Sedimentary history, diagenesis and organic facies of the Triassic Mungaroo Formation, Barrow Sub-basin, W.A.

SEDIMENTARY HISTORY, DIAGENESIS AND ORGANIC FACIES OF THE TRIASSIC MIJNGAROO FORMATION'

BARROW SUB-BASrN, \ry.A.

By:

JOHN TIANG.SHEN JONG

B. Sc. (Hons) March, t996

This thesis is submitted,in

fulfilment

of the requirements

of

the Master

of

Science Degree at the NCPGG of the

University

of Adelaide.

NATIONAL CENTRE FOR PETROLEIJM

GEOLOGY AND GEOPHYSICS (NCPGG)

TABLE OF CONTENTS

VOLTJME I

A C

KNOWLED GEMENT

^S

STATEMENT OF AUTHENTICITY AND AVAILABILITY ABSTRACT

CHAPTER 1: INTRODUCTION """'"" I

I

tl

tn

1.2 Objectives of study

1.3 Methods and work program 1.1 Economic background

eozolc

1

4 5 5 5 5 10 10

11 l1 t7 2l t7 2l

23 26 27 27 29

1.3.1 Location

1.3.2 Research strate

1.3.2.1 acqursrtron

t.3.2.2

1.3.2.3 and

other

data

CHAPTER 2: REGIONAL GEOLOGY AND STRATIGRAPHY 2.1 Regional geology and structural

^elements

2.2 Tectonic evolution

2.2.1 lntracratonic basin

stage

2.2.2 Rift valley to breakup

^stage

2.2.3 Post-breakup

stage

2.3 Depositional 2.4 Stratigraphy 2.4.1 Pala

cycles 2.4.2 Mesozoic 2.4.3 Cainozoic

CHAPTER 3: SEDIMENTARY HISTORY AND LITHOFACIES INTERPRETATION

3.1 Introduction

3.2 Triassic stratigraphy gv

3.3 Palynology and palynofacies 3.3.1 Triassic spore-Pollen 3.3.2 Late Triassic PalYnof

zones acies

3.3.3 Direction of progradation 3.4 Lithofacies unit interpretation

3.4.1 Rankin Trend

3.4.2

Eastern

Barrow

Sub-basin and Peedamullah

Shelf 3.5 Triassic eustatic

^events

3.6

Sedimentary

environments and

^facies

3.6.1 Lithology of

the

Mungaroo Formation 3.6.2 Rankin Trend

3.6.3 Eastern Ba¡row

30

30 33 36 36 38 42 42 42 50 57 54 55 56 Sub-basin

and shelfal

^{areas .}

...."...

60

3"7 Depositional model 3.8 Summary

CHAPTER 4: DIAGENESIS OF THE MUNGAROO FORMATION Part I: INTRODUCTION AND METHODOLOGY

63

&

74

74 76 79 79 79 79 86 87 88 89 89

4.1 Introduction and

Previous

4.2 Dîagenesis and porositY 4.3 Methods of investigation

investigations

4.3.1 Sampling

4.3.2 Analytical techniques 4.3.2.1

4.3.2.2 4.3.2.3 4.3.2.4 4.3.2.5 4.3.2.6

CHAPTER 5: DIAGENESIS OF THE MUNGAROO FORMATION Part II: SANDSTONE RESERVOIR

CHARACTERISATION ANI)

DIAGENETIC HISTORY ..."...

⁹¹

5.1 Introduction .91

5.2 XRD results and interpretation 5.3 Petrographic

^descriP

tions

5.4

Sandstone

composition of the Mungaroo Formaúon 5.4.1 Detrital components

5.4.1.1 Provenance

st

minerals

in

lithofacies units of the

Mungaroo Formation.

