NW - B.Sc. Thesis

Petroleum Source Rock Analysis of the Upper Devonian
Torquay Formation of South Eastern Saskatchewan
A Thesis Submitted to the Department of Geology In Partial Fulfillment of
the Requirements For the Degree of Bachelor of Science in Geology
Nathan T. Wielgoz
April 2014

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Abstract
This study examines the geochemical characteristics of the Three Forks Group Torquay
Formation and presents a preliminary assessment of its source rock potential in Southern
Saskatchewan using an analytical approach that incorporates the high resolution sampling of
core, Rock-Eval VI pyrolysis and organic petrography.
This study shows that although two, relatively thin, organic rich zones exist in the Torquay
Formation (within southern Saskatchewan), they are considered as having marginal source
potential due to their low level of thermal maturity and generally low amount of organic
carbon. Generally values for total organic carbon are below 0.5 wt. %, only exceeding 1.0 wt. %
between 1015.5m to 1016.5m and associated hydrogen index below 250. Rock-Eval VI analyses
also indicates that most of the organic matter within the Torquay Formation is Type II to III,
with some IV, although petrographic analysis indicates the absence of terrestrial material,
strongly suggesting either the presence of reworked organic material or the alteration of
organic matter by insipient oxidation. This preliminary analytical examination suggests that the
Torquay Formation has limited source potential within southern Saskatchewan.

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Acknowledgements
Nathan Wielgoz would like to thank Professor Stephen Bend for all of his instruction and help in
completing this thesis and the subsequent research as well as advancing knowledge in the field
of Petroleum Geochemistry. Thanks must also go to Titilade Aderoju, for her assistance and
guidance in operating the RockEval 6 Pyrolyzer, and Oluseyi Olajide, for assistance in use of
various geological software such as Geoscout, Geovista, and Schlumberger Petrel. Support was
provided by the Saskatchewan Ministry of the Economy and Petroleum Technology Research
Centre.

iii
Table of Contents
Abstract…………………………………………………………………………………………………………………….………………………..…i
Acknowledgments………………………………………………………………………………………………………………………………..ii
Contents………………………………………………………………………………………………………………………………………..…….iii
List of Figures……………………………………………………………………………………………………………..………………………..v
1. Introduction………………………………………………………………………………………………………………………………………1
1.1 Foreword………………………………………………………………………………………………………………..………….1
1.2 Background……………………………………..……………………………………………………………………………..….1
1.3 Study Purpose……………………………………….………………………………………………………………………..….2
1.3.1 Goals………………………………………..…………………………………………………………………..…….2
1.3.2 Objectives…………………………………………………………………………………………………….…….2
1.4 Previous Studies…………………………………………………………………………..…………………………………….3
1.5 Stratigraphic Setting ………….……………………………………………………………………………………………….4
1.6 Study Area …………………………………..………………………………………………………………………………….….5
2. Methods..…………………………………………………………………….………………………………………………………………..….7
2.1 Core analysis…………………………………………………………………………………………………………..….………7
2.2 Rock-Eval Pyrolysis…………………………………………………………………………………………………….….…..8
2.3 Microscopy/Petrography…………………………………..………………………………………………………….….11
3. Results and Discussion…………………………………………………………………………………………….……………………...13
3.1 Lithological Characterization……………………………………………………………….………………….………..13

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3.2 Assessment of Rock-Eval Parameters……………………….…………………………………………….……......16
3.3 Petrographic Analysis……………………….……………………………………………………………………………....22
3.4 Kerogen Analysis……………………….…………………………………………………………………………….………..24
3.5 Geochemical Subdivisions of the Torquay Formation……………………………………….………….......25
3.6 Production Index and the Relation to Source Potential……………………….……………………..…....28
3.7 Comparative Analytical Approach (The Assessment of Two Methodologies)……….….….…...29
3.7.1 The Assessment of Source Potential in Microhorizons Versus the Conventional and
Widely Used Bulk-Rock Approach……………………….……………………………………………….…...29
3.7.2 Implication of the use of geochemical data to subdivide units……………...….….....30
4. Conclusions……………………….…………………………………………………………………………………………………….….…..31
5. Future Work …………………………………………………………………………………………………………………….………………31
References Cited……………………….…………………………………………………………………………………………….………….33
Appendicies…………………………………………………………………………………………………………………………..………………35
Appendix I……………………….………………………………………………………………………………….………………….36
Appendix II……………………….………………………………………………………………………………….………….……..38
Appendix III……………………………………………………………………………………….…………………………………...39
Appendix IV…………………………………………………………………………………………………………….……………….41

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List of Figures
Figure 1: Previous subdivisions made to the Torquay Formation, p.4
Figure 2: Stratigraphic chart of southeast Saskatchewan, p.5
Figure 3: Isopach map of the Torquay Formation within Saskatchewan, p.6
Figure 4: Whole rock sample of Torquay Formation displaying extraction technique, p.7
Figure 5: Vinci Laboratories Rock-Eval Pyrolyzer, p.9
Figure 6: Schematic pyrogram for Rock-Eval pyrolysis, p. 10
Figure 7: Pyrolysis flow chart and derived/calculated parameters, p.11
Figure 8: Lietz Orthoplan microscope (UV/Fluorescence), p. 12
Figure 9: Leica M420 microscope (Macro), p.12
Figure 10: Whole rock sample form well 13-19-9-30W1, p.14
Figure 11: TOC chart for well 13-19-9-30W1, p.16
Figure 12: Geochemical log for well 13-19-9-30W1, p.17
Figure 13: Localized geochemical log for well 13-19-9-30W1, p.18
Figure 14: Migration Index Chart for well 13-19-9-30W1, p.19
Figure 15: Hydrocarbon Type Index chart for well 13-19-9-30W1, p.20
Figure 16: Genetic Potential chart for well 13-19-9-30W1, p.21
Figure 17: Petrographic analysis (UV/Fluorescence), p.22
Figure 18: Petrographic analysis (UV/Fluorescence), p.23
Figure 19: HI/OI Kerogen Type plot, p.24

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Figure 20: Suggested geochemical subdivisions for Unit 4 in the Torquay Formation, p.26
Figure 21: Production Index chart for the upper Torquay at well 13-19-930W1, p. 28

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1. Introduction
1.1 Foreword
A petroleum source rock is defined as any rock that is capable of generating and expelling
sufficient hydrocarbon that ultimately forms an economic accumulation of petroleum (Hunt,
1996). The source rock is only one component of a given petroleum system which is the sum of
all components that are necessary to generate and retain petroleum within the subsurface.
Such components include the source rock, the process of petroleum generation, a migration
pathway, reservoir rock, trap, and seal (Bend, 2007). Since the presence of a viable source rock
is a fundamental component of any petroleum system an assessment of all potential source
rocks must be conducted when seeking to assess and determine the viability of any given
petroleum system. To determine the source potential of identified formational units, the
development of a number of analytical techniques and protocols through various case studies
was done. This resulted in the establishment of key methods, characteristics and norms that
aid in the recognition of the quantity, quality, and maturation level of organic matter in rocks
associated with petroleum production (Tissot and Welte, 1984; Hunt, 1996; Peters et al., 2005;
Bend, 2007).
1.2 Background
This study is a part of the Saskatchewan Phanerozoic Fluids Project, initiated by the University
of Alberta and University of Regina. The objective of the Saskatchewan Phanerozoic Fluids
Project is to enhance the understanding of how and where hydrocarbons were generated in the

2
subsurface of Saskatchewan as well as where and when they may have migrated over geologic
time, and to determine where they are most likely to occur at the present time. A critical
component of the Saskatchewan Phanerozoic Fluids Project is to gather geochemical and
petrographical data that will aid in assessing source potential for a given number of geological
formations that will become part of an integrated petroleum systems analysis for the Williston-
Basin of southern Saskatchewan (Whittaker et al, 2009).
1.3 Study Purpose
1.3.1 Purpose
The primary purpose of this study is to provide a preliminary, high resolution, geochemical
assessment of the source rock potential of the Torquay Formation in southern Saskatchewan,
using an integrated geochemical and petrographic approach.
1.3.2 Specific Objectives
1. Identify a sample of core with the highest recovery within the Torquay Formation.
2. To use the Rock-Eval pyrolysis at extremely close sampling intervals at the millimeter to
centimeter scale, obtained by using a drill-press, rather than the conventional large
sample interval ‘bulk rock’ method.
3. Determine the effectiveness of using high resolution geochemical data to subdivide the
Torquay Formation.
4. Determine if there is a relationship between geochemical, lithological as well as
petrophysical data, and if such a relationship concurs with the previously published
subdivision of the Torquay Formation.

