Understanding Petroleum Reservoirs: Towards an Integrated Reservoir Engineering and Geochemical Approach (Geological Society Special Publication No. 237)

395 Pages·2004·2.51 MB·English

by  J. M. Cubitt

Understanding Petroleum Reservoirs:
Towards an Integrated Reservoir Engineering and Geochemical Approach
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CUBITT, J. M., ENGLAND, W. A. & LARTER, S. (eds) 2004. Understanding Petroleum Reser-
voirs: towards an Integrated Reservoir Engineering and Geochemical Approach. Geological
Society, London, Special Publications, 237.
MEULBROEK, P., CATHLES, L. & GODDARD, W. A. 2004. HCToolkit/EOSInterface: an open
source, multi-platform phase equilibria framework for exploring phase behaviour of com-
plex mixtures. In: CUBITT, J. M., ENGLAND, W. A. & LARTER, S. (eds) 2004. Understanding
Petroleum Reservoirs: towards an Integrated Reservoir Engineering and Geochemical
Approach. Geological Society, London, Special Publications, 237, 89-98.
GEOLOGICAL SOCIETY SPECIAL PUBLICATION NO. 237
Understanding Petroleum Reservoirs: towards an
Integrated Reservoir Engineering and
Geochemical Approach
EDITED BY
J. M. CUBITT
ES Information & Consultancy Ltd, Wrexham, UK
W. A. ENGLAND
BP, Sunbury-on-Thames, UK
and
S. R. LARTER
University of Calgary, Canada
2004
Published by
The Geological Society
London
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Contents
ENGLAND, W. A. & LARTER, S. Understanding petroleum reservoirs: towards an integrated 1
reservoir engineering and geochemical approach. Introduction
New approaches, analytical and geochemical developments
THOMPSON, K. F. M. Interpretation of charging phenomena based on reservoir fluid 7
(PVT) data
WILHELMS, A. & LARTER, S. Shaken but not always stirred. Impact of petroleum charge 27
mixing on reservoir geochemistry
PHILP, R. P., HSIEH, M. & TAHIRA, F. An overview of developments related to the 37
characterization and significance of high molecular weight paraffins/hydrocarbons
(>C ) in crude oils
40
HOLBA, A. G., WRIGHT, L., LEVINSON, R., HUIZINGA, B. & SCHEIHING, M. Effects and impact 53
of early-stage anaerobic biodegradation on Kuparuk River Field, Alaska
MEULBROEK, P. CATHLES, L. & GODDARD, W. A. HCToolkit/EOS interface: an open source, 89
multi-platform phase equilibria framework for exploring phase behaviour of complex
mixtures
Physical, chemical and numerical models
SMALLEY, C., ENGLAND, W. A., MUGGERIDGE, A., ABACIOGLU, Y. & CAWLEY, S. Rates of 99
reservoir fluid mixing: implications for interpretation of fluid data
STAINFORTH, J. G. New insights into reservoir filling and mixing processes 115
SKEIE, J. E., Di PRIMIO, R. & KARLSEN, D. A. An integrated basin modelling study applying 133
asphaltene kinetics from reservoired petroleum in the Snorre Area, northern North Sea
Di PRIMIO, R. & SKEIE, J. E. Development of a compositional kinetic model for hydrocarbon 157
generation and phase equilibria modelling: a case study from Snorre Field, Norwegian North
Sea
Case studies - Water and petroleum fluid compositional variations
LINES, M. D. & AULD, H. A. A petroleum charge model for the Judy and Joanne Fields, 175
Central North Sea: application to exploration and field development
WAVREK, D. A. & MOSCA, F. Compositional grading in the oil column: advances from a mass 207
balance and quantitative molecular analysis
MUELLER, E. & SCHOLZ, T. Application of geochemistry in the evaluation and development of 221
deep Rotliegend dry gas reservoirs, NW Germany
WEISSENBURGER, K. S. & BORBAS, T. Fluid properties, phase and compartmentalization: 231
Magnolia Field case study, Deepwater Gulf of Mexico, USA
TAYLOR, T., STANCLIFFE, R., MACAULAY, C. & HATHON, L. High temperature quartz 257
cementation and the timing of hydrocarbon accumulation in the Jurassic Norphlet sandstone,
offshore Gulf of Mexico, USA
DUTTON, S. P. & FLANDERS, W. A. Evidence of reservoir compartmentalization by calcite 279
cement layers in deepwater sandstones, Bell Canyon Formation, Delaware Basin, Texas
MCCARTNEY, R. A., WINEFIELD, P., WEBB, P. & KUHN, O. Spatial variations in the 283
composition of formation waters from the central North Sea: implications for fluid flow in
the deep high-pressure high-temperature hydrocarbon play
vi CONTENTS
KARLSEN, D. A., SKEIE, J. E., BACKER-OWE, K., BJORLYKKE, K., OLSTAD, R., BERGE, K., 305
CECCHI, M., VIK, E. & SCHAEFER, R. G. Petroleum migration, faults and overpressure.