5.5

Climatic

^influence

on

the diagenesis

of

Mungaroo Formation

5.5.1 Climatic control on detrital mineralogy

9l

97 99 106 108

5.4.2 Authigenic

^{comPonents 108}

5.4.2.1 Early

^{stage 109}

5.4.2.2 Intermediate

stage 116

5.4.2.3 Late 5.4.3

Distribution

of

13l r19 t22 t24 t24

127

t28

129 135 135

159

159 159

r62

165

5.5.2 Climatic control on early

^diagenesis

5.5.3 Climatic control on late

diagenesis

5.6 Dissolution of authigenic

^{carbonate cements}

5.6.1

Distribution

of

main authigenic minerals

r27

and secondary

porosity 5.7 Isotopic

5.7.1

composrtlon

of carbonate minerals Summary

5.8 Summary: authigenic mineral

paragenesis

CHAPTER 6: DIAGENESIS OF THE MUNGAROO FORMATION Part III: RESERVOIR PROPERTIES OF THE

MUNGAROO FORMATION

6.1 Introduction

6.2

Dependence

of

porosity on sediment composition and environments reduction

"

¹⁵⁹

6.3

b-facies

6.3.1 Porosity

6.3.2 Porosity ty

6.3.3 Effect of

^on

reservoir quality 6.3.3.1 Porosity reduction during early

^diagenesis

Porosity

reduction during burial

diagenesis

Mechanical compaction 6.4 Summary

CHAPTER 7: HYDROCARBON SOURCE POTENTIAL AND PETROLEUM GEOCHEMISTRY

Part I: INTRODUCTION AND METHODOLOGY 6.3.3.2

6.3.3.3

168

Ltl

17t L7l

174 174

t77

180 7.1 Summary of previous geochemical investigations

7.2

Thermal-

maturity of the Mungaroo Formation 7.2.1 Previous investigations

data

180 182

r82

185 185 185 188 190

t92 t92

196

t96

r97 198

202 202 206

208

2ro

213

2t3 214

215

215 215 225 227 227 230 230 237 237 238 243 243 249 255

7.2.2

7.2.3 7.2.4

indicator

7.2.5 Computerised maturation modelling 7.2.6 Results

and

oil-to-source correlation Introduction: thermal maturation

Maturity indicators

Reliabilifu, of vitrinite reflectance (Ro) ^{as a} thermal

matuity

7.3 Hydrocarbon migration

7.3.1 Hydrocarbon migration 7.3.2 Oil-to-source correlation 7.3.3 Origins of oils and

^gases

7.4 Petroleum

^geoc

hemistry

7.5 Source rock

^eval

uation: methodology 7.5.1 Organic

7.5.1.1 7.5.2 TOC

7.5.3 Rock-Eval pyrolysis 7.5.4 Solvent extraction of

petrology and

_Photo

Classification of

coal

graphy

...

macerals

whole-rock

samples

7.5.5 Column

chromatograPhY

7.5.6 Gas chromatograPhY (GC)

7.5.7

Gas chromatograptiy

-

mass spectrometry

(GC-MS) CHAPTER 8: HYDROCARBON SOURCE POTENTIAL AND

PETROLEUM GEOCHEMISTRY

PATt II: RBSULTS AND INTERPRETATION

8.1 8.2 8.3 8.4

Introduction

TOC and nock-BïàT' Organic facies of

the

Organic petrology 8.4.1 Barrow

^and

pyrolysis

Mungaroo Formation

8 8 8

Exmouth

Sub-basins

4.2

North-eastern

Ba¡row

Sub-basin and Candace Terrace

4.3 Rankin Trend 4.4 Peedamullah Shelf 8.4.5 Summary

8.5

The effect of inertinite on kerogen appraisal by programmed

pyrolysis

8-6

Characterisation

of

extractable

organic matter (EOM) 8.6.1 Composition of extracts

8.6.2 GC

^analysis

of C151

^alkanes

8.6.3 Biomarker analysis

8.6.

8.6.

8.6.

