07 resvr eng bw
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These powerpoint files were produced for the Earth History class at the Free University Berlin,Department of Geological Sciences
The copyright for texts, graphical elements, and images lies with C. Heubeck, unless otherwisespecified.
Download, reproduction and redistribution of theses pages in any form is hereby permitted forprivate, personal, non-commercial, and class-related purposes use as long as the source isidentified.
Despite of my efforts, I cannot guarantee the completeness, correctness and actuality of thematerial.
Prof. Christoph HeubeckInstitut fr Geologische WissenschaftenFreieUniversittBerlin
Malteserstr. 74-10012249 BerlinGERMANY
ph: ++49-(0)30-83870695 fax: ++49-(0)30-83870734cheubeck@zedat.fu-berlin.de http://userpage.fu-berlin.de/~cheubeck/
Reservoir Engineering
(light)
Todays Lecture:
Drive Mechanisms Pressure-Transient Analysis Recovery Factor
Subsurface Phases
Links and Literature
Reservoir engineering
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Drive Mechanisms
High Porosity Permeability HC saturation
Source of reservoir energy !
Driving force(s) to create apressure differential, causingHC to flow to the wellbore
(natural or artifical)
Drive Mechanisms
What causes hydrocarbons in the reservoir to move to thewellbore ?
Which forces should be supported or pushed back ?
Where and how should secondary recovery strategies beimplemented?
Drive Mechanisms
Gas cap driveSolution gas driveWater drive (Bottom-water, edge-water)
Gravity drainage driveCombination Drive Initial
Conditions
Gas Cap Drive
GasCap
Oil Zone
Danger of depressurizingvolatile phase (gas)
Only where a gas capexists (or where oneforms): RF ~20-45%;possibly assisted bygravity grive
DuringDepletion
GasCap
Oil Zone
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InitialConditions
DuringDepletion
Solution Gas Drive
Danger of producingvolatile phase (gas) first
Gas comes out of solution as
production causes reservoirpressure decline (cola-cananalogy): Least efficient ofthe drive mechanisms, RF 5-20 % Oil Zone
Bottom Water Drive
Aquifer
Danger of drawing theless viscous phase
(water) to the wellbore(water coning, water
tunneling)
Need aquifer underpressure. Need favorableuniform water advance.RF ~50% but may be ashigh as 85% !
OilZone
Edge Water Drive
Gravity Drainage /Gravity Drive
Present in all reservoirsbut very low productionrates.
Important only near reservoir depletion, in reservoirs with high
structure, and low-viscosity oils
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Gas Cap
Oil Zone
Gas Cap
OilZone
Combination Drive
Aquifer
Dangers (and possibilities!)from all sides !
0
1
2
3
4
5
0 10 20 30 40 50 60 70
Oil Produced - % of OOIP
Pro
ducingGORmscf/stb
Producing GOR trends by drive mechanism
Solution
gas drive Gravitydrive
Water drive
Gas-to-oil ratio
original oil in place
0
20
40
60
80
100
0 10 20 30 40 50 60 70
Oil Produced - % of OOIP
ReservoirPressure
(%o
fOriginal)
Reservoir Pressure Trends by drive mechanism
Solution
gas drive
Gravitydrive
Water drive
0
20
40
60
80
100
0 10 20 30 40 50 60 70
Oil Produced - % of OOIP
WaterCut(%o