Part II. Case history: The Haltenbanken Petroleum Province, offshore Norway
RUSHING, J. A., CHAOUCHE, A. & NEWSHAM, K. E. A mass balance approach for assessing 373
basin-centred gas prospects: integrating reservoir engineering, geochemistry and petrophysics
Index 391
Introduction
WILLIAM A. ENGLAND1 & STEVE LARTER2*
1BP Exploration, Chertsey Road, Sunbury-on-Thames, Middlesex TW16 7LN, UK
2NRG Petroleum Group, School of Civil Engineering and Geosciences,
University of Newcastle-upon-Tyne, UK
* Present address: Department of Geology and Geophysics, University of Calgary,
Calgary, Canada
Since the first Geological Society Special summarize these main areas, which provide the
Publication on reservoir geochemistry (Cubitt basic currency of development within the field
& England 1995), there has been a steady of reservoir geochemistry.
increase in the number of publications and
conferences on this topic. Reservoir geochemis-
try is now a routine tool of the petroleum New approaches, analytical and geochemical
industry with new companies now providing developments
dedicated reservoir geochemical services. With
95% of future world oil production likely to The development of analytical methods and
come from already discovered accumulations theoretical and practical methodologies for the
this steady increase in research and application determination and interpretation of fluid compo-
of reservoir geochemistry is welcome. Despite sitional variation in petroleum reservoirs has
this, there remain many challenges and great been one of the foundation stones of reservoir
areas of ignorance and missed opportunities. geochemistry and new developments continue
This volume therefore provides a summary of to appear.
the current status of reservoir geochemistry and Thompson presents a study of the molecular
the challenges that remain. distributions of petroleum fluids, as revealed by
Reservoir geochemistry studies the composi- standard PVT data. The method relies on the
tional variations of petroleum reservoir fluids observation that carbon number profiles may
(waters, oils and gases) at a variety of spatial be fitted by two exponential decline curves (C -
3
and temporal scales. These studies reveal infor- C and C !<>+). Using PVT data principally from
5
mation about petroleum basin development, western Canada, Thompson proposes that
details of reservoir filling and leaking, and changes to the C3-C5 and CIQ+ slopes can be
about petroleum mixing and alteration (Larter related to maturation and phase separation.
& Aplin 1995). This information is of interest The addition of allochthonous gas can also be
from both the academic and applied points of recognized. Given the ubiquity of PVT data,
view, and provides insights not available from these techniques will prove useful additions to
other methods. Reservoir geochemistry is con- the interpretive armoury.
cerned with the 3D compositional variations in Wilhelms & Larter review progress in under-
reservoir fluids that are commonly observed in standing the quantitative evolution of molecular
petroleum reservoirs as free fluids or as fluid marker compositions in reservoired petroleum.
inclusions in mineral cements. It strives to They suggest that all oils are mixtures, and that
understand the origin of these heterogeneities use of many of the high molecular weight bio-
and to apply them to enhance the understanding logical marker geochemical proxies is compro-
of the formation of petroleum accumulations mised by orders of magnitude concentration
and exploration, appraisal, development and variations of these components, within even
production strategies. Key components of the related oil charges or even within single reservoirs.
approach are (1) the analytical methods for They identify the less exotic non-biomarker
determination of fluid compositional hetero- molecules as best for assessing reservoir continuity
geneity, (2) the physical, chemical and numerical and charge mixing, and they suggest that the
models for interpreting the compositional differ- concept of maturity needs revising given this
ences in terms of basin history and reservoir complex scenario. They consider that the appar-
connectivity and (3) the case studies of applica- ent ubiquity of petroleum mixing, whilst a com-
tion. By way of introduction, we attempt to plication, may herald a new era of petroleum
From: CUBITT, J. M., ENGLAND, W. A. & LARTER, S. (eds) 2004. Understanding Petroleum Reservoirs: towards an
Integrated Reservoir Engineering and Geochemical Approach. Geological Society, London, Special Publications,
237, 1-5. 0305-8719/04/S15.00 © The Geological Society of London 2004.