8.7

^Comparison

8"8 Summary

3.1

^Bioma¡ker indicators

of

source biota and

3.2

matunty

3.3

Interpretation

of mlz

183

GC-MS

chromatogrrims "....""

of thermal maturity indicators

265 267 269

nl

271

CHAPTER 9z CONCLUSIONS """""'"" 280

9.1 Conclusions

²⁸⁰

282 9.2 Depositional model of the Mungaroo Formation 284

9.3 Implications for hydrocarbon exPloration

REFERENCES 285

VOLUME II

LIST OF APPENDICES

APPENDIX

^1:

APPENDIX

^2:

APPENDIX

^3:

APPENDIX

^4:

APPENDIX

^5:

APPENDIX

6:

CORE DESCRIPTIONS 301

X.RAY DIFFRACTOGRAMS 345

PETROGRAPHIC DESCRIPTIONS 395

THERMAL MATURITY PROFILES' BARROW SUB-BASIN (from KAIKO, in PreP.) 469

GC CHROMATOGRAMS ...""

^{47 5}

STRUCTURE OF IMPORTANT HOPANES AND

STERANES IDENTIFIED WITHIN THE

MUNGAROO FORMATION 482

Figure

1.1:

Figure

1.2:

Figure

^1.3:

Figure

1.4:

Figure

1.5:

Figure

1.6:

Figure 2.1:

Figure 2.2:

Figure 2.3:

Figure 2.4:

Figure 2.5:

Figure 2.6:

Figure 2.7:

Figure 2.8:

Figure 2.9:

LIST OF FIGURES

Australia's sedimentary basins (from le Poidevin

andLowden,

^1994)"

Australian remaining reserves

of

crude

oil

^plus condensate"

provisional

as at end-1993 (from

lePoidevin

and I-owden, 1994).

Australian remaining reserves

of

gas,

provision

^. as at end-1993

(from

le Poidevin and

Lowden,

1994).

Northern Carnarvon

Ba

in: tectonic Elements

(from

Kopsen and McGann, 198s).

Flow

diagram showing the techniques employed during the present study.

Map of Barow Sub-basin and surrounds, showing location of wells

selected for the present study.

Sedimentary basins of Western Australia

(9'q-d

B-asin;

YS'Voggy

^9-q9tt

Basin; N, Ñgalia Basin; S, Savory Basin; K, Karara Basin; W, Wiso

Basin), modifred

from

Purcell and Purcell (1994).

of Pilbara

Block,

across

the Abyssal

(Mutter

et a1.,1989) and the

work of (1981) on

^the

profile

Pilbara

Block

(from Stagg and

Colwell,

1994).

Northern Carnarvon Basin: tectonic elements

(from

Kopsen and McGann, 1985), showing

position of

sections

in

Figures

2.4

and2-70"

Regional geo-seismic section across Rankin Trend

(from

Stein, 1994)" See Figure 2.3 for approximately line location.

Tectonic

setting

of Western Australia's

sedimentary

basins at

selected

geological timãintervals. (a) Middle

Jurassic and

(b) Late

Cretaceous

[C"no"-unian) seafloor

^{spreading patterns}

(modifred from Baillie

^{et aI.,}

1994).

Australian-type passive continental

margin (from Falvey

^and

Middleton,

1981).

Reconstruction of northwest margin

of

Australia (from Veevers, ^1988)"

Barrow

Sub-basin and surrounds: generalised stratigraphic section

(ftom Barber,

1988).

Simplified structural

cross section,

Barrow

Sub-basin

(from Boote

and

Kirli l9S9).

^{See Figure}

2.3

for approximate

line

location.

Figure

2.102

Figure

^3.1:

Seismic and geological cross sections illustrati-ng Jhe stratigraphic

¿iitriU"tion of-the

Itñungatoo

Formation

^(Red)

in thè Barrow Suþbasin

and surrounds.

Late Triassic

palaeogeography:

Mungaroo Formation (modified from Hocking,

1988).

Detailed Triassic Stratigraphy, Barrow Sub-basin and

surrounds'

Þ¿V""l"gical

^ionatiõns

atãaot" Hdlby

et aI. (1987) and ^sea level curve is

moilified-from Haqet al.

