the university of adelaide asp€¦ · petrophysicists and reservoir engineers. core description...
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ASP
THE UNIVERSITYOF ADELAIDEAUSTRALIA
Australian School of Petroleum
IIYDRAULIC FLOW ZONE UNIT CHARACTERISATION
AND MAPPING FOR AUSTRALIAN GEOLOGICAL
DEPO SITIONAL ENVIRONMENTS
Shripad Biniwale
B. Eng.
The University of Adelaide
Australian School of Petroleum
This thesis is submitted for the degree of
Master of Engineering Science
May 2005
Abstract
prediction ofreservoir productivity and petroleum recovefy efficiency requires detailed
analysis of various reservoir properties and their interrelationship' Among fundamental
data used in such analysis, core data occupies a significant piace in characterizing
reservoirs. Core data is used in laboratory measurements to obtain basic and special
formation parameters and plays a vital role in terms of understanding geological
depositional environments and subsequent alteration (diagenesis)'
Geoscientists have traditionally classified rocks according to porosity, gfain parameters
(size, sorting and distribution) whereas reservoir engineers tend to emphasize the
dynamic behaviour of multiphase flow in rock formations (relative permeability and
capillary pressure). To bridge such differing views, the carman-Kozeny (c-K) equation
based Hydraulic Flow Zone Unit (HU or FZU) methodology, which considers variation
in flow behaviour properties as a function of geological facies, has been found ideal in
charcctenzing very diverse Australian reservoirs' Compared to previous studies' which
tended to classify formations firstly by rock parameters, this research work shows the
advantages of classifying formations firstly according to geological deposition and
secondly by rock parameters. For this purpose' the concept of 'Global characteristic
Envelopes' (GCEs) has been introduced which groups data by specihc geological
environments. Several such envelopes can be created for different f,relds, where the
internal structure of each envelope is a function of rock parameters' influenced by
variation in deposition and subsequent diagenetic effects, such as compaction'
cementation and mineralization (e'g' formation of clays)'
As a specific application that uses the above methodology, laboratory derived capillary
pressure data, for a number of Australian offshore fields, has been reviewed for the
purpose of establishing water saturation-height relationships as a function of rock tlpe'
forming part of a comprehensive petrophysical analysis' A modified'FZl-lt" method'
capable of giving improved estimates of reservoir fluid distributions, has been proposed'
The new methodology is particularly well suited for interpolating among different
lithologies and diverse rock types as evident from comparison with other methods
reported in the literature.
In conclusion, this work demonstrates the multidisciplinary approach to reservoir
characterisation, a requirement for a more comprehensive understanding of reservoirs'
This systematic approach, utilizing FZlJs, has resulted in an overall improved
methodology that is able to integrate geological, petrophysical and engineering aspects'
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Table of Contents
o Abstract
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Table of Contents
Declaration of AuthenticitY
a Acknowledgements
1. Research Overview
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Introduction .......'.'
Hydraulic Flow Zone Units
Validation of Core AnalYsis Data .
characterisation of Depositional Environments and Rock Pore structures... 5
Global Characteristic Envelope Method
Correlation and Integration among Wells
FZU Application for Fluid Saturation Modelling
Figures l- 8 ..
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References20
4. Paper one: Behrenbruch, P. and Biniwale, s. (2005). "Characterisation of
Clástic Depositional Environments and Rock Pore Structures Using the Carman-
Kozeny Équation: Australian Sedimentary Basins." Journal of Petroleum
Science and Engineering: 4713-4, 17 5-196'
5. Paper Two: Biniwale, s. and Behrenbruch, P. (2004). "The Mapping of
Hyãraulic Flow Zone Units and Characterisation of Australian Geological
Dêpositional Environments." SPE 88521, presented at the Asia Pacific Oil and
Gas Conference and Exhibition, Perth, Australia, october 18-20.
ehrenbruch, P. (2005). "An Improved
Depositional Characteristics and Fluid
s: Australian Offshore Fields'" to be
eeting, New Orleans, USA, June26-29'
7. paper Four: Biniwale, S. (2005). "An Integrated Method for Modeling Fluid
saturation Profiles and characterising Geological Environments using a
Modified FZI Approach: Australian Fields case Study'' sPE, to be presented at
the Annual Technical Conference and Exhibition, Dallas, USA, October 9-12.
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Summary and Conclusion
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Declaration
This thesis contains no material which has been accepted for the award of any other
degree or diploma in any other universities or tertiary institutions and, to the best of my
knowledge and belief, contains no material previously published or written by any other
person, except where due reference has been made in the text.
I give consent to this thesis, when deposited in the university Llbrary, being available
for photocopying and loan.
Shripad Biniwale
lv
Acknowledgements
I would like to take this opportunity to sincerely thank some of the many people who
have made my postgraduate studies and this thesis possible.
First and foremost, I wish to express my deep gratitude to my supervisor Prof' Peter
Behrenbruch for his invaluable technical advice, continuous support and enthusiasm
towards my project. Many thanks also go to my second supervisor Prof' Hemanta
Sarma, for his encouragement and valuable advice'
I would like to gratefully acknowledge the sponsors of the project: BHP Billiton'
ChevronTexaco, Santos Ltd and Woodside Energy for their financial support and
permission to use and publish their data and analysis results. In particular, I would like
to thank Santos Ltd. for their generous financial support through a 'santos Intemational
scholarship" thus providing me an opportunity to study at the university of Adelaide'
A thank you goes to all staff and students at the Australian School of Petroleum, for
their support and friendship, especially Yvonne, Maureen and Janet' I would like to
thank my fellow research students, Hussam and Thivanka, for being good friends and
for the informal technical discussions which were of great help.
I would like to thank my uncle Dilip Chirmuley, for his support, proof reading and
correcting my entire incoherent academic scribbles and making valuable suggestions'
Thanks also go to my friends, Akshay, Amit, Anuj, cyrus, Makarand, Mandar, sheetal,
Prasanna and vaijayanti, who tried to distract me from my studies but in fact made my
stay in Adelaide very pleasant and enjoyable'
I feel most indebted to my parents, Suhas and Anagha Biniwale, my grandmother and
my sister Maitreyee, who always encouraged me to face and overcome new challenges'
Thanks to my friends, Amol, Abhijit, chitragupt, Kedar, Niket, Nikhil, Pankaj, sachin
and Shailesh, with whom I discussed my long term career goals, for their support and
friendship.
This thesis is dedicated to all these very important people in my life'
Hydruulic Flo¡v Zone Llnit ClruracterisuÍion unil Mttpping for Australitttt Geologicul Deposìtionul Ettvironuettts
Resemclt Overview
Research Overview
Introduction
Formation characteristics, both qualitative and quantitative' are used by geologists'
petrophysicists and reservoir engineers. core description and analysis of core plugs give
information about facies, rock pore structure and their characteristics, where the pore
geometry is the end result of a long geological process involving deposition and
diagenesis. A conventional criterion for the subdivision used by geologists is that of
facies recognition and researchers have previously applied this idea of facies and flow
unit grouping for reservoir description (Rodriguez and Maraven', 1988; Ti et al'' 1993)'
Facies may be considered as fundamental building blocks for reservoir simulation and'
by using hydraulic flow unit identification and analysis, various layers may be grouped
into units that have similar flow characteristics (Barr and Altunbay, 1992)' Altunbay e/
al. (]994)proposed a method for predicting depositional and diagenetic facies by using
numerical geology from wireline logs and core data, while other researchers have used
electrofacies identification for describing reservoirs by grouping lithofacies based on
thickness, porosity and fluid saturation (wolff and Pelissiet,1982; Bucheb and Evans'
1994;Lee et al',2002).
Porosity and permeability are dominating factors for determining quality of a reservoir
and porosity-permeability cross plots have been used traditionally to establish the
general quality of reservoirs from basic core parameters. Kozeny (1927) and carman
(Ig3|)proposed a formula to mathematically correlate porosity and permeability' These
have been combined into a single equation, now known as the Carman-Kozeîy (C-K)
equation, in which reservoir rock can be represented by groups of capillary tubes' The
c-K equation, discussed in the next section, may be used to quantitatively describe
variation in flow behaviour as a function of geological facies, the correlation parameter
being the hydraulic radius. For a particular reservoir, various layers or facies may be
grouped together to form Hydraulic Flow Zone units (FZUs) or Hydraulic units (HUs)'
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fl¡,draulic FIox' Zone Unít Chtrt cteristtlio n and Mappiug.for Australian G eo I ogica I D epo sítio n u I E t' viro t"" e"ls
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Hydraulic Flow Zone Units
Hydraulic flow zone units have more recently been widely used in the petroleum
industry in terms of its application. Aguilera and Aguilera (2002) have outlined a
practical, synergistic engineering and geological approach for core data analysis' Flow
zone units are also used over a gteatextent as a tool for reservoir description (Rodriguez
and Maraven, 19gg; Ti et al. |993;Ratchkovski et al.,1999; svirsky et al',2004)' The
FZIJ approach has also been used in the correlation of various other rock characteristics'
for example with Nuclear Magnetic Resonance (NMR) measurements (ohen et al''
1995),andseismicvelocity(Prasad,2002).Abbaszadehetat'(1996)havedescribeda
detailed statistical treatment involving FZUs for carbonates' More recently' Míkes et al'
(2001) and Stolz and Graves (2003) have shown effective use of FZUs for the purpose
of upscaling and simulation'
A number of researchers have published articles on hydraulic flow zone unit concepts
and their importance in fluid flow in porous media, but Kozeny (1927) is generally
credited as the first to introduce more significant ideas regarding the interdependence of
permeability and porosity. Kozeny introduced the concept of a 'textural properties
constant', H., representing the product of tortuosity' shape factor and the square of the
specific surface atea. Catman (1937) described the flow of fluid through granular beds
and developed an equation to introduce direct dependence between porosity and
permeability, based on the concepts of specific surface area' hydraulic radius and
tortuosity. Combining the work of both scientists, the so-called Carman-Kozeny
equation, gives a theoretical foundation for the dependence of permeability on pore
structure.ThegeneralisedformoftheC-Kequationisasfollows:
: Permeability, pm2
: Effective porosity, fractional bulk volume: Shape facior (2 for a circular cylinder)
: Tortuosity _r: Surface area per unit grain volume, pm-'
(1)
where,k
þ,F,Tsru
2
Hydrttulic Flotv Zone LInit Clrurucleristtiott utttl Mapping.for A ustrul iu n G eot ogical D epo silio n u I E n vi ro n n en ts
Reseurch Overvìew
More recently, Ebanks (1987) explained the concept of a hydraulic flow unit from a
geological viewpoint and defined it as follows:
,,A Hydraulíc Ftow zone unít is the 'Representatíve Elementary volume' (REI) oÍ
the total feservoir rock wìth¡n whìch geologícal ønd petfophysícal propeftíes thøt
alþctltuidflowrøteareínternøllycons¡stentandpredictablydffirentfrompropertíes of othet rock volumes"'
Amaefule et al. (1988) were the first to describe the practical application of the flow
zone unit concept in the petroleum industry. They specifically used the FZU concept for
the analysis and prediction of permeability for actuar reservoir rocks. Barr and Altunbay
(1992) explained the practical aspects of FZUs more generally, for a variety of
depositional environments and diagenetic facies. They opposed the assumption of
.constant textural properties' (H") on the basis that, as tortuosity and shape factor vary
drastically from sample to sample, reflecting heterogeneity, H. must also depend on
pore structure variables such as cementation and roughness. Therefore, they suggested
that adherence only to the more fundamental assumptions of Kozeny may be
misleading, and that H" should be called 'hydraulic unit characterization factor"
reflecting the greater complexity that is found by incorporating alarger range of rock
ty.pes and depositional environments'
Later,Amaefule et al. (1993) suggested a methodology of using core and log data for
the identification of FZUs, for the purpose of permeability prediction' They elucidated
that core data provides information about various depositional and diagenetic controls
on pore geometry, which in turn defines existence of distinct zones (flow zone units)
with similar fluid-flow characteristics. They also observed variation of permeability by
several orders of magnitude for any porosity within a given rock type, which also
indicated the existence of several FZUs' They then proposed a methodology based on a
modified form of the c-K equation and the mean hydraulic radius concept for
identification and characlenzation of hydraulic flow zone units within mappable
geological units (facies). This technique includes a log-1og plot of a 'Reseryoir Quality
Index, (RQI), which is related to the hydraulic radius (w ø ,) 0'5 and a 'Normalized
porosity Index or Porosity Group' (PG) lÓ" | (l'ø "¡1, wherc þ " is the effective
porosity as a fraction. When RQI is plotted against PG' the relationship results in a
3
H!,draulic Flo¡v Zone Llnìt Churucterisution und Mapping for Austrnlitttr Geologícul Deposìfionul Environnents
Reseurch Overvietv
straight line with a unit slope and the intercept defines the characteristic 'Flow Zone
Indicator, (FZl). This offers flexibility for a pfactical implementation of the c-K
equation without exact determination of parameters such as pore throat shape factor'
tortuosity and surface area.
