dfit2 mini-frac' fall-off

$: DFIT2 Mini-frac' Fall-off$
eREPORT

Prepared for:Diana Engineer

Alberta Oil & Gas Company2000 300 4th A en e SW2000, 300 – 4th Avenue SWCalgary, Alberta, T2P 4A5

Welltest AnalysesG-function, PITA, PTA, AOF

AOGC Wildling100/01–02–030–04W5/06

Cadmium Perf’, Frac’ & Clean-up: Jul 18 – Aug 1, 2010g

Mini-frac’ Fall-off Test (DFIT): Jul 19 – 23, 2010

www.welltestspecialists.com [email protected]

Accreditation

Redress

403–256–5767403–561–0409

www.welltestspecialists.comMo da Ma 30 2011

If you have any queries, comments or amendments or wish to discuss these results, please feel free to contact the undersigned.

Respectfully,Welltest Specialists Inc. P11334A th d b Monday, May 30, 2011

[email protected]

Authored by:

David Leech, BTech, PL(Eng) M115837Co-PresidentCo President

Analytical Results Summary

AOGC Wildling 100/01-02-030-04W5/06

y yG-function Analysis

Cadmium Fluids

2151.0 – 2158.0 mKB-MD Gas = SG

2151.0 – 2158.0 mKB-TVD Oil = 0.870 SG

2146.1 – 2153.1 mCF-TVD Water = SG

Pressures G-Function

pbd = 45 093 kPaa Gc = 2.547

pinj = 40 968 kPaa tc = 0.846 h

p = 40 232 kPa p = 35 613 kPapisi = 40 232 kPaa pc = 35 613 kPaa

pfinal = 25 092 kPaa Grad. = 18.72 kPa/m

p* = 24 306 kPaa Inj. Vol. = 7.326 m3

Comments May 30, 2011

Pressure data were quite scattered and “noisy” – probably as a function ofwellbore hydrodynamics and/or phase redistribution. Leak-off type appearedto be “normal” – i.e. natural fracture behaviour was not apparent. Derivativedata presented a negative unit slope (−1) suggesting that pseudo-radial flowhad been achieved.

Analytical Results Summaryy yPITA & Slug Analyses

AOGC Wildling 100/01-02-030-04W5/06

Cadmium Petrophysical Fluids

2151.0 – 2158.0 mKB-MD h = 9.5 m Gas = SG

2151.0 – 2158.0 mKB-TVD = 9.3 % Oil = 0.870 SG

2146.1 – 2153.1 mCF-TVD Sw = 33.4 % Water = SGw

Pressures Radial Model Perforations

pinitial = 45 093 kPaa ko = 0.2 mD Gun (n) = 5.0 m

pfinal = 25 092 kPaa kh = 2.1 mDm SPM = 17

p* = 24 411 kPa s = −2 9 Ø (d) = 8 mmp PITA = 24 411 kPaa sd = −2.9 Ø (d) = 8 mm

p*SLUG = 24 410 kPaa hp = 0.68 m


Radial flow conditions were identified by the flattening of the PITA derivative and negative unit slope (1:1) exhibited onthe Slug derivativethe Slug derivative.

Analytical Results Summary

AOGC Wildling 100/01-02-030-04W5/06

y yRadial Flow Analysis

Cadmium Petrophysical Fluids Reserves

2151.0 – 2158.0 mKB-MD h = 9.5 m Gas = SG OOIP = e3m3

2151.0 – 2158.0 mKB-TVD = 9.3 % Oil = 0.870 SG A = 259 ha

2146.1 – 2153.1 mCF-TVD Sw = 33.4 % Water = SGw

Pressures Radial Model Deliverability Stabilized

pinitial = 45 093 kPaa ko = 1.4 mD qg = 5.1 e3m3/d

pfinal = 25 092 kPaa kh = 13.2 mDm AOF = e3m3/d

p = 24 858 kPa s = –1 78 TOF = 5 1 e3m3/dpi(syn) = 24 858 kPaa sd = –1.78 TOF = 5.1 e3m3/d

pwf = 40 232 kPaa rinv = 454 m Q = 46.5 e3m3

pwhd = kPaa N = 97.1 m3

ptf = kPaa W = 0.0 m3


Surface pressure fall-off data exhibited three (3) distinct anomalies: a 730 kPa pressure shift immediately after shut-in (a “hammer effect”) was followed 5 hlater by a break in pressure decline, and a subsequent shift in fall-off trend. Bottomhole pressure calculations assumed a static oil column to MPP. Pressurefall-off data were analyzed in terms of ∆t to remove injection (flow) rate & time errors.

