WELL LOG INTERPRETATION

WELL LOG INTERPRETATION

TH. Promsri

ID: 114338

TA

BLE

OF

CO

NT

EN

TS

FLOW CHART

DATA SET

ZONING/LITHOLOGY

POROSITY CALCULATION

SPECIAL CORE ANALYSIS (SCAL)

PICKETTE PLOT

WATER SATURATION by ARCHIE’s METHOD and SIMANDOUX’s METHOD

WATER SATURATION by HEIGHT METHOD

WATER SATURATION by WAXMAN-SMITS’s METHOD

WATER SATURATION COMPARISON

RESERVE

SHALE TYPE ANALYSIS

3

5

6

17

20

27

29

31

36

42

44

45

PREDICTION 46

7/2/2013

2WELL LOG INTERPRETATION

FLO

WC

HA

RT

WELL LOG

7/2/2013


Start

Porosity

Data Plots

Shale Volume

Zoning/Lithology

Water Saturation

Permeability

WL

k-Ø

Data collection and QC

Core

a, m, n, RwCore

FLO

WC

HA

RT

WELL LOG

7/2/2013


http://infohost.nmt.edu/~petro/faculty/Engler370/fmev-chap3-reserves.pdf

DA

TA

SE

TWELL LOG

7/2/2013


Well: Darling

Depth: 616 – 675 m

DT and DTS (usec/ft)

GAMMA RAY (API)

RESISTIVITY (Ωm)

CAL (inch)

NPHI (fraction)

DENSITY (g/cc)

PHIDT (fraction)

LRE PHID (fraction)

LRE

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


Well: Darling

Depth: 616 – 675 m

DT and DTS (usec/ft)

GAMMA RAY (API)

CAL (inch)

RESISTIVITY (Ωm)

NPHI (fraction)

DENSITY (g/cc)

Vsh

Hydrocarbon Zone (Normal case)

ReservoirØN-D cross

Cut offShale layers

and Net thickness

Most reliable indicator of reservoir rock

Vp, Vs

GOC, OWC, GRpre

HI

Wash out zoneHI

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


Depth

From (m)

Depth

To (m)

Thickness

(m)

LithologyLog Reading

GR

(API)

DENSITY

(g/cc)

Zone 1 616 622.5 6.5 Shale 86.843 2.65

Zone 2 622.5 625 2.5 Sand 42.535 2.50

Zone 3 625 626.5 1.5 Limestone 31.851 2.61

Zone 4 626.5 637.5 11 Clean Sand 33.932 2.48

Zone 5 637.5 639 1.5 Shale 76.691 2.57

Zone 6

639 646 7 Clean Sand 31.462 2.41

646 655.5 9.5 Clean Sand 30.238 2.44

Zone 7 655.5 660.5 5 Shale 81.848 2.43

Zone 8 660.5 662 1.5 Sand 46.269 2.57

Zone 9 662 664 2 Limestone 47.43 2.71

Zone 10 664 667 3 Shale 97.295 2.47

Zone 11 667 675 8 Shaly Sand 60.017 2.58

1) Shale line

2) Non shale line

GR

Flatlining zone

Depth

From (m)

Depth

To (m)

Thickness

(m)

LithologyLog Reading Petrophysical Properties Analysis

GR

(API)

VSH

Zone 1 616 622.5 6.5 Shale 86.843 0.9532

Zone 2 622.5 625 2.5 Sand 42.535 0.2968

Zone 3 625 626.5 1.5 Limestone 31.851 0.1385

Zone 4 626.5 637.5 11 Clean Sand 33.932 0.1694

Zone 5 637.5 639 1.5 Shale 76.691 0.8028

Zone 6639 646 7 Clean Sand 31.462 0.1328

646 655.5 9.5 Clean Sand 30.238 0.1146

Zone 7 655.5 660.5 5 Shale 81.848 0.8792

Zone 8 660.5 662 1.5 Sand 46.269 0.3521

Zone 9 662 664 2 Limestone 47.43 0.3693

Zone 10 664 667 3 Shale 97.295 1.1081

Zone 11 667 675 8 Shaly Sand 60.017 0.5558

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


GRcs = 22.5 API

GRsh = 90 API

Radioactive index IRA

GRcs is the gamma ray

log reading in a clean

sand zone and GRsh is

the gamma ray log

reading in a shale zone.

cssh

cssh GRGR

GRGRV

GAMMA RAY (API) VshCut off

Shale layers and Net

thickness

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


FUZZY LOGIC

Sand

Shale

Cut off at 56 API

Or about 50% Vsh

Note that in Quick Look, cut off at 50% Vsh is used.