k(md) (2)RQI (¡m)= Reservoir Quality Index = 0'03 1
ø"
ó z = p orosity Group (pore volume to grain voltrne ratio) =lh) (3)
FZr(pm)= Flow Zone rndicator = t;fu)(4)
substituting these definitions into Eq. 1, and taking logarithms:
log RQI = log þ" + log FZI
Equation 5 represents a straight line of the form
y:mx*c
(s)
(6)
In Eq. 6, variable y is a function of permeability (and porosity) and x is a function of
porosity. The slope m and constant c are functions of rock type' Amaefule et al' (1993)
suggested that the value of the FZI constant in Eq'l can be determined from the
intercept of the unit slope straight line at h:l'
Validation of Core AnalYsis Data:
In order to generate reliable results, validation is the most important step before
processing conventional core analysis data. For every analysis, the data validation step
is carried out, where all data is categorised into various classes, as explained in Papers
one and Two. The main data class omitted from analysis consists of non-reservoir data
(data with exceptionally low permeability and/or porosity), atypical data (data which
appears atypical or non-representative for a particular deposition) and scattered data
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H!,drsulic Flow Zone Unit Clrcnt cte risutio tt u n d M uPP ì n g .for Austruliurt Geological Depositionnl Environnenls
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(data scattering on both porosity-permeability and c-K plots)' The remaining dataset is
used for further, detailed analysis and study. In Paper Three capillary pfessure data
validation has been carried out based on similar criteria'
This methodology may also be used for validating Special Core Analysis (SCAL)
Samples for various depositional environments. As shown in FigUres 1 and 2' where
large symbols indicate scAL samples, the relative affinity of such samples with other
conventional core analysis samples is a measure of their representativeness for a
particular depositional environment. More specifically, SCAL sample 1 (Figures I and
2), which represents a fluvial channel/ mouth bar environment, is not representative of
the geological interval considered, with porosity and permeability values being
reratively high in Figure 1 and a higher ReI value being indicated in the c-K plot of
Figure 2. This means that SCAL analysis results for this plug are likcly to be non-
representative f-or the overall group and SCAL results require adjustment before being
used in upscaling and reservoir simulation (Behrenbruch, 2000; Goda and Behrenbruch'
2004). Careful review of conventional core analysis data can thus be invaluable in
validating the applicability of special core analysis derived relationships' such as
relative permeability, and this has largely been the impetus for the work described in
this research rePort.
characterisation of Depositional Environments and Rock Pore structures
paper one mainly details a classification scheme for depositional environments for
various Australian fields based on the C-K equation. In many instances, practitioners
have used the c-K equation in a more mechanistic manner' to identify rock similarities'
whereas the paper presents a systematic method for analysing flow zone units' to
classify clastic formations on a more general / universal scale, emphasising that geology
should form the basis for such analysis' Paper one presents a modified definition of
hydraulic flow zone units, from a practical perspective, which is stated as follows:
,,Hydraulic flow zone units are lìthologícalþ unique geological layers ot lìthofacíes
(or simply facies), øs mønífested by petrologícal characteristícs' and øs cotrelatøble ìn
termsofthehydrøulìcradíus,bystrictadherencetogeology.',
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H),¡lntulic Flow Zone Ilnìt Chnructerisuliott untl Muppítrg .fo r A ustru I ìtr rr G eo I ogical D epo s itio n n I E n v i ro n u ett ls
Resenrch Overvìew
The c-K equation is very populaf with practitioners due to minimum parameter
requirements (porosity and pemeability) and ready availability of conventional core
analysis data. The equation links permeability with other pore parameters' but is not
necessafily the best conelation for predicting permeability for clastic rocks (Dias and
Jing, 1996; Shang et a1.,2003); neveftheless, the c-K methodology is most useful in
comparing different rock pore structures'
Nagtegaal (1980) has outlined several factors such as grain size, geometry, orientation'
and other pore structure aspects that contribute to the overall global properties of clastic
formations. Paper One comments on the three global factors, i'e' provenance and
transport, depositional environment and diagenesis, which give rise to the properties of
clastic formations. The paper discusses various Australian offshore fields from the
Bonaparte and Carnarvon Basins. The Bonaparte basin is located in the'l'imor Sea and
the Carnarvon Basin is located offshore Western Australia, see Figure 3'
Detailed explanations of the proposed FZU methodology and analysis technique are
given in Paper One, using the Laminana-2 well from the Bonaparte Basin as a case
study. Data flow and analysis for the proposed methodology is shown in the flow chart
of Figure 4. The Laminaria freld is in many ways ideal for a reservoir characterisation
study, due to the presence of a large number of different geological environments and
the availability of an extensive dataset'
The proposed FZU methodolo Ey apptoach, based on depositional environments' is
compared in Paper one with an alternative, rock type classification scheme, considered
by Barr et al. (2001). The new FZU methodology considers depositional environments
as the highest level of classification and incorporates rock type, i.e. grain and pore
structure parameters, as a sesondary classification'
Global Characteristic Envelope (GCE) Method
Paper Two provides a new perspective of FZUs, by mapping similar types of rocks in
terms of a 'Characteristic Envelope'. The envelope may be seen as an aid in FZU
modelling, by mapping regions or envelopes in c-K space as a function of geological
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fl),clruulic FIow Zone IJn¡l Clruruclerisatìott mil Mappingfor Austruliatt Geologicul Dcpttsilíonul Envirottnenls
Reseurch Overview
depositional environments. A large amount of data, covering two Australian offshore
basins has been compared and analysed by the GCE methodology.
Altunbay and Barr (lgg4) have described factors affecting hydraulic quality of a rock,
mainly controlled by its pore geometry, which in turn is a function of mineralogy (type'
abundance, morphology and location relative to pore throats) and texture (grain size'
grain shape, sorting and packing). All these attributes are primarily influenced by
geological deposition and subsequent diagenesis, consequently controlling reservoir
quality. Such depositional trends and diagenetic aspects are generally responsible for
the location of HUs within a particular characteristic envelope. 'Global Characteristic
Envelopes' (GCEs) may be created for any specific situation, by grouping depositional
environments and their facies in terms of hydraulic units. The limits of GCEs are
controlled by the physical extend of compaction, grain and pore structure
characteristics.
Paper one describes such envelopes with the flexibility to compare similar
depositional environments and their relative quality, together with the ability to group
and compare major depositional environments. Papers Two, Three and Four show
such GCEs based on a Bonaparte Basin case study. For each well a HU classification
scheme is proposed, consisting of different quality zones. other HU zonation techniques
(Porras et al., 1999; Perez et al., 2003) based on petrofacies or electrofacies and
lithofacies can be compared and subsequently incorporated as additional characteristics
for particular quality zones/groups, as demonstrated in Paper Two' Furtherrnore' Paper
Two indicates how photomicrographs and Scanning Electron Micrographs' (SEMs) can
be used effectively in studying the peculiarities of grain parameters and diagenesis' The
paper shows that, the GCE method addresses the large number of rock attributes in a
systematic and hierarchical manner, effectively integrating geological attributes with
engineering parameters.
Correlation and Integration among Wells
Several researchers have taken different approaches for correlating data among wells
based on depositional environment, lithofacies, petrofacies, electrofacies' log
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ll),¡lraulìc Flow Zone Ltt,¡t Churucterisution anil Mapping for Austrulfun Geologìcul Depositionul Ettvironutettls
Researclt Overview
measurements and hydraulic flow zone units (Busharu et al' 1997; Fichtl et øL1997;
Barr, 2000; Barr et a1.,2001). Geological zones within a well can be cofrelated to
geologically similar zones from nearby wells within the same field (or nearby fields)'
considefing the continuity of a particular geological zone, while the general practice has
been to use wireline logs for correlation'
paper Two describes such correlation f-or the Griffin field, comparing logs with FZU
methodology for Zeepard and Birdrong formations. The outlined approach emphasizes
that initial correlation should be based on geological deposition, compared with
petrophysical log correlation and finally resulting in integration by FZUs for an overall
consistent treatment. Paper Two details construction of stratigraphic cross sections
based on shale layers, distinctly observable in all Griffin field wells, serving as a datum
or reference. only cored intervals are considered at this stage and FZUs tbr individual
zones are constructed following the FZU methodology' All zones can be analysed with
c-K plots and the ones with similar FZU values aro then considered for further
integration, possibly represented by a single FZU relationship. similarities of geological
properties and petrophysical attributes for such zones must be checked before
integration.
using the case study of the Griffin area fields, Paper Two shows that by strict
adherence to geological interpretation, the hydraulic radius based HU methodology can
be used for correlation and integration among wells' The paper also demonstrates the
use of a polar transformation of HUs and the correlation of FZIs with petrophysical
logs, and fuither shows that after establishing such relationships, correlation and
integration can be extended to uncored intervals of wells for a particular held'
FZU Application for Fluid Saturation Modelling
one of the principal contributions made by petrophysicists to the understanding of
hydrocarbon distribution within a reservoir is the determination of appropriate
saturation-height functions (Skelt and Harrison, 1995)' Capillary pressure data and
saturation-height relationships form the basis for a number of engineering and
geoscience applications (Swanson, 1977; Wells and Amaefule, 1985; Amaefule and
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HJ,druulìc Flotv Zone IJnìt Chorrclerisutiott nnd Mappìng fitr AusÍrttIiun GeoIogìcul DepositÍottnI Environnetús
Reseurch Overvìew
Masuo, 1986; Jennings et al., 1987; Ma et al., lggl; Aguilera and Aguilera,2002)'
Several methods are available in the literature for determining field-wide saturation-
height functions based on capillary pressure data and log derived data, mainly utilizing
parameters related to rock typing, porosity and permeability, all for the purpose of
grouping similar relationships. Papers Three and Four present a detailed description of
common methods used by the industry'
Leverett is generally regarded as the first person to introduce an equation for
normalization of capillary pressure data, widely known as the Leverett-J function
(Leverett, lg4l). However, this generalized method often gives poor results for diverse
rock types and is also inappropriate for a large range of permeability values' Johnson
(1987) proposed a 'permeability-averaged' capillary pressure technique, relating
saturation derived from capillary pressure data to permeability and capillary pressure'
This technique is also not universally applicable and fails to predict saturation for lower
permeability values and short distances above the 'Free Water Level' (FWL)'
Several researchers (Rajan and Delaney, lggl; Gunter et al. 1997; Ding et al',2003)
have used reconciliation methods between core and log data' and have obtained
improved results. Skelt and Harrison (1995) have proposed saturation-height functions,
as based on Thomeer's model of pore geometrical factors, using both capillary pressure
and log-derived data. Harrison and Jing (2001) have further modified the method using
regression and optimization techniques, providing better fitting for saturation curves'
Although this method provides increased flexibility and amore practical approach, the
link to permeability is less clear. Papers Three and Four discuss and compare several
such methods, together with their advantages and shortcomings, and Figure 7 gives a
comparative overview of these methods'
cuddy et al. (1993) proposed a simple model based on a Bulk Volume'water (BVW)
function, widely used by practitioners. More recently Amabeoku et al' (2005) have
proposed a modified function, incorporating hydraulic flow zone units, that does not
require permeability as previously used in Cuddy's method' Aguilera and Aguilera
(2001 ;2004) have used a more integrated approach for capillafy pressure modeling'
utilizing Pickett plots for determining flow zone units and saturations' Recently,
I
Hydruulic FIow Zone LInil Clnracferisuliott uttd Muppíng for Auslraliun Geologicul DepositÍottrtl Ettvironmetús
Reseurclt Overview
Desouky (2003) has developed a new method of normalizing capillary pressure curves
using FZUs.
while correlation of conventional rock properties and geological attributes, with
parameters such as capillary pressure and fluid saturation, has been carried out by many
researchers and practitioners, such corelation and analysis has often provided less
satisfactgry results. on the other hand, a flow zoîe unit appfoach' indirectly
incorporating a larger number of geological and petrophysical parameters' has shown
greater promise. Mapping of FZUs in terms of such reservoir characteristics may lead to
better understanding when compared to conventional analysis methods' A modified
'FZI-^'method has, therefore, been proposed in Papers Three and Four' comparing
this method with other saturation prediction models. The new model may be described
as follows:
S.: A (H - H )-^ (7)
S* is expressed as a fraction of the pore volume and A, H¿ and À are parameters, being
simple functions ofFZl, as follows:
AlFZI A2
(8)
(e)
A
),
H
I12
H1FZI H2
FZI(10)
d
where,
H : the height above the free water level (FWL)
H¿ : the entry height, equivalent height at which oil first enters the pores, equating
to the pore entrY Pressure P¿.
Ar, Az, Àr, À2, Hr and H2are specific constants, evaluated from capillary pressure data
and determined by optimization techniques, being specific for each field' H¿ is
introduced to model various entry heights above the FWL and to ensure that valid
saturations are achieved at the FwL. This method gives more realistic saturations' even
close to the FWL where other methods are less satisfactory. Based on Brooks and
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Hydruulìc Flot, Zone (lnìl Churucterisúion unl Mupping .for A ustru I irt tt G eo I ogi cu I D eposi I io n u I E n viro n n enls
Resesrclt Overviev'
corey,s equation, udegbunam and Amaefule (199S) have utilized a similar formulation
(Equations 9 and 10), relating the terms À and P¿ with FZIs'
This modified method uses FZI as a correlation parameter for saturation modelling,
which automatically incorporates the hydraulic radius (Leverett J function)' porosity
grouping (lambda function) and offers flexibility for tuning specific relationships using
regression and optimization techniques (Skelt-Harrison rnethod)' overcoming
shortcomings of earlier methods, the improved methodology offers a better solution for
saturation mode[ing. paper Three details a case study for the corallina field, whereas,
Paper Four provides a Griff,rn field case study for comparing the new 'FZI-À' method
with other, conventional methods available in the literature. It has been found that for
Australian offshore fields, for treating diverse lithologies and handling a wide range of
rock types, the method proves superior. In order to provide further insight, Paper Four
presents statistical comparisons of various saturation prediction models' For each
method, model predicted water saturation is compared with core-derived saturation,
indicating that the modified Fz!-t^,method gives overall the best results, as represented
by the highest RÍ (correlation coefficient) values. For comparison' histograms plots
have been generated, showing differences between water saturation predicted by each
model and core measured saturations. As a further measure, mean average enor (MAE)
and root mean square error (RMSE) have been calculated. The superior performance of
the modifie d1z!-Xmethod, as compared with the other methods, is clearly indicated in
Figures 5 and 6.