^(1987).

on of the Rankin

Plaform (Bint

^and

Laæ Triassic. ^Sea

I

zone correlation (1994)-

Modified from

Gorter (1994).

Geological cross-section_through the

Wilcox Field,

^Rankin

Trend" From Vinceñt

^and

Tilbury

^(1988).

Seismic dip line over the Goodwyn-Field

showing_the

g.*tl{ di¡pj1.g

Triassic enänts

(TrN - TrC),

^tn¡ncated

by

the

Main Unconformity (MU)'

From Vincent and

Tilbury

^(1988).

delta

which

have and adapted

from Figure

Figure

Figure

Figure Figure

Figure

3"2|

3.3:

3.42

3.5a:

3.5b:

3.6:

Figure 3.7:

Figure 3.8: Deoositional environments within the Late Triassic

^sequence

of

the Exmouth Plateau (from Barber, 1988).

Well log profiles of

Mungaroo The

lower

section indicates a de

Subdivision of

selected

Late Triassic well

sections

into lithofacies

^units (each unit is described

in

Section 3-4)-

Figure 3.9:

Figure 3.10:

Figure 3.11: Tritfm

Figure 3.l2az

Seismic

line

82-118 ^(Candace Terrace),

illustrating the lower

^and-u-ppgr

,onãr

of the

Mungarô-Formation, baselon

seismic character (from Mack, 1993).

Figure 3.12b:

^Seismic montag-e-illustrating packages

within lower

Mungaroo Formation'

- from Mack,

^1993).

sissiPPi

l,

1984

Figure 3.13:

Figure 3.14:

Figure 4.1:

Figure

^4"2:

Figure

5.1:

Figure 5.2:

Figure 5.3:

Figure 5.4:

Figure 5.5:

Figure 5.6:

Figure 5.7:

Figure 5.8:

Figure 5.9:

Figure 5.10:

Figure 6.1:

Illustrative

of

the geomorphology and sedimentary facies

of

^a recent delta.

Note the complexily of thè verti-cal sections which may result

(from

Selley, 1978).

Proposed

depositional model for the Mungaroo Formation,

^northern Carnanon Basin.

Location map of the Ba¡row Sub-basin, showing wells selected for

diagenetic study.

Flow

diagram showing the techniques employed

for

the present diagenetic study

of

the Mungaroo Formation.

Relative proportions

of

minerals based on

XRD

peak height

showing the framework grain comPosition of

andstonés.

Mungaroo Formation

sandstones are te, subarkose, sublitharenite and

lithic-a¡kose'

ⁿ = 65. From

Folk,

1974.

Elemental composition

of

ankerite, calcite, siderite

I

and siderite

II

cements of the Mungaroo Forrnation sandstones.

Chemical composition

of

the zoned siderite, redrawn

from

BSE

imaging' Central Gorgon 1,3743.3m.

^Scale

bar = 50pm. From Kraishan (in

prep.).

Chemical

va¡iation of

the extensively zoned ankerite, redrawn

from

BSE

imaging.

Flinders Shoal 1,

2009.5m.

Scale bar =

20pm. From

^Kraishan

(in

prep.).

Big-river

sand composition.

rivers draining low-relief no

Parana). Immature sands are

t"rr

^{itré draining either cold} or \üafm arid regions (from Potter, 1978)"

Mungaroo Formaúon carbonate cements and dissolution distribution

in

the

Barow

Sub-basin.

Isotopic composition ratios of authigenic

carbonates

in the

^Mungaroo Formation sandstones.

Generalised diagenetic history of the Mungaroo Formation- Generalised paragenetic ^sequence

of the

diagene-tic

-e.v-enls affecting.the

r-¿tton" tttè*oitt of

the ltiungaroo

Formatión.

ModiFred

from

Kraishan

(in

prep.).

Plot of total thin

section

porosity

versus

total rock

^{fragments and micas} (data from Appendix 3).

