
shale (Fig. 10). Finally, regardless of pore throat diameter
sorting, median pore throat diameter correlates negatively with
sealing capacity for all six HDS samples (Fig. 11A).
Thin section and XRD analysis reveals little difference in
total silt content between the Dunkirk and Hanover shales.
Indeed, although the mean detrital silt content of studied
Hanover shale samples (54%; nZ10) is marginally greater
than that of the Dunkirk shale (51%; nZ6), comparison of
means by a one-way ANOVA (Analysis of Variance) test
failed to reject the null hypothesis that there is no statistically
significant difference between the means (rZ0.2089). No
consistent relationship between detrital silt content and sealing
capacity was observed in the HDS samples (Figs. 8 and 11B).
Specifically, the increase in sealing capacity upward through
the Hanover shale, which mirrors an increase in the frequency
of calcareous siltstone beds (see Fig. 2), appears to be
accompanied by increasing sealing capacity (Fig. 11B). On
the other hand, the highest sealing capacity Dunkirk shale
samples at the base of the unit contain less silt than the lower
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
sealing capacity sample collected from near the top of the unit
(Fig. 11B).
There is no discernable relationship between the abundance
of calcite and quartz cement and sealing capacity over the
sampled interval of the HDS (Figs. 8 and 11C). Those samples
with the highest sealing capacity, the Dunkirk black shale,
contain only minor calcite and quartz cement, whereas
Hanover shale samples contain as much as 10% cement
(Figs. 8 and 11C). Indeed, that Hanover shale sample defined
by the lowest seal capacity (920 psia) contains the highest
amount of cement (Figs. 8 and 11C).
Clay mineral diagenesis has the potential to affect porosity
and fluid migration in compacting sediments (e.g. Bruce, 1984;
Shaw and Primmer, 1989; Bjørlykee and Høeg, 1997; Geir,
2000). In particular, the conversion of smectite to mixed-layer
illite–smectite and illite can result in the occlusion of pore
throats (Selley, 1998). Thus, widespread neoformation of clay
minerals in the HDS following NS jointing could have affected
petrophysical properties of these rocks, including sealing
capacity, porosity, and pore throat sorting.
Hosterman (1993) demonstrated that illite comprises the
bulk (40–90%) of the clay mineral fraction of Devonian black
shales of the Appalachian Basin. XRD analyses of six HDS
samples are consistent with Hosterman’s observations; illite is
by far the most abundant clay mineral in both the gray and
black shale (72–80%), followed by chlorite (11–14%),
kaolinite (3–7%), and finally, mixed-layer illite–smectite
(2–7%). However, rather than reflecting a high degree of
thermal maturation, the plentiful illite may tell of a source
terrane rich in illite. Strickler and Ferrell (1989), for example,
argued that the great abundance of illite in Louisiana Gulf
Coast clays reflects derivation from the Appalachian orogen.
Moreover, the location of the HDS along the Lake Erie
shoreline places these deposits in a region of inferred very low
illite crystallinity (Hosterman, 1993), which is consistent with
the low measured vitrinite reflectance values of these deposits
(0.55–0.62%; Lash et al., 2004). Finally, in their analysis of
clay mineral diagenesis in North Sea deposits, Pearson and
Small (1988) demonstrated that illitization occurs at depths of
2.4–3.5 km, within a vitrinite reflectance range of 0.54 and
0.72% and a temperature range of 87–100 8C. The modeled
maximum burial depth and temperature of the Dunkirk shale
based on a measured vitrinite reflectance of 0.62% and
assuming a geothermal gradient of 30 8C/km is 2.3 km and
88 8C, respectively, (Lash et al., 2004), barely at the minimum
threshold depth and temperature of illitization in the North Sea.
The contention that the Dunkirk shale failed to reach
thermal levels high enough for pervasive illitization appears to
be confirmed by a lack of textural evidence of widespread clay
mineral diagenesis in studied HDS samples. For example, the
presence of K-feldspar (0.9–1.5%) in all analyzed HDS shale
samples suggests that conversion of smectite to illite–smectite
had not resulted in the total loss of feldspar. Moreover, the
several K-feldspar grains observed in the backscattered
electron mode show no evidence of dissolution, which
typically accompanies illitization (Eberl and Hower, 1976;
Pearson and Small, 1988; Shaw and Primmer, 1989, 1991).
327
Shaw and Primmer (1991) illustrated that burial-related
neoformation of clay minerals in the Kimmeridge Claystone
Formation occurred primarily in microfossil tests and/or voids
within partially dissolved minerals, notably K-feldspar, rather
than within the clay matrix. No microfossil tests have been
observed in HDS samples; indeed, the only voids that might
have filled with authigenic clay minerals are Tasmanites cysts,
many of which were compressed early in the mechanical
compaction history of these deposits (e.g. see Fig. 14B). Those
cysts that filled during diagenesis contain pyrite framboids and
crystallites to the exclusion of clay minerals. In sum, then, clay
mineral diagenesis appears to have been minimal in HDS
samples, the abundant illite being more a record of source
terrane mineralogy than the level of thermal maturity. No
doubt, some burial-related neoformation of clay minerals,
especially chlorite and illite–smectite, has occurred in these
rocks. Indeed, it may be that the very small amount of mixedlayer illite–smectite in analyzed HDS samples reflects the
conversion of minimal detrital smectite during burial diagenesis. However, the likely mode of diagenetic mineral growth in
HDS samples, conversion of detrital grains such as K-feldspar
and smectite, would not have resulted in appreciable post-NS
jointing modification of capillary properties of these rocks,
assuming that diagenesis occurred after jointing.