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1.4 Previous Studies
The analysis and assessment of the Torquay Formations source rock potential has been largely
ignored, leaving to speculation the origin of Torquay Formation oil within southern
Saskatchewan. A small number of studies were conducted to assess reservoir characteristics
within the Torquay Formation published by Kreis et al., (2006), but no previous assessment of
the source rock potential has been carried out. Facies correlations within the Torquay
Formation were the focus of multiple studies (Christopher, 1961; Kreis et al., 2006; Nicolas
2006, 2007; and LeFever and Nordeng, 2009), using both petrophysical wireline logs and limited
core data gathered from various locations within the Williston Basin. Figure 1 displays various
facies subdivisions as a result of previous work. Both Christopher (1961) and Kreis and Costa
(2006) focused on southern Saskatchewan and Lefever and Nordeng (2009) proposed their
subdivisions based upon work conducted in the United States portion of the Williston Basin. It
should be noted that the Torquay Formation appears to possess a greater degree of
subdivisions that is not prevalent in all locations across southern Saskatchewan (Christopher,
1963). Nicolas (2012) made further subdivisions of units 1, 2, and 4 within the Torquay
Formation within the portion of the Williston Basin that lies in Manitoba. The principal
borehole analyzed in this study (i.e., 13-19-9-30W1) lies near the Manitoba border, therefore
the subdivisions proposed by Nicolas’ (2012) study have been adopted in this study.

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1.5 Stratigraphic Setting
The dolostones and doloarenites of the Torquay Formation make up a portion of what is the
Three Forks Group, which are Upper Devonian (Fammenian) in age. The Three Forks Group is
also comprised of the well-known and prominent Bakken Formation as well as the red and
green shales of the Big Valley Formation (Figure 3). The Torquay Formation ranges in thickness
from 25m to 80m and rises from 1676m below sea level at 1-14-1-8W2, proximal to the
International Border, to 61m above sea level in the northern portion of the Williston Basin
Figure 1 – Unit Classifications through the Torquay Formation
based on work from Christopher (1961), Kries and Costa (2006),
and Leferver and Nordeng (2009). Modified from Nicolas (2012).

5
(Christopher, 1963). In south eastern Saskatchewan, the Torquay Formation is stratigraphically
overlain by the Big Valley Formation and unconfomably overlain by the Bakken Formation
(Figure 2) in places. The unconformity between the Torquay Formation and Bakken Formation
is more prominent within the more southern portions of Saskatchewan, whereas towards the
northern rim of the Williston Basin and along the sub-crop, the Big Valley Formation
conformably overlies the Torquay Formation. Lithologies along this startigraphic contact are
marked by a lithologic shift characterized by a change from green argillaceous rocks to a more
silt dominated lithology, although this contact was not observed in this study. Conformably
below the Torquay Formation occur the evaporates of the Saskatchewan Group’s Birdbear
Formation, marking a shift to from the anhydrite rich dolomitic silts and sands of the Birdbear
Formation to the oxidized brecciated siltstones of the Torquay Formation.
Figure 2 – Stratigraphic chart of southeastern Saskatchewan. Black dots represent oil production form those Formations.
Modified from www.er.gov.sk.ca/stratchart.

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1.6 Study Area
Samples were collected from wells 04-02-001-10W2, 8-11-001-09W2, and 13-19-009-30W1,
spanning the northern rim of the Williston Basin from the Manitoba/Saskatchewan border to
the deepest portion of the sub-crop within Saskatchewan and proximal to the US/Canada
border. Figure 3 shows a map of both the sampled well locations and also those wells in which
petrophysical data was used to aid in geochemical facies correlations.
Figure 3 – Isopach map of southeast Saskatchewan representing the Torquay Formation total Thickness. The black dashed
lines indicate the furthest extent of the Lower Bakken Formation and the grey dashed lines represent the extent of the Big
Valley Formation. Sampled and studied wells are ploted over the map. Modified from Kries et al. (2006).

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2. Method
2.1 Core Analysis
Recovered core from well 13-19-9-30W1 was studied and logged in detail (Appendix III) from
1013.5 m to 1028 m and from 1048 m to 1050 m. No core was available between 1028 m and
1048 m giving 45% recovery for this well location. The well was chosen based on the amount of
recoverable core it had relative to other cored sections of the Torquay Formation. Core
samples were collected and washed after slabbing the core lengthwise with a water lubricated
rock saw. Individual samples for Rock-Eval analysis were obtained from the sampled core using
a drill press fitted with either a 5.0 or 2.0 mm masonry drill bit. A total of 172 samples were
collected from well 13-19-9-30W1. Extracting samples in this fashion enabled the sampling of
individual laminations, rather than the normal method of obtaining samples in bulk over a
much larger interval (Figure 4), thereby enabling the creation of a more detailed geochemical
Figure 4 - Sample of core from well 13-19-9-30W1 where the
microdrill was utilized to take powdered samples of differing
lithologies. (Original image in colour)

8
profile as well as providing, on a millimeter scale, the recognition of minor changes in Total
Organic Carbon, and the Rock-Eval parameters S1, S2, and Hydrogen Index (parameters
explained in Chapter 2.2) throughout the Torquay Formation. A total of 172 samples were
obtained in this way from well 13-19-9-30W1 and geochemically assessed using Vinci Labs
Rock-Eval VI analyses.
The basis for sample collection was established upon lithological variability and the presence of
sediment capable of containing elevated amounts of organically derived carbon as well as the
occurrence of red oxidized sediment. The oxidized sediment was sampled on a much larger
scaled interval due to the lack of organic matter preserved in such a lithology. Geochemical
data derived from the Rock-Eval analyses was compared to wireline log signatures as well as
detailed core descriptions to obtain an assessment of paleoenvironment, controls on sediment
and organic matter deposition and alteration, as well as the possible cyclic trend in
sedimentation and organic accumulation.
Petrophysical wireline logs were used to help provide and extend correlations in places where
core was not available for study. These ‘un-cored’ portions of the Formation were primarily
located at stratigraphically lower depth and occur below the first appearance of oxidized
mudstones (or red-beds), most likely no core was cut within these lower units due to their
perceived low economic significance.

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2.2 Rock-Eval Pyrolysis
The methods utilized for RockEval pyrolysis follows an industry standardized methodology, as
outlined by Espatalie et al., (1977) and Peters et al., (2005). Rock-Eval pyrolysis was originally
developed as a method to quickly and inexpensively characterize source rocks using drill
cuttings over intervals of one to five meters (Espitalie et al., 1977). Since the development of
the technique in the late 1970’s, Rock-Eval pyrolysis has been universally utilized as a ‘bulk rock’
pyrolysis technique to provide a rapid means of geochemically screening large sample sets,
providing an assessment in the quantity and quality of organic matter within a sample. In this
study, Rock-Eval pyrolysis was utilized in conjunction with a high-resolution cm to mm scale
sampling protocol throughout the Torquay Formation, forming a high resolution geochemical
data set at the micro-analysis scale to generate both a high resolution geochemical profile over
a zone of interest and asses the effectiveness of the Rock-Eval method with a micro-sampling
protocol as a form of micro-analysis.
This study utilized a Vinci Laboratory Rock-Eval VI analyzer (Figure 5 ) to conduct the Rock-Eval
Figure 5 – Vinci Laboratories Rock-Eval
Pyrolyzer at the Department of Geology,
University of Regina

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pyrolysis. The procedure is relatively simple. A powdered rock sample ~ 50 ±3 mg is heated in
an inert atmosphere (nitrogen) causing the thermal decomposition (i.e., pyrolysis) of organic
matter. The organic matter decomposes due to the sequential rupture of molecular bonds of
increasing binding energy, as the temperature increases from ambient at 25o
C per minute up to
850o
C. During pyrolysis, the products are detected by a flame ionization detector (FID) as well
as an infared (IR) cell, which together generates a number of analytical parameters, which
include: S1 (mgHC/g rock) representing free or in-situ hydrocarbons S2 (mgHC/g rock)
representative of the generation potential largely considered as kerogen and Tmax which is the
S2 peak maxima and taken as an index of thermal maturity. During the subsequent oxidation
process, the IR cell monitors the amounts of CO2 and CO that evolve during the final
decomposition of organic matter which give the S3 (mgCO2/g rock) and S4 peaks (Peters et al.,
2005).
Each analysis generates a pyrogram (Figure 6) showing the pyrolysis of organic compounds with
time increasing from left to right along the x-axis, and material yield along the y-axis. Important
acquisition parameters obtained during analysis are; S1, S2, S3, S4 (Vinci Labs, 2010). A sample
Figure 6 - Schematic pyrogram displaying the evolution of
hydrocarbons and CO2 from a sample during Rock-Eval pyrolysis
(Hunt, 1996).

