Duvernay Gas Liquids and Geomechanics ProjectWest-Central Alberta Duvernay Key WellImage Log-Core Correlation Crossplots

Petrophysical Analysis

Figure 30.1

Figures 30.2a-2c

Figure 30.3

Figure 30.2a Figure 30.2b Figure 30.2c

Fawkesplot Drilling Problem Summary - By Formation

Drilling Problem Summary - By Problem Type

Modeling

Figure 30.4

Figure 30.5a Figure 30.5b

Figures 30.5a, 5b

Figures 30.6a-e

2925

2930

2935

2940

2945

2950

2955

2960

2965

DST:

CUM. PROD. :

BY

CoregraphMetric 1:100

CA#PE

RFS

PERM(mD)

POROSITY(%)

FRA

C

DST R.R. :FIG.

Date Described :

0.1 1 60 12 1810 100

WELLNAME :

WELLLOCN :

CO

RE

CO

RR

’D

CO

RE

DR

ILLE

D

FM o

rU

NITDEPTH

m

PERFS:

AOF, OTHER:

PORETYPE DESCRIPTION

FIG #

OIL FACIES

CORE #:DIAM: SLAB:

RS

CONGL

FS

CSST

MSST

FSST

VFSST

GS PS WS MS

MSSILT

SHALE

SHALECARBONATE

CLASTIC

# BOXES: KB: GRAPHIC LITHOLOGYm

in. P of

Duvernay Gas Liquids and Geomechanics - West Central Alberta

WELLNAME :

WELLLOCN :

CORE INT. :WELL STATUS:

UNIT/FMENV.Sample,

PhotosPSFBIOTA,

GRAINTYPES

SED & BIOG.STRUCTURESBOUNDARY

TYPE

ACC/MOD.

ROCKTYPE

DEPTH(m)

LOG DEPTHfor coremarkers,

boundaries

TOTA

LCA

RB %

XRD

%TO

C DIAG.&

STRUC.FABRIC

STm ? ? ?

?PYRm

?

PYRm?

?

?SPIC

? ? ? ?

?

?

?

? ??

SILIC

IND

SILIC

PYR

PYRm

SPIC

VF

BPP

?

2,920

2,922

2,925

2,930

2,935

2,940

11-Oct-11

SCL KAYBOB 9-34-62-17 100/09-34-062-17W5/00

: G. R. Davies

none

Oil: 550 Bbl, Gas: 284 Mcf, Water: 967 Bbl

2933.0 ~ 2943.0m, 2934.5 ~ 2944.4 m

Jet Fracd 2934.5 ~ 2939.5

N-D GAMMA RESISITIVITY2922.0-2937.4, 2937.4-2960.0 m*

SCL KAYBOB 9-34-62-17 100/09-34-062-17W5/00

941.01 2

Flowing Oil 21AAug 2013

21A3,417 (37) 4.0

DUVERN2917.0 (-1976.0) [TVD] <S>

Diamond, conventional

Diamond, conventionalJET PERFORATIONFRACTURED

2900(-1959.0)

2925(-1984.0)

2950(-2009.0)

2975(-2034.0)

*

**

**

*

*

*

*

**

13.1

3.67

23.7

4.84

22.0

4.70

18.5

4.46

32.7

3.28

11.9

4.11

↑ ↑FR

Øn/m

FR

FR

Øn/m

Øn/m

Øn/m

FR

FR

FR

FR

IRE

TON

DU

VE

RN

AY

C5

C4

C3

C2

C1

B C

AR

BA

SH

ALE

MA

JEA

U L

AK

E

- P.1S.1

*became aware of additional

TerraTek depths marked on core

Plastic wrapped original, now stripped off. Pt. glued together (fracs)

some TRA (6 cm) foam plastic inserts out of place - not recorded

Found 20 boxes after completion(→do later)

DU

VER

NAY

: C

SH

ALE

DU

VER

NAY

: C

SH

ALE

87o Frac set, one calc. cementedS.2 : fine micritic calc grains in coarser laminae

black, non-calc/v. sl. calc : MFS?no obv. laminae

silty? microbioclastic styliolinid,m’pyrt laminae, v. calc

calc. thin coarser laminae, diagenetic cross-lam bdy top, basetwo fracs, at 85/87o one (at least)calcite cemented

coarser grain, silt?, styliolinid lags/laminae

less calc mx?

high angle NAT. m’fracs w/ calcite cmt in more calc mx, some open?