Figure 8 summarises the multidisciplinary approach advocated, integrating geology
(Gl-G4: showing core analysis, facies zonation techniques, photomicrographs and
SEMs), reservoir engineering (Rl-R2: capturing porosity-permeability and c-K
relationships) and petrophysics (P1-P4: integrating capillary pressure and log data with
modified FZI-^ approacþ. This integration of disciplines is thus paramount in
providing consistent and meaningful averages of data that may be assigned to grid
blocks for geo-cellular modelling and reservoir simulation. In offering greater flexibility
for modelling various relationships, the improved and recommended saturation
modelling method is able to provide an extra dimension to formation evaluation
techniques.
11
fl¡,t¡rn,,,,, FIo¡t'Zone Lluil Cl¡nructcrisutiott (rtd tVIupping for AustruIiutt Geologicul De¡sosilionul Ettvirottntenls
Reseurch OvervietY
Figures
Fig. I Data validation and scAL sample representativeness: porosity-pelmeability cross plot
Fig.2 Data validation and scAL sample repfesentativeness: cozeny-Karman
- - - Note: Large symbols indicate SCAL samples
,, I*r4
T I
a
a
Ì:x
ot a
)fi
2
3t*
/ ,Ìr
I t](
I1, T;lrrvial Cttantte I & nloL¡tlr tlal'
2. Fluvial Channels
3. Proximal Estuarine Channels
4. Point Bar & Stream Mouth Bar
J.
( 'r :1i
10000.0
1000.0
ît
5GoL
oo.
10.0
1.0
0.300.250.200.10
01 00.
0.050.1
0.00 0.15Porosity
Note: Large symbols indicate SCAL samples
1
2
^È3
tiìF.
4À
o
)f
llì r :x.
,X
^{^
a
^^^
^^ a
a
iliti t:
I Fltlvi;tl (lhirrt¡le,l & lnouth lrar
2. Fluvial Channels
3. Proximal Esttlarine Channels
4 Point Bar & Stream Mouth Bar
x o.2oEg0G'a
?- -o.,o(l)
E -0.4É.E)
-3 -o.o
-0.8
o.4
-0.6 -o.5 -0.4-1.3 -1.2 -1.1 -1 -0.9 -0.8 -o.7
Log PorositY GrouP
12
plot
fl¡,r¡rnr,,r, Fltnp Zttne LInit Churucterisulit¡tt unl Muppittg.fbr Ausîrulíurt Geologit'ul Depositiotrttl EnvironuenÍs
Reseurch Overview
Fig. 3 Locations of the Bonaparte.and carnarvon basins, Australia.
Fig. 4 Hydraulic flow zone unit methodology: flow chart
ùÅLil,EEr.ì,', l' l.l l l. ll
¡,4 L I lì l-lr \li
¡EÁl-Uiì/\
i-:¡ì RPEl,lT/\Rl,ù
Ríì:-itlr- K
DLlr\,'iEÌ'lzoÉzÉ.
o
PLli ll I
ùt.lf l
Moãifeà.Ser tutth,2003
x$.ö"Y
(i
Alr'l¿.¡EU::ì
iY:j\.lEY
PARTE
4ISLvr, ¡
'l;ì¡,1;{1LtAl:,lt I
Porosity ând perm eability välues from core analysis data
calculate PG and RQI values (by usirìg FZI equations)
Draw best f,rt elliPse foreach deposition
Calculate PG and RQI values
Plot (log) PG vs (l"g) RQI values
Draw straight line with unit sloPe for
each deposition (FZU line)
13
Ff=0.98-1.00MSE = 0.00013óRMSE = 0.0088
" 1'o
.9uÉ
E o.gfNl¡.
E o.ô!EoEE 0.1o
!tD
E 0.2l¡ËE
,i o.o1.00.80.20,0 0.1 0.0
Measuled S*
Hldraulic FIow Zoue Llnil Chtrucleristtion and Muppìng fo r A ustru I kt tt G eo I ogìcu I D eposit io n a I E n vint n n en ts
Reseurclt Overview
Fig. 5: comparison between modified FZI-), function predicted
,rut", saturation and core derived saturation, Griffin-2 well.
Fig. 6: Difference between modified FZI-ì," function predicted
wãter saturation and core derived saturation, Griffrn-2 well.
Mean = 0.0014Std Dev = 0.001ó
0.0fl {.014 .{1.006 0.005 0'012 0'009 0,008 0.005 {'001 0'001 {l'00,|
t0
Difference ln Predicted S,
5
35
30
25
Izotr0)aSr¡IL
14
\g\{
+
t.¡
G
.È
?q
\
'ti
\{
=i
G
at
I(tl
Log DerivedPorosity and
Depth
Pc6 Pc4 P czPo't
100
.l¿cDo10
I1 10 100
\
\
Johnson's APProach (1987) Ios(Sw) = B.PC( - A-Log(K)
Cap. Pressure DataFWL Galculations Sw
FZUr----|>
Satu¡ation ilodelling
Gore AnalysisData
Leverett J ApProach (1941)
skelt-Harrison Approach (1995) Modified Fzu-À Approach (2005)
300
200
100
ËJ
=l¿-
oo-oo
.9oI
10000 e-'10 K (md)'l
0 0.0 0.2 0.4 0.õ
Sw
0.8 1
k
ú
PcJ{Su,) = ------=
ocosd
Normalised S*
ìØ-t
l. Thomeer's Model
2. Lambda Function
Regrcssionand
OptimizationTechniques
,S/¡--l-.Su=J^^Bourr 50o ...>+uo^^4l JtìGe2ogr 1Û'õ-
0 û fiT 0,4 sw0.6 Û-8 1 0 ì 2
FZU20 0.253uoJE40lro30
Ezoo-c !u.9on- "0.0 Ð.2 0.4 0.6 0.8 1
Fig. 7 Comparison of various methods for saturation modeling
G2an s
G1 r9 It t t9 !t¡ t¡
)t
l,
1,
ffi
HU1HU2
HU3
Fac¡e 1
Fac¡e 2Core
AnalysisData
Facie 3 .4Facie 5'
I
HU
HU
Fac¡e 6
Far¡e 7
Fac¡e Iacie 1 0 :a.d ¡6û,.¡ ¡*i''ó I l:r
rFlifri:":ìe ons o
PGR3¿!
¡lJ 4al06
vo.S
a
":4olf
"pþ
n.,Ð.
R1 R2
^¡.rdat. Þ..ùsÌ ll ofo il
Global Characteristic Enve ach
PIP3 P4
Capillary Pressure DataFWL Calculations
P2
Log DerivedPorosity and DePth
Modified FZI-À APProach
roach
C-K Space (FZU)
PorositY GrouP
ge,
I'
P" = 45 Psi
FZU
FZU
3ctt
ÈvSlJ
E¿nl!
930oll înaú ¿*
_c 1u€
0.25 FZU
oI 0.6 0.8 1o o.o r.z o
-oGt
oÈPorosity
Reseruoir
roach
wAI
,. Le.Eæet H,
5òiþt
$9n
;L-r0dþF,''
G.iinSi:!.
J
^llç¡11ÞmP
ä¡
B
A
IO)
G
ñ
G
i
\<=s*
-{
\0l
{
?q
Fig. 8 Multidisciplinary approach: integration of geology, petrophysics and engineering for enhanced reservoir characterisation
Llydruulic Flow Zttne IJniÍ CharuclerÍsution urtd MuppÍng.for Australinu Geologícul Deposìtionul Envirottnettts
Researclt Overvìew
Summary and Conclusions
o A practical and theoretically based, improved flow zone unit (FZU) approach
has been outlined, representing an ideal method to characterise formations'
linking their geological attributes with engineering parameters for the purpose of
better quantification of petroleum recovery efficiency. Conventional core and
scAL sample data validation is paramount in determining representative
relationships, such as relative permeability. Overall reservoir description can be
improved significantly by integfation of various core analysis results' utilizing a
multidisciplinary approach that covers geology, petrophysics and reservoir
engmeenng.
a
Based on the logarithmic form of the modif,red Carman-Kozeny equation' the
proposed, modified formulation has been shown to be effective in characterising
the variability of rocks. This methodology can be used for a systematic
classification of clastic formations and appears to be universally applicable. A
modified definition of the hydraulic flow zone unit is proposed: lithologically
unique geological layers or lithofacies (or simply facies)' as manifested by
petrological characteristics, and as correlatable in terms of hydraulic radius' by
strict adherence to geology. The method may also be used in reverse modelling
to predict porosity-permeability relationships'
The introduced methodology has allowed mapping and integration of hydraulic
flow zone units into groups or 'Global Characteristic Envelopes' (GCEs)' which
have the potential for a unique classification scheme. Such GCEs have been
derived for d,ata from several Australian fields in two basins, covering
depositional trends and diagenetic aspects, major controlling factors for reservoir
quality. Extending such ideas, the methodology may be used as a prediction tool
for the case of a new geological province, where a particular geological
environment has a certain chance of occurrence'
photomicrographs and SEMs are a useful aid to study the peculiarities of grain
parameters and diagenesis, and in addition compliment and support results
obtained from FZU and GCE analYsis'
o
17
I I¡u¡ro r,," Flou' Zttne Llnit Clturucraristtion uttil tlluppiug .fit r,,l t rf ru I i u t t G eo I o gicu I D e po s i I i tt n u I E n v i ro n n e ttt s
Rcsetrch Overvien'
The FZU methodology has been found to be useful for correlation and
integration among wells, adhering strictly to geological interpretation, as
exemplified by the Griffin aÍea case study' The effective use of polar
transformation of HUs and the correlation of FZI with petrophysical logs has
also been demonstrated'
a
a
o
Different classihcation schemes for grouping of geological depositions/ facies
have been reviewed and compared with the FZU classification scheme' While
such comparison confiffns the validity of alternative methodologies, the authors
have found that geological deposition should be the super-category and that
specific grain and pore characteristics should be secondary. A systematic FZU
classification, mainly based on quality groups and FZI values, has been
proposed.
A modified FZI-À saturation-height function approach, which automatically
incorporates the hydraulic radius and porosity grouping, has been presented and
superiority of the functional form is manifested by the statistical comparison
with other published methods. while treating diverse lithologies, this method
offers greater flexibility and accuracy than other methods, as exemplified for
selected Australian offshore fi elds'
18
llyt¡¡'nr,¡rc FIo¡v Zttttc Llnit Clturucletisutiott rtnl tllrtppittg fttr +lustruliutt Gcologicul Dc¡tositionul Envírotttttcttts
Rcseurch Overvieu'
Notes:
a In Figures 6 and 7 from the 'Research Overview' section, the family of curves ts
labelled aS ,FZIJ, (not the ,FZI,) aS FZ| represents the flow Zone indicator value
for a particular sample, whefeas FZU indicates the flow zone unit vaiue for the
whole interval with simil ar FZI values and depositional envifonments' The
family of curves uses this FZU value to generate the curve over the entire
interval.
In Paper One, page 183, Para 2, reference to the 'W' should be read as '&'
12'.
In Paper One, page 189, Para 2,last sentence - "SandStOnes afe very fine to
course...", 'course' should be read as 'coarset'
In Paper One, page 183, Para 2, Second sentence - "the Mardie Greensand
member, named so after an abundance of siderite in the upper-most zone"""
'siderite' should be read as 'g!ryþ]'
a
a
a
a In Paper Two, page 3, last Para, second sentence - "These two formations are
separated by the þfp-Valanginian unconformity'", 'Intra' should be read as
'Urp4.
In Paper Two, page 4, fifth Para, third sentence - "...zones within the range of
2656-2682 m, being lower deltaic plane deposition. ..",'plaÍte' should be read
as'plü.
In Paper Three, page 4, ninth Para, third sentence - "...is he height above
FWL...", 'he' should be read as '!þ]'
a
a
19
Hydruulic Flow Zone Ilnit Churrcterisaliott unl Mapping for Austrtlktrr Geologicul Depositíontl Environnents
Researclt Overview
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H¡,druulic Flot' Zttne UuiÍ Chtruclerisutiott und Mappittg for Australfutt Geological Depositíotrttl Environments
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20
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23
J
Hydraulic Flow Zone Ilnil ChoructerísaÍion an d Muppíng.for ,4 ustru I Íu tt G eo I ogicu I D ep o sitio tt u I E n v iro n n enls
Reseurch OvervieY'
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24
Hyrlraulic Flotv Zone Unìt Churucterisution untl Mupping for Austrtlittrt Geologicul Deposìtiounl Et'vi''onnet'ts
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25
Ílyilrttulic Flot' Zone Llnir Churacterisulion und iVlupping.for Austrulittt Geologìcul Dcposìlionnl Envirottuents
CHAPTER 4
CHARACTERISATION OF CLASTIC DEPOSITIONAL ENVIRONMENTS
AND ROCK PORE STRUCTURES USING THE CARMAN-KOZENYEQUATION:AUSTRALIANSEDIMENTARYBASINS
Behrenbruch, P. and Biniwale, S
Australian School of Petroleum,
The university of Adelaide, Adelaide, sA. 5005 Australia.