Microscopic analysis of Hanover gray shale samples
confirms the pervasively bioturbated nature of these deposits
based on field observations (e.g. Baird and Lash, 1990) and the
study of polished slabs. Notably, thin section microscopy
reveals detrital silt grains distributed throughout a mottled clay
matrix, the result of homogenization of the originally
laminated sediment by burrowing organisms (Fig. 12A); rare
silt laminae depict the disruptive effects of bioturbation
(Fig. 12B). SEM observations show an open microfabric of
variably oriented platy grains (Fig. 12C). Angular silt grains
dispersed throughout the ‘swirled’ clay matrix appear to have
propped open larger voids and pore throats during compaction
precluding complete reorientation of the disrupted fabric
(Fig. 12D). In addition to a more or less even distribution of
silt grains throughout the clay matrix, detrital silt grains also
comprise mottles, likely filled burrows (Fig. 12E). The general
lack of primary structures and discrete burrow traces in field
exposures and thin sections suggests a level of bioturbation
equal to ichnofabric index 5 or 6 of Pemberton et al. (1992).
Petrographic and SEM examination of shale samples
collected from the base to the top of the Dunkirk shale along
the Walnut Creek section reveals the unit to be dominated by
two shale lithotypes: laminated pyritic black shale and
moderately bioturbated black shale (Lash and Engelder,
2005). The former, which dominates the lower third to half
of the Dunkirk shale, is characterized by generally continuous
thin to thick (O0.1 mm) quartz silt laminae that alternate with
dark, silt-poor carbonaceous clay layers (Fig. 13A). Scanning
electron microscopy shows the organic-rich clay layers to be
defined by a tight, bedding-parallel arrangement of clay grains
and flattened organic particles, locally disrupted by angular silt
grains and pyrite framboids (Fig. 13B and C). These rocks
show no evidence of bioturbation and thus, are classified as
328
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Fig. 12. Microfabric of the Hanover shale: (A) thin section image showing mottled texture and evenly dispersed silt grains (scaleZ0.1 mm); (B) thin section image of
disrupted (bioturbated?) silt laminae (scaleZ0.1 mm); (C) secondary electron image of the open, random microfabric typical of the gray shale; (D) secondary
electron image of angular detrital silt grains (s) and moderately planar microfabric in gray shale; (E) thin section image of a silt-filled mottle in gray shale
(scaleZ0.1 mm).
ichnofabric index 1 of Pemberton et al. (1992). The moderately
bioturbated black shale, most common to the upper part of the
Dunkirk shale, lacks the finely laminated structure described
above; instead, angular silt grains are distributed throughout
the organic-rich clay matrix (Fig. 13D). SEM observations
reveal an open to moderately planar clay grain microfabric
(Fig. 13E). Disrupted silt laminae and/or flattened silt-filled
burrows (Fig. 13F) indicate that the sediment was partially
reworked by burrowing organisms (ichnofabric index 2 or 3,
Pemberton et al., 1992).
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
329
Fig. 13. Microfabric of the Dunkirk shale: (A) thin section image of interlaminated silt and organic-rich clay (scaleZ0.5 mm); (B) secondary electron micrograph of
the planar microfabric of a clay laminae sample; (C) secondary electron micrograph showing compacted clay grains wrapping a pyrite framboid in a clay laminae
sample; (D) thin section image of bioturbated silt laminae and dispersed silt grains in clay laminae (scaleZ0.5 mm); (E) secondary electron image showing a large,
angular detrital quartz silt grain supported by a matrix of randomly oriented clay grains. The open clay microfabric in this sample is more likely a consequence of
bioturbation rather than the shielding effect of this single large quartz grain; (F) thin section image of bioturbated silt laminae and/or flattened silt-filled burrows and
abundant dispersed silt grains (scaleZ0.5 mm).
Hanover gray shale samples contain uniformly low
amounts of organic matter, typically !0.75% TOC
(Fig. 8). The organic carbon content of the Dunkirk shale
is highest at its base (TOCZ4.67%), diminishing upward
through the unit (Fig. 8). Thin section and SEM analysis
shows that much of the organic matter in the Dunkirk
samples has been flattened by mechanical compaction
(Fig. 14A), especially in the high sealing capacity basal
interval of the unit where most analyzed organic particles
have aspect ratios O10 (Fig. 15). The moderately
bioturbated, less organic-rich (TOC!2.3%) deposits higher
in the Dunkirk shale are defined by a sealing capacity
higher than that of the most resistant Hanover sample but
w25% lower than the sealing capacity of those samples
330
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Fig. 14. (A) secondary electron image of a clay laminae sample collected from
the lower 2 m of the Dunkirk shale. Note planar microfabric and flattened
organic particles, mostly Tasmanites cysts (white arrows); (B) thin section
image of a silty, moderately bioturbated black shale sample collected from the
upper 3 m of the Dunkirk shale. Note that the dark organic matter has been
compressed around quartz grains (scaleZ0.1 mm).
recovered from the carbonaceous basal interval of the
Dunkirk shale (Figs. 8 and 11D). Although organic matter is
not as abundant in samples recovered from the upper part of
the Dunkirk shale, microscopic observations show that those
organic particles present have been molded around inorganic
matrix grains and into pore throats thereby enhancing the
sealing capacity of these deposits (Fig. 14B).