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


Depth

From (m)

Depth

To (m)

Thickness

(m)


GR

(API)

DENSITY

(g/cc)

Zone 1 616 622.5 6.5 Shale 86.843 2.65

Zone 2 622.5 625 2.5 Sand 42.535 2.50

Zone 3 625 626.5 1.5 Limestone 31.851 2.61

Zone 4 626.5 637.5 11 Clean Sand 33.932 2.48

Zone 5 637.5 639 1.5 Shale 76.691 2.57

Zone 6

639 646 7 Clean Sand 31.462 2.41

646 655.5 9.5 Clean Sand 30.238 2.44

Zone 7 655.5 660.5 5 Shale 81.848 2.43

Zone 8 660.5 662 1.5 Sand 46.269 2.57

Zone 9 662 664 2 Limestone 47.43 2.71

Zone 10 664 667 3 Shale 97.295 2.47

Zone 11 667 675 8 Shaly Sand 60.017 2.58

1) Shale: Density lies to the right of the neutron.

2) Reservoir: Density moving to the left and crossing

the neutron curve.

3) Gas zone will exhibit a greater crossover.ØN-D cross

Flatlining zone

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


Depth

From (m)

Depth

To (m)

Thickness

(m)


GR

(API)

DENSITY

(g/cc)

Zone 1 616 622.5 6.5 Shale 86.843 2.65

Zone 2 622.5 625 2.5 Sand 42.535 2.50

Zone 3 625 626.5 1.5 Limestone 31.851 2.61

Zone 4 626.5 637.5 11 Clean Sand 33.932 2.48

Zone 5 637.5 639 1.5 Shale 76.691 2.57

Zone 6

639 646 7 Clean Sand 31.462 2.41

646 655.5 9.5 Clean Sand 30.238 2.44

Zone 7 655.5 660.5 5 Shale 81.848 2.43

Zone 8 660.5 662 1.5 Sand 46.269 2.57

Zone 9 662 664 2 Limestone 47.43 2.71

Zone 10 664 667 3 Shale 97.295 2.47

Zone 11 667 675 8 Shaly Sand 60.017 2.58

Low resistivity in hydrocarbon/water zone:

1) Formation water salinity is very high.

2) High proportion of conductive dispersed shale.

3) Invasion completely mask the HC response.RES_DEEP

Flatlining zone

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


DT and DTS (usec/ft) Vp, Vs

GOCOWCDTS

V

DTV

s

p

1

1

ZO

NIN

G/L

ITH

OLO

GY

FORMATION PRESSURE DATA

7/2/2013


Water Density

1.431 psi/m*(6 894.75729 Pa/psi)/(9.81 m/s2)

= 1,005.75 kg/m3 = 1.00575 g/cc

Oil Density

1.214 psi/m*(6 894.75729 Pa/psi)/(9.81 m/s2)

= 853.235 kg/m3 = 0.853235 g/cc

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


)V-2(V

)2V-(V=

1

1

2s

2p

2s

2p

DTSV

DTV

s

p

ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


ZO

NIN

G/L

ITH

OLO

GY

WELL LOG

7/2/2013


Depth

From (m)

Depth

To (m)

Thickness

(m)


GR

(API)

DENSITY

(g/cc)

Zone 1 616 622.5 6.5 Shale 86.843 2.65

Oil 622.5 625 2.5 Sand 42.535 2.50

Zone 3 625 626.5 1.5 Limestone 31.851 2.61

Oil 626.5 637.5 11 Clean Sand 33.932 2.48

Zone 5 637.5 639 1.5 Shale 76.691 2.57

Oil

Water

639 646 7 Clean Sand 31.462 2.41

646 655.5 9.5 Clean Sand 30.238 2.44

Zone 7 655.5 660.5 5 Shale 81.848 2.43

Zone 8 660.5 662 1.5 Sand 46.269 2.57

Zone 9 662 664 2 Limestone 47.43 2.71

Zone 10 664 667 3 Shale 97.295 2.47

Zone 11 667 675 8 Shaly Sand 60.017 2.58Flatlining zone

Water based mud is used.

PO

RO

SIT

YC

ALC

ULA

TIO

NWELL LOG

7/2/2013


Avg. Shale Properties

DENSITY

(g/cc)

ØN RES_DEEP

(Ωm)

DT

(usft)picking above 90 API

2.64 0.1201429 19.3 68.6945 above FWL

2.46 0.2532353 7.8 64.7583 below FWL

Avg. Grain Density of each zone (g/cc)

Data from SCAL

2.675 zone1

2.665 zone2

2.720 zone3

2.665 zone4

2.660 zone5

2.650 zone6

GR DENSITY NEUTRON RES_DEEP DT

104.638 2.663 0.129 19.841 71.991

102.528 2.654 0.131 20.287 71.613

99.254 2.634 0.128 20.183 70.830

97.172 2.648 0.124 19.741 70.163

95.056 2.664 0.118 19.241 69.291

90.259 2.639 0.110 18.752 68.946

94.643 2.652 0.112 16.986 74.788

97.146 2.651 0.109 17.263 71.832

94.166 2.637 0.105 19.810 64.523

90.908 2.639 0.117 19.978 66.490

90.690 2.653 0.125 19.667 68.539

SH avg. above FWL 2.640 0.120 19.334 68.695

GR DENSITY NEUTRON RES_DEEP DT

101.404 2.301 0.211 6.919 59.551

110.747 2.361 0.264 6.284 60.187

112.733 2.514 0.288 6.074 61.49

114.752 2.627 0.269 5.976 62.132

114.34 2.652 0.248 5.916 62.248

112.368 2.649 0.235 5.862 63.143

104.559 2.583 0.203 6.358 64.449

94.888 2.457 0.162 7.981 65.609

96.937 2.344 0.239 8.964 67.611

105.061 2.293 0.301 8.554 67.611

108.379 2.37 0.321 8.763 67.989

104.656 2.463 0.285 8.956 67.989

98.318 2.511 0.215 9.773 68.279

91.383 2.541 0.157 9.235 69.059

SH avg. under FWL 2.458 0.253 7.764 64.758

PO

RO

SIT

YC

ALC

ULA

TIO

NWELL LOG

7/2/2013



DENSITY

(g/cc)