Journal of petroleum Science and Engineering 2005; Volume 4713-4,175-196'
H),druulic Fltnt, Zone IJnil Clruructcrisuticùt urtd Ùluppittg.for rluslruliun Gaologicul Depositit¡tttl Envirottucttls
STATEMENT OF AUTHORSHIP
CHARACTERISATION OF CLASTIC DEPOSITIONAL ENVIRONMENTS
AND ROCK PORE STRUCTURES USING TIIE CARMAN-KOZENYEQUATION: AUSTRALIAN SEDIMENTARY BASINS
Journal of Petroleum science ønd Engíneer¡ng 2005; volume 47/3-4, 175-196.
Biniwale, S. (Candidate)
performed analysis on all the samples, interpreted data, wrote partial manuscript and
acted as co-author.
zSigned Date
Behrenbruch, P.
Supervised work, helped in data interpretation, wrote partial manuscript
and acted as author
Signed Date.
Available online at www.sciencedirect.com JourNArof
PsrnoruuScmrcr &Excn¡rrutc
www. el sev ier. co m,/locate/petrol
€¡"f ENc = @DrREcro
ELSEVIER Journal of Petroleum Science and Engineering 47 (2005) 175- 196
Characterisation of clastic depositional environments and
rock pore structures using the Carrnan-Kozeny equation:
Australian sedimentary basins
P. Behrenbruch*, S. Biniwale
The University of Adelaide, Adelaide SA 5000, Australia
Rcccived l0 June 2004; accepted l9 January 2005
Abstract
The Carman-Kozeny formulation is used to generalize concepts for classifoing clastic depositional environments for
At¡stralian formations, and to explore rock lypes and their diagenetic features. The interest is not so much to derive single
hydra'lic unit relationships for specific geological zones, but to introduce a model for the purpose of classiôring the
characteristics ofgeologiciepositional environments and associated pore structures. The paper demonstrates how this approach
may be used for data validation and integration, and in applications of "reverse modelling", allowing estimation of pore
structure parameters, porosity and permeabiliry for a particular geological situation'
O 2005 Elsevier B.V. All rights reserved.
1. Introduction
The pore structure of clastic rocks is a function ofprovenance and transport, depositional environment
and subsequent alteration or diagenesis, resulting from
a varied series of geological processes. As such, the
evolution of rocks is rather complex, resulting in large
variation in pore structure characteristics, responsible
for a considerable range in static and dynamic
reservoir characteristics.
* Corresponding author' Tet.: +61 I 8303 8020; fax: +61 8 8303
8011.
E -mai! addres s: peter. [email protected]
(P. Behrenbruch).
09204105/$ - see front matter O 2005 Elsevier B.V. All rights reserved'
doi: 1 0. l 0 l 6/j.petrol.2005.0 l.009
While geoscientists have traditionally classified
rocks according to porosity, grain characteristics, and
pore structure motphology, reservoir engineers tend to
emphasize the dynamic behaviour of rocks. To bridge
the gap between the geoscientist's world of real rocks
and the engineer's world of average hydraulic
behaviour, the hydraulic radius-based Carman-
Kozeny (C-K) equation may be used to compare
various geological situations and rock characteristics.
Practitioners have used the C-K equation in a
specific and often mechanistic fashion to facilitate the
identification of similar rocks for the purpose ofreservoir modelling and simulation. In this papeq a
more systematic "hydraulic flow zone unit''(HU/FZU)approach is outlined with the purpose of classiffing
176
rocks and related pore structure parameters for Aus-
tralian clastic rock situations. Hydraulic units are
defined here simply as lithologically uniquc geological
layers or lithofacies (or simply facies), as manifested by
petrological characteristics, and as correlatable in terms
of hydraulic radius. It is emphasized that the geology
should form the basis for the analysis, not the other way
around, where the C-K equation has been applied in a
mechanistic fashion and geology subsequently super-
imposed. A fully integrated approach, comparing
hydraulic facies with lithofacies and electrofacies is
recommended, and examples are given.
The methodology outlined may analogously be
compared to estimating the size of geological bodies'
However, for HU defined, depositional environments,
a more comprehensive statistical treatment is still under
development. While knowledge to date has been based
on thousands of actual core-plug measurements and
hundreds of pore structure images, the development ofa more universal system is ongoing. To outline the
concepts for such a classification system, detailed
analyses are presented for four offshore Australian
fields, situated in the Bonapafie and Carnarvon basins'
Many additional fields are currently under study with
the aim to validate the proposed model, the final goal
being a universal sYstem.
2. Previous investigations
The idea of geological zonation in terms ofvariation of facies has been well established for some
time, (see Ebanks, 1987). It has also been recognised
that a synergistic approach for the integration of core'
log-derived and other (geological) data is necessary to
fully characterise a geological formation or sequence;
see for example (Amaefule et al.' 1988). This
integration and characterization of rocks may be
facilitated by using the C-K equation and the method-
the HU concept and the logarithmic form of the C-K
equation. HU methodology has also been used in the
correlation of various other rock characteristics, for
example with NMR measurements (Ohen et al', 1995)
and seismic velocity (Prasad, 2002). For a statistical
treatment involving HUs, including carbonates, see
for example Abbaszadeh et al. (1996). Particularly for
P. Behrenbruch, S. Biniwale / Jottrnal of Petroleum Science and Engineerirtg 47 (2005) 175-196
carbonates, which tend to be more variable, alter-
native empirical or statistical methods may be more
satisfactory, see for example (Chilingarian et al.,
1990). Svirsþ et al. (2004) have proposed a simple
regression approach for "Flow Zone Indicator" (FZI)
prediction, which could predict free water level(FWL) depths in most logged wells and could be
useful for the construction of reservoir compartmen-
talisation and modelling of FWL'While the C-K equation encompasses an expres-
sion linking permeability to other pore structure
parameters, it represents not necessarily the best
formulation for predicting permeability for clastic
rocks, as described in a comparative study by Dias
and Jing (1996), and more recently by Shang et al.
(2003). It is well recognised that strictly speaking the
C-K cquation only holds for a uniform pore size
distribution and that is the reason why (integrated)
capillary pressure based methods tend to be superior
in predicting permeability. Researchers have also
pointed out deviations from the C-K equation, leading
to modified C-K equations or alternative models' a
recent example being (Civan, 2003). Nevertheless, the
C-K methodology can be very useful in comparing
different rock pore structures.
The C-K equation in its basic form tends to be
popular with practitioners because it requires a
minimum of parameters þorosity and permeability)
from readily available, conventional core measure-
ments. Other pore struchrre information may then be
used where available, to further characterise the
domain of the C-K space (defined below), differ-
entiating diverse pore structures. There have been
several studies that compare HU derived zonation
with geological zonation (lithofacies) or petrophysical
log zonation þetrofacies or electrofacies), see for
example (Porras et al., 1999; Perez et al., 2003).
3. The Carman-KozenY equation
As is often the case, methodologies used by the
petroleum industry have had their origins in other
fields, in this case with the reported work by Kozeny
(1927) and C an (1938). Amaetule et al. (1993)
described a more specific formulation for petroleum
applications. The basic equation and definitions are
briefly summarised in Appendix A for reference.
4. Geological aspects
4.1 . Praperties of clastic formations
The main factors and features that contribute to
the overall globat properties of clastic reseryoirs
may briefly be outlinecl: size, geometry orientation,
and particularly pore structure aspects, refer Nagte-
gaal (1980). Basically, there are three global factors
that give rise to the properties of clastic forma-
tions:
l. Provenance and transPott,
2. Depositional environment,3. Diagenesis.
The size and type of depositional systems is
largely determined by plate tectonic position and
climate, that is the general orientation of the resulting
deposits, and the composition and maturity of the
clastic assemblage. The composition of the clastic
assemblage is an important variable, allowing litho-logic corelation, and also influencing diagenetic
behaviour and thus reservoir quality at depth.
Secondary aspects directly controlling the occurrence,
size and geometry of depositional environments is the
influence of changes in sea level during deposition,
and also the processes often associated with uncon-
formity surfaces, such as erosion and leaching,
phenomena that are known as epidiagenesis, if the
rock was actually exposed.
Grain-size characteristics and sorting for clastic
reservoirs are directly tied to the depositional
environment, with breakdown into stratigraphic sub-
division and individual facies. Diagenesis, the third
major factor controlling the quality of clastic reser-
voirs, by definition leads to changes in the deposits
from the moment they are laid down. The earliest
changes are environmental-related and involve oxi-
dation-reduction reactions, clay-mineral authigenesis,
and the precipitation of the first cements. Subsequent
changes occur during burial and usually more
strongly influence the porosity and permeability
through compaction, pressure solution, cementation,
clay-mineral authigenesis and leaching. Table I
outlines typical diagenetic effects for quartz arenites,
after Nagtegaal (1980), which are coÍtmonly found in
offshore, northern and western shelf areas, of
t77
Australia. The properties and the quality of clastic
reservoir rocks in the subsurface are thus the outcome
of a long and highly varied series of processes that
operate successively in the provenance area, in the
depositional area, and during burial. V/hile diagenetic
affects may be very varied, the single most impoftant
factor contributing to a reduction of porosity and
permeability with depth is compaction. Manyresearchers have investigated this behaviour; for a
good summary see Buryakovskiy et al. (1991).
4.2. The Bonaparte and Carnarvon basins
The West Australian super-basin consists of the
northern and western shelf areas of Australia.
Bradshaw et al. (1988) described the geology for
this region in tletail, the Carnarvon and Bonaparte
basins. Fig. I itlustrates the main structural elements
of the Northem Carnarvon basin, after Jenkins et al.
(2003), and Fig. 2, likewise, shows the same for the
Bonaparte basin, after Mclntyre and Stickland(1ee8).
Changes in the depositional regime over the area,
described by Bradshaw et at. (1988), are related to
climatic controls, covering glacial, humid tropical to
more arid environments, sea level changes, and
tectonism accompanying the breakup of Northwest
of Western Australia. These involved basin initiation:
a sag phase, compression, and the separation ofAustralia and Antarctica, and the impacts from the
neighbouring African and Indian plates. The young-
est sediments are Cenozoic carbonates, which overlay
Mesozoic fluvio-deltaic sands and marine shales,
lying unconformably above Permian tills. A trans-
gressive peak is recorded in the early Triassic and a
progressive landward shift in the Late Jurassic and
early Cretaceous periods.In general, the stratigraphy over the Bonaparte
basin bears some similarity to that over the Northem
Camarvon basin. Recent Quaternary and Tertiary
carbonates, shales and marls, including some sands
and siltstones, overlie Cretaceous claystones, provid-
ing an important seal, and are underlain by further
sands. This situation reflects a transitional delta and
fluvial marine depositional environment' The under-
lying sequence consists of submarine sandstones and
siltstones, turbidites and deltaic shallow marine clay-
stones and mudstones. This sequence overlies the
p. Behrenbruch, S. Biniwale / Journal of Petroleum Scíence and Engineering a7 Q005) ]75-196
Environment Related
Diagenesis
Depth
Shallow
lntermediate
Deep
Note: assuming amPle cations and an
average geothermal gradien, less than
l07o feldspar and less than 107¿ lithics'
Refe¡ence: Modified after Nagtegaal
Vitrinite Fixed Ca¡bon Content: É 55
Porosity (7o): lO 5þl 25
Permeability(md): 5 5 k: 100+
VFCC: 55 - 65
<-
VFCC 65 - 95
. Pedogenic clay minerals
. Soils, calcrete, silcrete, ferricrete, laterite
. Authigenic goethite, hematite, Mn oxides
. Auth. calcite, dolomite, siderite, sulphides
. Authigenic glauconite, chamosite
. Peat, organic matter
. Mechanicalcompaction
. Grain breakage and healing
. Minor cementation
. Minor quartz overgrowth
. Kaolinite, mixed layers, auth' montmorillonite
. Potential leaching
PS Level (- start of solution)
. Grain breakage and healing
. Pressure solution
. Quartz overgrowth
. Various cements
. Authigenic kaolinite, mixed layers, illite
. Potential
. Pressure solution
. Quartz overgrowth
. Various late cements
. Authigenic illite, chlorite
. Potential leaching
IC Level (illlte and chlorite crystallised)
. 2M illite, chlorite, PYroPhilite,paragonite, chloritoid, margarite
. Stress shadows quartz grains, loss
classic texture
Meteoric WaterLeachingCementationOxydation
SurfaceDiagenesis Epidiagenesis
oçoàod
AÊ
F
Metamorphism(-8-10,000) metres)
CT Level (montmorillonite transformed,
kaolinite
p. Behrenbrnch, S. Biniwale / Journal of Petroleum Science and Engineerins 47 (2005) 175 196
Diagenetic zonation: fine-medium grained, well sorted quarlz arenite
178
Table I
Triassic pre-rift deposition, occuffing under manne
transgression. The stratigraphy of the Vulcan sub-
basin is also similaç although Cretaceous volcanics
are also noted. Carbonates pass into siltstone and
sandstones reflecting the changes from shelf to slope
facies and passive margin deposition' Diagenetic
alteration in the Vulcan sub-basin indicates an
association between diagenesis and fault zones'
Deposition in asin accom-
panied periods extensional
òr transtension outlines the
stratigraphic elements for both basins, modified after
Korn et al. (2003).