Pressure derivative patterns beyond the anomalies appeared radial in nature such that a Vertical model was employed for analysis Quantitative results werePressure derivative patterns, beyond the anomalies, appeared radial in nature such that a Vertical model was employed for analysis. Quantitative results wereindicative of fair permeability to oil (ko) and a slightly improved near wellbore region (negative skin, sd) consistent with the brief mini-frac’ treatment. Naturalfracture or dual-permeability behaviour could not be definitively interpreted from the data. Usually manifesting as parallel slopes on the semi-log plot, and adouble-hump on the derivative plot, perhaps the fall-off was of insufficient duration for the derivative (which was declining) to return…

Data Validation—Production

Alberta Production Testing Ltd.

Perf', Frac' Clean-up & Single Point TestAOGC W ildling100/01-02-030-04W 5/06Cadmium OilJul 18 - Aug 1, 2010

Alberta Oil & Gas Company2151.0 - 2158.0 mKBgg ,

22000

24000

26000

30

32

34

36

200

220

240Legend

Tubing PressOil RateCasing PressGas Rate (Inst)

End Primary Frac', Begin Frac' Clean-upDate Time 2010-07-24 12:45:00 PM

18000

20000

24

26

28

160

180

Flow Point Used for AOFDate Time 2010-07-30 01:00:00 PMGas Rate (Inst) 5.115Tubing Press 450

Casing Press 24420

12000

14000

16000

ubin

g Pr

ess

(kPa

(a))

asin

g Pr

ess

(kPa

(a))

16

18

20

22

Gas R

ate (Inst) (10 3m3

120

140

Oil R

ate (m3/d)

gOil Rate 0.960

8000

10000

Tu C

10

12

14

3/d)

60

80

100

2000

4000

6000

2

4

6

8

20

40End PID w/o Mini-frac' & Fall-off TestDate Time 2010-07-19 09:00:00 AMCasing Press 1185

0 0000 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12 00 12

07/18/10 07/19/10 07/20/10 07/21/10 07/22/10 07/23/10 07/24/10 07/25/10 07/26/10 07/27/10 07/28/10 07/29/10 07/30/10 07/31/10 08/01/10

Data Validation—Recorders

Mini-frac’ Fall-off Test (DFIT)( )G-function Analysis

Total Test

G-function AnalysisAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010

Alberta Oil & Gas Company2151.0–2158.0 mKB,

42000

44000

Inj . Volume 7.326 m3

ISIP 40232 kPa(a)Ddatum 2149.600 mFrac grad 18.72 kPa/m

Breakdown

t 0.06 h t 0.05 hpdata 45093 kPa(a)

Stop Injection

t 0.37 h

36000

38000

40000 t 0.37 hpdata 40968 kPa(a)

Initial Shut-in

t 0.38 h t 0.00 hpdata 40232 kPa(a)

30000

32000

34000

Pres

sure

(kPa

(a))

pdata ( )

Final Pressure

t 86.56 h t 86 19 h

24000

26000

28000

P

Pressure Anomaly

t 5.40 h t 5.03 h

t 86.19 hpdata 25092 kPa(a)

18000

20000

22000

pdata 29826 kPa(a)

160000 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85

Time (h)

pdata


Total Test

G-function AnalysisAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


43000

44000

45000Inj . Volume 7.326 m3


Breakdown

t 0.06 h t 0.05 hpdata 45093 kPa(a)

Stop Injection

40000

41000

42000

Stop Injection

t 0.37 h t 0.37 hpdata 40968 kPa(a)