determinants of sealing capacity in the HDS include the nature
of distribution of detrital silt grains (confined to discrete
laminae versus randomly distributed throughout the clay
matrix and/or concentrated in silt mottles), the degree of
bioturbation, and TOC content. The highest sealing capacity
deposits, the finely laminated organic-rich lower Dunkirk
shale, are not bioturbated. The undisrupted condition of these
deposits enabled the sediment, especially the clay layers, to
undergo relatively rapid mechanical compaction and consequent reorientation of originally flocculated clay flakes into a
bedding-parallel planar microfabric (e.g. O’Brien, 1995; Lash
and Blood, 2004a). The loss of porosity early in the diagenetic
history of these deposits probably accounts for their low
porosity and minimal cement. Mechanical compaction of clay
laminae was accompanied by the flattening of abundant ductile
organic particles into void spaces thereby further reducing pore
throat diameters.
Recently, Worden et al. (2005) argued that the planar
microfabric of illite-rich mudstones can be produced as a
consequence of the replacement of smectite by illite. Several
lines of evidence argue against the development of the
anisotropic microfabric observed in Dunkirk shale samples as
a result of illitization. As noted earlier, the inferred low level of
thermal stress and relatively shallow depth of burial of the
Dunkirk shale is not consistent with widespread illite
neoformation. Further, Lash and Blood (2004a) described
very open microfabrics typical of flocculated clay preserved in
strain shadows adjacent to early formed carbonate concretions
in Upper Devonian black shale of western New York State.
Laterally equivalent shale samples collected 0.2–0.3 m from
the strain shadows, however, are defined by a strongly
anisotropic bedding-parallel microfabric suggesting that the
microfabric was produced by mechanical compaction of
flocculated clay. Finally, illite is equally abundant in those
Hanover samples analyzed by XRD as in Dunkirk shale
samples, yet the former shows only minimal to moderate planar
grain alignment.
7. Discussion
Shale units are important barriers to fluid flow in
sedimentary basins and serve as effective top seals to the
majority of known petroleum reservoirs (Dawson and Almon,
1999, 2002). Nevertheless, these deposits have yet to receive a
level of study commensurate with their crucial role in the
petroleum system. The well-exposed HDS provides an
excellent opportunity to further our understanding of shale
top seals over a range of scales, from that of their microfabric
to their position within a sequence stratigraphic framework.
Those factors that appear to have been the most crucial
Fig. 15. Frequency plot of aspect ratios of organic particles in samples collected
from the lower 3 m of the Dunkirk shale. Aspect ratios were estimated first by
measuring the long and short dimensions of organic particles and then by
calculating the ratio of the former to the latter.
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
The comparatively low sealing capacities of the Hanover
shale samples reflect the high-degree of bioturbation and
related sediment disruption visited on these deposits.
Moreover, rigid detrital silt grains, redistributed throughout
the clay matrix by burrowing organisms, resisted platy grain
reorientation during mechanical compaction by shielding or
propping open larger pore throats thereby imparting a higher
porosity and permeability to these deposits (e.g. Krushin,
1997; Katsube and Williamson, 1998; Dewhurst et al.,
1998). The wide variation in sealing capacity and port
throat size and sorting of analyzed Hanover samples is
probably more a function of the nature of silt distribution—
i.e. mottled versus evenly disseminated—than any other
factor.
The relatively open microfabric of black shale higher in the
Dunkirk shale, a consequence of the moderate level of
bioturbation sustained by these deposits, is manifested by a
lower sealing capacity than that of the finely laminated
carbonaceous strata of the lower Dunkirk shale. The reduction
in sealing capacity upward through the Dunkirk shale probably
reflects the complex interrelationship of bioturbation and
detrital silt and TOC content. The apparent increase in silt
toward the top of the unit and, perhaps more importantly, the
moderate level of bioturbation and related redistribution of
detrital silt grains displayed by these deposits likely contributed to their reduced sealing capacity. However, although
the organic carbon content of these deposits is half that of the
basal strata, enough disseminated ductile organic matter was
331
forced into pore throats during mechanical compaction to
maintain a sealing capacity in excess of the tightest Hanover
sample.
Dawson and Almon (1999, 2002) and Sutton et al. (2004)
make a compelling case for the strong relationship between the
depositional environment of a shale lithotype, as expressed in
its sequence stratigraphic position, and its sealing capacity.
Upper transgressive systems tract (TST) and condensed
sequence (CS) shales form the best seals, they suggest;
coarser-grained high-stand systems tract (HST) and lowstand systems tract (LST) shales have somewhat lower sealing
capacities. The general lack of primary structures in rocks of
the shale-dominated HDS precludes easy environmental
interpretation; still, the sequence stratigraphic interpretation
offered here (Fig. 16) accords in general terms with Smith and
Jacobi’s (2001) sequence stratigraphic framework of the Upper
Devonian stratigraphic interval w80 km to the east in a more
shallow region of the basin.
The Hanover shale likely accumulated under dysoxic
conditions, which would have favored the extensive
bioturbation and, ultimately, the relatively low sealing
capacity of these deposits. The strongly bioturbated nature
of the Hanover shale suggests that bioturbation kept pace
with sediment accumulation, perhaps as hemiturbidites (e.g.
Stow and Wetzel, 1990; Stow and Tabrez, 1998). The
Hanover shale, by virtue its moderate increase in silt
content and decrease in the frequency of black shale beds
upward from its contact with the Pipe Creek shale is
Fig. 16. Sequence stratigraphic interpretation of the Hanover–Dunkirk sequence. Refer to text for details.