In terms of petrology, grain size and clay content
have had a significant influence on perrneability, with
horizontal permeability primarily related to grain stze
and sorting, and vertical permeabilily related to
bedding structure, grain orientation and diagenetic
variation. Grain size control is related to depositional
facies. Regionally the flow direction is parallel to the
structural grain and the basin margins, towards the
onshore and upwards to the shallower aquifer
systems. Clay horizons and local faults are observed
to provide hydrocarbon seals. Diagenetic alteration
such as burial cementation, dolomitization and
introduction of silica or carbonate cement has
affected sediment porosity. In general, the Bonapaúe
basin and other shelf areas exhibit formations that
tend be clay rich, particularly kaolinite. Sandstones
rypically show quartz overgrowth, which, together
- - Llmlt of Northcrn Bonæartc Bâsln
T¡ r
o 50 lo0t_----t .l
llIAN
o
Tlmor IPm
JPDA
FlðmlngoSyncllna
IìI
Dan¡ln
t0.s
stn
Klmberlcy Block
W,A. N.T
'{ SH
Arch
t25(E
lrrdonesiaALJstrdlic
ssyn
Biówsc Basln
North SavuBasln
BâthurstTcrrace
AshmoÍcPlatlorm
FetrelSub-8asln
Refcrcncc: Modlfl¿d aft crMclntyrc and Stlckland
p. Behre,bruch, S. Bíniwale / Jonrnal of Petroletm Science and Engineering 47 (2005) 175-196
Fig. l. Bonaparte basin: structural elements and field location map'
179
with other diagenetic features, have led to moderate
porosily at dePth.
5. Hydraulic unit analysis of clastic depositional
environments and rock types
5.1. The Carman-Kozeny space, depositionaL
envelopes and reverse modelling
Traditionally, the accepted view is that the high
quality formations, compared to those of lesser quality,
exhibit different trends on the traditional log-perme-
trends with considerable data scatter (less uniformi-
these data clusters may be translated into the C-K
space.
According to Eq. (4), data points for individual
or PG), as lines with 45" slopes. Data trends that are
attributable to the same depositional environment
may be grouped by drawing a "depositional enve-
lope", encompassing all relationships, for a particular
field, all helds in a basin, or depicting a more global
situation. Fig. 5 conceptually shows such an
envelope.While the purpose and hence definition of deposi-
tional envelopes may vary, a number of generic
characteristic features may be outlined. A depositional
envelope may firstly be more precisely defined by an
upper and lower (reservoir) quality limit' More
quantitatively, hydraulic envelope indices may be
Jetermined, the intersection of the above mentioned
quatity lines with the zero vertical line for the porosity
group. Furthermore, the envelope is defined by an
upper and lower limit of porosity (porosify group on the
piot). The envelope may be dehned for a very specihc
15. 00'
adl6r
sub€aslnlnve
Sub€a¡lnBrnow
l-l early Cretaccot¡s Depoccntre
El Jurasslc to Early C¡ctaccous Oepoccntra
f--l Late Jurassic DePoecnhc
Early to Mlddlc Jurassic
I t¡" 00'
AN
50km
t>Dampler
LcwisTrough
Modlllcd atlcr Jonklns er al.
WosternAustraliaCurvicl
Abyssal Plain
180 p. Behrenbrrch, S. Biniwale / Jottrnal of Petroleum Science and Engineering 47 (2005) 175-196
Fig.2. Camawon basin: structural elements and freld location map'
situation, covering a limited depth range, hence limited
diagenetic variation, where variations are primarily
relaìed to grain size and sorting, a function of the
particular depositional nsidera-
iion ("high and low en e global
anaþsis may include ¿ Shallow
to deep formations, in which case diagenetic features'
mainly compaction, will tend to show the largest
variation.
further insight, it is instructive to "reverse modell'HU
trends, 45' lines in the C-K space' shown as curyes indemonstrates that there
of what is traditionallY
ots and what can be
predicted. This means that by selecting an appropriate
àepositional envelope and expected geological char-
acieristics, porosity, permeability and related proper-
ties may be estimated, with greater clarity than
working with just conventional plots'
Statistically, a particular depositional envelope may
be characterised in terms of the density of HU
relationships, similar to the size classification ofgeological objects in terms of statistical distributions'
As such, the outlined methodology may be used as a
prediction tool for the case of a new geological
province, where a particular geological environment
has a certain chance of occurrence and a specific
envelope may be considered to identiff possible
formation characteri stics.
5.2. Laminaria field analysis-Bonaparte basin
The Laminaria field is located in the Timor Sea
. 2) and is the largest oil-producing field in the
aparte basin. The Laminaria field is of particular
interest in that it exhibits a large number of different
geologic depositional environments. There is also an
ãxtensive data set available, with a number ofcomprehensive studies reported previously (Barr,
2000; Ban et al., 2001).
In terms of geology, there is an association with
coastal facies, and deltaic and interdeltaic, linear
coastal sequences, as well as marine clastic facies,
involving shallow marine sequences. Clastic zones are
mainly represented by fine to moderate, well-sorted
qlartz arenite, being of intermediate burial depth'
Diagenesis, as exhibited by scanning electromicro-
graph irnages indicate grain-breakage and healing,
pres sure so lution, qlartz overgrowth, various cements,
authigenic kaolinite, minor illite and some leaching'
The clay transformation level has typically not been
reached, so that rarely other clays are present. Porosi-
ties are typically 10-25% and permeability ranges from
a few millidarcies to more than a thousand millidarcies'
Table 2 summarises the available conventional core
measurement data for the Laminaria and Corallina
fields, while Fig. 6 shows this data graphically' Ofnearly a thousand data points, about l0% was excluded
from detailed analysis, of which about half was non-
reservoir and the other half was deemed as atypical, as
further explained below. Figs' 7-9 give an overview
and summary of the HU analysis carried out in this
sfudy. Fig. 7 shows the HU analysis for one of the key
wells, Laminaria-2, which has been cored extensively'
l8l
A large number of different depositional environments
are represented, and overall HU correlation is excellent,
particularly for the higher energy depositions. Fig. 8
represents the f,rrst level of integration where, for
example, all "bat''depositional environments for the
entire field are compared. This hgure indicates differ-
ent types of bars, as well as their relative quality. The
final field level of integration attempted is shown in
Fig. 9, where four major depositional environments
have been grouped for comparison: channel (without
eshrrine), esfurine, bar and deltaic environments. It can
be seen that different depositional environments cover
different parts of the C-K domain.
In order to give some appreciation for the applied
methodology, Figs. l0-12 have been included. Figs. l0and 11 show an example where the geological facies
description could not be supported and the HU analysis
indicated in fact two lithofacies' Figs. ll and 12 also
show so-called outliers, i.e' atypical data points for this
zone. Table 3 shows the aclual core measurement data
and zonation calculations for the top part of the se-
quence, highlighting seven of the outliers. As evident,
P. Behrenbruclt, S. Biniwale / Jotrnal ofPetroleum Science and Ertgineeríng 47 (2005) ]75-196
Fig. 3. Stratigraphic column of the Noftlìern Bonapade basin and Northem Camawon basin.
å¡t!
't¿IG
r,t
È'Ió
Northern Carnarvon Basln
w Rock Unlts ER¡¡rtltrT¡e¡rl Pê-qtlùtJ
',fèt)útô
a
',2a
a
/
,I
,
tt,
/'
a2
a
Ë
+¡Í
l4¿rI
t.Zz& ¿
182 p. Behrenbruch, S. Biniwale / Jotrnal of Petroleum Science and Engineeríng 47 (2005) 175-196
Porosity (o/o)
10 15
Fig. 4. Conventional core data plot: concept of "reverse modeling"
Porosity GrouP-0.8 -0.7s -o'7
2510000.00
1000.00
10.00
1.00
0.10
-0.65 -0.6 -0.55 -0.50.6
200
-1
5
!o3o!tq
=cL
00.001
0.01
-0.95 -0.9 -0.85
0.4
Ð0.2 E
oe
09,ocgt
-0.2 =5CL
-0.4 (Dx
-0.6
A(permea¡¡llty, poroslty) 15 Porosity (%) 20
Fig. 5. Sedimentology and hydraulic unit concepts: hydraulic unit envelope.
Dlagenesls TrendHU Depositlonal EnveloPeupper qualw fim¡t
Deposítion Trends
Sorting GrainSize
:a6 a
a
ofst*
o.tj-om¿
fsI
I
A : lo9t{(per¡l
ShallowFormat¡ons
riÌ4o
10
-0.8
Well name and
number
Corallina I CorallinaEast I
LaminariaEast I
Laminaria2
Laminaria3
Laminaria3STI
Laminaria4
Total
Depth range(m)
TB
3r74325t
3377
34'13
32833312
32083369
32983317
35593514
3225
3372
Data points before
validation
217 94 97 361 47 42 l3l 989
Data points after
validation
198 90 87 316 40 36 t28 895
Porosity range(7o)
7.4-23.9 2.t-21.8 o;7-20.3 6-24 10.3-8.7 6.8-18.1 4.8-23
Permeabilityrange (md)
0.4-7356 0.0264490 0.001-4780 t.3-2361 57-1772 0.24-t't.6 o.08-2220
p. Behrenbruch, S. Biniwale / Journal oJ'Petroleum Science and Engineering 47 (2005) 175 196
Laminaria and Corallina fields, summary of conventional core analysis DataTable 2
all except two of these data points are at the interface offacies. This manifestation is quite coÍrnon, where
diagenetic affects are associated with this boundary
such as leaching, cementation, bioturbation, etc'
The opposite type of situation is shown in Fig' 9,
two cases where geological facies could be reasonably
combined into common HUs. This figure also shows
the standard deviation for each facies, with 'R2
in the
range of 0.374.72. At this point one may question:
what should the rules be for establishing HUs? While
they may vary depending on the amount and qualiry
r83
of data, as well as the purpose of the analysis, the
rules and steps adopted here were as follows:
1. validation of data, excluding non-reservoir units
and outlyin g data, as determined by HU trend
analysis;2. splitting of reservoir units, as previously defined
from geological facies or electrofacies analysis,
provided a minimum shift in HU trend was
observed, in this case a shift in reservoir quality
index of 0.15 RQl units;
15 20 2510000
1000
100
10
0.1
50
Porosity (%)
10
1
!o3oA¡g
3CL
¡l
q¡{ .¡ a
irnt.
I a
a
^ !+ at
ì:t¡:?'¡ I
ì.t.f'l¡t
ItI
a
a
I¡
l f
t¡
tIÊta
rtÌ.
I0l: r
.F
Total No. of SamPles:
Before Validation - 989
AfterValidation - 895
Excluded Data - 9.5%
.l f'4
ata¡,. l,
tl . aaa
aa
aa
o
¡I
t ¡lI ¡orf'Ò
I
I
':l Ilr.l
Fig. 6. Laminaria and Corallina helds: "validated'core data'
0.01
Before Validation - 361
AfterValidation - 316Excluded Dala'12"/"
6
3
11
5
7
Prox Est Ghannel
10 a
t Point Bar Channel11
InterdistributarY BaY: 1o¡
1
¿ -to
a
(4.4)
o
+
t¡L'a
a atF
8
ata
Ò
aa
¡ò
& Fluvi & Prox Est
6
I
a
a
a
2 aat a.4
o
aa
ô
¿
12
rE.
Oa
À
À
Fluviaf Channel (4.6, 4.71
Strm Mouth Bar
& Dist Channel:1s¡Outer Est Bay
& Dist-Prox Strm Mouth Bar: 1z.t' 2.3'2-41Strm Mouth Bar, Dist Est Channel,
(6'2)
3 FluvialChannel(4.2,4.s1
FluvialSheet:
(4.5)
Prox Est,- Prox Est:
(1.1, 1.2)
('t.2-21
a
o
aat
& Prox Est Channel'Prox Est Channel: e.2,5l1
5Deltaic -!nterdistr¡butaryBay: (s)
7
r84 p. Behrenbntch, S. Biniwale / Journal of Petroleum Science and Engineering 47 (2005) 175 196
Porosity Group-1 -0.9 -0.8-1.4 -1.3 -1.2 -1.1
-1.3 -1.2 -1.1
t FC 4.2 + FSMB 4.3o L3- Barrier Bar 1.2- L3ST-All 2 sMBx LE1-SMB s(2)+6
-o.7 -0.6 -0.5 -0.4
x PB-SMB 2.5I L3ST-SMB+ LE1-DC2.1 +
0.6
0.4
0.2
0
ÐoU,o
o='oÊP.
foox
-o.2
-0.4
-0.6
-0.8
-1
3. merging of HUs, as defined geologically or petro-
physically, provided HU trends are from adjacent
units, or from the same geolo gic unit in differentwells ;
Fig. 7. Laminaria field: Laminaria-2, hydraulic zonation.