fProducedFluid)
Reservoir Water Cut by drive mechanism
Solution gas drive
Gravity drive
Water drive
Gas cap drive
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Ultimate Recovery Ranges by Drive Mechanism
5-30 ( incremental)GravityGravity Drainage
35-75Aquifer ExpansionWater Drive
20-40Gas Cap and evolvedsolution gas expansion
Gas Cap Drive
5-30Evolved Solution GasExpansion
Solution GasDrive
Recovery (% OOIP)Energy SourceDrive Mechanism
?0
1
2
3
4
5
0 10 20 30 40 50 60 700
1
2
3
4
5
0 10 20 30 40 50 60 70
0
1
2
3
4
5
0 10 20 30 40 50 60 700
1
2
3
4
5
0 10 20 30 40 50 60 70
Gas Cap Expansion Drive Solution Gas Drive
Gravity DriveWater Drive
Black = GOR Blue = water cut Red = pressure
0
1
2
3
4
5
0 10 20 30 40 50 60 700
1
2
3
4
5
0 10 20 30 40 50 60 70
0
1
2
3
4
5
0 10 20 30 40 50 60 700
1
2
3
4
5
0 10 20 30 40 50 60 70
Gas Cap Expansion Drive Solution Gas Drive
Gravity DriveWater Drive
Black = GOR Blue = water cut Red = pressure
Recommendations for perforations
InitialConditions
Gas Cap Drive
GasCap
Oil Zone
As far away as posssible fromthe gas cap in gas capreservoirs
As close to the OWC in agravity drainage
Gravity Drive
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Recommendations for perforations
As high up as possible inwater-drive reservoirs
Water Drive
Oil Zone
Aquifer
Drive Mechanisms Pressure-Transient Analysis Recovery Factor Subsurface Phases
Links and Literature
Reservoir engineering
Pressure-transient analysis of drill-stem tests
DST 1 was performed over
the perforated interval12400 - 12517 MDRTin the Fulmar Fm.
Fig. 62: Halley 30/12b-8 test overview.
Pressure-transient analysis of drill-stem tests
Fig. 67: Interpretation of 30/11b-3 DST 1.
110innerradius
Undeterminedouterradius
5280= 1 mile
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Pressure-transient analysis of drill-stem tests
85
28
5280 = 1 mile
Open ?Open ?
Parallel-boundary model for 30/12b-6 DST 1
1550
450
open
4900psi
5800 psi
970 psi
923 psi
882 psi
110inner radius
1000
h(V2) ~ 300, Vol(V2) ~ 3.5e8ft3A(V2)~ 10,000 * 10000ft2
Representedby 4 blocks of2,500 sidelengtheachSpatial Relationto V1 unconstrained
1000
1000
200
V1
85
28ope
n
open
80
160 open
5280= 1 mile
2200
1100
1100
open
30/12b-3Dry hole.Not tested
30/12b-7Dry hole.Not tested
30/11b-1Noreservoir.
Not tested
30/12b-2U-shapedF block
960 psi
Appleton
Alpha
Appleton
Beta
FulmarField
Halley
833 psi
30/12b-4Close Faults (30 deg)
Incomm.with Fulmar ?
30/12b-8In pressure
comm.with 12b-4
30/11b-5poorshows.Not tested
30/12b-6CloseIIfaults.
1080 psi
Appleton / Halley
Fault Compartmentalizationfrom Seismic and Interpretation
ofPTAand RFTData
Fault
Fulmar
AukFault
ClydeField
Major PressureWellGeometrical
e r e e nt t i n1550
450
open
N
30/11b-4DST saw
only 8 -12 MMBOIP
Alpha
Beta
Halley
HalleyGamma
,
Delta
Fault
Outer radius
unknown due to
shorttestduration
Monikie
Zone
30/11b-3Shorttest
gas condensate
Seismic and test data show fieldwide compartmentalization
Drive Mechanisms Pressure-Transient Analysis Recovery Factor
Subsurface Phases
Links and Literature
Reservoir engineering
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Definition Recovery Factor
www.pore-cor.com.