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of an immature source rock typically will yield a low S1 peak and an elevated S2 peak, in
comparison, a sample of kerogen with a higher level of thermal maturity will result in a larger
S1 peak at the expense of the S2 peak. Tmax would also register a shift towards a higher
temperature (e.g. 420 to 435°).
A set of parameters are subsequently calculated from the acquisition data following pyrolysis,
which includes Production Index (PI), Hydrogen Index (HI), and Oxygen Index (OI). Total Organic
Carbon (TOC), expressed in weight percent (wt. %) is an important parameter that indicates the
total quantity of organically derived carbon within a sample. The Hydrogen index (calculated by
[S2/TOC X 100]) and the Oxygen index (calculated by [S3/TOC X 100]) are two valuable indices
that are utilized to determine the quality and genetic potential of a given kerogen, which helps
to identify the type of hydrocarbon (i.e., gas or liquid) that can be generated (Tissot and Welte,
1984).
Figure 7 – A combination of an analysis flow chart indicating the pyrolysis process, examples of Pyrolysis and Oxidation curves
(S1, S2, S3CO2, S4CO2), and derived and calculated parameters of the Rock-Eval Pyrolyzer. (Aderoju and Bend, in press 2012)

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2.3 Microscopy/Petrography
The estimation and analysis of visible organic matter within’ whole rock’ samples was conducted
using reflected light microscopy. Samples from core were cut using a rock saw parallel to the
depth direction (Figure 4), and were subsequently polished on a Buehler Roll Grinder equipped
with corundum sandpaper of varying grit sizes progressing from 240 to 600 grit. Once polished,
samples were adhered to a glass slide using a Leitz leveling press and adhesive putty.
Petrography was carried out in a darkened room using a Lietz Orthoplan microscope (Figure 8).
To conduct the analysis, the microscope was equipped with a 50 Watt mercury HBO lamp,
Ploem 4-Lambda UV/Fluorescence illuminator consisting of an UV/ violet excitation filter
(bandwidth λ = 400-490 nm), a dichroic mirror (bandwidth λ = 510 nm) and a yellow barrier
filter (bandwidth λ = 520 nm), x16 air incident light objective, giving an overall magnification of
x240. Plain light microscopy was conducted using a Leica M420 microscope equipped with a
Leica ClS light source operating at x150 (Figure 9).
Figure 8 – A Lietz Orthoplan microscope
equipped with a Ploem 4-Lambda
UV/Florescence illuminator an x16 air incident
light objective at the Department of Geology,
University of Regina. Original image in colour
Figure 9 – A Leica M420 microscope equipped
with a Leica CIS 150x light source at the
Department of Geology, University of Regina.
Original image in colour

13
Select samples from wells 4-2-1-10W2, 13-19-9-30W1, and 8-11-1-9W2 were petrographically
analysed in both incident white light and autoflourescent incident light. For wells 4-2-1-10W2
and 8-11-1-9W2 the concentration of analyses was on the upper most 10 cm below the
stratigraphic top of the Torquay - Lower Bakken Formation contact. For well 13-19-9-30W2, the
geochemical analysis emphasis was to create a geochemical profile throughout the Torquay
Formation.
3. Results and Discussion
3.1 Lithological Characterization
Compiled from wells 13-19-9-30W1, 4-2-1-10W2, and 8-11-1-9W2
The Torquay Formation is primarily composed of brecciated dolostones and doloarenites with
argillaceous interbeds. Primarily, dolomite occurs as very fine, well cemented, doloarenite
integrated with mudstones and shale as well as pebble to cobble sized fragments (ranging from
angular to subrounded) embedded within a silty mudstone (Figure 10). Intervals of intense
brecciation are often accompanied by argillaceous rip-up clasts suggesting the presence an
erosional current during deposition. Some cross bedding within the dolarenite intervals are
visible, though infrequent and occurring over a centimeter scale. Bedding structures are not
preserved or visible throughout the Torquay Formation. A majority of the weathered
argillaceous groundmass contains poorly sorted silt sized particles, dolomitic particles, as well
as very fine grained quartz sand particles. The clay mineral matrix, as well as aggregate

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material, is well cemented and tightly compacted. Such a lithology is reportedly associated
with low porosity values (Christopher, 1963). Lithological changes throughout the Torquay
Formation are abrupt and frequent; composite logs in Appendix I and II illustrate the frequent
changes in lithology throughout the upper portions of the Torquay Formation especially in the
upper section of the Formation (1013.5 m to 1023.5m in well 13-19-9-30W2 and 2274.75 m to
2290.00 m in well 4-2-1-10W2). There is a gap in cored material through the Torquay
Formation that leaves sections without a detailed description (Appendix II).
Dolomitic layers occurring at 1013.5 m to 1023.5m in well 13-19-9-30W2 and from 2274.75 m
to 2290.00 m in well 4-2-1-10W2 range in colour between light grey and tan/orange-brown.
The colouration of the interbedded mudstone suggests an alternation between periods of
oxidizing conditions (red-brown) and reducing conditions (green–brown) (Figure 10). Such
colouration was attributed by Christopher (1963) as relating to two distinct chemical
environments by: (a) a dominance of carbonate components that inhibited the oxidation of
ferric compounds (through the production of a reducing agent such as HCl), yielding a green
Figure 10 – Whole rock samples from well 13-
19-9-30W1. (Depths 1015.28 m to 1015.19 m
on left and depths 1018.47 m -1018.54 m on
the right). Original image in colour.

15
colouration of the argillaceous material; and (b) a low concentration of carbonate ions
dampened the reducing effect and along with strong oxidation to the ferric compounds the
argillaceous material assumed a red – brown colouration. Reduction by organically derived
reagents appears to have occurred through the upper one quarter to one half of the Formation
(Fuller, 1956). The oxidation surface rises and falls with the type of overlying lithology within
the Torquay Formation (Christopher, 1963). For example, in localities where the Torquay
Formation is overlain by the Lower Bakken Formation shale, the oxidized zone lies within the
lower two-thirds of the Formation, in contrast where the Torquay Formation is overlain by the
Big Valley Formation green shales and Bakken Formation middle member; the heavily oxidized
lithologies lie within the upper one quarter of the Torquay Formation. Low concentrations of
organic matter inhibit dolomitization in digenetic systems and promote an oxygenated
environment (Slaughter and Hill, 1991). The reducing environment that formed the black shale
of the lower Bakken Formation probably penetrated the sea floor thus causing a deeper
reducing zone in the Torquay Formation than in locations where the middle sands of the
Bakken Formation overly the Torquay Formation. Large quantities of organic matter, especially
protein rich, produce reducing conditions from the enzymatic degradation of protein (Slaughter
and Hill, 1991). Alternatively, the generation and presence of euxinic conditions during the
deposition of the lower Bakken Formation would generate the same conditions (Aderoju and
Bend, 2014). Wells 4-2-1-10W2 and 13-19-9-30W1 (Appendix I and II) illustrate this redox
difference since the more western location of the two wells do not contain oxidized zones in
the cored section of the Torquay (27m) whereas in well 13-19-9-30W1, the oxidation beds
appear four meters below the middle Bakken – Torquay Formation contact.

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3.2 Assessment of Rock-Eval Parameters
Total organic carbon (TOC) values throughout the Torquay Formation are relatively low, ranging
between 0.08 wt. % and 1.68 w.t % (Figure 11). Both Hunt (1979) and Tissot and Welte (1984)
state that the minimum TOC value necessary for an argillaceous rock to be considered a
potential source rock when deposited under reducing conditions is 0.5 wt. % for shales and 0.3
wt. % for carbonates. Between 1015.5 to 1016.5 m, associated with numerous thinly bedded
fine argillaceous interlaminations, is a zone with relatively high TOC (1.68 w.t %), values that are
generally higher than the remainder of the upper Torquay Formation (Figure 12). Coupled with
low values of Tmax throughout the Torquay Formation (i.e., below 425° Celsius), high S1 values
indicate an organic matter that is thermally immature and associated with a poorly developed
hydrocarbon content (Peters et al., 2005) or hydrocarbons that have migrated into the
1012
1013
1014
1015
1016
1017
1018
1019
1020
1021
1022
1023
1024
1025
1026
1027
1028
1029
0 0.5 1 1.5 2
Depth(m)
Total Organic Carbon (wt. %)
Figure 11 - An x-y scatter plot illustrating the concentration of elevated TOC levels at the depth of analysis.