Porosity GrouP
-0.9 -0.8
o ÍIPSMB 2.3 +2.4a L3- Stream Mouth Bar 2.2o tidal baro LE1-PSMB 5(1)
4. defining HUs in statistical terms: adequate amount
of data, a minimum of 5 or 6 points per trend, and
minimum corelation (R2 > 0.5).
-0.7 -0.6 -0.5 -0.4
ÐoØo
9.
otr!¡_
foox
0.6
0.2
-o.2
-0.6
-1+PB7+lDB6
I2
34
5
6
Bars.""""'Fluvial- Channel SMBDistal- FluvialSMBSMB - Barrier BarPoint Bar and Tidal Bar(Combination)Stream Mouth Bars
2
4a
1
+
3I
¿-x
q
6
.LI
¡¡..'
+
Fig. 8. Laminaria field: all welts, hydraulic zonation for bar depositions
MDC22 (2)+SM84
P. Behrenbntch, S. Biniwale / Journal ol'Petroleum Science and Engineering 47 (2005) 175 196
Fig. 9. Laminaria field: Laminaria wells, hydraulic unit envelopes'
185
-0.7 -0.51
HUs, while Fig. 14 shows that eight HUs were
required to accommodate the same data with a rock
ffpe classification. The authors of this study favour
the highest-level classification by depositional envi-
ronment, with rock lype being secondary. Rock type
can then be addressed with the parameters indicated
in Fig. 14: grain size, sorting, bedding' and
diagenesis. In reality, in the limit' the two classi-
o.17 0.19 o.2110000
-1.5
0.07
Porosity Group-0.9-1.3
0.09 0.11
-1.1
Ðooo
9.
øcg
JCLox
0.6
0.2
-o.2
-0.6
-1
The final aspect covered for Laminaria involves
a comparison of two alternative classification
schemes: by depositional environment and by rock
Fig. 13 indicates the depositional grouping into nine
Porosity0.13 0.15
1000 !oJo¡
1oo g
fCL
10v
1
. Proximal Estuarine 1.1 I Fluvial and Proximal Estuarine 1'2
Fig. 10. Laminaria field: example of fluvial and proximal estuarine channel.
Bars ^
Deltaic
Comparison withBuffalo Field: - 'FC - Fluvial Channels,DC - Distr¡butarY ChannelsPDC - Proximal
D¡str¡butarY Channels
l\ll e haitnels
i\@ Channels(without esturine)
E Estur¡ne,1
*'Í'T
a.)'{a
c.JÊB
4
n)a(:-r- "4g
31
7
51
/g)
--4,.^ l al1JJ
Outlier
3750 it¡:G)5r
Outliers
//
Outliers:at
52,
o34
r26
8331.30
¿ ol5
Proximal Esturine (3-271(interval outliers 4, 7, 141
o25
r35
Fluvial (30-51)(interval outlier 36)
186 p Behrenbruch, S. Biniwale / Journal of Petroletm Scíence and Engineering 47 (2005) ]75 196
-1 -0.95 -0.9 -0.85
-0.8s -0.8
o fluvial to st¡eam mouth bar channel 4.3
: fluvial sheet flow 4.5
o fluvial & proximal estuarine 1.2o fluvial channel 4.6 + 4'7
PorositY GrouP
-0.8 -0.75 -0.7
Porosity GrouP-0.75
-0.65 -0.6 -0.55 -0.50.15
0.1
0.05
-0.1
-0.15
where the output from such an analysis may be
used for detailed geological modelling and reservoir
simulation, and average parameters (porosity, per-
-o.7 -0.65 -0.6
¡ tluvial channel 4.4, proximal estuârine 1.1+fluvial proximal estuarine 1'2
e fluvial channel 4.2
Ðooo
9.
ocP.
fCLox
0
-0.05
. Pfoximal Estuarine 1,1 + Fluvial & Proximal Estuaf¡ne 1'2 r Fluvlal & Proximal Estuarine 1'2
- - proximal Estuarine 1.1 + Fluvial & Proximal Estuarine 1.2 -
Fluvial & Proximal Estuarine 1'2
Fig. ll. Laminaria field: example of hydraulic zonation, fluvial and proximal estuarine channel'
fications amount to the same, if every lithotype is
analysed separately, i.e. before any grouping'
Indeed, this is the best scheme for detailed analysis
-0.9 0.6
0.5 ¡o0.4 g
0.3 õ.
0.2 ?g.
0.1 .ã
0d.ox
-0.1
-o.2
t¡a
These may be combined R2 = o.sz
-¡tl
R2 = 0.68
R'?= 0.60
rÈl
a
I ¡¡o ¡
aoo
ox
'L
!
I
R2 = 0.60o
tt -vú6
ta
l
^-O .
ooÉAfter merging R2 = 0'62 ood
6O ÔÞ
!-- Oo
IR2 = 0.58
af 'R2 = O]2a
These maY be combined
';ì'?= 0.37
After merging R2 =\0'68
Fig. 12. Laminaria field: atl fluvial depositions, merging of hydraulic units'
Plugnumber
Depth(m) Porosity Permeability(md)
Geologicalfacies
Geologicalunit
PorosityGroup, X
Res
lndex, YLog X Log Y
I23
45
67
3204.353204.603204.903205.203205.s'7
3205;78??oÁ oR
0.1430.1820.1320.146o.r'740.165o.089
602.00274.46
5.702t6.12
20.0028.8127.OO
proximalestuarineestuarineestuar1ne
estuanne
estuarineestrarine
1.1
l.ll.l
0.167o.2220.1520. 171
o.2ll0. t98o og8
2.037t.2t90.2061.208
0.337
0.415o 505
-o.778-0.653-0.818
-0.767
-0.676
-0.704-r.olo
0.3090.086
-0.685
0.082-0.473
-0.382
-o).s1
8
9
t0t1
t2l3t415
T6
t718
t9202T
2223
2425
2627
28
29
3206.423206.783206.953201.323207.603207.903208.213208.49
3208.803209.1O
3209.363209.703209.903210.25321O.60
3210.9032lt.I532lL.60321 t .85
3212.lo3212.653212.95
0.1980.2030. t940.t970.1 89
0.1900.201
0.1970.1950.1980.191
0.1840.1850.1 86
0.1840.1820.1850.1460.1670.18 1
0.1680.175
137. l92l I .00
|4.21167.00
13s.48
r99.00'1o.74
83.00t20.t5t72.OO
t32.92147.00
t47.48r02.00t36.34138.00
1s6.94
43.0097.35
232.00234.59352.00
fluvial and proximalestuarineestuarineestuarlne
estuanneestuarineestua¡ineestuanneestuarineestuarlneestuanneestuarineestuarineestuarlneestuarineestuarlneestuanneestuarineestuailneestuarineestuarineestuanne
t.2t.2t.21,2
t.2t.21.2
t.2t.2t.2t.21,2
r.2t.2t.2t.21.2
t.2t.2t.21.2
t.2
0.247o.255o.z4l0.245o.233o.235o.2520.245o.2420.2470.236o.2250.227o.228o.2250.222o.2270. 171
0.200o.221
o.202o.212
0.827t.012o.7620.9140.841
l.0160,5890.645
0.779o.9250.828
0.888
0.887
0.7360.8560.86s0.915
0.5390.758
t.124r.t731.408
-0.608-0.594-0.619-0.610-0.633-0.630-0.599-0.6 t0-0.616
-0.608-o.621
-0.647
-0.644
-o.642-0.648-0.653
-0.644-0.16'l-0.698-0.6s6-0.695-0.673
-0.083
0.005-0.1 l8-0.039-0.07s
0.007-0.230-0, 191
-0.108-0.034-0.082-0.o52-0.052-0.133
-0.068-0.063-0.039
-o.269-0. 120
0.051
0.0690.149
p. Behrenbruch, S. Biniwale/Journal ofPetroleum Science and Engineerins 47 (2005) 175-196
Table 3
Laminaria field: example of core measurements and zonation calculations
r87
meability, initial saturation, etc.) are determined for
each lithofacies. These ideas are further developed
for the next field example.
A more detailed analysis may be presented for one
of the wells, Corallina East-l, and Fig. 16 shows the
HUs for this well. Six of these HUs have been reverse-
modelled, as shown in Fig. 17, supporting the concepts
explained above. Fig. l8 shows the same HUs and
individual lithofacies in a bar chart. For the purpose ofgeological modelling and simulation, similar lithofa-
cies have only been combined if they are adjacent in
sequence. Fig. 19 summarises the alternative for
comparison, classification by rock fype, from Barr et
al. (2001). To gain more insight into this comparison'
hows a direct comparison, the original
classification with that of the depositional
on, as well as the rock type classification' As
evident, the overall sequence may be defined with
different schemes, but overall there is agreement.
5. 3. Corallina field analYsis
The Corallina field geology is overall similar to
that of the Laminaria field and the two fields are part
of the same offshore development. For further details
of the geology see Barr et al. (2001). Fig. 2 shows
again the location of the field, and surnmarises
the available data. Overall, HU results are
summarised in Fig. 15, for the two wells cored for this
field, and correlation is excellent. A considerable
number of distinct HU trends aÍe again exhibited the
result of varied depositional environments.
II
2.1 - 2.2
Distal Delta Front 5,6.1
Proximal Delta
Distributary Channels 2.6
Distributarychannels 2.6 Distributary
Channels2.7,2.4
OislributaryChannels
2,2.11,2.12Distributary
Channel2.11
FluvialChannel
13
TidalBar 9
CrevasseSplays
7.1,7.2,7.3Proximal Delta
Front 4.2
Mouth Bar /Distal
DistributaryChannel I
DistalDeltaFront
6.4
Front 4.1, 3
Distributary Channels
188
5.4. Bulfalo and GrilJin Jiekls
A third example is for the Buffalo field, also
located in the Bonaparte basin. The geological setting
for the Buffalo field involves the upper Elang
formation and the lower Plover formation, the latter
40
being reduced to about half its thickness when
compared to the Laminaria flteld, down to 80m' Fig'
2 shows the location for this field.
The Plover formation was deposited during the
early extension or onset of the NE-SW trending
rifting phase, as mentioned above. The Elang for-
p Behrenbruch, S. Biniwale / Journal of'Petroleum Science and Engineeríng 47 (2005) 175 196
HU-Q4HU-05HU-Q9HU-Q2HU-Q6HU.Q8HU.03HU-Q1HU-Q7Poorest Qual¡ty -'-'-'-'->
Fig. 13. Lantinaria fietd: Laminaria-4, hydraulic zouation by depositional envirotrment and quality'
35
30
25 'nol¡206fo
15 -<
10
5
0
High QualitYHUl
Low QualityHU8HU2 HU3 HU4 HU5 HU6 HU7
100%
8O7"
600/o
4Oo/"
20%
oC0)
=EElJ.
Sm: fine / coarse ss
Sgran: granule-rich, variable ss
Hi-laminated: sandy upp / low fine ss
Gms: graded matr¡x-supported conglomeratessfine grained Sb
Fig. 14. Laminaria tield: Laminaria-4, hydraulic zonation by sandstone type and quality.
Barrier Bar or Prox Strm Mouth Bar 2
.Transverse Bar 3.1 & Esturine Channel 4¡ Prox Mouth Bar 5'1 & Dist Strm Mouth Bar 6'1
- Transverse Bar 3.2r Prox Strm Mouth Bar 6.2
D¡st Strm Moulh Bar 6.3 & DSS 7.1
^Prox Strm Mouth Bar 6.4
Delta Slope of Lower Shoreface IDist Channel 8.1 & Strm Mouth Bars 5.2,6.5lnterdistributary BaY 12
. Dist Chânnel & Proximal Delta FrontÀ D¡st Delta Front 3.2+3'3
l1-2.5&5.2,3&8É D¡st Channel 2.6
I ail 1-4
o
II
L
I
t
f
a
t
tI
/¿ /-'
-a
al
) a |J
p. Behrenbruch, S. Biniwale / Journal of Petroletm Scíence and Engineering 47 (2005) 175-196 189
PorositY GrouP
-0.9 -0.8 -o.7 -0.6 -0.5 -0.4-1.2 -1.1 1
-1.4 -1.3 -1.2 -1.1
Fig. 15. corallina field: corallina-l and corallina East-1, hydraulic zonation'
0.4
depositional environment is varied, extending from
fluvial to marginal marine and distal delta sediments'
In this case, the Frigate marine shales form the seal' In
terms of petrology, framework grains are dominated
by q,nrtz (over 90%), with minor lithic fragments and
accessory minerals. Sandstones are very fine to course
0.6
o.2
0
-o.2
-0.4
-0.6
¡ooo9.
otrP.
JCLox
mation is the hydrocarbon bearing formation, as it isfor most of the neighbouring helds in the region:
Laminaria, Corallina, Elang, Kakatua and Bayu-
Undan. The Elang formation occurs at the initial
onset of marine waters entering the basin, inundating
the Plover delta system. As stated above, the
Porosity GrouP
-1 -0.9 -0.8 -o.7 -0.6 -0.5 -0.4
0.6
0.4
0.2
0
-0.2
-0.4
-0.6
-0.8
Toano
9.
ocg
=clox
Fig l6 coratlina fietd corallina East-1, hydraulic zonation by depositional environment
5
Distributary Channel 2.6
Proximal Delta Front 5.2Distributary Channel 2.5, Delta Front 5.3 &
Proximal Delta Front IDistributary Channel 2.4 & Proxirnal Delta Front 5'1
Distal, D¡str¡tlutary Channel Delta Front all 1-4 .
