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7/29/2019 BasicPetro_4.ppt
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S ch l um b
er g er P r i v a t e
Core Data Analysis andComparison with Logs
7/29/2019 BasicPetro_4.ppt
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S ch l um b
er g er P r i v a t e
Objectives
Core Data Types
Comparison with logs
Advantages
Disadvantages
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S ch l um b
er g er P r i v a t e
Cores
Allow direct measurement of reservoir properties
Used to correlate indirect measurements, such as
wireline/LWD logs
Used to test compatibility of injection fluids
Used to predict borehole stability
Used to estimate probability of formation failure and sand
production
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S ch l um b
er g er P r i v a t e
Information from Cores
Porosity
Horizontal permeability to air
Grain density
Vertical permeability to air
Relative permeability
Capillary pressure Cementation exponent (m) and
saturation exponent (n)
Standard Analysis Special Core Analysis
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S ch l um b
er g er P r i v a t e
Coring
Whole-core Analysis
Full-Diameter Core Analysis
Core-Plug Analysis
Up to
2 ft 6 in.1-1.5 in.
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S ch l um b
er g er P r i v a t e
PDC Cutters
Fluidvent
Drill collarconnection
Inner barrel
Outer barrel
Thrust bearing
Core retainingring
Core bit
Coring Assembly and Core Bit
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S ch l um b
er g er P r i v a t e
(Whole Core Photograph, MisoaSandstone, Venezuela)
Whole Core
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S ch l um b
er g er P r i v a t e
Sidewall Sampling Gun
Core bullets
Core sample
Formation rock
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S ch l um b er g er P r i v a t e
Sidewall Coring Tool
Coring bit
Samples
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S ch l um b er g er P r i v a t e
Comparison with Cores
Taking a core remains the only opportunity for the petroleumengineer of the geologist to physically examine a continuous
interval of reservoir rock. This technique has been continuously
improved to increase recovery and to keep the sample collected in
conditions as close as possible to the ones observed downhole
Three types of analysis are performed depending on the size of
the sample:
Fullbore analysis
Analysis of the plugs extracted from the fullbore core
Sidewall cores
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S ch l um b er g er P r i v a t e
Comparison of logs with drilled cores
The comparison of core and log results is comsuming largeamounts of the petroleum engineer and geologist energy and
time. There is a number of reasons why the parameters differ:
Physical configuration
Depth mismatch
Changes in fluid type and saturation Difference of volume of inverstigation and of vertical resolution
Porosity
Saturation exponent
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S ch l um b er g er P r i v a t e
Physical Configuration
A fullbore core extracted from a hole of nominal bitsize
b would have a diameter approximately equal to b/2.
The high resolution logging tools, generally of pad
type, have sensors directly against the borehole wall,
while the outside of core is several inches away from
the borehole wall during drilling. This discrepancy
causes a depth offset
hole hole
Logging toolFullbore Core
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S ch l um b er g er P r i v a t e
Depth Mismatch
Most laboratories match core depth with log depth byrunning a gamma ray survey over the core. However,
when the recovery is poor and the core is short, the
match is often unsatisfactory. It may even happen that
the cores are wrongly labelled or put upside down in
their boxes
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S ch l um b er g er P r i v a t e
Change in Fluid Type and Saturation
When a conventional core is cut with a standard diamond or corebarrel, it is partly flushed by the drilling fluid or mud filtrate. The
core cut at downhole pressure and temperature contains a mixtureof fluids including connate water, mud filtrate and residual oil orgas. When the core is brought to the surface, the pressure andtemperature are reduced till they reach atomospheric conditions.The gas in solution in the oil is liberated. The free gas or solutiongas expands forcing mud filtrate, oil and possibly connate water out
of the core. Consequently, a core taken from an oil bearing zone contains gas,
oil and a large amount of water (filtrate or connate). A core comingfrom a gas bearing zone contains gas, no oil and a larger amount ofwater
These changes of phase may be reduced by special coring
techniques using rubber or plastic sleeves. The cores aremaintained at bottom hole pressure at which they were cut until theyare analyzed in the laboratory
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S ch l um b er g er P r i v a t e
Difference of Volume of Investigation and ofVertical Resolution
Logs average porosity over a depth sample,
typically 0.3 m [1ft]. Core porosity may change by
several p.u. within a few inches, as shown in the
following table. Core plug porosity measurements
taken at 0.5m [2ft] intervals do not represent theaverage porosities every 0.5m [2ft]. In fractured or
vuggy carbonates, the core laboratory analysts cut
the plugs in homogeneous zones and high porosity
zones are often missed.
