Enhance Gravity Inversion Result Using Integration of Time-lapse Surface and Borehole Microgravity
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Transcript of Enhance Gravity Inversion Result Using Integration of Time-lapse Surface and Borehole Microgravity
Enhance Gravity Inversion Result Using Integration of Time-lapse Surface and
Borehole MicrogravityBy:
Andika Perbawa(1)(2), Wawan G. A. K(3)
(1)Medco E&P Indonesia(2) Formerly Geophysical Engineering ITB
(3) Geophysical Engineering ITB
The Bali 2010 International Geosciences Conference and Exposition, Bali, Indonesia, 19-22 July 2010
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Time-lapse microgravity survey Supporting production management, Monitoring fluid movement.
Acquisition At least two gravity measurements (Kadir, et. al., 2003).
Limitation in vertical resolution.
Time-lapse borehole microgravity survey Enhance the signal sensitivity, Sharpen vertical resolution.
Inversion Understanding distribution of density contrast.
Background
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Basic Theory(equation)
(Plouff, 1976)
2
1
2
1
2
1,, )log()log(arctan
,,i j
iijkiiijkiijkk
iik
kijkrqpz yRyxRx
RZyxZGg
rqp
222kjiijk zyxR
kjiijk 111
Where:
∆ρ=(+)
Basic Theory (Gravity Anomaly)
∆gmgalmgal
1st measurement 2nd measurement
=
=
TLSM
TLBM
Density contrast
waterwater
oil oil
t1 t2 ∆t=t2-t1
µgal
µgal∆g
ρmatrix (gr/cc) ρoil (gr/cc) ρwater (gr/cc) Φ2.65 0.85 1 27%
Bulk Density Assumption (example)
ρb= (1- )Φ ρmatrix + Φ (So*ρoil+Sw*ρwater)
1st Condition (100% oil)ρb(1) = (100% - 27%)2.65 + 27%(100%*0.85 + 0%*1)ρb(1) = 2.16 gr/cc
2nd Condition (100% water)ρb(2) = (100% - 27%)2.65 + 27%(0%*0.85 + 100%*1)ρb(2) = 2.2 gr/cc
∆ρ=ρb(2)-ρb(1)
∆ρ=2.16-2.2
∆ρ=0.04 gr/cc
(Schön, 1995)
Time-lapse Borehole Microgravity Anomaly
ρ1=2
ρ1=2.1
ρ1=2.16
ρ1=2.3
ρ1=2.4
ρ2=2
ρ2=2.1
ρ2=2.2
ρ2=2.3
ρ2=2.4
∆ρ=0
∆ρ=0
∆ρ=0.04
∆ρ=0
∆ρ=0
- =
2ndcondition
1stcondition
Density contrast
TLBM response
(+)
(-)
ρ in (gr/cc)
Basic Theory(inversion)
Relationship between data and model parameter:
Damp least square inversion solution:
dGGGm
mGdTT 1
dGIGGm TT 12
(Grandis, 2008)
Damp Least Square Inversion
m : density contrast G : geometry factor matrixε : damping factorI : identity matrixd : gravity anomaly
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Body Anomaly Geometry(Actual Density Contrast Distribution)
Δρ(gr/cc)
Borehole location
Positive anomaly (red)
Negative anomaly
(blue)
4 Layers
Layer-1Layer-2Layer-3Layer-4
(a) 3D view (b)map view
(c) Cross section
Forward Modeling(Time-lapse Surface Microgravity)
Body anomaly location (black rectangle)
ForwardModeling(Time-lapse Borehole Microgravity)
Separate into two bodies
∆ρ(-)∆ρ(+)
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Actual Model TLSM Inversion
TLBM Inversion Joint Inversion
Δρ(gr/cc)
Actual model Δρ(gr/cc)
TLSM Inversion
Δρ(gr/cc)
TLBM Inversion Δρ(gr/cc)
Joint Inversion
Inversion Results
InversionComparison
(Layer-1)
Actual model Surface inversion
Borehole inversion Joint inversion
InversionComparison
(Layer-2)
Actual model Surface inversion
Borehole inversion Joint inversion
InversionComparison
(Layer-3)
Actual model Surface inversion
Borehole inversion Joint inversion
InversionComparison
(Layer-4)
Actual model Surface inversion
Borehole inversion Joint inversion
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Comparison of contrast density distribution (Northing-line Section)
Δρ(gr/cc)
Actual model
Joint inversion
Borehole inversion
Surface inversion
0 50 100 150 200 250 300 350
-0.04
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Density Profile at Layer 1
0 50 100 150 200 250 300 350
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Layer 2
0100
200300
-0.03
-0.02
-0.01
-3.46944695195361E-18
0.01
0.02
0.03
0.04
Layer 3
0 50 100 150 200 250 300 350
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Layer 4
Layer 4 Origin
Layer 4 from surface inversion
Layer 4 from All Borehole inversion
Layer 4 from Join Inversion
Initial model
TLSM
TLBM
Joint
(∆ρ) (∆ρ)
(∆ρ) (∆ρ)
Comparison of contrast density distribution(Easting-line Section)
Δρ(gr/cc)
Actual model
Joint inversion
Borehole inversion
Surface inversion
0 50 100 150 200 250 300 350 400
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Density Profile at Layer 1
0 50 100 150 200 250 300 350 400
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Layer 2
0100
200300
400
-0.03
-0.02
-0.01
-3.46944695195361E-18
0.01
0.02
0.03
0.04
Layer 3
0 100 200 300 400
-0.03
-0.02
-0.01
0
0.01
0.02
0.03
0.04
Layer 4
Layer 4 Originlayer 4 from surface inversionLayer 4 from all borehole inversionLayer 4 from join inversion
Initial model
TLSM
TLBM
Joint
(∆ρ) (∆ρ)
(∆ρ) (∆ρ)
RMS error (gr/cc)
surface inversion borehole inversion joint inversion
0.010 0.006 0.005
Error Analysis
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Time-lapse Borehole Microgravity Forward modeling : good vertical resolution. Inverse modeling : increase sensitivity to detect
density contrast.
Joint inversion shows the best result to determine density contrast distribution.
Conclusions
Background Basic Theory Forward Modeling Inverse Modeling Analysis Conclusions Recommendations
Outline
Apply joint inversion for real data.
Try other inversion methods to optimize the result,
Try other models (more complex),
Analyze how much optimum boreholes that we need and the distance between them,
Recommendations
Thank You
Back Slide
Detail inversion result of TLSM
Inversion using 1 borehole
Δρ(gr/cc)
Inversion using 1 borehole
±75 meter radius
Error distribution of iteration
TLSM Inversion Error
TLBM Inversion Error
Joint Inversion Error
Resolution : 1-20 µgal Gas-oil ± 2 µgal Gas-water ± 5 µgal Oil-water 0.7-3 µgal Accessable casing up to 5½ inch. 14 degree from vertical.(Nabighian, et. al., 2005)
Instrument
Instrument ofboreholegravitymeter.(Goodell, R. R., 1964).