Recovery Factor:
Percentage ofeconomicallyrecoverable reservoirfluid, compared toOriginal Oil in Place(OOIP)
FIELD NAME COUNTRY RSVR AGE RSVR CLSS
HASSI MESSAOUD ALGERIACAMBRIAN FRACTURED TIGHT SANDSTONE
ELMWORTH-WAPITI CANADACRETACEOUS FRACTURED TIGHT SANDSTONE
TURNER VALLEY CANADACARBONIFEROUS FRACTURED MUDDY DOLOMITE
WATERTON CANADADEVONIAN-CARBONIFEROUS FRACTURED MUDDY DOLOMITE
RENQIU CHINAPRECAMBRIAN KARSTIC/FRACTURED MUDDY DOLOMITE
AHWAZ IRAN CRETACEOUS FRACTURED MICROPOROUS LIMESTONE
MANSURI IRAN CRETACEOUS FRACTURED MICROPOROUS LIMESTONE
AIN ZALAH IRAQ CRETACEOUS FRACTURED MUDDY CARBONATE
BAI HASSAN IRAQ TERTIARY FRACTURED ORGANIC BUILDUP
KIRKUK IRAQ TERTIARY FRACTURED/KARSTIC ORGANIC BUILDUP
KARACHAGANAK KAZAKHSTANDEVONIAN-PERMIAN FRACTURED ORGANIC BUILDUP
TENGIZ KAZAKHSTANDEVONIAN-CARBONIFEROUS KARSTIC/FRACTURED ORGANIC BUILDUP
CANTARELL MEXICOCRETACEOUS-TERTIARY FRACTURED FORESLOPE CARBONATE
POZA RICA MEXICOCRETACEOUS FRACTURED FORESLOPE CARBONATE
EKOFISK NORWAYCRETACEOUS-TERTIARY FRACTURED FORESLOPE CHALK
SAFAH OMANCRETACEOUS FRACTURED MICROPOROUS LIMESTONE
IDD EL SHARGI NORTH DOME QATAR CRETACEOUS FRACTURED MICROPOROUS LIMESTONE
VERKHNEVILYUY RUSSIA CAMBRIAN FRACTURED MUDDY DOLOMITE
ABQAIQ SAUDI ARABIA JURASSIC FRACTURED MUDDY CARBONATE
ANSCHUTZ RANCH EAST USA JURASSIC TIGHT SANDSTONE
JONAH USA CRETACEOUS TIGHT SANDSTONE
LOST HILLS USA TERTIARY FRACTURED SILICEOUS SHALE
POINT ARGUELLO USA TERTIARY FRACTURED MICROPOROUS CHERT
WATTENBERG USA CRETACEOUS TIGHT SANDSTONE
YATES USA PERMIAN KARSTIC/FRACTURED CARBONATE SAND
Study of 100fracturedreservoirs
(by C&CReservoirs)
Lithology matrix heterogeneity fracture distribution fluid viscosity drive mechanism wettability
Study of 100 fractured reservoirs ( by C&C Reservoirs)
Reservoir properties
Reservoir managementstrategy
Optimization of production rate EOR technique:
Water flood, steam flood
Enhanced oilrecovery
Fractured
reservoirs
Little matrixporosity andpermeability.Fracturesprovide bothstorage capacityand fluid-flowpathways
Type I
Fractured porous
reservoirs
Low matrixporosity andpermeability.Matrix providessome storagecapacity;fractures providethe fluid-flowpathways
Type II
Microporous
reservoirs
High matrixporosity and lowmatrixpermeability
Type III
Macroporous
reservoirs
High matrixporosity andpermeability.Matrix providesboth storagecapacity andfluid-flowpathways, whilefractures merelyenhancepermeability
Type IV
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Which one are you goingto buy?
Type I Type II Type III Type IV
Fracturedreservoirs
ave. RF = 21 % ave. RF = 26%
Microporousreservoirs
ave. RF = 24%
Macroporousreservoirs
ave. RF = 34%
Type I Type II Type III Type IV
easily damaged byexcessive production rates.Many perform well underunassisted primary recoverywhen managed properly
dependent uponlithology, wettability,and fracture intensity.The choice of properEOR technique isessential for optimumexploitation
most sensitive todrive mechanism
Fracturedporousreservoirs
Development strategies and reservoir management techniques play crucial roles in maximizingexpected ultimate recoveries for given reservoir/fluid parameters.