332
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
ascribed to a HST sequence (Fig. 16). The scarcity of black
shale and the subtle increase in the frequency of calcareous
siltstone beds near the top of the Hanover shale (see Fig. 2)
may reflect accumulation of these deposits as part of a lowstand systems wedge (Posamentier and Vail, 1988), though
limited data makes this interpretation difficult at best. Baird
and Brett (1991) interpret the Hanover–Dunkirk contact, a
submarine erosional disconformity, as a marine flooding
surface that formed following accumulation of CS/TST
deposits (Fig. 16). The erosional episode reflected in the
disconformity may have resulted in the loss of CS/TST
deposits leaving only the w1-m-thick interval of interbedded black and gray shale immediately beneath the
contact (see Fig. 2). It is noteworthy that the depth of
erosion diminishes to the east (Baird and Brett, 1991).
Accumulation of the Dunkirk shale above the marine flooding
surface probably signaled the onset of a high-stand interval
(Fig. 16; Posamentier and Vail, 1988). The lack of bioturbation
and high TOC of the lower Dunkirk shale, the most effective seal
deposits in the HDS, is reflective of an anoxic depositional
environment that favored the preservation of the finely laminated
character of these deposits and the abundant organic matter.
Gravitational compaction of clay laminae into a tight, beddingparallel microfabric and the molding of abundant ductile organic
matter into pore throats occurred soon after deposition. Higher in
the Dunkirk HST, a moderate level of bioturbation, likely the
result of increased dissolved O2, disrupted the sediment fabric
thereby diminishing the sealing capacity of these deposits
(Fig. 16). However, compaction-induced squeezing of disseminated organic matter into void spaces of the sediment framework
contributed to a sealing capacity manifestly higher than that of the
most resistant Hanover shale sample.
The 17-m-thick Dunkirk shale is not an especially thick seal by
comparison with top seals documented from modern basins. Fluid
retention in the post-Dunkirk sedimentary column may have
occurred well up into the Gowanda shale, yet the most effective
part of the seal was the Dunkirk shale, especially its lower
interval. Deming (1994) demonstrated that the time over, which a
seal may persist before failing by capillary leakage is proportional
to the square of the seal thickness and inversely proportional to
the permeability of the seal as per the following expression
t Z ðz2 =kÞ !ð2:4 !10K27 Þ;
(1)
where t is the maximum duration of the seal in million years, z is
the seal thickness in meters, and k is permeability. Assuming that
the Dunkirk shale had been compacted to its present 17-m
thickness by the time it began to prevent vertical migration of
fluids and using a mean permeability of 2.6!10K21 m2 for the
Dunkirk shale based on MICP measurements indicates that
the black shale seal would have been compromised after the
unrealistic time of only 270 years. Doubling the thickness of the
Dunkirk shale extends the duration of seal integrity only to
w1000 years.
The estimates of seal duration of the Dunkirk shale cited
above are well shy of what would be considered by most to be a
geologic interval of time (e.g. Deming, 1994), especially in
light of the fact that natural hydraulic fractures were generated
before capillary leakage occurred. Confinement of overpressured fluids by the 17-m-thick Dunkirk shale for 1 MY
would have required a permeability of less than 7!10K25 m2,
two orders of magnitude lower than the lowest measured shale
permeabilities (Neuzil, 1994, 1995). The extraordinarily high
sealing capacity of the Dunkirk shale, beyond that reflected in
its petrophysical and textural/microfabric characteristics, may
have been a response to the generation of biogenic methane
within these organic-rich deposits. Gas capillary seals,
especially durable barriers to vertical fluid flow, form in
layered sequences of variable grain size and in the presence of
free methane (Revil et al., 1998, 1999; Shosa and Cathles,
2001). Such seals can form very early in the burial history of
sediment and at relatively shallow depths. Indeed, Revil et al.
(1998, 1999) demonstrate that Pp at ODP Site 975 in the
Western Mediterranean at a sub-seafloor depth of only 170–
240 m, immediately below an inferred gas capillary seal,
equals lithostatic pressure thereby placing the sediment in a
condition of incipient open mode fracture.
The accumulation of sediment tends to drive pore water
vertically through interconnected pores. When methane is
produced by decomposition of organic matter, upward flow
involves both water and methane. The methane accumulates
preferentially in coarser grained (silt, sand) layers while the
water is confined to clay layers (Revil et al., 1998, 1999;
Deming et al., 2002). After enough methane has accumulated
in a coarse-grained layer to form an interconnected phase, the
flow of both methane and water is halted and a nearimpermeable gas capillary seal is formed at the layer interface.
A pressure differential (the capillary entry pressure) that is
partly a function of the respective pore throat radii of the fine
and coarse grained sediment must be overcome (Revil et al.,
1998) for the gas to invade the overlying fine-grained layer.
However, the great strength of the gas capillary seal comes not
from the pressure differential across individual layer interfaces,
but rather from the sum of the capillary pressure drops across
each interface (Revil et al., 1998; Cathles, 2001; Shosa and
Cathles, 2001). Indeed, Cathles (1996) maintains that gas
capillary seals can only be compromised by natural hydraulic
fracturing.