ØN RES_DEEP

(Ωm)

DT


2.64 0.1201429 19.3 68.6945 above FWL

2.46 0.2532353 7.8 64.7583 below FWL

Recommended

Avg. Grain Density of each zone (g/cc)

Data from SCAL

2.675 zone1

2.665 zone2

2.720 zone3

2.665 zone4

2.660 zone5

2.650 zone6

Table 2.4.1

(Toby Darling: Well logging and formation evaluation book)

Selection of fluid density for porosity calculated from density tool

Formation Fluid OBM

WBM

Heavy Mud System Light Mud System

Gas, clear gas effect

on logs0.4 0.6 0.5

Gas, no clear gas

effect on logs0.55 0.7 0.6

Light oil 0.6 0.8 0.7

Heavy oil 0.7 0.9 0.8

Low – salinity water 0.85 1.05 1.0

High – salinity water 0.9 1.1 1.05

ff

-

-V

-

-

*)S-(1*S-

)-(V)-(

*)-V-(1*V

*)S-(1**S*

ma

shmash

ma

bma

hcxomfxoma

shmashbma

mashshsh

hcxomfxob

Formation pressure data versus depth:

1) Oil density = 0.853235 g/cc , likely to be heavy oil.

2) Formation water density = 1.00575 g/cc, high – salinity.

Note that in Quick Look, Grain density = 2.65 g/cc is used and

fluid densities have to be assumed.

PO

RO

SIT

YC

ALC

ULA

TIO

NWELL LOG

7/2/2013



DENSITY

(g/cc)

ØN RES_DEEP

(Ωm)

DT


2.64 0.1201429 19.3 68.6945 above FWL

2.46 0.2532353 7.8 64.7583 below FWL

ff

-

-V

-

-

*)S-(1*S-

)-(V)-(

*)-V-(1*V

*)S-(1**S*

ma

shmash

ma

bma

hcxomfxoma

shmashbma

mashshsh

hcxomfxob

Recommended

Avg. in-situ porosity of each zone

Data from SCAL

1.896 zone1

10.475 zone2

0.948 zone3

11.016 zone4

5.688 zone5

15.879 zone6

Depth

From (m)

Depth

To (m)

Thickness

(m)


Petrophysical

Properties

DENSITY

(g/cc)

Ø

Zone 1 616 622.5 6.5 Shale 2.65

Zone 2 622.5 625 2.5 Sand 2.50 0.0880

Zone 3 625 626.5 1.5 Limestone 2.61

Zone 4 626.5 637.5 11 Clean Sand 2.48 0.1033

Zone 5 637.5 639 1.5 Shale 2.57

Zone 6639 646 7 Clean Sand 2.41 0.1389

646 655.5 9.5 Clean Sand 2.44 0.1185

Zone 7 655.5 660.5 5 Shale 2.43

Zone 8 660.5 662 1.5 Sand 2.57

Zone 9 662 664 2 Limestone 2.71

Zone 10 664 667 3 Shale 2.47

Zone 11 667 675 8 Shaly Sand 2.58

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


SCAL: Darling (12 cores)

Depth: 620– 642 m

Resistivity Index (I)

Permeability

FRF

Porosity

Pc Test

Water Saturation a and b coefficient inSw=Swirr+aJb

Most reliable indicator of reservoir rock

b, n, I*, n*

Grain Density Ø Calculation

K - Ø correlationCalibr.

+ Log Density Fluid densitiesAt the same depth

a, m, F*, m* RwPickette

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


POROSITY and PERMEABILITY CALIBRATION

Porosity as Fraction at Overburden POR/PORatm

Pressure (psi) Sample 1 Sample 2 Sample 3 Sample 4 Sample 1 Sample 2 Sample 3 Sample 4

50.0 0.080 0.120 0.140 0.170 1.000 1.000 1.000 1.000

500.0 0.078 0.117 0.137 0.167 0.975 0.975 0.979 0.982

1500.0 0.077 0.115 0.135 0.163 0.963 0.958 0.964 0.959

2000.0 0.076 0.114 0.133 0.161 0.950 0.950 0.950 0.947

2500.0 0.076 0.113 0.132 0.161 0.950 0.942 0.943 0.947

4500.0 0.073 0.110 0.127 0.155 0.913 0.917 0.907 0.912

6000.0 0.072 0.107 0.125 0.153 0.900 0.892 0.893 0.900

Brine Permeability in Measured Depth at overburden PERM/PERMatm

Pressure (psi) Sample 1 Sample 2 Sample 3 Sample 4 Sample 1 Sample 2 Sample 3 Sample 4

