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Formation Evaluation.ppt
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PETROLEUM ENGINEERING PETROLEUM GEOSCIENCE ENGINEERING
PEEG 151
PEEG151
Chapter 7:
Formation Evaluation
Material prepared by:
Dr. Karl Berteussen
Dr. John Williams
Richard Lau
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PETROLEUM ENGINEERING PETROLEUM GEOSCIENCE ENGINEERING
PEEG 151
Chapter 7 - Formation Evaluation
Data Requirements
Rock/formation properties
Fluid properties
(hydrocarbon and water) Flow potential
There was
no oil here
when we
drilled!
Why Must We Evaluate the
Formation?
At least;
study the
cuttings.
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PEEG 151
Chapter 7 - Formation Evaluation
Why Must We Evaluate the Formation? Data Requirements Rock/formation properties (thickness, lithology, porosity,
permeability, pressure)
Fluid properties (hydrocarbon and water, saturation)
Flow potential
Data While Drilling Drilling Operations Log (progress, mud, cuttings, etc.)
Cores
Flow Potential (Drill Stem Test)
(and today we have MWD or LWD or Wireline Formation Test)
After Drilling Open-Hole Well Logs (before casing!)
Cased-Hole Logs (CBL)
Initial Production
Reservoir Fluid Samples
Sometimes wells
are drilled only
to gatherinformation.
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Drilling Operations Log
Wellsite
geologist
Continuous record of the hole as it is being drilled;
cuttings, mud returns, drilling operations plotted against depth
Cuttings data:Lithology (correlation)
PorosityOil Shows
Gas Shows
Hydrocarbon Odor
Cuttings data Problem:Lag time
Disintegrated
Re drilled
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MUD DATA
Continuous monitoring
Gas shows
Oil shows
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Cores Provide Valuable Data
Core analysisPorosity (several methods)
Fluid saturations
Permeability
Vertical
Horizontal
Some fluid data
(often contaminated)
Conventional CORING
Diamond
or PDC bit
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Sidewall CoreGun:Typical sample 2
inch long half inch
diameter
Sidewall CORINGRun on wireline
Usually in soft unconsolidated
formation.
Cylinder impact might crush
core, i.e. porosity & permeability
might not be correct
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Productivity or Production Tests
(Important Information!) Potential flow rates,
Permeability,
Fluid properties, and in some cases
Reservoir boundaries.
Better Method than the alternatives
(Well logs give only indirect indications of
permeability and fluid saturations)Costly development mistakes have been made
using inadequate or no production tests
SPE definition of reserves as proved requires
confirmation through production testing
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Production Tests
1. Drillstem testing (DST)
2. Wireline formation testing (WFT)
Drillstem testing (DST)
Tool run on drillstring Fluid flow & pressure versus
time.
Good productivity data, fluidsamples
Indication of reservoir boundary(size)
Expensive, high risk of packerfailure
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12345
1. Both valves closed(Does not feel outside
pressure, ref figure.)
2. Open bottom valve
3. Open top valve4. Close top valve
5. Close bottom valve
Drillstem testing (DST)
hourorso
H
ighDrama
W
ant:Oiltosurface
Afterwards: String pulled wet --- meaning what?
Information stored in downhole sensors, brought up.Can get info immediately, how?
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Production Tests
Drillstem testing (DST)
Wireline formation testing (WFT)
smaller tool,
smaller test,
less fluid,
results less reliable
Can test multiple zones
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Wireline Formation Testing
Springforce
Electric conductingwireline
Test
tool
Formation pressureFlow samples
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Initial Potential (IP) test(discussed in detailchapter 9)
Well completed and load fluids removed
Typically 24 hours
Reports Produced barrels of Oil
Produced barrels of Water
Produced MCF of Gas
Tubing pressure Choke size
Marks the wells transition from drilling toproduction or other status
If artificial lift:
Parameters are described
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Production Testing Challenges
May be difficult to get the packer to seal(especially when dual-packers are used)
DSTs can also be run after wells have beencompleted, cased and perforated.
Wireline formation testing data are of less quality(small volumes of fluid involved)
WFT samples are usually contaminated to some
degree Gas reservoir productivity requires extended
production testing
Wireline results can be used to determine where
DSTs need to be run.
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Open-Hole Well Logs
Operations:
Sonde lowered to the bottom then
slowly retrieved as logging takes place.
Often several different measurements
are made in one run.
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Logging Tools
Spontaneous Potential (SP) - Lithology
Gamma rayLithology
Sonic or Acoustic
Porosity DensityPorosity
NeutronPorosity
Resistivity
Formation Fluids
CaliperHole diameter & Permeability
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Spontaneous Potential (SP)
Spontaneous Potential (SP):
Measures electrochemical
potential present in the
borehole at boundaries
between porous, permeable
zones and surroundingshales:
Lithology indicatorDepth
The potential difference (DC voltage)
between a movable electrode in the
borehole and a distant reference electrode
usually at surface. The voltage is due to
currents generated by the Electrochemicaland Electrokinetic potentials
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Gamma Ray Log
A common and inexpensive measurement
of the natural emission of gamma rays by a
formation. Gamma ray logs are particularly helpful
because shales and sandstones typically
have different gamma ray signatures thatcan be correlated readily between wells.
(shales emit more gamma rays)
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More logs
Density Logs (Gamma)
Emits gamma rays
Returned radiation (gamma source),
more absorbed implies greater density.
Neutron logs
Emits neutrons
Hydrogen (in water and oil) will capture them Returned neutron gives porosity
(gas exception, used to differentiate gas and oil (togetherwith density log))
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Resistivity Logs
Saltwater saturatedporous zones
conduct electrical
current better than
same zones with oil,
natural gas or freshwater.
Resistivity ~ potential/current
Resistivity
SP
More porous/
permeable
Note: This figure isa graphit does not
show the actual hole
dimension.
WellDepth
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PEEG 151
Spontaneous Potential
(SP) - Lithology
Gamma ray
Lithology
Resistivity
Formation Fluids
Neutron
Porosity DensityPorosity
(emits gamma rays)
Sonic or Acoustic
Porosity
Caliper
Hole
Diameter &
Permeability
Log overview
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PEEG 151
Reservoir Fluid Samples:
Hydrocarbons
Samples can be taken in the well (downhole or bottomhole sampling) or from surface production (well heador separator samples)
Fluid samples are used to perform Pressure-Volume-Temperature (PVT) studies which model reservoirdepletion and surface production processes
Samples are analysed to provide a detailed fluidcomposition, which is used as a basis for reservoirsimulation, facilities design, and determination of sales
values
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PEEG 151
Reservoir Fluid Samples:
Formation Water Samples of reservoir water also give
valuable data
They can help in the interpretation of logs.
In many cases no formation water is
produced in a DST.
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PEEG 151
Chapter 7
FINISHED