The concentration of NS-trending joints in the upper part of
the Hanover gray shale suggests that natural hydraulic
fracturing was not linked to the thermal generation of
hydrocarbons in the Dunkirk shale, which is the case for
subsequent joints preferentially formed in black shale units of
the Catskill Delta Complex during the Alleghanian orogeny
(Lash et al., 2004). Indeed, the NS joints probably formed
before the Dunkirk shale was buried deep enough to produce
thermally generated hydrocarbons (Lash et al., 2004). Several
aspects of the Dunkirk shale favor the relatively early and
shallow formation of gas capillary seals within this organicrich unit. Most notably, the interlaminated siltstone and
claystone, especially in the lower part of the Dunkirk shale,
would have provided a framework within which to segregate
biogenic methane and water. Still, the key ingredient in the
development of a gas capillary seal is methane, which, upon
sequestration in coarse-grained layers, causes a dramatic
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
reduction in permeability across sedimentary interfaces (Revil
et al., 1998; Shosa and Cathles, 2001; Deming et al., 2002).
Results of stable carbon isotope analysis of carbonate
concretions in the Upper Devonian Rhinestreet black shale of
western New York State (see Fig. 1) suggest that the carbon
necessary to sustain the growth of the large concretions
originated within the zone of biogenic methanogenesis (Lash
and Blood, 2004b). Similarly, moderately depleted carbon
isotope values of carbonate samples collected from Dunkirk
shale concretions (d13CZK11.2‰ PDBG2.4‰; nZ4) probably reflects the generation of biogenic methane in the organicrich host sediment.
8. Conclusions
The restriction of vertical natural hydraulic fractures to the
contact of the Upper Devonian Hanover gray shale and
overlying Dunkirk black shale of the western New York
Appalachian Plateau indicates that the latter was a top seal to
overpressured fluids early in the Alleghanian orogeny. The
generation of open mode joints in this relatively narrow
stratigraphic interval comports with known pressure/depth
gradients and in situ stresses documented from modern basins,
notably the Central Graben of the North Sea where the
Kimmeridge claystone formation serves as a top seal inhibiting
the movement of overpressured fluids from the underlying
pressure cell. Episodic natural hydraulic fracturing at the
Hanover–Dunkirk contact suggests that the organic-rich shale
was a hydraulic seal that halted the vertical migration of
formation fluids. At length, Pp at the top of the Hanover shale
reached the fracture gradient resulting in the propagation of
natural hydraulic fractures before the capillary entry pressure
of the Dunkirk shale was exceeded.
The inferred high sealing capacity of the Dunkirk shale
based on the preferential development of the NS-trending
natural hydraulic fractures is confirmed by consistently high
(O10,000 psia) 10% mercury saturation pressures for samples
collected from the base and top of the Dunkirk. The high
sealing capacity of the Dunkirk shale, especially its basal
interval, reflects its finely laminated nature, the confinement of
most detrital silt to discrete laminae, the lack of bioturbation,
and high organic carbon content. The somewhat lower sealing
capacity of moderately bioturbated, less carbonaceous deposits
that comprise much of the upper half of the Dunkirk shale
confirms the importance of both bioturbation and TOC content
as determinants of sealing capacity. Ultimately, these factors
are linked inextricably to the depositional environment and
sequence stratigraphic position of each shale lithotype. The
anoxic depositional environment of the lower part of
the Dunkirk shale, inferred early HST deposits, favored the
preservation of abundant organic matter and the finely
laminated depositional structure of the sediment. The lack of
bioturbation enabled these deposits, especially the clay-rich
laminae, to undergo rapid mechanical compaction.
Compaction-induced squeezing of abundant ductile organic
matter into void spaces further reduced pore throat diameters.
Immediately underlying heavily bioturbated HST deposits of
333
the organic-lean Hanover shale accumulated in a dysoxic
depositional environment. Disruption of layering and homogenization of the sediment by burrowing organisms yielded a
more porous and permeable microfabric through which
formation fluids ascended the sediment column only to be
arrested by the high capillary entry pressure of the basal
Dunkirk shale. Petrophysical properties of the organic-rich
shale, especially the laminated high TOC basal interval of the
Dunkirk shale, were enhanced by the generation of biogenic
methane, which resulted in the formation of a near impermeable gas capillary seal that could be compromised only by
natural hydraulic fracturing. Results of this study suggest that
while organic-rich HST and CS/TST deposits may serve as
strong top seals, they are also prone to compromise by natural
hydraulic fracturing. Indeed, episodic hydraulic fracturing of
these deposits and resultant leakage may manifest itself in the
form of gas chimneys, especially over positive structural
elements such as uplifted blocks and salt diapers (Holm, 1996).
Acknowledgements
Randy Blood is thanked for his help in the field and in the
microscopic analysis of shale samples. Peter Bush and his staff
at the University of Buffalo, South Campus Instrumentation
Center, School of Dental Medicine, are acknowledged for their
help with the scanning electron microscopy. This paper
benefited from the comments of the anonymous reviewers.
References
Almon, W.R., Thomas, J.B., 1991. Pore system aspects of hydrocarbon
trapping. In: Gluskoter, H.J., Rice, D.D., Taylor, R.B. (Eds.), Economic
Geology. US Geological Society of America, P-2. The Geology of North
America, pp. 241–254.
Aplin, A.C., Yang, Y., Hansen, S., 1995. Assessment of b, the compression
coefficient of mudstones and its relationship with detailed lithology. Marine
and Petroleum Geology 12, 955–963.
Baird, R.A., 1986. Maturation and source rock evaluation of the Kimmeridge
Clay, Norwegian Sea. AAPG Bulletin 70, 1–11.