17
formation (Hunt, 1996).
Results calculated from Rock-Eval Pyrolysis are displayed in Figures 12 and 13 as a series of
geochemical logs that suggest a cyclical nature of organic matter accumulation within the
Torquay Formation. The rising and falling in organic matter content (relatable to TOC) can
possibly be attributed to varying conditions that either favour or diminish organic matter
accumulation during deposition. Appendix II shows the possible cyclical relationship between
the occurrence of organic matter accumulation and lithological changes within the Torquay
Formation. Lithologies associated with a very fine grain size (i.e., argillaceous/silt) see a rise in
TOC, Hydrogen Index (mg HC/g rock), S1, S2, and in addition, a decrease the Oxygen Index. This
is consistent with the traditional observation that a reduction in grain sizes leads to more
Figure 12 – Geochemical log for the Torquay Formation at well 13-19-9-30W1, showing the range in values for Hydrogen Index
, Oxygen Index, TOC, S1, S2, and Production Index between 1013.5 m and 1028 m.
Depth(m)

18
favourable conditions for greater accumulations of organic matter depending on the
environment (Peters et al., 2005). In the case of the Torquay Formation, a decrease in grain
size is usually associated with the presence of argillaceous laminations. In Chapter 3.4, this will
be examined further.
All depths in which there was an observed hydrocarbon show (i.e., 1013.5 m, 1015.2 m to
1017.0 m) the TOC, HI, S1, and S2 values are relatively high, typically representing the largest
values for each parameter in well 13-19-9-30W1. High S1 values at these depths as well as high
Figure 13 – Geochemical log for the upper five meters of the Torquay Formation at well 13-19-9-30W1 between 1013.5 m
and 1018.5 m. Note the cyclic organic matter accumulation nature visible at an increased resolution indicated by arrows
Depth(m)

19
TOC percentages indicate the presence of allochthonous (migrated) petroleum based on an
assessment using the Migration Index (S1/TOC) (Figure 14) (Hunt, 1996). Such values could
typically be attributed to the presence of petroleum that has migrated into the Torquay.
Petrographic analysis indicates that the residual petroleum occurs as a coating around mineral
grains, though in low amounts. However the permeability values at these depths range from
0.19 mD to 0.69 mD, which is relatively low but within the range typical for petroleum source
rocks (Hunt, 1995). At such low permeabilities, the presence of migrated hydrocarbons would
necessitate the existence of a viable fracture permeability rather than matrix permeability
(Jones, 1986). However the Migration Index (Figure 14) could also indicate the presence of
indigenous hydrocarbons that are the result of generation at very low levels of thermal
maturity. An index between 0.1 and 0.2 typically indicate a zone in which oil expulsion has
occurred (Hunt, 1996). A majority of the Torquay Formation falls beyond of this zone indicating
1012
1014
1016
1018
1020
1022
1024
1026
1028
1030
0.00 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00
Depth(m)
Migration Index
Zone of Oil Expulsion
Figure 14 – The derived Migration Index plotted against depth for well 13-19-9-30W1. The space in between the purple
vertical lines indicates the zone where oil is expelled from the rock.

20
the presence of high S1 values (hydrocarbon) relative to S2 (kerogen). Combining this data with
both Total Genetic Potential (TGP) (S1+S3) and Hydrocarbon Type Index (HCTI) (S2/S3) provides
a further evaluation of the hydrocarbons within this narrow zone of the Torquay Formation.
The Hydrocarbon type index (Figure 15) suggests that the majority of organic matter within the
Torquay may generate gas, which largely reflects the relatively high Oxygen Index values, with
exception to depths 1014 m, and 1017 m. A calculation of the Total Genetic Potential, which is
a combination of both S1 and S2 values is shown in Figure 16, suggests that samples within this
zone of interest fall within the range from ‘Very Good’ to ‘Good’ source rocks, in contrast to the
majority of the Torquay Formation appears to have a ‘low’ hydrocarbon generative potential.
An alternative explanation for the presence of hydrocarbons (Figure 14) within this zone of
interest (i.e., 1014 to 1017 m) necessitates the generation of hydrocarbons at very low levels of
1012
1014
1016
1018
1020
1022
1024
1026
1028
0 1 2 3 4 5 6 7 8 9 10 11 12 13
Depth(m)
Hydrocarbon Type Index
Gas Gas and Oil Oil
Figure 15 – The Hydrocarbon Type Index for well 13-19-9-30W1 indicates the quality of the hydrocarbons present in the rock by
indicating which petroleum product they are capable of producing as thermal maturation progresses.

21
thermal maturity. This initially appears problematic in that the Tmax values for this zone range
from 294°C to 402°C which is well below the 425°C threshold normally associated with the
onset of oil generation (Tissot and Welte, 1984; Hunt, 1996; Peters, 2005; and Bend, 2007). The
presence of weaker bonds, such as C–S bonds, with low binding energy, are acknowledged as
capable of generating hydrocarbons at very low levels of thermal maturity (Orr, 1982). Sulfur is
typically higher in Type II kerogen types (Peters et al., 2005). Unusually high sulfur content in
certain types of Type II kerogens may explain the tendency of these kerogens to generate
petroleum at relatively low levels of thermal maturity (Orr, 1986; Peters et al., 1990; Baskin and
Peters, 1992) even though increased atomic O/C has been associated (Jarvie and Lundell, 1991).
Within the Torquay Formation, the sulfur content is high (6.0%), below the Lower Bakken
Formation black shale.
1012
1014
1016
1018
1020
1022
1024
1026
1028
0 1 2 3 4 5 6 7 8 9 10 11 12
Depth(m)
Genetic Potential
Poor Fair Good Very Good
Figure 16 – The calculated Genetic Potential of Rock Eval samples from well 13-19-9-30W1. Indicates the source rock potential
for a particular sample at a particular depth based on quantity.

22
3.3 Petrographic Analysis
The petrographic analysis for samples selected from wells 13-19-9-30W1, 4-2-1-10W2, and 8-
11-1-9W2 revealed the presence of low amounts amorphous organic matter, generally
characterized by a moderate yellow-orange fluorescence. Fluorescing colour is a function of
kerogen type and thermal maturity. A yellow – orange colour is often associated with kerogen
that is either within the oil window or underwent insipient alteration (Bend, 2007). Such a
finding strongly suggests that the organic matter within the Torquay Formation has undergone
some form of ‘degradation’ with the loss of hydrogen-rich material, yielding, in places, a false
Type III kerogen analysis which may be caused by post-depositional reworking.
a
c
b
d
Figure 17 – UV/Fluorescence microscopy images taken at x240 magnification. a) Tasminites in-filled with silt at a depth of
2274.74 m (Well 4-2-1-10W2) b) Tasminites ‘draped’ around a clast at depth 2274-76 m (Well 4-2-1-10W2) c) Broken algal
bodies within a silty matrix at a depth of 2274.765 m (Well 4-2-1-10W2) Parasinophyte at the contact between the Lower
Bakken Formation (dark colouration) and the Torquay Formation (Well 8-11-1-9W2)
40 μm

23
The Torquay Formation near the Lower Bakken Formation was the primary zone of interest in
wells 4-2-1-10W2, and 8-11-1-9W2. A presence of fractured algal bodies and Tasminites within
the silt sized particles of the Torquay Formation (Figure 17 and 18), is increased with proximity
to the lower Bakken shale. This trend was not seen at the top of well 13-19-9-30W2 as this
zone has been eroded away.
Intact algal bodies are observed at a depth of 1015.21 m within argillaceous material along the
edges of transported dolomitic siltstone (Figure 17). This is the only observed occurrence of
intact algal bodies within well 13-19-9-30W1. The majority of the cored portion of the Torquay
sees broken algal bodies and amorphous organic material along grain boundaries and fractures
(Figure 18). This is indicative of migratory petroleum that at one point moved through the
system but no longer there in economical amounts. Between depths of 1015.5 m to 1016.5 m,
which corresponds with the highest values for TOC, amorphous organic matter is observed
coating grain boundaries and at fractures, amorphous organic matter has the greatest tendency
to generate hydrocarbons at low levels of thermal maturity (Orr, 1982).
a b
Figure 18 – UV/Fluorescence images at x240 magnification from well 13-19-9-30W1. a) Parasinophyte within an argillaceous
lamination (1015.21 m). b) Fluorescing hydrocarbons along a fracture in a clay-silt matrix (1016.15 m).
40 μm

24
3.4 Kerogen Analysis
Kerogen is the ‘sedimentary organic matter that is insoluble in common organic solvents and
aqueous alkaline solvents’ (Tissot and Welte, 1984). An assessment of kerogen Type is
conducted to assess the source potential of a given rock. The pyrolysis parameters, Hydrogen
Index and Oxygen Index are plotted against one another on an x – y scatter plot (HI/OI plot) and
thereby designated into one of three Kerogen Types, which indicates the hydrocarbon
generation potential of organic matter within the source rock.
The Hydrogen Index v. Oxygen Index cross-plot suggests that the kerogen content within the
0
100
200
300
400
500
600
700
800
900
0 50 100 150 200
Hydrogenindex,mgHC/gTOC
Oxygen index, mg CO2/g TOC
Kerogen Typing
Figure 19 – A HI/OI plot indicating kerogen type through well 13-19-9-30W1 for the
Torquay Formation (Depths: 1013.5m to 1026.5 m). Only values that plotted
within this graph area were used.
I
II
I
III I