indistinct sharp based bed 3 - 4 cmless calc

1.5 cm lighter gy calcblk grains in coarser laminae

S.4: abundant150-160 µm

calcispheres,spicular

FRAC : segment cemented to coresuggesting 10-11 cm offset

- don’t trustless calc- max 43 cm calcite nodule/beds compactional drapessome BPP

fracs w/ hackle plumes; another frac set ≈ 90o to this - natural or induced (S.X1 ABCD)black grains

Perfed zone - many fractures some nat., some induced

S.6 : chalcedonic silica cement burrowed at base?orthogonal frac set, one (at least) w/ hackle plumesexc. hackle plume

S.7 : chalcedonic silica in m’lensoid clusters

FRAC, glued - prob nat. but can’t see facesharp based blk grain bed, burrowed, less calc., ‘oily’ below, small plug

less laminae

orthogonal frac set ?

S.8 : v. silty laminae; less chal’c silica cf. S.7?- Frac zone may correspond

to cleaner gammafracs, VIF, orthogonal but also not?

Note : intervals w/ BPP are lesscalc than frac’d zones

- some BPP

S.9 in ≈ BPP intervalmany fractures are cemented

in place - poor practice -unable to see frac. face

eg. for hackle plume = induced

*

cleangammaspike

2934.1mhigh

neutronspike

prob highgammaspike

2935.1m

16.5abovemaincarbtop

ca. highgamma2938.9

2937.1?

mayincl.

cleanergamma2935.6

to2936.2

- S.2A,B- P.X1

- S.3

- P.3- P.4

- S.4P.5

- P.6

- P.7- S.5

- P.8

- P.X2

- P.X3

- S.6- P.11

P.9

- P.12

- S.7

- P.13- P.14

P.15- P.16

- P.17

- S.8A, B

- P.18

- P.19S.10

- S.9A, B

Preserved core (not described)or core removed for RMA/TRA

*

P.10

S.X4

- S.X1

Fracs, orthogonal

S.X4 : coarser bioclastic sandy lime PS w/ spicules, thick-walled calcispheres, MS interlaminae

S.8,9,10,11 : silty lam’d MS

B Carbonate correlates wellby resistivity log to

B Carbonate in updip well #20

DVF.2C

DVE.2C

DVF.2C

DVE.2C

DVF.2A

DVE.2A

DVF.6/2C

DVE.26/C

DVF.6 DVE.6

DST:

CUM. PROD. :

BY

CoregraphMetric 1:100

CA#

PER

FS

PERM(mD)

POROSITY(%)

FRA

C

DST R.R. :FIG.

Date Described :

0.1 1 60 12 1810 100

WELLNAME :

WELLLOCN :

CO

RE

CO

RR

’D

CO

RE

DR

ILLE

D

FM o

rU

NITDEPTH

m

PERFS:

AOF, OTHER:

PORETYPE DESCRIPTION

FIG #

OIL FACIES

CORE #:DIAM: SLAB:

RS

CONGL

FS

CSST

MSST

FSST

VFSST

GS PS WS MS

MSSILT

SHALE

SHALECARBONATE

CLASTIC

# BOXES: KB: GRAPHIC LITHOLOGYm

in. P of

Duvernay Gas Liquids and Geomechanics - West Central Alberta

WELLNAME :

WELLLOCN :

CORE INT. :WELL STATUS:

UNIT/FMENV.Sample,

PhotosPSFBIOTA,

GRAINTYPES

SED & BIOG.STRUCTURESBOUNDARY

TYPE

ACC/MOD.

ROCKTYPE

DEPTH(m)

LOG DEPTHfor coremarkers,

boundaries

TOTA

LCA

RB %

XRD

%TO

C DIAG.&

STRUC.FABRIC

m

PYR

PYRm

??

?

INC

?