Lower part of a typical fining upwards

sequence

iT ,h"

lVlungaroo

Formatiðn. eetroptryiical

^data

aó

aierage ya\rés for_eagþlitholo-gy, using available core daiä

from Bluebell l, Cental

^{Gorgon 1,}

Elder

^{1, Go1go1}

I' ÑofihityJ no"f.r

1, Observation 1, Onslow

I

^{and West}

Tryal

^{Rocks 3.}

Figure 6.2:

Figure 6.3:

Figure 6.4:

Figure 6.5:

Figure 7.1:

Figure 7.2:

Figure 7.3:

Figure 7.4:

Figure 7.5:

Crossplot

of core v

mean and the rang facies discussed

in

Porosity va¡iations

of

the Mungaroo Formation

lithofacies-

Note that the porosities are observed

thin

section porosities (pore

>

50

pm),

number

of

samples = 93.

Average porosity - depths plots

of

wells. Note that there is no define indicating factors other than mec

role in porosity

reduction/prese from

well

completion reports.

Figure 6.6:

Figure 6.7:

Figure 6.8:

Crossplot of core porosity

(7o) versus

permeability. (Pj)' V/est Tryal

nocts 3.

Data

frod well

cómpletion report

(WAPET,

1982).

Intergranular volume versus total

Formation sandstones used to evalu Drocesses and cementati

iggq

an¿ modif,red

from

are those from the southern

_Part

Peedamullah Shelf and

Exmouth

Sub-basin (Sandy

Point

1).

*

_represents

the average

of

64 samples

from

¹³ wells.

Habits of the main authigenic minerals and their effect on

^Mungaroo

Forrnation reservoir properties (porosity and permeability).

Depth to the peak of the

oil

generation zone (from Powell et a1.,1978).

Mungaroo Formation schematic palaeogeography (from Kopsen

^and

McGann,

1985).

Correlation of common organic maturation pafamgtgrs

with

coal rank and hydrocarbon generation (nio¿itie¿ from Senftle and

Lantis,

1991)"

Approximate correlation of various ryltu.iry,.Parametell.with

^stages

of

Lóaiiftcation and perroleum generation (from

killops

and

Kilþs,

^1993).

Figure 7.6:

Calculated Ro values,

top of

the Mungaroo

Formation (from Kaiko, in

prep.).

Figure 7.7:

Figure 7.8:

Figure 7.9:

Figure 7.10¡

Figure 7.llz

Figure 7.12:

Figure 7.13:

Figure

^7.142

Figure 8.1:

Figure 8.2:

Figure 8.3a:

Figure 8.3b:

Figure 8.3c:

Figure 8.3d:

Figure 8.4:

Figure 8.5a:

Figure 8.5b:

Figure 8.5c:

Figure 8.5d:

Figure 8.6:

Ternary

diagram showing

^the

relative

percentage

of czt,czs

and czq,

5a(H), 14a(H), 17a(H), 20R steranes in oils from the northern

Carnarvon

(from

Robertson Resea¡ch

Australia,

1986)" Note that the

oils

pfo't

in

the ìame part

of

the diagram as the Mungaroo Formation ^extracts

(see Figure 8.14).

õr¡

saturates

against õr¡

arOmatics

for

^source

rocks extracts from

^the

northern Carnan¡on Basin (from Robertson Research Australia, 1986)' õr3 saturates

against

õrs aromatics

for oils from

the northern Carnaryon Basin (from Robertson Resea¡ch Australia, 1986).

Map of

the

Barow SuÞbasin

and su¡rounds, showing

location of wells

selùted for geochemical investigation.

Flow diagram of organic geochemical analyses employed in this study"

Schematic Rock-Eval Pyrogram"

Pseudo-van

Krevelen

diagram used

for Rock-Eval pyrolysis

^data

(from

Waples, 1985).

Hydrogen Index versus T-"* cross plot showing kerogen type

^and

maturity.

Oreanic-richness

classification of Mungaroo Formation

^{based on}

TOC, Ba:íow

Sub-basin and surrounds.