50.0 2.000 12.000 60.000 540.000 1.000 1.000 1.000 1.000

500.0 1.758 10.581 52.542 474.874 0.879 0.882 0.876 0.879

1500.0 1.492 9.024 45.070 402.493 0.746 0.752 0.751 0.745

2000.0 1.396 8.429 42.128 377.865 0.698 0.702 0.702 0.700

2500.0 1.319 7.909 39.502 355.987 0.659 0.659 0.658 0.659

4500.0 1.061 6.326 31.627 286.359 0.531 0.527 0.527 0.530

6000.0 0.922 5.504 27.619 248.496 0.461 0.459 0.460 0.460

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


psi 2,196

(psi/kPa) 7730209230.14503773 kPa 15,141.7

(m) 630 )(m/s 9.81 (g/cc) 2.45

Pressure Overburden2

Overburden Pressure

Approximationavg. density

Assume

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


Rock type Depth PORin-situ PERMin-situ Log Density (g/cc) Grain Density (g/cc)

Shale 620.00 1.896 0.0068 2.675zone1

Shale 622.00 1.896 0.0136 2.675

Sand 624.00 10.4754 14.96 2.485 2.665 zone2

Limestone 626.00 0.948 0.0204 2.720 zone3

Sand 628.00 9.006 7.14 2.502 2.665

zone4

Sand 630.00 14.7888 92.208 2.391 2.662

Sand 632.00 14.22 81.6 2.438 2.658

Sand 634.00 7.11 7.48 2.500 2.674

Sand 636.00 9.954 10.404 2.515 2.666

Shale 638.00 5.688 0.544 2.660 zone5

Sand 640.00 16.9692 238 2.373 2.651zone6

Sand 642.00 14.7888 88.4 2.392 2.649

The values only in reservoir zone

are picked.

Plot

K - Ø correlation

Fluid densities

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


K - Ø correlation Fluid densities

k = 0.2862581887 * exp(0.389595792 * Ø) Oil density = 0.906 g/cc (heavy oil)

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


FRF Measurement Data

Porosity FRF

0.1 89.2785

0.15 44.0185

0.17 33.3675

0.08 133.3982

0.14 43.3121

0.13 58.2223

F = aØ-m

m = 1.843a = 1.280

Note that in Quick Look, a = 1 and m = 2 are

used.

SP

EC

IAL

CO

RE

AN

ALY

SIS

SCAL

7/2/2013


Resistivity Index Data

Plug I (Ø = 17%) Plug 2 (Ø = 15%) Plug 3 (Ø = 13%)

Sw I= (Rt/Ro) Sw I Sw I

1 1 1 1 1 1

0.8 1.61592 0.8 1.541192 0.9 1.297253

0.6 2.955611 0.6 2.660774 0.7 2.353045

0.4 8.05591 0.5 3.783241 0.6 3.247888

0.35 10.15069 0.4 6.397332 0.55 3.986601

0.3 12.88598 0.5 5.242788

0.28 15.20306

I = b(Sw)-n

n = 2.17b = 1.00

Note that in Quick Look, b = 1 and n = 2 are used.

Ø = 17% Ø = 15% Ø = 13% average

n = 2.163 1.999 2.343 2.17

b = 1.007 0.983 1.005 1.00

PIC

KE

TT

EP

LOT

WELL LOG

7/2/2013


Note that in Quick Look, a = 1, b = 1, m = 2, and n = 2 are

used.

Pick data in water-bearing sand zone (Log data)

Deep Resistivity Calculated Porosity

0.987 0.159

0.989 0.163

0.950 0.162

0.846 0.168

0.801 0.170

0.837 0.173

0.849 0.173

0.839 0.170

0.833 0.179

0.841 0.181

Rt = aRwØ-m(Sw)-n

Sw = 1 (water-bearing sand)m = 1.843, a = 1.28

m

C

FT

T

027715.0R

meter. 100per 3 gradient e temperturUsing

11.112;)77.611.112(

6.7777R01953.0

)77.6(

6.7777RR

77F

77F

77F2

T w,

2T w,

2T w,T w,

PIC

KE

TT

EP

LOT

SCAL

7/2/2013


Note that in Quick Look, grain density = 2.65 g/cc, a = 1, b = 1, m = 2, and n = 2 are used.