Initial Shut-in

37000

38000

39000

Pres

sure

(kPa

(a))

t 0.38 h t 0.00 hpdata 40232 kPa(a)

34000

35000

36000

P

30000

31000

32000

33000

Pressure Anomaly

t 5.40 h t 5.03 hpdata 29826 kPa(a)

29000

30000

0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00 4.20 4.40 4.60 4.80 5.00 5.20 5.40

Time (h)

pdata


G-Function

AOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010

Alberta Oil & Gas Company2151.0–2158.0 mKB

17 84

Fracture Closure

Gc 2.547 t 0.85 h tc 50.75 mintc 72 95 min

t 0.00 hp 40232 kPa(a)

14

15

16

17

500

550

76

78

80

82

84Semilog Derivativepdata

First Derivative

Inj . Volume 7.326 m3


Analysis 1

Fracture Closure

Gc 2.547 t 0.85 h

tc 72.95 minpc 35613 kPa(a) 56.01 %pnet 4619 kPa

11

12

13

Pa2 /

Pa.s

)

400

450

First 68

70

72

74

76 tc 50.75 mintc 72.95 minpc 35613 kPa(a) 56.01 %pnet 4619 kPa

8

9

10

vativ

e G

dp/

dG

(106

kP

250

300

350

tDerivative dp/dG

(

60

62

64

66

68

p (10 6kPa 2/Pa.s)

5

6

7

Sem

ilog

Der

iv

150

200

50 10 6kPa 2/Pa.s)

54

56

58

60

Fracture Closure

Gc 2.547 t 0.85 h tc 50.75 mintc 72.95 min

35613 kP ( )

1

2

3

4

50

100

46

48

50

52pc 35613 kPa(a) 56.01 %pnet 4619 kPa

Pressure Anomaly

t 5.00 hp 29819 kPa(a)

t 86.19 hp 25092 kPa(a)

0 042

44

0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38

G-function time


MiniFrac Sqrt(t)



200084

Fracture Closure

t 0.85 h

20

22

1700

1800

1900

2000

76

78

80

82

84Semilog Derivativepdata

First Derivative

Inj. Volume 7.326 m3


t 0.85 h tc 50.75 mintc 72.95 minpc 35613 kPa(a)pnet 4619 kPa

16

18

(106

kPa2

/Pa

.s)

1300

1400

1500

1600

First De68

70

72

74

76Fracture Closure


10

12

14

ve

(t1/

2 ) d

p/d(

t1/2 )

900

1000

1100

1200

erivative dp/d(t 1/2) 60

62

64

66

68

p (10 6kPa 2/Pa.s)

6

8

0

Sem

ilog

Der

ivat

iv

500

600

700

800

(10 6kPa 2/Pa.s)

52

54

56

58

60

Fracture Closure

t 0 85 h

2

4

100

200

300

400

44

46

48

50

52 t 0.85 h tc 50.75 mintc 72.95 minpc 35613 kPa(a)pnet 4619 kPa

0 0

100

42

44

0.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50 4.00 4.50 5.00 5.50 6.00 6.50 7.00 7.50 8.00 8.50 9.00 9.50 10.00

t1/2 (h)


Derivative



102

3

4

5

6

8Inj. Volume 7.326 m3


Fracture Closure

t 0.85 h tc 50.75 min

101

8

2

3

(106

kPa2

/Pa

.s)

tc 72.95 minpc 35613 kPa(a)pnet 4619 kPa

Slope -3/4

3

4

5

6

8

ativ

e (

t a)d

/d(

t a)

Fracture Closure


Slope -1

1.0

6

8

2

, Sem

ilog

Der

iva pnet 4619 kPa

2

3

4

5

10-1

10-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

Pseudo-Time (h)

data

Derivativedata

Perforation Inflow Diagnostic (PID)Testg ( )PITA Results

Total Test

PITA AnalysisAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


42000

44000

-600

-400

-200

0

t 0.06 h t 0.05 hpdata 45093 kPa(a)

36000

38000

40000

-1400

-1200

-1000

-800

30000

32000

34000

Pres

sure

(kPa

(a))