Five main fluid type/permeability clastic-reservoir classes, with characteristic ultimate recoverydistributions and controls, are:
(1) heavy oil/tar reservoirs, in which RF is controlled by well spacing/reservoir depth, reservoirconnectivity and the application of tertiary recovery techniques;
(2) low-permeability oil reservoirs, in which RF is controlled by permeability variations, well spacingand application of waterflooding/miscible flooding, fraccing and horizontal drilling;
(3) intermediate-permeability oil reservoirs, in which RF is controlled by fluid viscosity variations,reservoir heterogeneity/architecture and application of waterflooding;
(4) high-permeability oil reservoirs, in which RF is controlled by natural drive strength/type andcontrol of aquifer and gas-cap encroachment; and
(5) gas/condensate reservoirs, in which RF is controlled by permeability variations, aquiferencroachment and condensate drop-out.
Ultimate recovery efficiency in 450 mature clastic fields
Drive Mechanisms Pressure-Transient Analysis Recovery Factor Subsurface Phases
Links and Literature
Reservoir engineering
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Vaporization of a pure substance at constant Pressure
Hg
Hg
Hg
Hg
Liquid
Liquid
Liquid
Gas
Gas
Gas
P1 P1 P1 P1T1 T2=Tv T2=Tv T3
Hg flows out so thatp stays constant
Heating
Vaporization of a pure substance at constant Temperature
Hg
Hg
Hg
Hg
Liquid
Liquid
Liquid
Gas
Gas
Gas
P1 P2=Pv P3T1 T1 T1 T1
P aboveVaporPressure
P2=Pv
Pressure-Volume Diagram of a Pure Substance
T1
T2
T3
T4
T5 = Tc
T6
T7
Dew
PointL
ine
CriticalPoint
Liquid
VaporLiquid+
Vapor
VcSpecific Volume, v
Pressure,p
Bubble
PointLin
e
Pc
Pressure-Temperature Diagram of a Pure Substance
Critical Point
Pc
Liquid
VaporPressure,p Solid
Sublimation
Evaporation
Melting
Condensation ?
Precipitation,Condensation
Freezing
TcTemperature, T
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Phase properties of the binary ethane ethane system
Reservoir Temperature, deg F
R
eservoirPressure(psia)
200
400
600
800
1000
1200
1400
0 100 200 300 400 500
CriticalPoint
Ethane,CE
CriticalPoint
Heptane,CH
MixtureA
CA
CB
Mixture
B
Dew
Po
intLin
e
Bubble
Poin
tLin
e
Dew
PointLine
Bubb
lePo
intLine
Chemical Composition of Hydrocarbons
Composition of Reservoir Fluids
86,1292,46
73,19
57,6
34,62
8,21
22,57
56,4
0%
20%
40%
60%
80%
100%
DryG
as
WetGa
s
Gasc
onde
nsate
volatile
Oil
Blacko
il
C7+
C6
nC5
iC5
nC4
iC4
C3
C2
C1
N2
CO2
Temperature, deg F
Pressure
,psia
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200-100-200-300
Wet gas
Typicalreservoirtemperatures
92,46
0%
20%
40%
60%
80%
100%
C7+
C6
nC5
iC5
nC4
iC4
C3
C2
C1
N2
CO2
Wetgas
Phase behavior of reservoir hydrocarbon mixtures
Liquid
Gas
Temperature, deg F
Pressure
,psia
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200-100-200-300
GasCondensate
0%
20%
40%
60%
80%
100%
C7+
C6
nC5
iC5
nC4
iC4
C3
C2
C1
N2
CO2
73,19
8,21Typicalreservoirtemperatures
GasCondensate
Phase behavior of reservoir hydrocarbon mixtures
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Temperature, deg F
Pressure,psia
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200-100-200-300
0%
20%
40%
60%
80%
100%
C7+
C6
nC5
iC5
nC4
iC4
C3
C2
C1
N2
CO2
57,6
22,57
Typicalreservoirtemperatures
Volatileoil
Phase behavior of reservoir hydrocarbon mixtures
Temperature, deg F
Pressure,psia
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200-100-200-300