Core Data

Zone DEPTH (m)Arithmetic Average

kH vs Ø m a Rw n bØ K Gr. DENSITY (g/cc)

Zone 1 620, 622 1.896 0.010 2.675

Zone 2 624 10.475 14.960 2.665 k = 0.2862581887 * exp(0.389595792 * Ø) 1.843 1.28 0.019766116 2.17 1

Zone 3 626 0.948 0.020 2.720

Zone 4 628 - 636 11.016 39.766 2.665 k = 0.2862581887 * exp(0.389595792 * Ø) 1.843 1.28 0.019692341 2.17 1

Zone 5 638 5.688 0.544 2.660

Zone 6640, 642 15.879 163.200 2.650 k = 0.2862581887 * exp(0.389595792 * Ø) 1.843 1.28 0.019597925 2.17 1

Zone 7

Zone 8

Zone 9

Zone 10

Zone 11

WA

TE

RS

AT

UR

AT

ION

BY

AR

CH

IE’SM

ET

HO

DWELL LOG

7/2/2013



RES_DEEP

(Ωm)picking above 90 API

19.3 above FWL

7.8 below FWL

By Archie’s law

sh

wsh

n

tm

w

R

RV

R

aR

4.0S

1

w

Well Log Data

Rt Vsh Ø Rw Sw, archie’s

17.837 0.43237037 0.052 0.019777 0.57643

15.861 0.3832 0.055 0.019775 0.5893

14.257 0.404237037 0.063 0.019774 0.54991

13.042 0.387481481 0.064 0.019772 0.56817

12.543 0.322592593 0.074 0.019771 0.51391

12.638 0.268814815 0.099 0.019770 0.39889

12.730 0.250533333 0.100 0.019768 0.39712

12.529 0.252948148 0.100 0.019767 0.40013

12.116 0.2796 0.104 0.019765 0.39015

11.852 0.293422222 0.098 0.019764 0.41564

Note that in Quick Look, a = 1, b = 1, m = 2, and n = 2 are used.

WA

TE

RS

AT

UR

AT

ION

BY

SIM

AN

DO

UX’S

ME

TH

OD

WELL LOG

7/2/2013


By Simandoux’s equation

Well Log Data

Rt Vsh Ø Rw Sw, simandoux

17.837 0.43237037 0.052 0.019777 0.42626237

15.861 0.3832 0.055 0.019775 0.45556941

14.257 0.404237037 0.063 0.019774 0.42144463

13.042 0.387481481 0.064 0.019772 0.44191233

12.543 0.322592593 0.074 0.019771 0.42174349

12.638 0.268814815 0.099 0.019770 0.34202433

12.730 0.250533333 0.100 0.019768 0.34453002

12.529 0.252948148 0.100 0.019767 0.34663121

12.116 0.2796 0.104 0.019765 0.33256486

11.852 0.293422222 0.098 0.019764 0.35066277

n

shtw

m

sh

sh

sh

shn

mshw

w VRaRR

V

R

VVaRS

122

1

4

2

1

Note that in Quick Look, a = 1, b = 1, m = 2, and n = 2 are used.

WA

TE

RS

AT

UR

AT

ION

BY

HE

IGH

TM

ET

HO

DCAPILLARY PRESSURE TEST

7/2/2013


b

wirrw

Cw

aJSS

θσφk

PSJ

cos

Air/Brine Capillary Pressure Curves Height Function

Sw J

phi K Pc = 3 10 25 50 125 200 Pc = 3 10 25 50 125 200

0.131 67 0.861 0.617 0.388 0.29 0.239 0.216 0.204103 0.680343 1.700857 3.401713 8.504283 13.60685

0.058 3.7 0.963 0.874 0.782 0.673 0.597 0.525 0.072083 0.240277 0.600693 1.201387 3.003467 4.805547

0.032 3.8 0.942 0.85 0.739 0.638 0.572 0.512 0.098348 0.327826 0.819564 1.639128 4.097819 6.55651

0.179 278 0.73 0.43 0.282 0.214 0.176 0.144 0.355667 1.185555 2.963888 5.927777 14.81944 23.71111

By Height Method (Core – Derived)