2,942

2,945

2,950

2,955

2,960

2,964

11-Oct-11

SCL KAYBOB 9-34-62-17 100/09-34-062-17W5/00

: G. R. Davies

none

Oil: 550 Bbl, Gas: 284 Mcf, Water: 967 Bbl

2933.0 ~ 2943.0m, 2934.5 ~ 2944.4 m

Jet Fracd 2934.5 ~ 2939.5

N-D GAMMA RESISITIVITY

SCL KAYBOB 9-34-62-17 100/09-34-062-17W5/00

941.02 2

Flowing Oil 21BAug 2013

21B3,417 (37) 4.0 2922.0-2937.4, 2937.4-2960.0 m*

DUVERN2917.0 (-1976.0) [TVD] <S>

Diamond, conventional

Diamond, conventionalJET PERFORATIONFRACTURED

2900(-1959.0)

2925(-1984.0)

2950(-2009.0)

2975(-2034.0)

24.0

3.87

24.2

4.99

FR

FR

FR

FR

Øn/m

Øn/m

IRE

TON

DU

VE

RN

AY

C5

C4

C3

C2

C1

B C

AR

BA

SH

ALE

MA

JEA

U L

AK

E

- P.20

S.11 A,B

*became aware of additional

some TRA (6 cm) foam plastic inserts out of place - not recorded

DU

VER

NAY

: C

SH

ALElime MS w/ argill seams - out

of place : probablybelongs in core interval≈ 2452 - 2452.5 m

Nat. fracs

Nat. fracs, w/ calcite

orthogonal set of nat. fracs

very finely lam’d (acid wash differentiate) seasonal/annual? sl. coarser micrograin layer, some laminae w/ many calcite-filled styliolinids, few buff claystone

more calc., thicker MS bedsbdy missing

ca. 50 cm, v. unusual; dark ‘oil wet’appearance, non-wetting/beadingsl. calc, w/ vertical induced?/ ‘fluted’fracture swarms, and poss.cleavage parallel to fracture :‘friable’ - in RMA 8, 9 bags -no boundaries in core

marked : TopCooking Lakeon tab in core box

ca. 50 cm interval of darker ‘oily’ burrowed finely lam’d, calc MS, cf. ‘Duv MS’ but no preserved top/base - ‘out ‘of place’; boundaries - suspicious

poss. incipient cleavage

out of place

shown schematically

plugs taken at varioushorizons throughout

- poss. incipient cleavage parallel to calc.-lined frac

darker MS, less lime MS

lime MS nodule and beds withcalc. argill interbeds/laminae,

with subvertical parallel fractures

recorded end Core 4

darker MS, less calc MS interbeds

- P.21

- P.22

S.12

- P.23.24

- P.25

S.13

- P.26

- P.27

S.14

- P.28 A,B

- P.29

- P.30

cleanergammacentred

at2951.3m

P

highgammaspike

2952.3 m

majorgammashoulder2953.7 m

lowerdensity

≈2961.5 m

DU

VER

NAY

: B

CA

RB

S.14 : lime MS

B Carbonate correlates wellby resistivity log to

B Carbonate in updip well #20

DVF.2A/2C

DVE.2A/2C

DVF.5/1A

DVE.5/1A

DVF.5/1A

DVE.5/1A

0 10 20 30DRILLING DAYS

3000

2500

2000

1500

1000

500

0

MD

(ME

TRE

S)

0 5 10 15 20LATERAL OFFSET

(METRES)

3000

2500

2000

1500

1000

500

0

TVD

(ME

TRE

S)

1

2 3

4-67-8

1

2,3,6

5

4

7,8

AB

C

D

EFGH

IJKLM

NO

P

Q

RSTUVWXYZAABBCCDD

Cross Sectional ViewDrilling Days vs MD

3000

2500

2000

1500

1000

500

0

TVD

(ME

TRE

S)

244.5mm surface casing139.7mm production liner

Casing Depth & Size

MW (kg/m3)

Spud Date: September 21, 2011Rig Release: October 7, 2011License No.: 0435925Surface Location: 100/09-34-062-17W5/00UWI: 100/09-34-062-17W5/00GL: 935.0m TVD: 2974mKB: 941.0m MD: 2974m

Total Drilling Cost: $3,736,000

FORMATIONS/ ZONESA: Lea Park P: WinterburnB: Colorado Q: WoodbendC: Cardium SS R: Ireton FD: Second White Specks S: Ireton EE: Base of Fish Scales T: Ireton DF: Viking U: Ireton CG: Joli Fou V: Ireton BH: Mannville W: Duvernay C5I: Fernie X: Duvernay C4J: Nordegg Y: Duvernay C3K: Shunda Z: Duvernay C2L: Pekisko AA: Duvernay C1M: Banff BB: Duvernay BN: Exshaw CC: Duvernay AO: Wabamun DD: Cooking / Majeau Lake

Geomechanics Notes1: Gel Chem mud type.2: Bridge.3: Cored from 1946.8-1965m with

100% recovery.4: Back reamed from 2530-2430m.5: Reamed from 2131-2560m.6: Reamed from 1952-1959m. Reamed

and cleaned from 2119-2855m.7: Cored from 2922-2937m with

15.4m recovered.8: Cored from 2937.4-2960m with

100% recovered.