1
2
¡
6
4
5Distal Delta Front 3.2
Distal Delta Front 3.3
3
1
5
4
4
5
-b
L Ó.4
3
190 p. Belyerbruclt, S. Biniwale / Jotrnal of Petroleun Science ancl EttgineerinT 47 (2005) 175-196
PorositY (%)
10.0 15.0
OeltaFront
s O¡sttlOelta Front
20.0 25.00.0 5.0
1 00000
1 0000
1 000
100
10
1
0.1
0.01
0.001
!o3oÐg
3CL
grained, with the majority being fine to medium
grained. Grains are sub to well rounded and with
moderate sorting. The detrital matrix is relatively low,
less than l0%, being more abundant in the poorer
quality sandstone, with only trace amounts in the
better quality sandstone. Authigenic qrtatlz is again
the dominant cement, present as quartz overgrowth'
Variable amounts of pyrite cement are also found'
Permeability and porosity are similar to that observed
Fig. 17. Corallina hetd: Corallina East-1, reverse modelling'
Channels, Oelta Front
2.3Channels& AÞandon
s 3 Proximal
z { DistributarYClrannels
Moolh 8ar,D¡stal oF
for Laminaria and Corllina. For other core-related
analyses see also Behrenbruch (2000).
Fig.2l gives the HU classification for Buffalo-2'
As is evident, the analysis has resulted in six HUs,
with the better quality environments being represen-
tative of channels. The envelope for these channels
has been superimposed on Fig' 9, for cotnparison with
Laminaria, demonstrating good agreement' Such
integration among other fields is currently in progress'
Channcls, BarsDlstal Dalta FrontDlstributary
ChannelsProxlmal
60% 11
ror. õ.ct
ro"r" f;.or. f,
3,2
100./.
90"/o
80"/"
70%
200h
10"/o
o%
2.2 Oistr¡butaryChannolDelter
Front 5l
ta
D¡stalOcltâ Front
Orstrlbut¡ryChannel
2.1
11 Estu í rinoChannels
HU:7g5214qualityi Q1(best) Q2 q3 a4 Qs 06
Fig. lg. Corallina field: Corallina East-1, hydraulic zonation by depositional enviroument.
6
Q7(poorest)
3.3
3.'l
DeltaFront
DoltîFront
z ø Dlstr¡butarychannols
5.2
p. Beltrenbruch, S. Biníwale / Journal o['Petroleum Science ancl Engineerirrg 47 (2005) 175 ]96
Hydraulic UnitHUz HU4 HUs HU7 HU8
t9l
HUIBest Qua
HU3lncreas
HU6
-Þ PoorlY Sorted ) Bioturbated
oo=Eo¡-tr
D
Coarse --) Medlum 4 Flne ---_*
very Flne
Sand Sorting: wetl Sorted
fl sttfne/uppmedss
Sgran: granule+ich, variable ss
5,061.062.O4
Srn: fine / coanie ss
Sb: bioturbated uPP / low fine ss
Fig. 19. Corallina field: coLallina Eastl, hydraulic zonation by sandstorre quality
Layel-T,hic"þesE-(rn) Facies
1:E84.062.82
! sit veryfine/line ss
[-'l xi-taminated: sandy upp / low fine ss
De¡:tlt (tn)
339ê
100
90
80
70
Ê60,t.tl
Ë50.t(,Eß
30
n
l0
Distal Estuarine Channel ID¡strtbutary Cha nnel 2, I
Dlstal Oclla Front 3.1Oistributary Cha nnel 2.2
Mouth Bar , Oistal Delta Front 4Drsrflbulârv Channel & Abândonment 2.3óiiiri¡utaú chiìnnel & Ab¿ìndonmont 2 3'2
Proxrmal Delta Front 5 I
Orstnbutary Channels 2 4
Proxrmal Oclta Front 5 2
Dislal Oelta Front 3.2Prodclt¿ì 6 & Tldal Channol 7
Distnbutiìry channels 2,5Proxrmal Dolta Front 5 3
Distîl Ocltî Front I
oastal Oella Front 3 3
Distr¡butary Channels 2 6
:J176 2
3388'l
?,,t28 f
344fi 7
3.151 5
7j5
Facie GrouPs (Rock tYPe)
I
u
I
n
I
'r
21.78
'to.75
3.294.652.311.753.335.83
10.06
10.90
0Hydraulic Units Group Geological Facies
H
HU1
F
EHU2
HU5
U
AHU7
Fig. 20. corallina field: coraltina Easrt, hyd|aulic zotratiou and lithofacies.
Comparason w¡thLaminaria Field:FC - Fluvlal Channels,DC - DistributarY ChannelsPDC - Proximal
DlstributarY Channels
rt
It¡
91
0.62
0.57
I
E
=053
It R2 = 0,74
t92 P. Behrenbrtrch, S. Biniwale / Jottrnal of Petroleum Science and Engineering a7 Q005) 175-196
-1.4Porosity GrouP
-1.2 -1 {t.8 4.6-1.6
5.5. Grffin area Jields-Cqrnarvon basin
From a commercial standpoint, the Camarvon basin
is currently Australia's most important basin, in terms
for the Bonaparte basin, the Birdrong formation being
of relatively poor quality and very diverse petrology'
The location of the fìelds is shown in Fig. l 'The so called Grifhn area fields consist of the
commercial Griffin and Scindian-Chinook fields, and
lie along a northeast-southwest Triassic high trend
known as the Alpha arch' Hydrocarbons have been
trapped in Early Cretaceous sediments of the Mardie
Grèènsand member, named so after an abundance ofsiderite in the upper-most zone, the Birdrong formation
and the Zeepard formation sequences. The Birdrong
formation sequence appears to have been deposited in a
shallow marine shelf environment, with a slow
sedimentation rate and low clastic influx, but covering
a relatively large area' Petrophysical logs and core
exhibit the interval to be a series of thin, alternating
{t.4
7ooo?9,aÐcÐ
=CLox
0
4.8
-1.2
-1.6
I EiÐOF5 ¡ Èoxrml Osributary Chãmds 2'4 ¡ ALL 3 PCF
- Low Sinuos¡ty Flwial channels I ' Ûe'/ass€ SPlays 6 Â ALL æ,f IBS 4
- - - Linear(oEt+ocF5t
-Lnear(ftoxiÍEl
ost.ibt¡trychannels 241
-lJîeaf
(ALL 3PCF)
- -. - Linear (Lo/ Shuosrty Flwial Chanriels 8)
-
LiæÜ (qevasse Splays 6f - - Linear (ALL æ+ IBS 4)
Fig. 21. Buffato held: Buffalo-2, hydraulic zonation'
being characterised by abundant bioturbation' The
sandstones are predominantly very fine to hne-grained
sands, and are poorly sorted with a common to
abundant detrital clay matrix and carbonate cemented'
Accessory minerals include variable amounts ofglauconite, pyrite, coal/carbonaceous fragments and
iare chert. Reservoir quality of the Birdrong formation
is thus relatively poor and highly variable' The
formation has been cored in several wells and core
permeability varies from 2 to 300 md, core porosity
from 8% to l0o/o, with a high shale fraction of up to
50%. The Zeepard formation underlies the Birdrong
formation and forms the primary reservoir. In contrast
to the latter, the Zeepatd formation is a high quality
formation, having good porosity and permeability,
consisting of massive, clean sands with aminimal shale
fraction, ranging from 0.05 to 0.15, and minor volumes
of potassium feldspar and pyrite. Occasional carbona-
ceous streaks have also been detected. Porosity is in the
range of 0.ll-.0.24 exceed a
darcy. The HU maPP ation is in
many tù/ays similar ¡ Corallina
and is not presented here. Overlying the Birdrong
formation is the actual Mardie Greensand, which tends
to be a non-net interval over most of the region and
forms the seal, together with the thick Muderong shale'
p. BehrenbrLtch, S. Biniwale / Journal of Petrolerm Science and Engineering 47 (2005) 175 196
150 2000
193
Mafdle Gfeensand
ZeepaardFormatlon
6. Discussion of results
2625
Depth (mD)
Fig.22. Griffin field: Griffin-2, Birdrong sub-units'
GeologicalZonat¡on
MuderoRg Shale
PctrologryLegend:
1:1.r (M)
2: 1.2 (D,M)
3: 2.r (A)
4i2.2lÀl
5: 2.3 (F2,4)
6: 3.2 (R,K)
7: 3.3 (K)
8: 3.5 (K)
B1
82
B3
84
22 shows both, the geological zonation for the
Gr -2 well, Birdrong formation, and the more
possible but the quality of relationships has deterio-
iated due to greater data scatter, directly attributable to
the greater heterogeneity over a relatively small
interval.
A model for a general HU based classification
scheme has been outlined, for the purpose ofidentifliing the varied characteristics of (Australian)
formations and associated rock types, as demon-
strated by several field examples.
White considerable work remains to establish a
more universal system, results to date are encour-
aging. It is envisaged that the final classification
scheme would be for specific depositional environ-
ments, for example distributary channels, by basin
and Australia-wide. Individual depositional enve-
lopes would be described in terms of envelope
boundaries and statistical distributions, covering the
entire depth range. The HU composition inside each
exhibit distributions with greater variance (equal to
rock variability), hence uncefiainty for prediction
purposes.To accomplish the planned task, many other fields
have been examined or are under study, including
onshore fields. Apart from further defining the above-
mentioned scheme, related aspects, for example the
influence of rock compressibility in defining HUs, is
also being investigated, see Biniwale and Behren-
bruch (2004).
7. Conclusions
A generalised methodology for analysing flow
zone units has been presented, validated for Australian
data. However, the proposed model may be used to
systematically classiff clastic formations, for a field, a
basin, and is universally applicable:
(1) Hydraulic Units, as defined by the logarithmic
form of the Carman-Kozeny equation, present a
convenient way to characterise the variabiliry ofrocks.
ot!Eol¡.ElÉo!t6
PetrologYZonation
1
t94 p. Behrenbrtrch, S. Biniwale / Journal of Petroleum Science and Engineering 47 (2005) 175-196
PorositY GrouP
.150.110.130.120.1.10.t¡0{1.90{l¡0{t.70.1¡.60 {t.50
03
o.r dtr,o{r?9.nrõÊ{59
4'7 =CIox
-1l
-t¡02- Ortffln-2, I .1- Llthofacle3 Oroup, M' Ll$ofacles
c2.r.r(Ð xG2-2.llAl ¡G2-2.2(A) oG2-23lF2Al -G2{2(R,K!':Gl't2(D,Mf ¡G2'!3lK) oO2{slKl
Fig.23. Griffin held: Griffin-2, hydraulic zonation of Birdrong formation.
(2) The concept of a characteristic "depositional
envelope" has been defined, a classification
system which allows the unique definition ofspecific geologic depositional environments'
Pore structure properties, as a function of detailed
depositional conditions and diagenesis, are then
defined within limits inside each envelope.
(3) The envelope methodology may be used in
"reverse modelling", where porosity, permeabil-
ity and related properties may be predicted for
an assumed depositional environment and
related geological conditions, for example for-
mation dePth or the amount of claY.
Acknowledgements
We wish to gratefully acknowledge the support ofour sponsors: BHP Billiton, ChevronTexaco, Santos
and Woodside Energy, for their financial support, the
field data and their permission to publish the analysis
results presented. The authors would also like to thank
Vanessa-Ngoc Pham for her assistance in preparing
the manuscriPt.
(r)
Dividing both sides of the above equation by the
effective porosity and taking roots: Ë:permeabiliry
¡tmz; þ.:effective porosity, fractional bulk volume;
F" : shape factor (2 for a circular cylinder); t : tortuos-
tortuosity; .Sru :surface area per unit grain volume,
pm-I.
o: (,+Í("ä)
.FL: ó' I :' I! ó" - (l - d") \.'/4'sr' /
Appendix A
(2)
Converting permeability, Æ, from micrometer
squared to millidarcies:
)
Flne gralncd ol clny m¡lrùOpcn grtln F¡m.worllVêry llnâÍnG gr.in?d, lemlnàl.dF¡nrfied¡um Ír¡inodM.dium gr¡¡ncdtled¡um{o¡r* gralned
Flncfladlum gr¡ln6dSllllon., v.rY llnG{lnt gralnÊd
sidGritc noduloc concrotion¡
f 1.21O,
2.2(At-_,.¡.àixi
Lithofacies Groug1 Pootly rorted, a
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^lr
I
aI
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ea3'st I
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rl
a
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af
conl¡ln3 coâfÊa gralns, ¡,1
gr¡nuhr ot Pcbblat E
2 wGll $dâd, A
cloân 3ânds BF2c
3 Slllyto mrdlum oð¡nod, K
vrry thlnly lâm¡nâtcd R
or burowQd S
Lithofaciê3
-o
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X -¿
0.0314k(md) ó. ( t:-
ó. - (l - 4"¡ lufitSev(3)
p Behrenbrttch, S. Biniwale / Jortrnal of Petroletrm Science and Engíneering a7 Q005) 175-196 l9s
Defining now the following, as in Barr and
Altunbay (1992):
RQI (pm):Reservoir Quality Index:0'0314f¡oa
v --r"þ,:Porosiry Group (pore volume to grain volume
;?îÌJ--,ì ow zoîerndicator: (*r)and substituting these definitions into Eq. (3), .and
taking logarithms:
logRQI : lo16, * logFZI (4)
The reservoir quality index, RQI, and porosity
group, @,, include only readily available parameters
suctras permeability and porosity. FZI, on the other
hand, includes pore throat shape factor, tortuosity and
surface area per grain volume, parameters which are
not usually available. The logarithmic form of the C-
K formulation given in Eq. (4) forms the basis for
establishing HUs for individual facies. While the use
of the hydraulic radius as a correlation parameter is
somewhat analogous to the Leverett J-function
approach in correlating capiltary pressure relation-
ships, the C-K formulation has the advantage ofinctuding surface area, as an additional parameter'
64285, Presented at the Asia Pacific Oil and Gas Conf' Exhib',
Brisbane, Australia'
Barr, D.C., Altunbay, M., 1992. Identifring hydraulic units as an aid
to quantiffing depositional envirotrmettts and diagenetic facies'
Geology of Malaysia, Symp' Res. Eval./Form' Damage, Kuala
Lumpuç MalaYsia.