2 W. A. ENGLAND & S. LARTER
geochemistry, with great potential for improved models of petroleum charging and mixing in reser-
resolution of charging processes. voirs crucial to useful interpretation of reservoir
Philp et al. summarize their decade of work on geochemical data, yet utilitarian models capable
high molecular weight hydrocarbons (HMWHC) of integrating compositional and reservoir prop-
in oils, emphasising the analytical issues asso- erty data in an effective manner still elude us.
ciated with separation of pure wax and asphal- This volume contains several new and welcome
tene fractions (which frequently contaminate developments in this area.
one another). Improved understanding of the Smalley et al. studied the rates at which pres-
variability in composition of the fraction may sure differences, contact differences, density dif-
ultimately aid in prediction and avoidance of ferences and chemical compositional differences
flow assurance problems associated with wax equilibrate in a simplified reservoir model. They
deposition. These HMWHC compounds, with supply analytical solutions, supported by numer-
more than 40 carbon atoms, are now known to ical simulations. These solutions should prove
be a complex mixture of up to eight homologous useful for screening studies, by comparing the
series of alkanes and alkyl aromatic hydro- various mixing timescales with the time available
carbons. They are found in oils sourced from since the reservoir was filled. This is a much
essentially all source rocks facies, not just quicker process than building and running a
source rocks containing higher plant debris. full-scale reservoir model.
Holba et al. have studied the impact of Stainforth presents new models for reservoir
petroleum biodegradation on reservoir fluid filling and mixing. He presents data to support
properties and well productivity in the Kuparuk the idea that, in many cases, petroleum does
River field, Alaska. Very significantly, they show not mix at all during reservoir filling. As new
that the major factor affecting the hydrocarbon petroleum enters the trap, it fills from the crest
degradation process is anaerobic biodegradation of the structure, forcing previously emplaced
by dissimilatory iron reduction that selectively petroleum downwards. This is a result of the
removes long chain alkyl benzenes and alkyl general decrease in fluid density with maturity.
toluenes. The classical first signatures of oil This model predicts that the shapes of saturation
biodegradation (removal of «-alkanes) are not pressure versus depth curves are related to trap
seen in this system, but nevertheless the process geometry (depth versus volume curves) as well
severely reduces oil quality and flow properties as source rock kitchen parameters. Field data
deteriorate. This study is a good example of are presented to support this model.
how studies focused on practical production Skeie et al. use the new approach of kinetics of
objectives can also substantially improve our reservoired oil asphaltene thermal degradation
knowledge of basic processes, such as biodegra- and basin modelling to try to better define the
dation, that are still poorly understood. source kitchen maturity and extent in inade-
Meulbroek et al. have created an innovative quately sampled source kitchens. They use the
computational framework to estimate phase approach to re-evaluate the evolution of the
equilibria, equation of state properties and Tampen Spur petroleum systems, with particular
compositionally dependent viscosity for the emphasis on the charging of the Snorre Field.
modelling of reservoir processes. This toolkit They suggest that the M0re Basin was not a
has been designed with the reservoir geochemist major source of petroleum to the Snorre Field,
in mind and therefore is created as a set of with the bulk of the charge coming from the
modules that can be utilized within standard east. Though still controversial, this represents
spreadsheet applications. an ambitious attempt to try to deal with our
inability to adequately characterize source
kitchens.
Physical, chemical and numerical models Di Primio & Skeie use compositional data
from closed system pyrolysis experiments to
The interpretation of chemical compositional data construct a compositional kinetic model of
from petroleum systems in the context of quantita- petroleum generation from the Draupne Forma-
tive models was one of the major advances in tion. Although this, in itself, is not new, they
petroleum geoscience in the 1980s and 1990s. developed the model in a format compatible
Great strides were made in basin modelling and with the data resolution used in PVT models
in understanding the timescales of petroleum that are familiar to reservoir engineers. Most
system processes such as petroleum mixing importantly, they tuned their PVT models to
within reservoirs. Despite this, we lack effective the observed properties of actual petroleum
models or model calibrations in many areas of accumulations observed in a well-defined portion
petroleum geoscience. We consider effective of the North Sea. This represents a significant
INTRODUCTION 3
advance in our ability to make direct com- the reservoir geochemical study. Practical
parisons between model predicted and actual sampling issues were also discussed, as samples
compositions and phase behaviour of reservoired at the well head are impossible to acquire due
petroleums. to gas pressure and temperature.