Sonic LogsImage Log Graphic Core Description

Gamma

Young’s Modulus

(GPa)

Poisson’s Ratio

(GPa)

BRRickman

(GPa)Young’s Modulus

(GPa)

BRClay

%

Poi

sson

’s R

atio

TOC

Quartz Content (V/V)

Eps

BRClay

Porosity

No Fractures(Strong Rock)

No or Low Frequency of Fractures (Ductile Rock)

0.00

0.00

0.05

0.05

0.10

0.10

0.15

0.15

0.20

0.20

0.25

0.25

20 20

30 30

40 40

50 50

60 60

70 70

80 80

41.00

Youn

g’s

Mod

ulus

(GP

a)

Illite Content (V/V)

Porosity

No Fractures(Strong Rock)

No or Low Frequency of (Ductile Rock) Fractures

Log-derived Young’s modulus versus clay content

Poisson’s ratio versus total organic content (TOC)

Plane-strain Young’s Modulus (Eps) versus clay-based mineralogical brittleness index (BRClay)

The critical pressure change required for reactivation of existing fractures. This upper hemisphere diagram shows the change of pore pressure required to reactivate fractures in different orientations and azimuths. Hot colors indicate that it is more likely to reactivate the fracture; whereas, cold colors indicate a higher critical pore pressure is required.

Actual borehole stresses with mud weight of 1,180 kg/m3. Borehole stresses when tensile fractures occur.

BreakoutWidth

Borehole Breakout

Borehole Breakout

Borehole Breakout

Induced Fractures

IRETON

WABAMUN

BANFF

NORDEGG

2WS

CARDIUM SS

DVRNCOOKING LK

COLORADO

BASE OF FISH SCALESVIKING

SHUNDAPEKISKO

EXSHAW

LEA PARK

MANNVILLE GRPJOLI FOU

WINTERBURN

FERNIE

Breakout Initiation

Breakout Width at the Tolerated Limit

Actual Mud Weight

Mud WindowUnstable Borehole

Circulation Lost

Bridge and reaming

Multiple reaming

Drilling Experience

WOODBEND

0

300.0

400.0

500.0

600.0

700.0

800.0

900.0

1000.0

1100.0

1200.0

1300.0

1400.0

1500.0

1600.0

1700.0

1800.0

1900.0

2000.0

2100.0

2200.0

2300.0

2400.0

2500.0

2600.0

2700.0

2800.0

2900.0

5 10 15 20 25 30 35 40 45

Stress [MPa]

Mea

sure

d D

epth

[M]

Mea

sure

d D

epth

[M]

100/09-34-062-17W5/00(whole well)MXMUD PW MNMUDCT MNMUDC

Tolerated brk width : 90Scale 1 : 14000.0

Angle clockwise from HIGH SIDE of hole (deg)

Tolerated brk width : 90Scale 1 : 14000.0MCL MCR TL TR

0

2900.0

2800.0

2700.0

2600.0

2500.0

2400.0

2300.0

2200.0

2100.0

2000.0

1900.0

1800.0

1700.0

1600.0

1500.0

1400.0

1300.0

1200.0

1100.0

1000.0

900.0

800.0

700.0

600.0

500.0

400.0

300.0

30 60 90 120 150 180 210 240 270 300 330 360

Borehole Breakout

BreakoutWidth

Borehole Breakout

Induced Fractures

IRETON C

DVRN C3

IRETON B

IRETON F

IRETON D

IRETON E

DVRN C5

DVRN C2

DVRN BDVRN A

COOKING LK

DVRN C4

DVRN C1

WOODBEND

Mud Window

Unstable Borehole

Circulation Lost

Breakout Initiation

Breakout Width at the Tolerated Limit

Actual Mud Weight

100/09-34-062-17W5/0(Ireton and Duvernay

formations)

Drilling Experience

Reaming

20.0 25.022.5 27.5 30.0 32.5 37.535.0 40.0 42.5 45

Stress [MPa]

2850.0

2875.0

2900.0

2925.0

2950.0

2825.0

2800.0

2775.0

2750.0

2725.0

Mea

sure

d D

epth

[M]