Hydrogen Index vs

T-o, Buttqry

Sub-basin and surrounds

(total

number

ãíru-!f"r measuredi.î ¡.eatdown by

^a¡ea

is

shown

in

Figures 8.3a - 8.3d.

Hydrogen Index vs

T-o

@arrowÆxmouth Sub-basins)"

Hydrogen

Index vs T-.,

^(Candace

Terrace/l{orth-eastern Barrow SuÞ

basin).

Hydrogen Index vs

T,',o

(Rankin Trend).

Hydrogen Index vs

T-o

(Peedamullah ShelÐ.

Plot of

HI

vs

OI, Barow

Subbasin and surrounds showing organic facies

(from

Jones, 1987).

Average composition of

DOM,

Ba¡row and Exmouth Sub-basins.

Average composition of DOM, North-eastern Barrow and

Candace Terrace.

Average composition of

DOM,

Rankin trend.

Average composition of

DOM,

Peedamullah Shelf'

Comparison

of HI:OI plots of Rock-Eval data,

^as

meas¡red

and after correètion for inertinite content.

Figure 8.7:

Average Composition

of

sour e rocks

extracts,,ìylulg-og

Fo.rmation. (a)

= Bariow andExmouth Suþbasins, (b) = Rankin

^Trend,

(c) =

^Candace

Tetrace, and

(d)

₌ Peedamullah Shelf'

Figure 8.8:

^Source

rock rating diagra4:

^Mungaroo

Formation.

Boundaries between source types a¡e

from

Powell (1978).

Figure 8.9:

Gas chromatograms of alkanes from organic-rich_ samples of the Mungaroo Formation,

Bñrow

Suþbasin and surrõunds.

Manriþ

^increases

from

^(a)

to (f).

Figure 8.10:

Depositional environments of Mungaroo Formation based on isoprenoid/n- alkanes ratios.

Figure 8.11:

Figure 8.122

Mass fragmentograms

of

triterpanes

-(mlz

l9t)-ir-r-re-presgntative source

ro"i ru-i't"s of

tñe MungarooF-ormation. The labelledpeaks ^a¡e identified

in

Table 8.14.

Figure 8.13:

Mass fragmenrograms

of

steranes (mtz_.217)

i"_Tn-*t"lttative

^source

rock

samples

õf

tfre lùungaroo

Formation.

The labelled peaks are identif,red

in

Table 8.14.

Figure 8.14: Ternary diagram showing the relative

percentage

oL

C27, C2s and C29,

Scr(H), 14a(H), 17ct(H), 20R

steranes

in

selected source

rocks of

the Mungaroo Formation, Barrow Sub-basin and surrounds.

Figure 8.15: Illustration of a mlz 183 fragmentogram showing only n-alkane

distribution, and no indication

of

C3a-botryococcane'

Table

1.1:

Table 2.1:

Table 3.1:

Table 3.2:

Table 3.3:

Table 4.1:

LIST OF TABLES

List of important wells that have intersected the Triassic Mungaroo

Formation

within

the study ^area.

Event history

for

the Carnan¡on Basin, shqwing the effect of each event

in

the basin

(frõm

AGSO North V/est Shelf Study Group, ^1994)-

summary of Triassic spore-pollen zones, Barrow Sub-basin

^and

surrounds.

Mun garoo

Formation

palynofacies

definition :

summÍry

-

of

characteristic palyñologicat and lithoiogical features (from

Bint

and

Helby,

1988).

Summary

of

Mungaroo Formation sedimentary history,

Barrow

Sub-'basin and surrounds.

Summary of diagenetic

and

reservoir

investigations.

of the Mungaroo

Formation, North Rankin 5 and l-eatherback

I

discoveries.

Summary of core

samples

of the Mungaroo Formation selected for

diageneti-c investigation,B arrow Sub-basin and surrounds.