Weissenburger & Borbas describe a study on
the fluid properties and compartmentalization
Case studies - water and petroleum fluid in the Magnolia deep-water field from the Gulf
compositional variations of Mexico. They highlight observations that
suggest that mixing is incomplete within what
In recent years, interest is increasingly moving are expected to be well-connected compartments.
from the techniques employed in reservoir For example, fine-scale MDT sampling across
geochemistry to the interpretation of results in one reservoir shows a gradient in methane
a wider geological context. In particular, there carbon isotope of 2.5 parts per thousand per
is increased emphasis on understanding the 100 feet, despite the apparent absence of pressure
processes responsible for fluid variations (e.g. discontinuities. Given that Miocene, Pliocene
gravitational segregation, filling direction, bio- and Pleistocene reservoirs were deposited about
degradation) and relating these to the rates of 7.0 to 1.4 Ma ago, it is clear that this is a very
the processes that lead to reductions in fluid recent hydrocarbon-bearing province. Presently
heterogeneity (diffusion, thermal and density- occurring filling and leakage, coupled with low
driven convection). reservoir temperatures, are also factors making
Lines & Auld present a detailed analysis of the complete compositional homogenization less
complex fluid distribution found among the likely.
fields of the J-Block, UKCS, involving several Taylor et al. describe how a petrographic and
reservoir intervals. In an integrated study, the fluid inclusion study, coupled with quartz preci-
authors identify differences in maturity and pitation kinetic modelling, of a deep gas reservoir
source input using high resolution GC finger- in the Norphlet trend in Mobile Bay reveals a
printing. Pressure data and strontium isotope very complex charge and leakage history of oil,
analyses were used to investigate reservoir prior to a late final gas charge. Reservoir connec-
connectivity/compartmentalization. 2D basin tivity and performance is influenced by quartz
modelling was employed to estimate the timing cementation, with preservation of porosity and
and extent of petroleum expulsion and migra- formation of tight zones being controlled by
tion. These results were integrated to produce a the extent of chlorite coating of quartz grains
charge model to explain the differences observed, controlling quartz diagenetic deposition rates.
enabling the authors to assess the likely impact Button & Flanders examined the diagenesis
on field development. and reservoir quality of the East Ford Field,
Wavrek & Mosca report a study of the giant oil Texas, which is undergoing a carbon dioxide
fields of the Val D'Agri region of Italy. They flood. The compartmentalization of the arkosic
identified gravitational^ induced compositional sandstone reservoir is chiefly controlled by authi-
grading as the dominant cause of variation genic calcite layers associated with the tops and
between samples in this complex area. An exten- bottoms of turbidite sandstone units. Gases pro-
sive analytical programme was undertaken in duced from zones below low permeability calcite
order to establish the key molecular fractions cemented sandstone intervals in new infill wells
and molecular signatures that best characterize have high carbon dioxide contents. These,
the alteration signature. They included PVT together with geophysical log interpretations,
data, conventional geochemical measurements indicate that the calcite-cemented zones are
and measurements on the organic sulphur laterally continuous and act as vertical barriers
fraction. in the reservoir.
Mueller & Scholz describe an application of McCartney et al. analysed a very significant
reservoir geochemistry to the Voelkersen dry data set of formation water composition and
gas field in Germany. Due to the well depths formation pressure data to determine whether
(>4700m), it is important to identify large con- regional barriers to fluid flow affect formation
nected compartments for economic production. water compositions, evolution of overpressure
Condensate and gas isotope variations were distribution and changing hydrocarbon migra-
found to be valuable in establishing compart- tion pathways through time. They suggest the
ment boundaries. The geochemically-derived Jurassic and Triassic aquifers of the Central
compartments correlated well with those based North Sea have essentially behaved as a large
on conventional characterization methods. composite aquifer, which has many implications
Further refinements were suggested based on for the deep prospectivity of the CNS.