Mea

sure

d D

epth

[M]

MXMUD PW MNMUDCT MNMUDCTolerated brk width : 90

Scale 1 : 1500.0

Angle clockwise from HIGH SIDE of hole (deg)

Tolerated brk width : 90.0Scale 1 : 1500.0MCL MCR TL TR

0

2950.0

2925.0

2900.0

2875.0

2850.0

2825.0

2800.0

2775.0

2750.0

2725.0

30 60 90 120 150 180 210 240 270 300 330 360

Figure 30.6a

Figure 30.6b

Figure 30.6cFigure 30.6d

Figure 30.6e

MW at which tensile cracks will form (lost circulation risk)

minimum MW needed to prevent breakouts entirely

minimum MW needed to prevent breakouts wider than tolerated limit

Min/Max Mud WeightTolerated brk width = 60, UCS = 49.00 MPA, pp= 47.49 MPa / 1.63G/CM3 TVDrkb: 2968.75M

110

100

90

80

70

60

Mud

Wei

ght (

MPA

) [M

ohr-

Cou

lom

b]

Equ

ival

ent D

ensi

ty (G

/CM

3)

Deviation [Hole Azimuth = 135]

MaxMud MaxMudMinMudTol MinMudTolMinMud MinMud

Hole Azimuth [Deviation = 90.00]

50

40

30

20

10

00 10 20 30 40 50 0 50 100 150 200 250 300 35060 70 80 90

0.00

0.25

0.50

0.75

1.00

1.25

1.50

1.75

2.00

2.25

2.50

2.75

3.00

3.25

3.50

3.754.00 Omega describes the

angle of inclined tensile fractures

omega

Requires ~ 100 MPa of�uid pressure to initiatetensile failure, which will�rst occur on the sides ofthe hole and will beoriented parallel to theborehole axis.

Effective principal borehole wall stresses Effective principal borehole wall stresses

120

1307065

6055

5045

4035

3025

2015

105

0

110

100

90

80

70

60

50

40

30

20

10

00 25 50 75 100 125 150 175 200 225 250 275 300 325 350

Effe

ctiv

e S

tress

(MP

a)

Effe

ctiv

e S

tress

(MP

a)

0102030405060708090100110120130140150160170180

Om

ega

(deg

)

Angle clockwise from NORTH of hole (deg)

Max Tangential Min Tangential To Radial

0 25 50 75 100 125 150 175 200 225 250 275 300 325 350Angle clockwise from NORTH of hole (deg)

Max Tangential Min Tangential To Radial Omega

Cohesion = 0 MPACritical Pressure Perturbation (ΔP method)

37.5

35.0

32.5

30.0

27.5

25.0

22.5

20.0

17.5

15.0

12.5

10.0

7.5

5.0

2.5

0.0

ΔP

[MPA

]

Poles to planesWULFF ProjectionUPPER HemisphereBorehole

Gamma, elastic properties and brittleness logs and core description.

1

Bridge

N=1

1

1

1

1

1

1

2

1

Overpull/Ream & Back Ream

N=9

1

1

1

1

11

1

2

1

ALL PROBLEMS

1

Winterburn

N=1

1

Wabamun

N=2

1

Exshaw

N=1

1

Banff

N=1

1

Nordegg

N=1

1

Fernie

N=1

1

Ireton D

N=1

1

Ireton E

N=1

1

Ireton F

N=1

9

1

ALL FORMATIONS

The results of borehole stability modeling for the entire well and a zoom up for the Ireton and Duvernay formations.

Introduction

The key well in the Kaybob area has been selected as a key well due to the

availability of different sets of data including core description, image log, sonic

log, petrophysical analysis and drilling experience.

Core Description, Image Logs, and Elastic Proper ties

As shown in Figure 30.1, a strong consistency exists between the location and

types of fractures observed in both image log and core. Most of the fractures

observed in these figures have been classified as nested petal fractures induced

by drilling and/or coring, and these fractures are also observed in the core. The

vertical fractures that only appear on the image log, but have not been mapped in

the corresponding core are considered to be stress-induced, borehole wall tensile

fractures. The gamma log and log-derived Young’s modulus and Poisson’s ratio

show a very good correlation with the location of the observed induced fractures.

Also, variation of plane-strain Young’s modulus (Eps) and Rickman’s brittleness

index (BRRickman) calculated using elastic properties (see Poster 24 on rock properties

for the equations) seem to be consistent with the location of these fractures.