Table 4.2:

Table 5.1:

Table 5.2:

Table 5.3:

Table 5.4:

Table 5.5:

Table 5.6:

Table 6.1:

Table 6.2:

Table 7.1:

Table 7.2:

Table 7.3:

Table

^7.4a2

Table

7.4b2

Table 7.4c:

Table 8.1:

Table 8.2:

Table 8.3:

Table 8.4:

Table 8.5:

Bulk X-ray diffraction

results

of

sandstones samples

from

the Mungaroo Formation.

Summary of thin section petrography for the Munga¡oo Formation

sandstones.

Chemical composition of authigenic

^carbonate

minerals of Mungaroo

Fomration sandstones.

Distribution of main authigenic minerals in lithofacies of Mungaroo

Formation,

Balrow

Sub-basin and surrounds.

Framework grain composition

of

selected Triassic sandstones.

Stable isotope composition (ôl3Cpon, õttOpo" and

ôl8O5rr¡ow)

of

the authigenic carbonate minerals of the Mungaroo Formation sandstones'

core porosity

and

permeability

and

entral Gorgon

^1.

Data from

^Central

APET,

1983).

for

sed les.

Summary

of

the

previous

geochemical

investigations of the

^Mungaroo Formation, northern Carnarvon ^B asin.

Cuttings/core chips

^samples_

of

_Mungar-oo

Formation selected for

geoche-mical analyslis, Barrõw Sub-basin and surrounds'

Coal

^maceral

classification (from

^Standards

Association of Australia,

1986).

Geochemical parameters

describing source

generative

potential (from

Peters and

Moldowan,

1993).

Geochemical parameters

describing level of thennal maturation (from

Peters and

Moldowan,

1993).

Geochemical parameters describing type

of

hydrocarbon ^generated

(from

Peters and

Moldowan,

1993).

Results of TOC analysis and Rock-Eval pyrolysis.

Key

to rock-Eval pyrolysis ^{data sheet.}

Summary of the best source rock intervals within the Mungaroo

Formation, based on Rock-Eval parameters-

Organic matter type and

liptinite

composition,

Barow

and

Exmouth

Sub- basins.

Organic matter type and

liptinite

composition, Candace Terrace and north- eastem Barrow Sub-basin'

organic matter type and

liptinite

composition, Rankin Trend.

Table 8.6:

Table 8.7:

Table

^8"8:

Table

8"9:

Table 8.10:

Table 8"ll:

Table

8"122

Table

8"13:

Table 8.14:

Table 8.15:

Organic matter type and

liptinite

composition, Peedamullah Shelf.

Key

to Tables 8.4, 8.5, 8.6 and 8.7.

Recalculated

TOC,

52 and

HI

values,

with

corresponding maceral

Soup

percentages.

Extract

yield

and composition, and selected alkane ratios"

Biomarkers potentially useful as indicators of biological.ìnpu-t or

ãepositional

ênvironmént for

the

Mungaroo Formation (modifred from

Peiers and

Moldowan,

^1993).

Some useful maturity-dependent biomarkers and

their

thermal

maturity

domain.

Selected

biomarker pafameters of source, maturity and depositional

environment determinêd for the Mungaroo Formation.

Peak identification

onmlz

^{191 and}

rnlz

217 fragmentograms'

Selected biomarker

parameters

of source, maturity and depositional

environment determinèd for the Mungaroo Formation.

Table 8.16:

^{Summary of thermal}

manrity

investigations, Mungaroo Formation-

ACKNOWLEDGMENTS

I would like to

extend

my appfeciation to Australian Agency for International

Development

(AusAID) for providing me with an Equity

and

Merit

Scheme

Scholarship to complete my

postgmduate snrdy

in Australia.

Special thanks is also extended to the

University of

^Adelaide

for

the University of Adelaide Scholarship

living

allowance.

This

resea¡ch project \Ãras negotiated and obtained

by Dr. Bill

Stuart and supported

by funding from

the Australia petroleum Co-operative Research Centre (APCRC) and the participants of the

Barrow

Sub-basin Project;

Mobil

^{Producing and} Production Australia Pty.