Barr, D.C., Kennaird,4.F., Fowles, J', Marshall, N.G', Cutten, V'L',
2001. Determining reservoir continuity in the Laminaria
formation by integrated geological study. APPEA J'' 415-428'
Behrenbruch, P., 2000. Waterflood residual oil saturation-the
Buffalo field, Timor Sea. SPE 64282, Presented at the Asia
Pacific Oil and Gas Conf. Exhib., Brisbane, Australia'
Biniwale, S., Behrenbruch,P',2004. The mapping of hydraulic flow
zone units and characterisation of Australian geological
depositional environments. SPE 88521, Presented at the Asia
Pacific Oit and Gas Conf. Exhib., Pefth, Australia'
Bradshaw, M.T., Yeates, A.N', Beynon, R.M', Brakel, A'T',
Langford, R.P., Totterdell, J'M., Yeung, M., 1988' Palaeography
evolution of the Northwest Shetf region. In: Purcell, P'G,
Purcell, R.R. (Eds.), The Sedimentary Basins of Western
Australia. Proc. WA Basin Symposium, Per1h, pp' 29 54'
Buryakovskiy, L.4., Djevanshir, R.D., Chilingarian, G'V'' l99l'Mathematical simulation of sediment compaction' J' Pet' Sci'
Eng. 5, 151 l6l.Carman, P.C., 1938. Fluid flow through granular beds' J' Soc'
Chem. Ind.57,225.Chilingarian, G.V., Chang, J., Bagrintseva, K.I , 1990' Empirical
expression of permeability in terms of porosity, specific sutface
area, and residual water saturation of carbonate rocks' J' Pet'
Sci. Eng. 5,317-322.Civan, F., 2003. Leaþ-tube permeability model for identification,
characterisation and calibration of reservoir flow units' SPE
84603, Presented at the Annu. Tech. Conf' Exhib', Denver,
Colo.Dias, 4., Jing, X.D., 1996. Permeability estimation from porosity
and pore size distribution: comparative case studies from fwo
North Sea fields. Advances in Petrophysics: 5 Years of Dialog,
pp. 84-87.Ebanks, V/.J., 1987. Geology in enhanced oil recovery' In: Tillman,
R.W., Weber, K.J. (Eds'), Reservoir Sedimentology, SEPM
Spec. Pub., vol.40, PP. 1-40'Jenkins, C.C., Maughan, D.M., Acton, J.H', Duckett, A', Kom'
8.E., Teakle, R.P., 2003. The Jansz gas field, Camawon basitr,
Australia. APPEA 1.,303 324.
Kom, 8.E., Teakle, R.P., Maughan, D'M., SifÏleet, P'B'' 2003' The
Geryon, Oftheus, Maenad and Urania gas frelds, Camanvon
basin, Westem Australia. APPEA J., 285-301'
Kozeny, J., 1927 . Sitzungsber. Akad. Wiss. Wien, Math'-Naturwiss'
KL136,271.Mclntyre, C.L., Stickland, P.J., 1998. Sequence stratigraphy and
hydrocarbon prospectivity of the Campanian to Eocene
succession, Northem Bonaparte basin, Australia' APPEA J"
313,337.Nagtegaal, P.J.C., 1980. Clastic reservoir rocks-origin, diagenesis,
and quality. Presented at the Intemational Meeting of Pet' Geol',
Beijing, China.
References
Abbaszadeh, M., Fujii, H., Fujimoto, F., 1996' Permeability
prediction by hydraulic flow units-theory and applications'
SPE Form. Eval., 263 -27 l.Attunbay, M., Ban, D.C., Kennaird, 4.F., Manning, D'K', 1994'
Numerical geology: predicting depositional and diagenetic facies
from wireline logs using core data. SPE 28794, Presented at the
Asia Pacifrc Oil and Gas Conf. Exhib., Melbourne, Australia'
Amaefule, J.O., Kersey, D.G., Marschall, D'M', Powell, J'D',
Valencia, L.E., Keelan, D.K., 1988. Reservoir description: a
practical synergistic engineering and geological approach based
on analysis ofcore data. SPE 18167, Presented at the Annu'
Tech. Conf. Exhib', Houston, Tex.
Amaefule, J.O., Altunbay, M., Tiab, D., Kersey, D'G', Keelan, D K',
I 993. Enhanced reservoir description: using core and log data to
identifu hydraulic (flow) units and predict permeability in
uncored intervals/wells. SPE 26436, Presented at the Annu'
Tech. Conf. Exhib., Houston, Tex.
Barr, D., 2000. Reservoir description of the mid to late Jurassic
Laminaria formation: Laminaria./Corallina area, Timor Sea' SPE
t96 p Behrenbruch, S. Biniwale / Journal ofPetroleum Science and Engineerins 47 (2005) 175-196
Ohen, H.4., Ajufo, 4., Manni, F, 1995. A hydraulic (flow) unit
based model for the determination of petrophysical properties
from NMR relaxation measurements. SPE 30626' Presented at
the Annu. Tech. Conf. Exhib., Dallas, Tex'
Perez, H.H., Datta-Gupta, A., Mishra, S., 2003' The role of
electrofacies, lithofacies, and hydraulic flow units in perme-
ability predictions from well logs: a comparative analysis using
classiftcation trees. SPE 84301, Presented at the Annu' Tech'
Conf. Exib., Denver, Colo.
Porras, J.C., Barbato, R', Khazen, L., 1999. Reservoir flow units: a
comparison between three different models in the Santa Barbara
and Pirital fields, North Monagas area, Eastem Venezuela basin'
SPE 53671, Presented at Latin America Caribbean Pet' Eng'
Conf., Caracas, Venezuela.
Prasad, M., 2002. Velocity-permeability relations within hydraulic
units. Annu. International Meeting of Soc. Expl' Geop',
Stanford, Catif., PP. 108 117.
Shang, 8.2., Hamman, J'G., Chen, H.L., Caldwetl, D'H" 2003' A
-od"l to correlate permeability with efficient porosity and
ineducible water. SPE 84303, Presented at the Annu' Tech'
Conf. Exhib., Denver, Colorado.
Svirsky, D., Ryazano¿ 4., Pankov' M., EB Y', Corbelt, P''
Posysoev, A, 2004. Hydraulic flow units rcsolve reservoir
description challenges in a Siberian oil field' SPE 87056,
Presented at the SPE Asia Pacific Conf' On Inte' Mod' For Asset
Manag., Kuala LumPur, MalaYsta.
HJ,draulic Flott,Zone IJnít ChuructerisuÍiott untl rlluppittg.l'or Áustrulfun Gcologicul Depos it íonnl E tt viro tt u cnls
CHAPTER 5
THEMAPPINGOFHYDRAULICFLO\ilZONEUNITSANDCHARACTERISATION OF AUSTRALIAN GEOLOGICAL DEPOSITIONAL
ENVIRONMENTS
Biniwale, S. and Behrenbruch, P.
Australian School of Petroleum,
The University of Adelaide, Adelaide, SA' 5005 Australia'
Society of Petroleum Engineers 2004; SPE: 88521
fl¡'lrnu,rrt Iìlt¡¡v Zt¡ttc Llttìt Clttructcrisulitttt att¿ 14(PPing.fbr ''lustruliurt Geologiutl Dcposil io ttu I EL r¡ n ) tt,t, ttt, I s
STATEMENT OF AUTHORSHIP
THE MAPPING OF HYDRAULIC FLOW ZONE UNITS AND
CHARACTERISATION OF AUSTRALIAN GEOLOGICAL DEPOSITIONAL
ENVIRONMENTS
Socíety of Petroleum Engíneers 2004; SPE: 88521
Biniwale, S. (Candidate)
Performed analysis on all , interpreted data and wrote manuscript.
Signed Date
Behrenbruch' P.
Supervised of work, helped in data interpretation and manuscript evaluation'
Signed Date
Biniwale, S., & Behrenbruch, P. (2004, October). The Mapping of Hydraulic
Flow Zone Units and Characterisation of Australian Geological Depositional
Environments. Paper presented at the SPE Asia Pacific Oil and Gas
Conference and Exhibition, Perth, Australia.
NOTE:
This publication is included in the print copy
of the thesis held in the University of Adelaide Library.
It is also available online to authorised users at:
https://doi.org/10.2118/88521-MS
fl¡tr¡¡nu¡¡, FIttn Z¿ne [.Jnit Churucterisolìott unl Ùln¡spirtg,for zlttslrulitttt Gaologicul DeposìÍío nu I E tt vi rott ut cttls
CHAPTER 6
AN IMPROVED APPROACH FOR MODELING GEOLOGICALDEPOSITIONAL CHARACTERISTICS AND FLUID SATURATION BY USING
HYDRAULICUNITS:AUSTRALIANOFFSHOREFIELDS
Biniwale, S. and Behrenbruch, P.
Australian School of Petroleum,
The University of Adelaide, Adelaide, SA. 5005 Australia'
society of Petrophysicists and well Log Analysts; 2005: submitted manuscript
p¡,lrnulic Floty Zole Llnit ChuructerisuÍi¿tt and i4uppirtg,fitr Austrulitrtt Geologicul Depositittnul Ettvìrontttettts
STATEMENT OF AUTHORSHIP
AN IMPROVED APPROACH FOR MODELING GEOLOGICALDEPOSITIONAL CHARACTERISTICS AND FLUID SATURATION BY USING
HYDRAULIC UNITS: AUSTRALIAN OFFSHORE FIELDS
Socíety of Petrophysicrsls and Well Log Analysts; 2005: submìtted manuscr¡pt
Biniwale, S. (Candidate)
performed analysis on all the samples, interpreted data and wrote manuscript
Sígned
Behrenbruch' P.
Supervised of work, helped in data interpretation and manuscript evaluation.
Signed ...Date..
Biniwale, S., & Behrenbruch, P. (2005, June). An improved approach for
modeling geological depositional characteristics and fluid saturation by
using hydraulic units: Australian offshore fields. Paper presented at the
SPWLA 46th Annual Logging Symposium, New Orleans, Louisiana.
NOTE:
This publication is included in the print copy
of the thesis held in the University of Adelaide Library.
HJ,lruttlic Flott,Zutte IJttil Churactcrisutiott uttd tlluppittg for AusÍruliutt Geologicul Deposilíonul Ettvirott nt ents
CHAPTER 7
AN INTEGRATED METHOD FOR MODELING FLUID SATURATION
PROFILES AND CHARACTERISING GEOLOGICAL ENVIRONMENTS USING
A MODIFIED FZI APPROACH: AUSTRALIAN FIELDS CASE STUDY
Biniwale, S. and Beluenbruch, P.
Australian School of Petroleum,
The University of Adelaide, Adelaide' SA. 5005 Australia
Society of Petroleum Engineers 2005; SPE International Student Paper Contest
Il¡,r¡ruu,,, Itlpu,Zone Llnit Churucl¿risuliott uttl iVlupping litr ¡lusÍrulitttt Geologicul Depositio ttul Ett vi ro n tn enls
STATEMENT OF AUTHORSHIP
AN INTEGRATED METHOD FOR MODELING FLUID SATURATION
PROFILES AND CHARACTERISING GEOLOGICAL ENVIRONMENTS USING
A MODIFIED FZI APPROACH: AUSTRALIAN FIELDS CASE STUDY
Society of petroleum Engineers 2005; SPE Internatíonal Student Papet Contest
Biniwale, S. (Candidate)
Performed analysis on all samples, interpreted data and wrote manuscript'
Signed
Biniwale, S. (2005, October). An integrated method for modeling fluid
saturation profiles and characterising geological environments using a
modified FZI approach: Australian fields case study. Paper presented as part
of the student paper contest associated with the Annual Technical Conference
and Exhibition, Dallas, Texas.
NOTE:
This publication is included in the print copy
of the thesis held in the University of Adelaide Library.
It is also available online to authorised users at:
https://doi.org/10.2118/99285-STU