25
Torquay Formation ranges from Type II to Type III with minor amounts of ‘residual’ or non-
generative Type IV (Figure 19). Type III kerogen is typically associated with terrigeneous organic
matter, which neither fits with the stratigraphic age of the Torquay Formation or its probable
sabkha-like depositional setting. The absence of terrestrial material was confirmed using UV
Florescence microscope analysis. Oxidized or moderately oxidized Type II (or Type I) kerogen
will result in a false Type III assessment (Figure 19) due to the high incidence of post or syn-
depositional oxidation within Torquay Formation.
3.5 Geochemical Subdivisions of the Torquay Formation
In this study, the detailed geochemical analysis of source potential primarily focused on the
upper cored portion of well 13-19-9-30W1 from 1013.5 m to 1018.5 m, which represents Unit 5
and 4 as subdivided by Nicolas (2012) (See Section 1.5). Nicolas (2012) further subdivided this
unit into Subunit 4a, 4b, and 4c, based upon a combination of geochemical, lithological and
petrophysical data. A division into four subunits within Unit 4 is herein suggested (Figure 20).
Descriptions of the four proposed sub-units follows:
Subunit 4a - Characterized by a shift from a brecciated dolomitized siltstone to a more massive
green siltstone, and geochemically characterized by a peak in the Oxygen Index and a low
plateau in the TOC content. In this transitional subunit, values for S1 and S2 are very low,
exhibiting little change that suggests an organic poor interval and a period of rebound from the
oxidized Unit 3.

26
Subunit 4b - Characterized by tan coloured brecciated dolomitized siltstone within a green
matrix. The Hydrogen Index appears generally low throughout, rising slightly to 100 towards
1016 m with a moderately high Oxygen index, which is likely due to a high level of reworking or
the dolomitization of the host sedimentary rock.
Subunit 4c - This sub-unit is represented by the presence of argillaceous laminations
throughout the dolomitic, brecciated siltstone. This zone exhibits both the greatest range and
Figure 20 - Subdivisions made to Unit 4 of the Torquay Formation based on geochemical data from well 13-19-9-30W1. These
divisions also relied on lithological and petrophysical data (Figure 2, Appendix I).
Sub-divisions based on Rock-Eval data

27
the highest level of Total Organic Carbon, the highest associated values for HI, S1, S2 and the
lowest values for the Oxygen Index. Oil shows were prominent through this subunit as well as a
petroliferous odour. The Production Index remains above 0.6 throughout and the Migration
Index (Figure 14) remains high. This sub-zone also has the highest Hydrocarbon Type Index.
Pyrite begins to become more prominent with decreasing depth within this sub-unit.
Subunit 4d - Dolomitized, green siltstone with a tan brecciated siltstone (tan) throughout; the
argillaceous content is less than from the previous sub-unit and grain size increases within the
matrix. This sub-unit generally exhibits S1 and S2 values that decrease with depth as well as
relatively low levels of Total Organic Carbon. This possibly indicates the occurrence of low
organic sedimentation rates through this zone and an increase in depositional energy. High
oxygen index values through this sub-unit support this suggestion.
Unit 5 - Dolomitization through this unit appears to have decreased relative to Unit 4, which is
also characterized by an influx of very fine grained quartz sand. Cross bedding appears within
this sub-unit as well as discontinuous ripple bedding. Geochemically, this sub-unit is
characterized by an increase and subsequent decrease in the Hydrogen Index. Values for S1
and S2 exhibit a similar trend. Pyrite occurrence is quite high through the this unit and quite
high in this locality, and the second highest concentration to Unit 6 which is occurs deeper
within the Williston Basin.
This study only observes Unit 6 in wells 4-2-1-10W2 and 8-11-1-9W2. However, no geochemical
information has been acquired for these wells, therefore defining subunits is limited. Appendix
I and II illustrates where the subunits of the Torquay Formation exist in the cored section of the
well.

28
3.6 Production Index and the Relation of Source potential
The Production Indexes (PI) values for the upper Torquay Formation show considerable
variation (Figure 21), with the majority of values plotting outside the zone of significant oil
generation (i.e., between 0.1 to 0.4) (Espitalie et al., 1977). However, many of the plotted
values may not be accurate since most S2 values are less than 0.2 mg HC/g rock. Such very low
values indicate that very little organic matter within Subunit 4d of the Upper Torquay at 13-19-
009-30W1 has or is capable of significant oil generation. Production Index values viewed along
side the Total Organic Carbon and Hydrogen Index values show that samples with the greatest
S1 values (i.e., free hydrocarbons) have PI values above 0.4, indicating samples at this depth
and locallity are incapable of sigificant oil generation. High PI values are typically associated
with migrating hydrocarbons (Figure 21) (Peters, 2005).
It is also nteresting to note the that aibrupt decreases in Production Index values conincide with
changes in lithofacies (Figure 20) (Appendix II).
1014
1016
1018
1020
1022
1024
1026
1028
1030
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8
Depth(m)
Production Index
Production index vs. Formation depth
Zone of Significant Oil Generation
Possible upper limit of
significant oil generation
Figure 21 - Figure 21 – Production Index related to depth for the Torquay Formation at well 13-19-9-30W1. The gap between
the two blue dashed lines suggests the upper limit of oil generation. The gap between the two black lines is the zone of oil
generation as determined by Espitalie et al., 1977.

29
3.7 Comparative analytical approach (The assessment of two methodologies)
3.7.1 The assesment of source potential in ‘microhorizons’ versus the conventional and widely
used bulk rock approach.
This study utilized a sampling methodology that allowed for a significant increase in data
resolution. The use of a micro drill enabled the direct sampling of thin, distinct argillaceous
laminae without the dilution of organic material by silliciclastic and/or carbonate material
which typically occurs using the bulk-rock method. The traditional bulk-rock method of analysis
involves the crushing of rock material, such as drill cuttings, that were obtained over a sample
interval of 1 to 5 meters, with the associated dilution of indigenous organic matter. Sampling in
this fashion will lead to reduction in TOC, a loss in resolution, and the inability to accuratley
detect thin interbeds with high TOC amongst the interleaving non-source material rather than
providing a true assesment of the organic rich material within the zone of interest. No previous
analysis for the Torquay exist that would permit a comparison, however, Latimer (2013),
compared the analysis derived using the bulk-rock method against the microhorizon method
within the Birdbear Fomation of Southern Saskatchewan. Within that study, bulk rock samples
yielded a TOC of 3.63 wt. % whearas this microhorizon method gave a TOC of 16.87 wt. % from
a centimeter scale argillaceous lamination within that bulk-rock sampled depth interval. Such a
difference in values confirms the dilution of samples that occurs with use of the bulk-rock
method of analysis .
However, microhorizon scale sampling may impact the established normative threshhold values
of TOC considered necessary in an effective source rock. If the published norms for assessing
the generative potential of a source rock are used to assess samples acquired through the

30
microhorizion method of analysis, they may be greatly undervalued. Classification of the
generative potential according to Peters et al. (2005) is as follows:
Potential
(quantity)
TOC (wt. %)
Poor <0.5
Fair 0.5-1
Good 1-2
Very good 2-4
Excellent >4
The application of such values suggests that some intervals within the Torquay Formation have
good source potential, although petrographic analysis indicates that this is not the case. It
becomes clear that although thin isolated laminations may contain very high TOC values, by
virtue of thickness and their association with organically lean adjacent laminae such fine
laminations are may be incappable of expelling petroleum generating hydrocarbons.
Adjustments must therefore be made to source rock classifications that accommodate rock
mass when using a microhorizon sampling method.
3.7.2 Implications of the use of geochemical data to subdivide units
The use of geochemical information, petrophysical data and lithological descriptions provided a
more accurate means of subdividing Unit 4, as shown in Figure 20. The high resolution
geochemical data not only indicates changes in litholgy but also reflects changes in organic
matter accumulation rates. Such geochemical changes are also not visible in most cases in
petrophysical logs since logs do not provide a resolution below 1 meter. Using high resolution
microhorizon analysis provides greater efficiecy in determining divsions and subdivisions within
a formation. Employing this method on more heavily disputed facies boundaries in other
formational units could potentially put many controversies to rest.