Ltd.,

Western

Mining

Corporation ^and Boral Energy Resources. Research data were also supplied by Geological Survey of Western Australia (WAGS), ^rü/est Australian Petroleum Pty.

Ltd. (WAPEÐ

and Morgan Palaeo Associates.

My

sincerest thanks are

conveyed to Dr. Nick Lemon

^and

A/Prof. David McKirdy for their

enthusiastic supervision,

invaluable

advice and constructive

criticisms provided

thrcughout my

phD

candidature. Various ^chapters

of

this thesis were reviewed by

Dr.

Peter Tingate (NCPGG)'

to whom I am grateful. I

have also benefited

greatly from valuable

discussions

with fellow students throughout my candidature, especially Ghazi Kraishan, Khaled Al-Arouri

^and

Mohammad Kamali.

I would

also

like

to express

my

gratitude to

all

the

Staff

and students

of

NCPGG who made my postgraduate study ^at NCPGG a most enjoyable experience'

Finally, I wish to

acknowledge

my

parents,

Mr

and

Mrs K. H.

^Jong,

your

^constant

moral

^and

financial

supports throughout

my

academic studies are

very

much

appreciated- I

dedicate this thesis to both

of

you.

STATEMENT

STATEMENT OF AUTHENTICITY AND AVAILABILITY

This

thesis contains no material

which

has been accepted

for

the awa¡d

of

any other degree

or

diploma in any

university.

^{To the best} of my knowledge ^and belief, the thesis contains no material previously published or written by another person, except where due reference is made in the text"

If

accepted

for

the awa¡d

of the

degree and,

if

applicable,

I

^consent

to the

^thesis

being

^made

available for photocopying and loan.

(John -Shen Jong)

il

ABSTRACT

The Triassic, largely regressive

fluvio-deltaic

the Barrow Sub-basin

within

the North West a Jurassic

to

Cretaceous

rift

and downwarp un

Triassic

depositional'supercycle'

^started deltaic condïtions became dominant by th

the Archaen Pilba¡a

Block

to the east

of

the basi

formation is ^as

follows:

1. precipitation of pyrite

(I)

(framboidal);

2. siderite G) (micriric) cementationr

p.äipiotion

of microcrystallised siderite rhombs in voids ^and around quartz grains;

3. Kaolinisation

oiiJãrp*, --t

^{kaolin + quartz (major quartz} overgrowths), early cementation

of

framework grains;

4. dissolution

of

quartz along microstylolites ^and formation

of

minor quartz overgrowths, which continue after (5);

5. calcite and siderite

(tr)

(zoned);

6. ferroan dolomite/ankerite;

7

8

secondary PorositY;

9

1;

1 I _" Hydrocarbon migration.

lil

by quartz has compacuon- nts 5,

6

andT

oil

^{and gas.}

iv

FACIES OF THE TRIASSIC MTJNGAROO FORMATION' BARROW SUB-BASrN, Vy.A.

By:

JOHN TIANG-SHEN JONG B. Sc. (Hons)

March, L996

This thesis is submitted in

fulfilment of

the requirements of the

Doctorof

Philosophy Degree in NCPGG at the University of Adelaide.

NATIONAL CENTRE FOR PETROLEUM

GEOLOGY AND GEOPHYSICS (NCPGG)

TABLE OF CONTENTS

VOLTJME II

LIST OF APPENDICES CORE DESCRIPTIONS

APPENDIX

1:

APPENDIX

^2Z

APPENDIX 3:

APPENDIX 4:

X.RAY DIFFRACTOGRAMS

PETROGRAPHIC DESCRIPTIONS

THERMAL MATURITY PROFILES, BARROW

SUB-BASIN (from KAIKO' in PreP.) 469 APPENDIX 5: GC CHROMATOGRAMS 475

APPENDIX 6: STRUCTURE OF IMPORTANT HOPANES AND STERANES IDENTIFIED WITHIN THE

MUNGAROO FORMATION ...".. 482

30r

345

395