Among these two parameters, plane-strain Young’s modulus (Eps) seems to be

more representative of mechanical behaviour of the rock with a more consistent

location of fractures. The fractures disappear on the image log and cores in two

cases: (i) where Eps is very high and it is likely that the rock is too strong to be

naturally fractured in shear, as observed in the Duvernay B zone, and (ii) where

Eps is very low and, presumably, the rock is too ductile.

Mineralogy

A detailed petrophysical analysis has been performed for this well, and the rock

mineralogy has been determined as shown in Figure 30.3. A comparison between

the log-derived elastic properties and mineralogy of the rock shows strong

correlations between Young’s modulus, clay content and porosity of the rock

(Fig. 30.2a). In addition, there is a good correlation between Poisson’s ratio, total

organic content (TOC), and the quartz content of the rock as shown in Figure 30.2b.

Mineralogical brittleness index based on clay content (BRClay) that is calculated

using the mineralogical composition of the rock (see Poster 24 on rock properties

for the equation) proves to be very consistent with plane-strain Young’s modulus

(Eps) as can be seen in Figure 30.2c. According to this figure, BRClay can also be

considered to generally represent the fracturing potential of the rock.

Drilling Experience and Borehole Stability Modeling

Drilling experience for this well has been documented in the Fawkesplot shown

in Figure 30.4. This plot captures the major geomechanics issues during drilling

along with information on well trajectory, drilling days, casing and mud weight. A

summary of drilling issues for each formation is shown in Figures 30.5a, 5b. The

observations from drilling experience and image log have been used to determine

and validate the stress tensor. The results of modeling, which are shown in

Figures 30.6a, 6b, include the mud window required for stable drilling, as well

as the actual mud weight during drilling. This figure shows a good consistency

between the modeling results and reported problems during drilling. Compared

to the Duvernay C zone, a higher horizontal stress value has been used for the

Duvernay B zone in this modeling to match the observations on the image log. This

assumption seems to be a valid considering the higher strength of this zone. The

lower part of the Ireton Formation just above the Duvernay Formation has been

assumed to be influenced by the high pore pressure of the latter.

The left-hand plot on Figure 30.6d shows the wellbore stress concentration for a

theoretical horizontal well drilled in a NW-SE direction in the Duvernay Formation

(2,969m TVD) with the maximum mud weight of 1,180 kg/m3 that was used for

drilling this key well. When the minimum tangential stress drops below zero, the

wellbore is in tension (for an introduction on the wellbore stress concentration

see Poster 28 on modeling). When it drops below the tensile strength of the rock

(less than 10 MPa for most rocks), tensile cracks will form. The right-hand plot

shows that when a fluid pressure of 100 MPa is applied, the hoop stress around

the borehole wall drops below zero, and the first part of the well that will go into

tension is on the sides of the hole. It also shows that omega, which defines the

angle the tensile cracks will form with respect to the wellbore axis, is approximately

zero, so tensile cracks (or initial hydraulic fractures) will essentially be parallel to

the wellbore axis. In the case of the strike-slip stress state in this area, hydraulic

fractures are expected to be vertical and propagate to the NE and SW. Since this

well was drilled parallel to the SE, the initially formed fracture will ultimately re-

orient itself to propagate in these directions.

Figure 30.6e is an upper hemisphere stereonet plot that shows the amount of

additional fluid pressure required to put pre-existing fractures with any azimuth

and dip angle into a critically-stressed state in the area in which this well was

drilled (for an introduction on critically-stressed fractures see Poster 28 on

modeling). According to this plot, a large population of moderately- to steeply-

dipping fractures dipping to the N, S, E, W, SE and NW require just a few MPa of

additional pressure to become critically-stressed assuming a sliding friction angle

of 30°. Highly-deviated wells drilled in these directions are most likely to encounter

such fractures if they exist in the subsurface.

* all the stress and wellbore stability modeling in this project have been performed

using Vinland Software Suite®.Duvernay Gas Liquids and Geomechanics Project

West-Central Alberta

Duvernay Key Well

CanadianDiscoveryLtd.

Project DVRN-1 File Name *.indd

Database N/A

Created 05/15/2014

Last Edited 10/30/2014

Author M.Soltanzadeh/S. Jia

Graphics P. Patton

Reviewer D. HumeCopyright © 2014 Canadian Discovery Ltd. All Rights Reserved

Poster

30