Baird, G.C., Brett, C.E., 1991. Submarine erosion on the anoxic sea floor:
stratinomic, palaeoenvironmental, and temporal significance of reworked
pyrite-bone deposits. In: Tyson, R.V., Pearson, T.H. (Eds.), Modern and
Ancient Continental Shelf Anoxia. Geological Society, London. Special
Publication 58, pp. 233–257.
Baird, G.C., Lash, G.G., 1990. Devonian strata and environments: Chautauqua
County region: New York State. New York State Geological Association,
62nd Annual Meeting Guidebook, pp. Sat. A1–A46.
Bjørlykee, K., Høeg, K., 1997. Effects of burial diagenesis on stresses,
compaction and fluid flow in sedimentary basins. Marine and Petroleum
Geology 14, 267–276.
Boult, P.J., 1993. Membrane seal and tertiary migration pathways in the
Bodalla south oilfield, Eromanga basin, Australia. Marine and Petroleum
Geology 10, 3–13.
Bruce, C.H., 1984. Smectite dehydration—its relation to structural development and hydrocarbon accumulation in northern Gulf of Mexico basin.
AAPG Bulletin 68, 673–683.
Caillett, G., 1993. The caprock of the Snorre field, Norway: a possible leakage
by hydraulic fracturing. Marine and Petroleum Geology 10, 42–50.
Cathles III, L.M., 1996. Gas transport of oil: its impact on sealing and the
development of secondary porosity. Gas Research Institute, Contract No.
5093-260-2689, Annual Report; July 1994–June 1995, 35 pp.
334
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Cathles III, L.M., 2001. Capillary seals as a cause of pressure compartmentation in sedimentary basins. In: Filton, R.H. et al. (Eds.), Petroleum Systems
of Deep-Water Basins: Global and Gulf of Mexico Experience, 21st Annual
Bob F. Perkins Research Conference [CD-ROM]. Gulf Coast Section.
Society of Economic Paleontologists and Mineralogists, Houston, TX,
pp. 561–571.
Darby, D., Hazeldine, R.S., Couples, G.D., 1996. Pressure cells and pressure
seals in the UK Central Graben. Marine and Petroleum Geology 13,
865–878.
Dawson, W.C., Almon, W.R., 1999. Top seal character and sequence
stratigraphy of selected marine shales in Gulf Coast style basins. Gulf
Coast Association of Geological Societies Transactions 49, 190–197.
Dawson, W.C., Almon, W.R., 2002. Top seal potential of Tertiary deep-water
Gulf of Mexico shales. Gulf Coast Association of Geological Societies
Transactions 52, 167–176.
Deming, D., 1994. Factors necessary to define a pressure seal. AAPG Bulletin
78, 1005–1009.
Deming, D., Cranganu, C., Lee, Y., 2002. Self-sealing in sedimentary basins.
Journal
of
Geophysical
Research
107
(B12),
2329
(10.1029/2001JB000504).
Dewhurst, D.N., Aplin, A.A., Sarda, J.-P., Yang, Y., 1998. Compaction-driven
evolution of porosity and permeability in natural mudstones: a experimental
study. Journal of Geophysical Research 103, 651–661.
Downey, M.W., 1984. Evaluating seals for hydrocarbon accumulations. AAPG
Bulletin 68, 1752–1763.
Eberl, D.D., Hower, J., 1976. The kinetics of illite formation. GSA Bulletin 87,
1326–1330.
Engelder, T., Fischer, M.P., 1996. Loading configurations and driving
mechanisms for joints based on the Griffith energy-balance concept.
Tectonophysics 256, 253–277.
Engelder, T., Lacazette, A., 1990. Natural hydraulic fracturing. In:
Barton, N., Stephansson, O. (Eds.), Rock Joints: Proceedings of the
International Symposium on Rock Joints, Balkema, Brookfield,
Rotterdam, pp. 35–43.
Engelder, T., Oertel, G., 1985. The correlation between undercompaction and
tectonic jointing within the Devonian Catskill Delta. Geology 13, 863–866.
Engelder, T., Loewy, S.L., Hagin, P., 1998. Sorting out the role of organic
carbon content in maintaining overpressure. Evidence based on joint
development within Devonian black shales in the Catskill Delta. In:
Mitchell, A., Grauls, D. (Eds.), Overpressures in Petroleum Exploration
Bulletin Centre Rech. Elf Explor. Prod., Memoir vol. 22, pp. 33–35.
Ettensohn, F.R., 1985. The Catskill Delta complex and the Acadian orogeny: a
model. In: Woodrow, D.L., Sevon, W.D. (Eds.), The Catskill Delta.
Geological Society of America Special Paper 201, pp. 39–49.
Ettensohn, F.R., 1992. Controls on the origin of the Devonian–Mississippian oil
and gas shales, east-central United States. Fuel 71, 1487–1492.
Faill, R.T., 1985. The Acadian orogeny and the Catskill Delta. In:
Woodrow, D.L., Sevon, W.D. (Eds.), The Catskill Delta. Geological
Society of America Special Paper 201, pp. 15–37.
Fischer, M., Gross, M.R., Engelder, T., Greenfield, R.J., 1995. Finite element
analysis of the stress distribution around a pressurized crack in a layered
elastic medium: implications for the spacing of fluid-driven joints in bedded
sedimentary rock. Tectonophysics 247, 49–64.
Gaarenstroom, L., Tromp, R.A.J., de Jong, M.C., Brandenburg, A.M., 1993.