-2200

-2000

-1800

-1600

Liquid Rate (m

3/d

t 86.56 h t 86.19 h

24000

26000

28000

P

-3000

-2800

-2600

-2400

d)

pdata 25092 kPa(a)

18000

20000

22000

-3800

-3600

-3400

-3200

16000 -4200

-4000

0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85

Time (h)

pdata

qoil


Typecurve


Alberta Oil & Gas Company2151.0–2158.0 mKByp,

104

105

2

3

5

Derivativedata

Radial 0

k 0.2202 mDp* 24411 kPa(a)

103

2

3

5

(kP

a h)

p 24411 kPa(a)

Slope 1.75

s' -2.910

102

5

2

3

5

vativ

e (

t)2 d

p/d(

t)

101

3

5

2

3

Impu

lse

Der

iv

1.0

2

3

5

2

3

10-1

2

10-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

Real Time (h)


Early Time



40000

40200

39400

39600

39800

39000

39200

p (k

Pa(a

))

38600

38800

Analysis 1

s' -2.910

38200

38400

38000

0.00 0.01 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.09 0.10 0.11 0.12 0.13 0.14 0.15 0.16 0.17 0.18 0.19 0.20 0.21 0.22 0.23 0.24 0.25 0.26

t (h)

pdata


Late Time



29200

29600

28000

28400

28800Analysis 1

k 0.2202 mDp* 24411 kPa(a)

27200

27600

28000

p (k

Pa(a

))

26400

26800

25600

26000

25200

0.000.010.020.030.040.050.060.070.080.090.100.110.120.130.140.150.160.170.180.190.20

1 / t (h-1)

pdata

Perforation Inflow Diagnostic (PID)Testg ( )Slug (Impulse) Results

Derivative

Slug DiagnosticAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


105

2

3

4

6

104

4

6

2

103

6

2

3

Der

ivat

ive

(kPa

(a))

102

2

3

4p,

Slope -1

2

3

4

6

101

10-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

Real Time (h)

pdata

Derivativedata

Perforation Inflow Diagnostic (PID)Testg ( )Slug (Impulse) Results

Impulse Radial

Slug DiagnosticAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


41000

38000

39000

40000

41000

35000

36000

37000

38000

32000

33000

34000

35000

p (k

Pa(a

))

29000

30000

31000

26000

27000

28000

Analysis 1

p* 24410 kPa(a)

2500001234567891011121314151617181920

1 / t (h-1)

pdata

Pressure Transient Analysis (PTA)

Total Test

Diagnostic AnalysisAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


y ( )Diagnostic

,

40000

42000

44000

-80

-40

0

t 0 38 h

34000

36000

38000

-160

-120

t 0.38 h t 0.37 hpdata 40232 kPa(a)qo -475.20 m3/d

30000

32000

Pres

sure

(kPa

(a))

-240

-200

Liquid Rate (m

3/d

t 86.56 h t 86.19 hpdata 25092 kPa(a)

24000

26000

28000

P

360

-320

-280

d)pdata 25092 kPa(a)

18000

20000

22000

-440

-400

-360

16000 -4800 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85

Time (h)

pdata

qoil

Pressure Transient Analysis (PTA)y ( )Diagnostic

Derivative



105 105105

2

3

4

6

105

2

3

5

7

104

3

4

6

104

2

3

4

6

103

6

2

3

p, D

eriv

ativ

e (k

Pa(a

))

103

2

3

5

7 p (PPD

) (kPa/h)

102

2

3

4

p

102

2

3

5

7

2

3

4

6 101

2

3

5

7

pdataDerivativedata

101 1.010-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

t (h)

Derivativedata

PPDdata


Derivative



105

2

3

4

6

104

4

6

2

103

6

2

3

Der

ivat

ive

(kPa

(a))