31
4. Conclusions
- This preliminary assessment of the source rock potential of the Torquay Formation
determined that the petroleum source rock potential is low overall. Only small isolated
argillaceous laminations would appear capable of producing petroleum, though not on an
economical scale.
- Rock-Eval pyrolysis method utilized in this study displayed effectiveness of the Micro-horizon
sampling method through the Torquay Formation by identifying a high degree of variability in
TOC and enabled the definition of subdivisions through the formation based on geochemical
parameters. The traditionally used bulk-rock sample method is incapable of achieving either.
-The Rock-Eval derived geochemical data was shown to relate to lithology possibly indicating
shifts from low organic accumulation rates to higher rates and vice-versa where lithology was
unchanging.
-The traditionally used Rock-Eval data norms that that are used to assess source potential may
need to be adjusted to reflect data derived from a high resolution micro-horizon sampling
method due to the absence of dilution.
5. Future Work
This study provided a preliminary assessment of the source potential of the Torquay Formation.
However, this study has also identified areas of further potential research which included:

32
1. Detailed geochemical analysis of Unit 4c to determine the origin of the high values for
S1.
2. Conduct further work to determine if the geochemical anomaly within Unit 4c continues
down dip and into the paleo-shelf environment.
3. Conduct a comparative assessment using traditional (bulk) sampling method and the
microhorizon methodology.
4. Examine reasons for such low Tmax values through the Torquay Formation.

33
References Cited
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in Bakken Formation in Saskatchewan. In: AAPG Annual Convention and Exhibition, April 2
-25, 2012, Long Beach, California.
Aderoju, T., Bend, S., 2014, Organic matter variations within the Bakken shales of Saskatchewan:
with implications upon origin and timing of hydrocarbon generation. In: AAPG Annual
Convention and Exhibition, April 7-10, Houston, Texas.
Baskin, D. K., and Peters, K. E., 1992, Early generation characteristics of a sulfur-rich Monterey
kerogen: AAPG Bulletin, v. 76, p. 1-13.
Bend, S.L., 2007, ‘Petroleum Geology eTexbook’; Introductory etextbook on petroleum geology,
AAPG Special Publication: Discovery Series #11, American Association of Petroleum
Geologists, Tulsa, OK, USA, 210p.
Christopher, J.E., 1961, Transitional Devonian-Mississippian Formations of southern
Saskatchewan; Saskatchewan Mineral Resources, Report 66, p. 103.
Christopher, J.E., 1963, Lithological and geochemical aspects of the upper Devonian Torquay
Foration, Saskatchewan, Journal of Sediment Petrology, Vol. 33, p. 5-13.
Espitalie, J., Madec, M., Tissot, B. and Leplat, P., 1977, Source rock characterization method for
petroleum exploration. In: Proceedings of the Offshore Technology Conference, May 2–5,
1977, Houston, TX, OTC, p. 439–44.
Fuller, J.G.C.M., 1956, Mississippian rocks and oilfields in southeastern Saskatchewan,
Saskatchewan Department of Mineral Resources, Report 19, p. 72.
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348.
Hunt, J. M., 1996, Petroleum Geochemistry and Geology, New York, Freeman and Co.
Jarvie, D.M. and Lundell, L.L., 1991, Hydrocarbon generation modeling of naturally and artificially
matured Barnett shale, Ft. Worth Basin, Texas, Southwest Regional Geochemistry
Meeting, Sept. 8-9, 1991, The Woodlands, Texas, 1991.
Jones, R. W., 1986, Origin, migration, and accumulation of petroleum in Gulf Coast Cenozoic,
AAPG Bulletin, vol. 70, p. 65.
Kreis, L.K., Costa, A.L., and Osadetz, K.G., 2006, Hydrocarbon potential of Bakken and Torquay
Formations, southeastern Saskatchewan; in Gilboy, C.F. and Whittaker, S.G. (eds.),
Saskatchewan and Northern Plains Oil & Gas Symposium 2006, Saskatchewan Geological
Society Special Publication 19, p.118-137.

34
Latimer, A., 2013, An evaluation of source rock potential of the Devonian Birdbear Formation in
southern Saskatchewan, Bachelors of Science thesis, Department of Geology, University of
Regina.
Nicolas, M.P.B., 2006, Petroleum geology of the Devonian Three Forks Formation, Sinclair Field
and surrounding area, southwestern Manitoba, in Saskatchewan Northern Plains Oil and
Gas Symposium Core Workshop Volume, E.H. Nickel (ed.), Saskatchewan Geological
Society, Special Publication 20, p.32-49.
Nicolas, M.P.B., 2007, Devonian Three Forks Formation, Manitoba (NTS 62F, parts of 62G, K),
Report of Activities 2007, Manitoba Science, Technology, Energy and Mines, Manitoba
Geological Survey, p. 171-179
Nicolas, M.P.B., 2012, Stratigraphy and regional geology of the Late Devonian- Early Mississippian
Three Forks Group, southwestern Manitoba (NTS 62F, parts of 62G, K) Manitoba
Innovation, Energy and Mines, Manitoba Geological Survey, Geoscientific Report GR2012-
3, p.92
LeFever, J.A. and Nordend, S.H., 2010, Stratigraphic transect of the Sanish and Parshall Fields,
Bakken Formation, Mountrail County, North Dakota, North Dakota Geological Survey,
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Nicolas, M. P. B., 2012, Stratigraphy and regional geology of the Late Devonian-Early Mississippian
Three Forks Group, southwestern Manitoba (NTS 62F, parts of 62G, K), Geoscientific
Report - Manitoba Geological Survey.
Orr, W.L., 1986, Kerogen/asphaltene/sulfur relationships in sulfur-rich Monterey Oils, Organic
Geochemistry, Vol. 10, Issue 1-3, p. 499-516.
Peters, K.E., Waters, C.C., Moldowan, J.M., 2005, The Biomarker Guide, Second Edition, I.
Biomarkers and Isotopes in the Environment and Human History. Cambridge, UK
Cambridge University Press.
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edition. Springer-
Verlag, Berlin, 699 p.
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Vinci Laboratories, Rock-Eval 6 User’s Guide.
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Saskatchewan Geological Survey, Saskatchewan Ministry of Energy and Resources, Misc.
Rep. 2009-4.1, Paper A-1, 3p.

35
Appendices
Appendix I – Composite log for well 4-2-1-10W2
Appendix II – Composite geochemical log for well 13-19-9-30W1
Appendix III – Core descriptions for wells 4-2-1-10W2 and 13-19-9-30W2
Appendix IV - Rock-Eval Data for well 13-19-9-30W1

37
Appendix I
Composite logs for well 4-2-1-10W2

39
Appendix III
Core Descriptions
Well 4-2-1-10W2
2274 – 2274.74m
SHALE: Black laminated, organic rich
Top of Torquay
2274.74 –2275.70m
SILTSTONE: Tan – grey colouration, laminations of argillaceous material (wavy), pyrite stringers, very
fine sandy laminations and interbeds periodically, grades into dolomitic sandstone
2275.70 – 2278.70m
SANDSTONE: dolomitic, very fine grained, grey, rip-up clasts present throughout, periods of medium to
heavy brecciation of dolomitic siltstone, some green argillaceous laminations , micro pyrite present
throughout.
2278.70 – 2279.92m
MUDSTONE: green argillaceous material with silt and very fine grained sandstone fine interbeds
throughout
2279.92 – 2280.27m
SILTSTONE: dolomitic, tan-grey, pyrite infilled fractures, fine laminations of black argillaceous material
(wavy).
2280.27 – 2280.47m
SHALE: massive, green/grey, finely brecciated with tan dolomitized silt, pyrite blebs.
2280.47 – 2280.54m
SHALE: massive, green/grey, pyritization occurs in small cm scale blebs
2280.54 - 2282.90m
MUDSTONE: wavy, interbedded, brecciated green clay with some lam of dolomitic very fine grained
sandstone. Brecciated silt clasts have an orange colour to them.
2282.90 – 2284.11m
MUDSTONE: green-grey, with wavy interbeds of dolomitic sandstone and orange/tan dolomitic
siltstone.
2284.11 – 2285.19m
SILTSTONE: dolomitic, tan to orange colouration, frequent wavy and planar laminations of green
argillaceous shifting to black with depth.

40
2285.19 – 2285.56m
SHALE: black, laminated with fine orange dolomitic siltstone periodically.
2285.56 – 2287.30m
SILSTSTONE: dolomitic, tan/orange, frequent black shale wavy and planar laminations, some green
argillaceous laminations as well.
2287.30m – 2287.54m
SHALE: brown-black, some fine laminations of tan/orange dolomitic sandy siltstone, some infrequent
brecciation clasts of dolomitic siltstone.
2287.54 – 2289.05m
SANDSTONE: very fine grained, orange/tan, silty, wavy laminations of black argillaceous material.
2289.05 – 2289.80m
SANDSTONE: dolomitic, tan/orange, with frequent black cm scale shale laminations throughout
2289.80 – core base
SANDSTONE: dolomitic, massive, tan/orange
Well: 13-19-9-30W1
1013.5 – 1014.0m
SANDSTONE: very fine, silty, dolomitic, shale laminations (light green), oil stain, bright yellow
fluorescence. Pyrite crystals common.
1014.0 – 1015.0m
SILTSTONE: dolomitic, brecciated, tan, mixed with lesser amounts green clay, oil stain, bright yellow
fluorescence
1015.0 – 1016.80m
SILTSTONE: dolomitic, brecciated tan silt, cm scale green argillaceous interbeds throughout, fine pyrite
crystals, oil show, yellow fluorescence.
1016.80 – 1018.45m
SILTSTONE: dolomitic, tan-grey, brecciation, wavy argillaceous laminations (green), grades to massive
siltstone with depth.
1018.45 – 1020.9m
MUDSTONE: Red, low porosity, occasional light coloured brecciations
1020.9 – 1028.0m
MUDSTONE/SILTSTONE: altering beds of tan-green siltstone with green argillaceous material and red
mudstones.