Air – Brine: σ = 72 mN/m and cosθ = 1.0

WA

TE

RS

AT

UR

AT

ION

BY

HE

IGH

TM

ET

HO

DCAPILLARY PRESSURE TEST

7/2/2013


J Sw Swr

0.204103 0.8610 0.8510

0.072083 0.9630 0.9530

0.098348 0.9420 0.9320

0.355667 0.7300 0.7200

0.680343 0.6170 0.6070

0.240277 0.8740 0.8640

0.327826 0.8500 0.8400

1.185555 0.4300 0.4200

1.700857 0.3880 0.3780

0.600693 0.7820 0.7720

0.819564 0.7390 0.7290

2.963888 0.2820 0.2720

3.401713 0.2900 0.2800

1.201387 0.6730 0.6630

1.639128 0.6380 0.6280

5.927777 0.2140 0.2040

8.504283 0.2390 0.2290

3.003467 0.5970 0.5870

4.097819 0.5720 0.5620

14.81944 0.1760 0.1660

13.60685 0.2160 0.2060

4.805547 0.5250 0.5150

6.55651 0.5120 0.5020

23.71111 0.1440 0.1340

a = 0.5661998186b = - 0.2438141755

WA

TE

RS

AT

UR

AT

ION

BY

HE

IGH

TM

ET

HO

DWELL LOG

7/2/2013


Ø k J Sw, Archie's Swr, Archie's

0.105 16.8636202 0.446843867 0.35433 0.344326633

0.108 19.4889142 0.468355862 0.33127 0.321267025

0.110 20.9445552 0.477655366 0.32201 0.312007106

0.100 14.216226 0.40929451 0.35082 0.340816846

0.107 18.5675437 0.44892632 0.33137 0.321365235

0.114 23.8993968 0.49059544 0.31475 0.304747054

0.107 18.7325155 0.443160013 0.33175 0.321745432

0.108 19.0147217 0.442041139 0.3281 0.318099854

0.094 11.0721303 0.358402354 0.3626 0.352598808

0.084 7.4351486 0.308544252 0.38818 0.378180411

0.090 9.54795237 0.334119911 0.35731 0.347313127

0.100 13.8687379 0.379564768 0.33367 0.323671489

0.104 16.448463 0.401111103 0.33373 0.323730168

0.095 11.7755361 0.351243957 0.3718 0.361804195

0.094 11.0907928 0.34067488 0.38662 0.376624651

0.097 12.4143519 0.351889385 0.38358 0.373575631

0.098 12.9137295 0.353858069 0.38354 0.373537538

0.101 14.8086524 0.368979658 0.3735 0.363495791

0.114 23.8851379 0.438557374 0.34632 0.336320613

0.138 61.9090945 0.634659381 0.35063 0.340625203

0.163 165.802193 0.946077193 0.38402 0.37402167

0.160 144.317984 0.884136551 0.4081 0.398101448

0.149 93.2065776 0.730008312 0.40948 0.399482463

bwirrw

c

Cw

aJSS

depth

).-.(Pθσφk

PSJ

281.3)646(

433.0853200061cos

By Height Method(Log – Derived)

Air – Brine: σ = 72 mN/mand cosθ = 1.0

Water saturation by Archie’s method is selected.

WA

TE

RS

AT

UR

AT

ION

BY

HE

IGH

TM

ET

HO

DWELL LOG

7/2/2013


a = 0.33996b = - 0.21914

Ø k J Sw, Archie's Swr, Archie's

0.105 16.8636202 0.446843867 0.35433 0.344326633

0.108 19.4889142 0.468355862 0.33127 0.321267025

0.110 20.9445552 0.477655366 0.32201 0.312007106

0.100 14.216226 0.40929451 0.35082 0.340816846

0.107 18.5675437 0.44892632 0.33137 0.321365235

0.114 23.8993968 0.49059544 0.31475 0.304747054

0.107 18.7325155 0.443160013 0.33175 0.321745432

0.108 19.0147217 0.442041139 0.3281 0.318099854

0.094 11.0721303 0.358402354 0.3626 0.352598808

0.084 7.4351486 0.308544252 0.38818 0.378180411

0.090 9.54795237 0.334119911 0.35731 0.347313127

0.100 13.8687379 0.379564768 0.33367 0.323671489

0.104 16.448463 0.401111103 0.33373 0.323730168

0.095 11.7755361 0.351243957 0.3718 0.361804195

0.094 11.0907928 0.34067488 0.38662 0.376624651

0.097 12.4143519 0.351889385 0.38358 0.373575631

0.098 12.9137295 0.353858069 0.38354 0.373537538

0.101 14.8086524 0.368979658 0.3735 0.363495791

0.114 23.8851379 0.438557374 0.34632 0.336320613

0.138 61.9090945 0.634659381 0.35063 0.340625203

0.163 165.802193 0.946077193 0.38402 0.37402167

0.160 144.317984 0.884136551 0.4081 0.398101448

0.149 93.2065776 0.730008312 0.40948 0.399482463

WA

TE

RS

AT

UR

AT

ION

BY

HE

IGH

TM

ET

HO

DWELL LOG

7/2/2013


By Height Method

Well Log Data

DEPTH Ø k Sw, J-function(core) Sw, J-function(log)