Overpressures in the Central North Sea: implications for trap integrity and
drilling safety. In: Parker, J.R. (Ed.), Petroleum Geology of Northwest
Europe: Proceedings of the 4th Conference. Geological Society, London,
pp. 1305–1313.
Geir, S., 2000. Clay mineral and organic diagenesis of the Lower Oligocene
Schöneck Fishshale, western Austrian Molasse Basin. Clay Minerals 35,
709–717.
Holm, G.M., 1996. The central graben: a dynamic overpressure system. In:
Glennie, K., Hurst, A. (Eds.), AD1995: NW Europe: Hydrocarbon Industry.
Geological Society, London, pp. 107–122.
Holm, G.M., 1998. Distribution and origin of overpressures in the central
graben of the north Sea. In: Law, B.E., Ulmishek, G.F., Slavin, V.I. (Eds.),
Abnormal Pressures in Hydrocarbon Environments AAPG Memoir vol. 70,
pp. 123–144.
Hosterman, J.W., 1993. Illite crystallinity as an indicator of the thermal
maturity of Devonian black shales in the Appalachian basin. USGS Bulletin
1909, G1–G9.
Hudak, P.F., 1992. Terminal decollement tectonics in the Appalachian Plateau
of northwestern Pennsylvania. Northeastern Geology 14, 108–112.
Jennings, J.J., 1987. Capillary pressure techniques: application to exploration
and development geology. AAPG Bulletin 71, 1196–1209.
Johnson, J.G., Klapper, G., Sandberg, C.A., 1985. Devonian eustatic
fluctuations in Euramerica. GSA Bulletin 96, 567–587.
Katsube, T.J., Williamson, M.A., 1998. Shale petrophysical characteristics:
permeability history of subsiding shales. In: Scheiber, J., Zimmerle, W.,
Sethi, P. (Eds.), Shales and Mudstones. I.E. Schwiezerbart’sche, Stuttgart,
pp. 69–91.
Krushin, J.T., 1997. Seal capacity of non-smectite shale. In:
Surdam, R.C. (Ed.), Seals, Traps, and the Petroleum System AAPG
Memoir 67, pp. 31–67.
Lacazette, A., Engelder, T., 1992. Fluid-driven cyclic propagation of a joint
in the Ithaca siltstone. In: Evans, B., Wong, T.-F. (Eds.), Fault
Mechanics and Transport Properties of Rocks. Academic Press, London,
pp. 297–324.
Ladeira, F.L., Price, N.J., 1981. Relationship between fracture spacing and bed
thickness. Journal of Structural Geology 3, 179–183.
Lash, G.G., Blood, D.R., 2004a. Depositional clay fabric preserved in early
diagenetic carbonate concretion pressure shadows, upper Devonian
(Frasnian) Rhinestreet shale, western New York. Journal of Sedimentary
Research 74, 110–116.
Lash, G.G., Blood, D.R., 2004b. Geochemical and textural evidence for early
diagenetic growth of stratigraphically confined carbonate concretions,
upper Devonian Rhinestreet black shale, western New York. Chemical
Geology 206, 407–424.
Lash, G.G., Engelder, T., 2005. An analysis of horizontal microcracking during
catagenesis: an example from the Catskill delta complex. AAPG Bulletin
89, 1433–1449.
Lash, G.G., Loewy, S., Engelder, T., 2004. Preferential jointing of upper
Devonian black shale, Appalachian Plateau, USA: evidence supporting
hydrocarbon generation as a joint-driving mechanism. In: Cosgrove, J.,
Engelder, T. (Eds.), The Initiation, Propagation, and Arrest of Joints and
Other Fractures. Geological Society, London. Special Publications, 231,
pp. 129–151.
Leonard, R.C., 1993. Distribution of sub-surface pressure in the
Norwegian Central Graben and applications for exploration. In:
Parker, J.R. (Ed.), Petroleum Geology of Northwest Europe:
Proceedings of the Fourth Conference. Geological Society, London,
pp. 1295–1303.
Loewy, S., 1995. The post-Alleghanian tectonic history of the Appalachian
Basin based on joint patterns in Devonian black shales. MS thesis,
Pennsylvania State University, University Park, Pennsylvania, 179 pp.
Lundegard, P.D., Samuels, N.O., 1980. Field classification of fine-grained
sedimentary rocks. Journal of Sedimentary Research 50, 781–786.
Luo, X., Vasseur, G., 1997. Sealing efficiency of shales. Terra Nova 9, 71–74.
McConaughy, D.T., Engelder, T., 1999. Joint interaction with embedded
concretions: joint loading configurations inferred from propagation paths.
Journal of Structural Geology 21, 1637–1652.
Neuzil, C.E., 1994. How permeable are clays and shales? Water Resources
Research 30, 145–150.
Neuzil, C.E., 1995. Abnormal pressures as hydrodynamic phenomena.
American Journal of Science 295, 742–786.
O’Brien, N.R., 1995. Origin of shale fabric—clues from framboids. Northeastern Geology and Environmental Sciences 17, 146–150.
O’Brien, N.R., Slatt, R.M., 1990. Argillaceous Rock Atlas. Springer, New
York. 141 pp..
Olson, J., Pollard, D.D., 1989. Inferring paleostress from natural fracture
patterns: a new method. Geology 17, 345–348.