Radial 0

k 24.4340 mDs' -4.789

Storage 1

C 0.000 m3/kPaCD 9562 97

102

2

3

4p,

CD 9562.97

2

3

4

6

101

10-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

t (h)

pdata

Derivativedata


Radial



40000

38000

39000

40000

35000

36000

37000

Analysis 1

kh 232.12 mD.mk 24.4340 mD

32000

33000

34000

p (k

Pa(a

))

s' -4.789

29000

30000

31000

26000

27000

28000 t 86.19 hp 25092 kPa(a)rinv 453.703 m

2500010-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

t (h)

pdata

Fluid Properties Reservoir Temperature (Tresv) 67.6 °CReservoir Pressure (presv) 25000 kPa(a)Oil Gravity (o) 31.1 °APIOil Viscosity (o) 0.8079 mPa.sOil Compressibility (co) 1.6443e-06 1/kPaOil Formation Volume Factor (Bo) 1.359Solution Gas Ratio (Rs) 116.01 m3/m3

Oil Correlation Vasquez and BeggsOil Viscosity Correlation Beggs & Robinson

Production and Times Corrected Time (tc) 0.37 hTotal Cumulative Production Oil (Cumoil) -0.007 103m3

Final Oil Rate (qo final) -475.2 m3/d

Reservoir Parameters Net Pay (h) 9.500 mTotal Porosity (t) 9.30 %Gas Saturation (Sg) 0.00 %Oil Saturation (So) 66.60 %Water Saturation (Sw) 33.40 %Formation Compressibility (cf) 7.2678e-07 1/kPaTotal Compressibility (ct) 1.9609e-06 1/kPaWellbore Radius (rw) 0.057 m

Pressures Extrapolated Pressure (p*) kPa(a)Final Flowing Pressure (pwfo) 40232 kPa(a)Final Measured Pressure (plast) 25092 kPa(a)

Total Skin (s') -4.789Skin Due to Damage (sd) -4.789Skin Due To Inclination (sInc) Skin Due To Partial Penetration (sPP) Pressure Drop Due to Total Skin (pskin) kPa(a)Damage Ratio (DR) 0.434Flow Efficiency (FE) 2.303

Analysis ResultsFlow Capacity (kh) 232 mD.mEffective Permeability (k) 24.4340 mDEffective Gas Permeability (kg) mDEffective Oil Permeability (ko) 24.4340 mDEffective Water Permeability (kw) mDTotal Fluid Rate (in situ) ((q)t) -645.8 rm3/dTotal Mobility ((k/)t) 30.24 mD/mPa.sTotal Transmissivity ((kh/)t) 287.31 mDm/mPa.sSemi-Log Slope (m) 4768.11 kPa/cycle

Oil Well Test - FalloffRadial Flow Analysis

AOGC Wildling100/01-02-030-04W5/06CadmiumJul 19–23, 2010

WellTest32 Ver 7.4.2.52 114402TM

H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\DFIT2 Mini-frac' Fall-off\Wildling 100.01-02-030-04W5.6 Cadmium\100.01-02-030-04W5.6 AWSX.PFO 10-07-23.FKT 30-May-111

Pressure Transient Analysis (PTA)y ( )Synthetic Model

Total Test

Vertical ModelAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 19–23, 2010


42000

44000

0.40

0.60

0.80

1.00

36000

38000

40000

-0.40

-0.20

0.00

0.20

30000

32000

34000

Pres

sure

(kPa

(a))

-1.20

-1.00

-0.80

-0.60

Error (%)

24000

26000

28000

P

2 00

-1.80

-1.60

-1.40

0

18000

20000

22000

-2.60

-2.40

-2.20

-2.00

pi (syn) 24858 kPa(a)* 24867 kP ( )

kh 13.19 mD.mh 9 500

Xe 804.672 mY 804 672C 16912 339

16000 -3.00

-2.80

0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85

Time (h)

pdata

pmodel

% Error

p*model 24867 kPa(a)Cumoil -0.007 103m3

OIPmodel 2.80e+02 103stm3

h 9.500 mk 1.3887 mDsd -1.777

Ye 804.672 mXw 402.336 mYw 402.336 m

CaD 16912.339CD 35716.25CpD 0.486


Derivative



105

2

3

4

6

105

2

3

4

6

104

4

6

2104

2

3

5

7

103

6

2

3

Der

ivat

ive

(kPa

(a))