Typicalreservoirtemperatures
0%
20%
40%
60%
80%
100%
C7+
C6
nC5
iC5
nC4
iC4
C3
C2
C1
N2
CO2
34,62
56,4
Blackoil
Phase behavior of reservoir hydrocarbon mixtures
Volatileoil
Temperature, deg F
Pressure
,psia
Phase behavior of reservoir hydrocarbon mixtures
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200
Blackoil
-100-200-300
GasCondensate
Wet gas
Typicalreservoirtemperatures
Temperature, deg F
Pressure
,psia
Behavior of fluids during depletion
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
0
0 100 200 300 400 500 600 700 800 900 1000 1100 1200-100-200-300
Bubble
PointL
oci
Dew
PointL
oci
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Pressure-Temperature Phase Diagram
Reservoir Temperature, deg F
Rese
rvoirPressure(psia)
500
1000
1500
2000
2500
3000
3500
4000
0 50 100 150 200 250 300 350
Liquid Volume
0%
5%
10%
20%
40%
80%
CriticalPoint
B
Gascondensatereservoir
ReservoirFluid
Bubb
lePo
int
Loci
DewP
ointLoci
Pressure-Temperature Phase Diagram
Reservoir Temperature, deg F
Rese
rvoirPressure(psia)
500
1000
1500
2000
2500
3000
3500
4000
0 50 100 150 200 250 300 350
CB
A
pat
hofreservoirfluid
Liquid
Volum
e
0%
5%
10%
20%
40%
80%
CriticalPoint
Single-phaseoil reservoir
path ofproduced
fluid
Single-phasegas reservoir
Gascondensatereservoir
ReservoirFluid
ProducedFluid
Bubb
lePo
int
Loci
DewP
ointLoci
Temperature
Pressure
1
C
4
s
3
s
2
s
ReservoirFluid
ProducedFluid
Behavior of fluids during depletion
BubbleP
oint
Line
Dew
PointLine
Temperature
Pressure
1
C
4
s
3
s
2
s
ReservoirFluid
ProducedFluid
Behavior of fluids during depletion
BubbleP
oint
Line
Dew
PointLine
Hydrate may form from gas andwater upon gas expansion (needantifreeze injection)
Propane injection in oilcan cause dramaticnonlinear viscosityreduction (CO2 isbest)
Gas injection causes re-vaporizationof gas condensate
Gas evolving from oildue to pressure dropduring depletion cancause waxprecipitation
Adding gas (a solvent)to oil (about 40%) cancause asphalteneprecipitation
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Difficulty and relevance of early reservoirfluid sampling !
Behavior of fluids during depletion
Pressure
1
C
4
s
3
s
2
s
Temperature
0
1
2
3
4
5
0 10 20 30 40 50 60 70
pressure
time
asphaltene precipitation
Last word
ReservoirEngineer
ProductionEngineer
PlantEngineer
Geologist GeologistHydrocarbon
Basins
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Lectura 11 (Summary: Reservesand Resources, unconventional HC)
Lab 10 (PetroMod)
Lectura 10 (Exploration:Hydrocarbon classificationof basins; play types)
Vi
Lectura 8 (Geophysics inexploration and reservoirmanagement)
Lab 9 (Loggingexercise)Lectura 9 (Loggingconcepts and tools;quantitative evaluation oflithology, fluids, andporosity)
Ju
Lectura 7 (Reservoir engineering:Drive mechanisms, phasebehavior,
production problems, scaleformationetc.)
Lab 5 (Boundwater, capillarity
exercise)
Lectura 5 (Reservoirpetrophysics: capillary
pressure, pore-sizedistribution, bound water
etc.)
Mi
Lectura 6 (The reservoir: Lithology,geometry, and facies. Reservoircharacterization and management)
Lab 4 (Porositycalculation)
Lectura 4 (porosidad,permeabilidad)
Ma
Lectura 3 (Geochemistry: Origin ofHC; organicmatter, source rocks,accumulation. The "petroleumkitchen")
Lab 2 (Internetresources)
Lectura 1 / 2 (Introduction;The petroleum system)
Lu
15:15-16:4511:30-13:009:15-10:45
LecturaPracticaLectura
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