41
Appendix IV
Rock-Eval data for well 13-19-9-30W1
Depth
Qty -
(mg)
S1 -
(mg/g)
S2 -
(mg/g)
S3 -
(mg/g) PI Tmax(°C) HI OI TOC(%) MINC(%)
1013.5 52.8 1 0.67 0.79 0.6 402 209 247 0.32 8.24
1013.55 52.4 0.75 0.29 1.03 0.72 300 54 191 0.54 4.77
1013.6 50.9 1.93 0.85 1.08 0.69 306 127 161 0.67 5.59
1013.65 50.3 1.3 0.76 1.05 0.63 372 190 262 0.4 6.18
1013.7 52.5 2.2 1.03 1.54 0.68 303 156 233 0.66 4.49
1013.75 51.3 2.08 0.79 0.92 0.72 308 155 180 0.51 5.11
1013.8 51.5 1.61 0.73 1.34 0.69 310 162 298 0.45 6.55
1013.85 50.7 1.2 0.74 1.4 0.62 402 168 318 0.44 9.32
1013.9 51.6 2.22 1.12 1.46 0.66 385 224 292 0.5 7.45
1013.95 51.4 1.67 0.74 1.24 0.69 400 195 326 0.38 7.6
1013.98 50.3 2.9 1.06 0.84 0.73 303 208 165 0.51 6.92
1014 52.2 3.73 1.9 0.88 0.66 383 268 124 0.71 6.4
1014.05 52.3 2.29 1.18 0.97 0.66 385 251 206 0.47 7.25
1014.06 51.7 0.63 0.41 1.46 0.61 416 146 521 0.28 8.36
1014.08 51 3.48 1.53 1.18 0.7 311 239 184 0.64 5.81
1014.1 50 1.37 0.72 0.69 0.65 398 206 197 0.35 7.58
1014.15 51.4 2.53 1.07 1.3 0.7 303 202 245 0.53 5.64
1014.2 52.1 1.28 0.53 1.41 0.71 309 132 352 0.4 5.67
1014.23 52.7 1.06 0.48 1.24 0.69 363 117 302 0.41 6.3
1014.25 53 2.16 0.98 1.34 0.69 321 166 227 0.59 5.47
1014.28 50.9 1.65 0.83 1.62 0.67 299 143 279 0.58 6.13
1014.3 50.6 2.36 0.95 1.12 0.71 303 127 149 0.75 4.35
1014.33 52.6 1.59 0.78 1.19 0.67 320 104 159 0.75 5.18
1014.35 51.5 0.14 0.2 1.22 0.41 337 74 452 0.27 6.05
1014.36 53 0.57 0.37 1.47 0.61 360 128 507 0.29 6
1014.4 52.1 0.09 0.08 1.34 0.52 297 12 197 0.68 4.33
1014.43 50 1.02 0.44 1.18 0.7 336 85 227 0.52 5.05
1014.45 51 0.18 0.15 0.58 0.54 338 83 322 0.18 6.59
1014.5 52.3 1.99 1.18 1.57 0.63 309 176 234 0.67 6.36
1014.54 50.6 0.87 0.48 1.15 0.65 361 130 311 0.37 6.3
1014.55 50.2 1.21 0.54 0.39 0.69 357 180 130 0.3 5.86
1014.6 53 3.53 1.49 0.98 0.7 304 122 80 1.22 4.83
1014.63 52.5 1.3 0.77 0.68 0.63 399 179 158 0.43 7.34
1014.65 50.8 0.59 0.19 1.04 0.76 303 63 347 0.3 5.25
1014.67 50.5 1.96 1.11 1.78 0.64 393 188 302 0.59 9.5

42
1014.69 52.8 1.85 0.78 1.19 0.7 312 142 216 0.55 6.6
1014.7 52.7 1.52 0.67 1.23 0.69 303 186 342 0.36 5.06
1014.75 52.5 1.28 0.48 0.95 0.73 319 89 176 0.54 4.69
1014.78 51.1 1.23 0.65 0.62 0.66 361 250 238 0.26 5.66
1014.8 52 1.08 0.46 0.9 0.7 326 135 265 0.34 4.75
1014.85 52.9 1.91 0.85 0.88 0.69 386 236 244 0.36 6.3
1014.9 53 1.66 0.7 0.7 0.7 322 121 121 0.58 5.38
1014.94 52.7 1.29 0.47 1.14 0.73 302 115 278 0.41 5.53
1014.95 50.1 1.13 0.71 1.11 0.61 379 173 271 0.41 6.14
1015 50 0.14 0.12 0.6 0.53 340 71 353 0.17 5.88
1015.05 52.5 0.15 0.1 1.21 0.58 318 45 550 0.22 6.18
1015.08 52.6 0.85 0.35 1.1 0.71 302 50 157 0.7 3.18
1015.1 52.7 0.25 0.14 1.4 0.64 304 58 583 0.24 5.59
1015.15 52 0.37 0.24 1.16 0.6 298 133 644 0.18 3.09
1015.2 51.3 1.15 0.84 1.36 0.58 387 171 278 0.49 6.91
1015.21 51.6 0.25 0.17 1.41 0.6 307 55 455 0.31 6.06
1015.24 50.5 0.15 0.13 1.15 0.52 348 57 500 0.23 5.9
1015.25 50 0.19 0.11 1.44 0.64 333 42 554 0.26 5.94
1015.3 51.2 0.28 0.2 0.9 0.59 300 80 360 0.25 3.2
1015.32 51 0.45 0.28 0.61 0.62 299 156 339 0.18 3.27
1015.35 51.8 2.18 1.02 1.3 0.68 308 144 183 0.71 6.65
1015.4 51.5 0.11 0.12 1.11 0.47 294 52 483 0.23 5.29
1015.45 52.7 0.07 0.1 1.13 0.38 333 40 452 0.25 6.66
1015.5 51.1 0.15 0.21 0.29 0.42 416 191 264 0.11 4.52
1015.55 52.6 0.18 0.33 0.77 0.35 377 80 188 0.41 1.74
1015.6 52.5 0.2 0.27 0.51 0.43 398 159 300 0.17 5.79
1015.65 51.8 0.84 0.57 0.57 0.6 396 158 158 0.36 5.99
1015.68 51.2 0.97 0.51 0.7 0.65 310 109 149 0.47 4.99
1015.7 50 0.17 0.17 0.4 0.5 319 212 500 0.08 3.24
1015.71 50.6 0.12 0.15 0.5 0.43 312 150 500 0.1 4.62
1015.75 53 0.12 0.16 1.65 0.43 368 40 412 0.4 6.3
1015.76 51.9 0.92 0.65 1.11 0.59 363 250 427 0.26 5.32
1015.79 50.9 0.2 0.2 0.96 0.51 609 65 310 0.31 4.89
1015.8 52.1 0.45 0.24 1.32 0.65 300 83 455 0.29 6.61
1015.81 52 1.77 0.9 1.17 0.66 322 180 234 0.5 5.51
1015.83 50.8 1.63 0.86 0.73 0.65 395 172 146 0.5 6.59
1015.85 52.2 1.75 0.91 1 0.66 393 118 130 0.77 9.43
1015.85 51.2 2.58 1.28 1.11 0.67 300 162 141 0.79 5.52
1015.86 51.2 2.41 1.12 1.28 0.68 374 175 200 0.64 7.25
1015.87 50.9 0.32 0.15 0.72 0.68 334 75 360 0.2 6.37
1015.88 52.9 0.75 0.29 0.56 0.72 333 66 127 0.44 10.16