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S ch l um b er g er P r i v a t e
Porosity
Measured core porosity depends on the technique
used (table). For unconsolidated formations, thedifferences between porosities measured with and
without overburden can be even larger.
In shaly sands, core porosity includes bound water
volume and is equivalent to total porosity, a parameter
introduced in the Waxman-Smits and Schlumberger
shaly sands interpretation models. It could be
significantly higher than log porosity, equivalent to
effective porosity.
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S ch l um b er g er P r i v a t e
Saturation Exponent
If careful procedures are not followed, the rock fabric of
the core may be altered and the laboratory-derivedsaturation exponent is erroneous.
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S ch l um b er g er P r i v a t e
Comparison with Sidewall Cores
Sidewall samples are obtained by percussion. The
petrophysical properties of the formation such asporosity and permeability cannot be evaluated because
of compaction, mud invasion and shattering. Despite
these limitations, sidewall cores are a useful
complement to logs to evaluate lithology. Since thesidewall core and log information have different
resolutions, a potential difficulty in core/log comparison
is depth matching
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S ch l um b er g er P r i v a t e
Determination of Depth Shifts Between
Core and Log Data The method is similar to the correlation of
microresistivity dipmeter curves. It searches for an
optimal displacement between the two parameters
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S ch l um b er g er P r i v a t e
Comparison with Production Data:Capillary Pressure Curves In a homogeneous formation, the capillary pressure curve gives
the saturation profile . The pressure is proportional to the heightabove the free water level, precisely defined as the depth wherethe capillary pressure is nil. The threshold pressure is defined asthe lowest capillary at which water is displaced from the formation.It corresponds to the most shallow level with 100% water saturation computed from the logs.
The curved section of the capillary pressure curve represents thetransition zone. Corresponding to higher pressure, the zone abovethe transition displays the lowest water saturation values thatreach an asymptotic minimum, the irreducible water saturation.
Discrepancies between core and log-derived saturations are
mainly due to their respective resolution. Correct log valuescannot be obtained from low resolution tools in thin layers. In thatcase higher resolution logs, such as the ElectromagneticPropagation logs help resolve or explain the differences.
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S ch l um b er g er P r i v a t e
Uses of Logs
A set of logs run on a well will usually mean different
things to different people.
The Geophysicist The Geologist
The Drilling Engineer
The Reservoir Engineer
The Production Engineer
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S ch l um b e
r g er P r i v a t e
The Geophysicist
As a Geophysicist what do you look for?
Are the tops where you predicted?
Are the potential zones porous as you haveassumed from seismic data?
What does a synthetic seismic section show?
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S ch l um b e
r g er P r i v a t e
The Geologist
The Geologist may ask:
What depths are the formation tops?
Is the environment suitable for accumulation of Hydrocarbons?
Is there evidence of Hydrocarbon in this well?
What type of Hydrocarbon? Are Hydrocarbon present in comercial quantities?
How good a well is it?
What are the reserves?
Could the formation be commercial in an offset well?
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S ch l um b e
r g er P r i v a t e
The Drilling Engineer
What is the hole volume for cementing?
Are there any Key-seats or severe Dog-legs in the
well?
Where can you get a good packer seat for testing?
Where is the best place to set a Whipstock?
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S ch l um b e
r g er P r i v a t e
The Reservoir Engineer
The Reservoir Engineer needs to know:
How thick is the pay zone?
How homogeneous is the section?
What is the volume of Hydrocarbon per cubic meter?
Will the well pay-out?
How long will it take?
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S ch l um b e
r g er P r i v a t e
The Production Engineer
The Production Engineer is more concerned with:
Where should the well be completed (in what
zone(s))?
What kind of production rate can be expected?
Will there be any water production?
How should the well be completed?
Is the potential pay zone hydraulically isolated?
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S ch l um b e
r g er P r i v a t e
GeoFrame Applications
Petrophysics
Borehole Geology
Seismic Interpretation
Synthetics
Geology Office
WellPix
ResSum