Pearson, M.J., Small, J.S., 1988. Illite-smectite diagenesis and palaeotemperatures in northern north Sea Quaternary to Mesozoic shale sequences. Clay
Minerals 23, 111–132.
G.G. Lash / Marine and Petroleum Geology 23 (2006) 317–335
Pemberton, S.G., Frey, W.R., Ranger, M.J., MacEachern, J., 1992. The
conceptual framework of ichnology. In: Pemberton, S.G., et al. (Eds.).
Applications of Ichnology to Petroleum Exploration. SEPM Core Workshop No. 17, pp. 1–32.
Posamentier, H.W., Vail, P.R., 1988. Eustatic controls on clastic deposition
II—sequence and sequence tract models. In: Wilgus, C.K., Hastings, B.S.,
Posamentier, H.W., van Wagoner, J.C., Ross, C.A., Kendall, C.G.S.J.C.
(Eds.), Sea Level Changes: an Integrated Approach. SEPM, Special
Publication 42, pp. 125–154.
Revil, A., Cathles III., L.M., Shosa, J.D., Pezard, P.A., de Larouzière, F.D.,
1998. Capillary sealing in sedimentary basins: a clear field example.
Geophysical Research Letters 25, 389–392.
Revil, A., Pezard, P.A., de Larouzière, F.D., 1999. Fluid overpressures in
western Mediterranean sediments, sites 974–979. In: Zahn, R.,
Comas, M.C., Klaus, A. (Eds.), Proceedings of the Ocean Drilling Program,
Scientific Results, 161. Ocean Drilling Program, College Station, TX,
pp. 117–128.
Roberts, S.J., Nunn, J.A., 1995. Episodic fluid expulsion from goepressured
sediments. Marine and Petroleum Geology 12, 195–204.
Rudd, M., Pandey, G.N., 1973. Threshold pressure profiling by continuous
injection. American Institute of Mining, Metallurgy and Petroleum—
Society of Petroleum Engineers, Paper 4597, 7 pp.
Schlömer, S., Krooss, B.M., 1997. Experimental characterization of the
hydrocarbon sealing efficiency of cap rocks. Marine and Petroleum
Geology 14, 565–580.
Schowalter, T.T., 1979. Mechanics of secondary hydrocarbon migration and
entrapment. AAPG Bulletin 63, 723–760.
Selley, R.C., 1998. Elements of Petroleum Geology, second ed. Academic
Press, New York, 470 pp.
Shaw, H.F., Primmer, T.J., 1989. Diagenesis in shales from a partly
overpressured sequence in the Gulf Coast, Texas, USA. Marine and
Petroleum Geology 6, 121–128.
Shaw, H.F., Primmer, T.J., 1991. Diagenesis of mudrocks from the
Kimmeridge Clay formation of the Brae area, UK north Sea. Marine and
Petroleum Geology 8, 270–277.
335
Shosa, J.D., Cathles III, L.M., 2001. Experimental investigation of capillary
blockage of two phase flow in layered porous media. In: Filton, R.H., et al.
(Eds.), Petroleum Systems of Deep-Water Basins. Global and Gulf of
Mexico Experience, 21st Annual Bob F. Perkins Research Conference [CDROM]. Gulf Coast Section, Society of Economic Paleontologists and
Mineralogists, Houston, TX, pp. 725–739.
Smith, G.J., Jacobi, R.D., 2001. Tectonic and eustatic signals in the sequence
stratigraphy of the upper Devonian Canadaway group, New York state.
AAPG Bulletin 85, 325–357.
Stow, D.A.V., Tabrez, A.R., 1998. Hemipelagites: processes, facies and
model. In: Stocker, M.S., Evans, D., Cramp, A. (Eds.), Geological
Processes on Continental Margins: Sedimentation, Mass-wasting and
Stability. Geological Society, London. Special Publications No. 129,
pp. 317–337.
Stow, D.A.V., Wetzel, A., 1990. Hemiturbidite: a new type of deep water
sediment. In: Cochran, J.R., Stow, D.A.V., et al. (Eds.), Proceedings of the
Ocean Drilling Program, Scientific Results, 116. Ocean Drilling Program,
College Station, TX, pp. 25–34.
Strickler, M.E., Ferrell, R.E., 1989. Provenance and diagenesis of Upper
Wilcox Formation clay minerals. Ninth International Clay Conference,
Strasbourg, p. 379.
Sutton, S.J., Ethridge, F.G., Almon, W.B., Dawson, W.C., Edwards, K.K.,
2004. Textural and sequence-stratigraphic controls of lower and upper
Cretaceous shales, Denver basin, Colorado. AAPG Bulletin 88, 1185–1206.
Vavra, C.L., Kaldi, J.G., Sneider, R.M., 1992. Geological applications of
capillary pressure: a review. AAPG Bulletin 76, 840–850.
Watts, N.L., 1987. Theoretical aspects of cap-rock and fault seals for singleand two-phase columns. Marine and Petroleum Geology 4, 274–307.
Werne, J.P., Sageman, B.B., Lyons, T.W., Hollander, D.J., 2002. An integrated
assessment of a ‘type euxinic’ deposit: evidence for multiple controls on
black shale deposition in the middle Devonian Oatka Creek formation.
American Journal of Science 302, 110–143.
Worden, R.H., Charpentier, D., Fisher, Q., Aplin, A.C., 2005. Porosity loss,
fabric development and the smectite to illite transition in Upper Cretaceous
mudstones from the North Sea: an image analysis approach. AAPG Annual
Convention, Calgary, p. A155.