43
1015.9 51.1 0.31 0.22 0.4 0.58 391 85 154 0.26 6.82
1015.92 52.7 1.85 0.91 1.01 0.67 331 121 135 0.75 9.52
1015.93 50.3 1.54 0.67 1.07 0.7 307 88 141 0.76 9.19
1015.95 52 4.53 2.2 0.35 0.67 327 234 37 0.94 7.19
1015.96 50.4 5.76 2.8 0.71 0.67 322 211 53 1.33 6.21
1015.98 52.8 5.97 2.55 0.96 0.7 323 189 71 1.35 7.63
1016 51.5 0.84 0.45 1 0.65 378 110 244 0.41 11.66
1016.02 50 7.45 3.18 0.45 0.7 305 254 36 1.25 5.91
1016.03 52.6 1.38 0.67 1.1 0.67 395 126 208 0.53 12.86
1016.04 51.3 4.92 2.03 0.99 0.71 306 209 102 0.97 8.58
1016.05 52.6 4.56 1.96 1.21 0.7 379 173 107 1.13 8.12
1016.06 50.3 1.75 0.81 1.33 0.68 399 125 205 0.65 10.67
1016.1 50.9 3.42 1.15 0.45 0.75 301 128 50 0.9 4.96
1016.11 50.3 1.95 0.86 0.8 0.69 395 183 170 0.47 8.46
1016.12 50.1 6.79 3.01 0.26 0.69 383 232 20 1.3 6.24
1016.13 52.8 7.08 3.13 0.69 0.69 306 209 46 1.5 5.08
1016.14 52 3.57 1.3 0.83 0.73 321 125 80 1.04 6.92
1016.15 51 7.61 2.93 0.55 0.72 328 174 33 1.68 5.66
1016.16 52.7 1.94 0.78 0.63 0.71 389 137 111 0.57 10.68
1016.18 52.4 1.4 0.66 1.19 0.68 390 116 209 0.57 13
1016.19 50.7 2.92 1.5 0.97 0.66 307 138 89 1.09 7.21
1016.2 53 1.16 0.56 0.64 0.67 309 124 142 0.45 2.85
1016.22 50 0.23 0.12 1.13 0.65 369 43 404 0.28 4.56
1016.24 50.1 0.26 0.15 0.59 0.63 374 56 219 0.27 3.19
1016.25 50.8 1.22 0.82 1.03 0.6 377 195 245 0.42 8.41
1016.27 51.6 0.35 0.33 0.47 0.52 366 97 138 0.34 5.92
1016.29 53 1.53 0.93 0.93 0.62 397 139 139 0.67 9.09
1016.3 51.8 1.1 0.72 1.35 0.6 324 124 233 0.58 8.27
1016.32 50.4 0.11 0.11 1.51 0.49 360 52 719 0.21 7.99
1016.33 52.1 0.11 0.1 1.22 0.51 335 16 194 0.63 4.88
1016.35 51 0.18 0.23 1.06 0.43 377 79 366 0.29 4.98
1016.36 52 0.18 0.14 1.29 0.57 336 48 445 0.29 4.84
1016.37 50.8 0.52 0.31 0.9 0.63 297 66 191 0.47 3.1
1016.38 51.1 0.8 0.38 1.07 0.68 302 84 238 0.45 3.49
1016.4 50.3 0.61 0.33 0.88 0.65 298 51 135 0.65 3.72
1016.42 51.3 2.83 2.18 0.97 0.56 392 240 107 0.91 7.11
1016.43 50 1.05 0.47 0.89 0.69 307 121 228 0.39 6.79
1016.44 51.4 0.07 0.06 1.4 0.57 331 20 467 0.3 11.73
1016.45 50.3 0.17 0.13 1.35 0.55 334 37 386 0.35 7.03
1016.47 50.3 0.14 0.12 1.39 0.54 365 41 479 0.29 12.57
1016.49 52.9 0.46 0.37 1.33 0.56 366 84 302 0.44 11.4

44
1016.5 51.6 0.12 0.06 1 0.67 347 15 250 0.4 10.5
1016.51 50.2 0.08 0.07 1.29 0.53 340 21 379 0.34 7.96
1016.53 50.2 0.1 0.1 1.69 0.5 348 27 457 0.37 7.58
1016.55 52 0.08 0.04 1.33 0.67 346 12 403 0.33 13.78
1016.58 50.7 0.07 0.05 1.42 0.58 349 19 526 0.27 9.65
1016.6 51.9 0.09 0.1 1.33 0.47 361 50 665 0.2 9.26
1016.62 51.6 0.33 0.2 0.58 0.63 345 69 200 0.29 3.34
1016.63 51.8 0.25 0.16 1.34 0.61 345 21 174 0.77 5.26
1016.65 50.1 0.09 0.08 0.96 0.54 362 30 356 0.27 7.42
1016.67 51 0.08 0.05 1.14 0.6 360 19 438 0.26 11.63
1016.69 50.1 0.07 0.08 1.65 0.44 362 53
110
0 0.15 7.04
1016.7 52.3 0.06 0.06 0.95 0.53 348 9 138 0.69 5
1016.73 51.6 0.08 0.07 1.19 0.54 354 23 384 0.31 12.27
1016.75 52.6 0.11 0.07 1.03 0.6 341 10 147 0.7 2.92
1016.76 52.2 0.13 0.08 1.09 0.63 340 12 170 0.64 2.96
1016.8 52.7 0.11 0.08 1.39 0.58 351 11 193 0.72 7.56
1016.82 52.8 0.21 0.14 1.49 0.6 367 20 216 0.69 6.96
1016.85 50 0.04 0.07 0.93 0.39 373 26 344 0.27 9.49
1016.9 52.1 0.08 0.06 0.91 0.57 353 4 61 1.48 7.54
1016.91 52.5 0.06 0.1 0.75 0.38 370 8 60 1.26 6.82
1016.93 50.2 0.07 0.03 1.06 0.7 340 14 482 0.22 13.02
1016.95 52.9 0.05 0.05 1.14 0.49 348 22 496 0.23 12.35
1016.96 51.7 0.05 0.06 0.93 0.43 359 4 67 1.39 9.32
1017 53 0.07 0.07 0.42 0.48 349 28 168 0.25 6.2
1017.03 51.6 0.08 0.04 1.06 0.65 334 15 408 0.26 10.59
1017.07 51.7 0.1 0.14 0.96 0.43 350 67 457 0.21 9.88
1017.1 51.3 0.09 0.13 0.89 0.41 347 81 556 0.16 9.85
1017.15 51.7 0.09 0.13 0.86 0.41 355 162
107
5 0.08 7.4
1017.2 50.6 0.07 0.16 0.17 0.32 341 145 155 0.11 7.59
1017.3 50.3 0.09 0.12 1.06 0.42 351 63 558 0.19 8.55
1017.4 52.1 0.12 0.12 0.54 0.5 344 40 180 0.3 7.95
1017.5 50.7 0.06 0.1 1.16 0.35 340 42 483 0.24 11.15
1017.6 50.4 0.09 0.11 0.8 0.45 347 28 200 0.4 8.47
1017.7 50 0.06 0.1 0.89 0.38 348 29 262 0.34 7.42
1017.8 50.8 0.07 0.1 1.13 0.39 341 38 435 0.26 9.23
1017.9 53 0.09 0.13 0.37 0.4 354 54 154 0.24 10.04
1018 51.1 0.11 0.12 0.93 0.48 362 32 251 0.37 8.02
1018.1 51.4 0.09 0.12 1.15 0.42 356 36 348 0.33 9.16
1018.2 50.9 0.08 0.1 0.92 0.44 347 59 541 0.17 10.14
1018.3 52.3 0.18 0.11 1.34 0.62 348 55 670 0.2 9.65

45
1018.35 51.4 0.18 0.14 1.17 0.57 365 54 450 0.26 8.92
1018.4 52.8 0.08 0.1 1.41 0.43 336 43 613 0.23 10.09
1018.45 50.9 0.07 0.14 0.83 0.35 348 67 395 0.21 10.82
1018.5 52.1 0.06 0.11 0.8 0.38 348 85 615 0.13 6.32
1019.5 50.6 0.08 0.1 0.54 0.44 338 91 491 0.11 6.26
1020.5 50.6 0.11 0.12 0.8 0.47 363 80 533 0.15 10.36
1021.5 52.8 0.1 0.11 0.75 0.48 346 58 395 0.19 16.11
1022.5 50.4 0.04 0.11 0.7 0.28 348 41 259 0.27 13.83
1023.5 50.2 0.16 0.14 0.68 0.55 351 34 166 0.41 12.85
1024.13 53 0.08 0.12 0.73 0.41 348 63 384 0.19 9.51
1024.5 51.3 0.1 0.19 0.15 0.36 419 112 88 0.17 8.83
1025.5 50 0.09 0.14 0.14 0.4 349 25 25 0.55 10.68
1026.5 50.1 0.1 0.17 0.42 0.37 354 40 100 0.42 9.59
1027.5 50.3 0.07 0.17 0.16 0.3 349 41 39 0.41 5.78
1048.5 51.6 0.15 0.16 0.4 0.48 364 84 211 0.19 8.71

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