622.706 0.052 2.19044222 0.545381099 0.462025012

622.859 0.055 2.40477814 0.543080802 0.460279053

623.011 0.063 3.31000569 0.532372818 0.452141439

623.164 0.064 3.41531467 0.532038556 0.451887144

623.316 0.074 5.03922487 0.517612075 0.44089611

623.468 0.099 13.7104602 0.476767666 0.40960301

623.621 0.100 13.8494764 0.477117332 0.409872052

623.773 0.100 13.8310332 0.47795058 0.410513094

623.926 0.104 16.6243445 0.47094172 0.405117352

624.078 0.098 12.9414196 0.482353649 0.413898589

depth...-.P

φkPSJ

J.derived:SLog

J.derived:SCore

c

Cw

w

w

6462813433085320006130cos30

0.33996010

0.56620100.21914-

-0.243814

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013


Cwa,1 1/Ø

28.82490988 6.695965717

31.20384849 6.980505292

35.5673039 7.122594401

34.47407835 6.804802809

32.33757941 6.518630667

30.16984244 6.305555941

28.73200079 6.147429009

30.05851878 6.163802499

31.73479695 5.960947462

32.72330458 5.883874669

By Waxman-Smits’s Method

c

c

wt

m

wa CRRC

111*

)/( toequalgradient

aon fall should points The

1/ represents cloud

data ofstart at value)(1/ The

1/R represents cloud

data ofstart at valueC The

:sandswater for

1/againt plotted is C

w

wa

wa

Cc

c

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013



Porosity FRF BQv F*

0.1 89.2785 13.51574 129.0985

0.15 44.0185 3.51629 49.12629

0.17 33.3675 1.163478 34.64861

0.08 133.3982 21.01533 225.9106

0.14 43.3121 4.944783 50.37972

0.13 58.2223 6.593044 70.88975

BQv=(0.182-Ø)(0.06067Ø)Rw = 0.033 Ωm

F* = (1+RwBQv)*FF* = Ø-m*

From plot: m* = 2.12685Recalculate Cwa using m*

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013


Cwa,2 1/Ø

49.46510247 6.695965717

54.18412057 6.980505292

62.11553047 7.122594401

59.43089616 6.804802809

55.07162847 6.518630667

50.89726934 6.305555941

48.12323674 6.147429009

50.38306811 6.163802499

52.68964439 5.960947462

54.13044084 5.883874669

By Waxman-Smits’s Method

c

c

wt

m

wa CRRC

111*

)/( toequalgradient

aon fall should points The

1/ represents cloud

data ofstart at value)(1/ The

1/R represents cloud

data ofstart at valueC The

:sandswater for

1/againt plotted is C

w

wa

wa

Cc

c

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013



Porosity FRF BQv F*

0.1 89.2785 13.51574 129.0985

0.15 44.0185 3.51629 49.12629

0.17 33.3675 1.163478 34.64861

0.08 133.3982 21.01533 225.9106

0.14 43.3121 4.944783 50.37972

0.13 58.2223 6.593044 70.88975

BQv=(0.182-Ø)(0.022Ø)Rw = 0.0206 Ωm

F* = (1+RwBQv)*FF* = Ø-m*

From plot: m* = 2.2223Using this m* and Rw

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013



Plug 2 (Ø = 15%) Plug 3 (Ø = 13%)

Sw I I* Sw I I*

1 1 1 1 1 1

0.8 1.541192 1.605343 0.9 1.297253 1.336529

0.6 2.660774 2.956117 0.7 2.353045 2.627834

0.5 3.783241 4.413144 0.6 3.247888 3.837892

0.4 6.397332 7.995049 0.55 3.986601 4.875389

0.5 5.242788 6.671378


Plug I (Ø = 17%)

Sw I= (Rt/Ro) I*

1 1 1

0.8 1.61592 1.640966

0.6 2.955611 3.077773

0.4 8.05591 8.80509

0.35 10.15069 11.31944

0.3 12.88598 14.7501

0.28 15.20306 17.6268

Rw = 0.0206n* = 2.40

02201820

1

1

* *

.-.BQ

BQR

ISBQR

SI

v

vw

w

vw

nw

n*

Ø = 17% 2.2794

Ø = 15% 2.2409

Ø = 13% 2.6884

average 2.40

Well Log Data

Rt Ø Sw, Waxman-Smits, 1 Sw, Waxman-Smits, 2 Sw, Waxman-Smits, 9 Sw, Waxman-Smits, 10

17.837 0.052 0.556811223 0.463050029 0.42025383 0.420236045

15.861 0.055 0.57131375 0.480559376 0.439828166 0.439812981

14.257 0.063 0.555507749 0.467613184 0.430149391 0.430138121

13.042 0.064 0.572721241 0.48723995 0.451179885 0.451169909

12.543 0.074 0.539645313 0.456469514 0.423517116 0.423509981

12.638 0.099 0.460098734 0.387068542 0.362706791 0.36270429

12.730 0.100 0.458084575 0.385107616 0.360785396 0.360782901

12.529 0.100 0.461215495 0.388407856 0.364194351 0.364191911

12.116 0.104 0.456468548 0.386634164 0.364395409 0.364393626

11.852 0.098 0.476312514 0.403331286 0.378945723 0.378943272

WA

TE

RS

AT

UR

AT

ION

BY

WA

XM

AN

-SM

ITS’S

ME

TH

OD

WELL LOG

7/2/2013


equation. of side handright on the S updatedlast

thereplacingby S erecalculat Then, equation. the

of side handright on the 1 S assuming Firstly,

40.2*2.2223, *m,02201820

0206.0,1

w

w

w

*1

*

n.-.BQ

mRS

BQR

R

RS

v

w

n

w

vwm

w

tw

WA

TE

RS

AT

UR

AT

ION

CO

MP

AR

ISO

NWELL LOG

7/2/2013


Petrophysical Properties Analysis

ZONE VSH ØDC ØNC Ø=ØDC Sw (Achi's law) Sw (Simandoux) PERM Sw (J-function, core) Sw (J-function, log) Sw (Waxman-Smits)

