Seismic data has limited resolution and in offshore
reservoirs the spacing between wells may be relatively
large, usually several 100 m or a few kilometres. It is
difficult to construct a 3D model when the producing
units are offset by faults that are below seismic resolution so that they can not be detected. Outcrops of similar
reservoir rocks may be used to provide quantitative data
on the geometry of sand bodies and the distribution of
minor faults. to be used in the reservoir model.
It is however critical that the field analogue was
deposited in a similar sedimentary environment and
plate tectonic setting. Many factors such as sediment
supply, climate, water depth, tidal range, etc. have to
be similar.
All reservoir analogues that are exposed have been
buried to a certain depth and then uplifted to the
surface. It is difficult to reconstruct the burial history
in terms of temperature and effective stress so that the
diagenetic effects can be compared with reservoirs at
their maximum burial depth.
The structures observed in the field analogue must
be analysed so that the deformation which occurred
during uplift can be distinguished from that produced
during subsidence.
Offshore production from a separate platform is
expensive and requires a relatively high production to
offset the production costs. Still many oil fields can be
produced with a tail production stimulated by different
methods. Onshore oil and gas fields on the other hand
can be economical at rather low production rates.
21.16 Conclusion
Production geology encompasses many different
specialities in geology, geophysics and engineering
subjects:
Reservoir sedimentology/diagenesis.
Reservoir geophysics.
Reservoir modelling (modelling of fluid flow).
Reservoir modelling has become a special field where
the flow during production is simulated mathematically based on assumptions about the distribution of
rock types with different porosity and permeability.
See Chap. 22.
Drilling and well completion.
A team of specialists is therefore required to produce a reservoir efficiently.
This depends very much on reservoir modelling
which is a complex process were the fluid flow in the
reservoir is simulated.
Further Reading
Archer, J.S. and Wall, C.G. 1994. Principles of Petroleum Engineering. Principles and Practice. Graham and Trotman,
London, 362 pp.
Burchette, T.P. 2012. Carbonate rocks and petroleum reservoirs:
a geological perspective from the industry. In: Garland, J.,
Neilson, J.E., Laubach, S.E. and Whidden, K.J. (eds.),
Advances in Carbonate Exploration and Reservoir Analysis.
Geological Society Special Publication 370, pp. 17-37.
Dandekar, A.Y. 2006. Petroleum Reservoir Rocks and Fluid
Flow Properties. CRC Publications, Boca Raton, FL, 460 pp.
Dickey, P.A. 1979. Petroleum Development Geology. Petroleum Publishing Co., Tulsa, OK, 398 pp.
Dikkers, A.J. 1985. Geology in Petroleum Production.
Developments in Petroleum Science 20, Elsevier Science,
239 pp.
Hyne, N.J. 2012. Nontechnical Guide to Petroleum Geology,
Drilling and Production, 3rd. edition. Pennwell Corporation,
Tulsa, Oklahoma, pp. 698.
Loudon, R.C. 1996. Principles of Petroleum Development Geology. PTR Prentice Hall. New Jersey. 267pp.
Lynn, G.J., Ellis, A.C., Brain, J., Parker, R., Lortzer, G-J. and
Michelet, S. 2014. Gannet F field - Unexpeted fluid flow
between reservoirs identfied from time-lapse seismic data.
First Break 32(4), 53-59.
Robinson, A., Griffiths, P., Price, S., Hegre, J. and Muggeridge,
A. 2009. The Future of Geological Modelling in Hydrocarbon Developments. Geological Society Special Publication
309, 232 pp.
Tiab, D. and Donaldson, E.C. 2004. Petrophysics. Elsevier,
Amsterdam, 889 pp.
558
K. Bjørlykke
reservoirs the spacing between wells may be relatively
large, usually several 100 m or a few kilometres. It is
difficult to construct a 3D model when the producing
units are offset by faults that are below seismic resolution so that they can not be detected. Outcrops of similar
reservoir rocks may be used to provide quantitative data
on the geometry of sand bodies and the distribution of
minor faults. to be used in the reservoir model.
It is however critical that the field analogue was
deposited in a similar sedimentary environment and
plate tectonic setting. Many factors such as sediment
supply, climate, water depth, tidal range, etc. have to
be similar.
All reservoir analogues that are exposed have been
buried to a certain depth and then uplifted to the
surface. It is difficult to reconstruct the burial history
in terms of temperature and effective stress so that the
diagenetic effects can be compared with reservoirs at
their maximum burial depth.
The structures observed in the field analogue must
be analysed so that the deformation which occurred
during uplift can be distinguished from that produced
during subsidence.
Offshore production from a separate platform is
expensive and requires a relatively high production to
offset the production costs. Still many oil fields can be
produced with a tail production stimulated by different
methods. Onshore oil and gas fields on the other hand
can be economical at rather low production rates.
21.16 Conclusion
Production geology encompasses many different
specialities in geology, geophysics and engineering
subjects:
Reservoir sedimentology/diagenesis.
Reservoir geophysics.
Reservoir modelling (modelling of fluid flow).
Reservoir modelling has become a special field where
the flow during production is simulated mathematically based on assumptions about the distribution of
rock types with different porosity and permeability.
See Chap. 22.
Drilling and well completion.
A team of specialists is therefore required to produce a reservoir efficiently.
This depends very much on reservoir modelling
which is a complex process were the fluid flow in the
reservoir is simulated.
Further Reading
Archer, J.S. and Wall, C.G. 1994. Principles of Petroleum Engineering. Principles and Practice. Graham and Trotman,
London, 362 pp.
Burchette, T.P. 2012. Carbonate rocks and petroleum reservoirs:
a geological perspective from the industry. In: Garland, J.,
Neilson, J.E., Laubach, S.E. and Whidden, K.J. (eds.),
Advances in Carbonate Exploration and Reservoir Analysis.
Geological Society Special Publication 370, pp. 17-37.
Dandekar, A.Y. 2006. Petroleum Reservoir Rocks and Fluid
Flow Properties. CRC Publications, Boca Raton, FL, 460 pp.
Dickey, P.A. 1979. Petroleum Development Geology. Petroleum Publishing Co., Tulsa, OK, 398 pp.
Dikkers, A.J. 1985. Geology in Petroleum Production.
Developments in Petroleum Science 20, Elsevier Science,
239 pp.
Hyne, N.J. 2012. Nontechnical Guide to Petroleum Geology,
Drilling and Production, 3rd. edition. Pennwell Corporation,
Tulsa, Oklahoma, pp. 698.
Loudon, R.C. 1996. Principles of Petroleum Development Geology. PTR Prentice Hall. New Jersey. 267pp.
Lynn, G.J., Ellis, A.C., Brain, J., Parker, R., Lortzer, G-J. and
Michelet, S. 2014. Gannet F field - Unexpeted fluid flow
between reservoirs identfied from time-lapse seismic data.
First Break 32(4), 53-59.
Robinson, A., Griffiths, P., Price, S., Hegre, J. and Muggeridge,
A. 2009. The Future of Geological Modelling in Hydrocarbon Developments. Geological Society Special Publication
309, 232 pp.
Tiab, D. and Donaldson, E.C. 2004. Petrophysics. Elsevier,
Amsterdam, 889 pp.
558
K. Bjørlykke