Zone 1 0.9532

Zone 2 0.2968 0.0880 0.0217 0.0880 0.4602 0.3822 10.9819 0.4965 0.4247 0.3981

Zone 3 0.1385

Zone 4 0.1694 0.1033 0.0459 0.1033 0.3934 0.3574 28.0055 0.5330 0.4523 0.3591

Zone 5 0.8028

Zone 6

0.1328 0.1389 0.0871 0.1389 0.6634 0.6184 86.9017 0.7031 0.5783 0.7480

0.1146 0.1185 0.0701 0.1185 1.0590 0.9768 76.7452 1.1458

Zone 7 0.8792

Zone 8 0.3521

Zone 9 0.3693

Zone 10 1.1081

Zone 11 0.5558

WA

TE

RS

AT

UR

AT

ION

CO

MP

AR

ISO

NWELL LOG

7/2/2013


RE

SE

RV

EWELL LOG

7/2/2013


factor recovery Er

(Er) * N R

:by defined are Reserves

fraction ,saturation water S

fraction porosity,

ft , thicknesszone individual h

rb/stbfactor,

volumeformation initial B

acres area, drainage A

stb place,in oil N

where,

)1(7758A

N

PlaceIn OilOriginal

wi

i

i

oi

1

n

iwiii

oi

ShB

Thickness

(m)

Petrophysical Properties Analysis

Ø Sw (simandoux)OOIP

(STB/Acre)

Zone 1 6.5

Zone 2 2.5 0.0880 0.3822 2,661.47

Zone 3 1.5

Zone 4 11 0.1033 0.3574 14,292.25

Zone 5 1.5

Zone 6

7 0.1389 0.6184 7,265.53

9.5 0.1185 0.9768

Zone 7 5

Zone 8 1.5

Zone 9 2

Zone 10 3

Zone 11 8

TOTAL = 24,219.25

Assumption:Oil: Boi = 1.3

SH

ALE

TY

PE

AN

ALY

SIS

WELL LOG

7/2/2013


The plot shows that the shale is primarily dispersed,

rather than structural or laminated.

PR

ED

ICT

ION

WELL LOG

7/2/2013


Geomechanical Properties

DT Vp1/DT

GRpredicted

DTS Vs1/DTS

Poison’s ratio

)V-2(V

)2V-(V=

2s

2p

2s

2p

DT Vp1/DT

GRlogging

DTS Vs1/DTS

Poison’s ratio

)V-2(V

)2V-(V=

2s

2p

2s

2p

corr

ela

tio

n

PR

ED

ICT

ION

WELL LOG

7/2/2013


GR and μ correlationAbove, GR = POW(u,2.254156303) * 812.7061971

Below, GR = POW(u,3.905678377) * 4267.399233

PR

ED

ICT

ION

WELL LOG

7/2/2013


Using GR and μ correlation to predict

the GR in other zone or other

regional well.

μ Predicted GR

0.378420039 90.91201561

0.378419462 90.91170355

0.378418384 90.91111957

0.378422457 90.91332525

0.378421849 90.91299579

0.378420065 90.91202983

0.375578573 89.38048712

0.375914103 89.56058142

0.376896556 90.08906997

0.37404725 88.56111468

0.371537422 87.22724171

0.378015569 90.69312586

0.378419567 90.91176036

0.378419132 90.91152478

0.37842171 90.91292067

PR

ED

ICT

ION

WELL LOG

7/2/2013


Artificial Neuron Network (GR)

PR

ED

ICT

ION

WELL LOG

7/2/2013


Using math lab program creating the

correlation between GR and other

parameter from logging.

GR ANN Predicted GR

60.000 59.79253767

60.000 77.33556865

60.000 53.22729087

60.000 34.88463445

60.000 34.57072593

60.000 43.71926552

60.000 42.85173103

60.000 39.8935741

60.000 45.86815259

60.000 59.41851046

60.000 71.15624479

60.000 61.90667877

60.000 54.01330694

60.000 58.1102058

60.000 58.45838785

PR

ED

ICT

ION

WELL LOG

7/2/2013


Artificial Neuron Network (DTS)

PR

ED

ICT

ION

WELL LOG

7/2/2013


Using math lab program creating the

correlation between DTS and other

parameter from logging.

DTS ANN Predicted DTS

116.075 111.2181392

112.566 111.5207757

113.092 112.5801029

114.117 110.2608527

116.652 108.5642262

118.931 112.9594443

118.622 113.876678

116.870 111.5680651

113.469 108.8263643

110.993 107.409617

110.227 106.3531217

109.704 106.5382806

110.172 107.3466881

110.800 108.3413241

110.498 112.0283234

DA

TA

AV

ER

AG

ING

CORE DATA

7/2/2013


n

i i

H

nG

n

ii

A

k

nk

knkkkk

n

kk

1

321

1

1

...

HGA

H

G

A

kkk

averageharmonick

averagegeometrick

averagearithmetick

Where

:

k

sV

n

kks

n

kk

k

i

n

ii

A

2

1

)(

tCoefficien

ParsonsDykstraV

deviationstandards

averagearithmetick

:

K

A

Where

THANK YOU

TH. Promsri

ID: 114338

WELL LOG INTERPRETATION

Documents

Transcript of WELL LOG INTERPRETATION