103

2

3

5

7 p (PPD

)(kPa/h)

102

2

3

4p,

102

2

3

5

7

)

2

3

4

6 101

2

3

5

7

pdata

pmodelDerivativedata

Derivativemodel

PPD

pi (syn) 24858 kPa(a)p*model 24867 kPa(a)

kh 13.19 mD.mh 9.500 m

Xe 804.672 mYe 804.672 m CaD 16912.339

101 1.010-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

t (h)

PPDdata

PPDmodelCumoil -0.007 103m3

OIPmodel 2.80e+02 103stm3k 1.3887 mDsd -1.777

Xw 402.336 mYw 402.336 m

CD 35716.25CpD 0.486


Radial



41000

38000

39000

40000

41000pdatapmodelp*

Ext. pmodel

35000

36000

37000

32000

33000

34000

p (k

Pa(a

))

28000

29000

30000

31000

CaD 16912.339CD 35716.25CpD 0.486

25000

26000

27000

8000

pi (syn) 24858 kPa(a)p*model 24867 kPa(a)Cumoil -0.007 103m3

OIPmodel 2.80e+02 103stm3

kh 13.19 mD.mh 9.500 mk 1 3887 mD

Xe 804.672 mYe 804.672 mX 402 336 m

2400010-3 10-2 10-1 1.0 101 1022 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8 2 3 4 5 6 7 8

t (h)

k 1.3887 mDsd -1.777

Xw 402.336 mYw 402.336 m

Fluid Properties Reservoir Temperature (Tresv) 67.6 °CReservoir Pressure (presv) 25000 kPa(a)Oil Gravity (o) 31.1 °APIOil Viscosity (o) 0.8079 mPa.sOil Compressibility (co) 1.6443e-06 1/kPaOil Formation Volume Factor (Bo) 1.359Solution Gas Ratio (Rs) 116.01 m3/m3

Oil Correlation Vasquez and BeggsOil Viscosity Correlation Beggs & Robinson

Synthesis Results Average Error (Eavg) 0.73 %Synthetic Initial Pressure (pi (syn)) 24858 kPa(a)Extrapolated Model Pressure (p*model) 24867 kPa(a)Pressure Drop Due to Total Skin (pskin) kPa(a)Flow Efficiency (FE) 1.008Damage Ratio (DR) 0.992

Reservoir Parameters Net Pay (h) 9.500 mTotal Porosity (t) 9.30 %Gas Saturation (Sg) 0.00 %Oil Saturation (So) 66.60 %Water Saturation (Sw) 33.40 %Formation Compressibility (cf) 7.2678e-07 1/kPaTotal Compressibility (ct) 1.9609e-06 1/kPaWellbore Radius (rw) 0.057 m

Production and Pressures Total Fluid Rate (in situ) ((q)t) -645.8 rm3/dFinal Gas Rate (qg final) 0.000 103m3/dFinal Oil Rate (qo final) -475.2 m3/dFinal Water Rate (qw final) 0.0 m3/dTotal Cumulative Production Oil (Cumoil) -0.007 103m3

Final Flowing Pressure (pwfo) 40232 kPa(a)Final Measured Pressure (plast) 25092 kPa(a)

Reservoir Length (Xe) 804.672 mReservoir Width (Ye) 804.672 mWell Location X-Direction (Xw) 402.336 mWell Location Y-Direction (Yw) 402.336 m

Analysis ResultsEffective Oil Permeability (ko) 1.3887 mDTotal Mobility ((k/)t) 1.72 mD/mPa.sTotal Transmissivity ((kh/)t) 16.33 mDm/mPa.sTotal Skin (s') -1.777Skin Due to Damage (sd) -1.777Wellbore Volume (Vw) 772.263 m3

Dim. Apparent Wellbore Storage Constant (CaD) 16912.339Dim. Wellbore Storage Constant (CD) 35716.251Dim. Wellbore Storage Pressure Parameter (CpD) 0.486

Oil Model - Vertical Model

Forecasts Forecast Flowing Pressure (Report) (pflow) 40232 kPa(a)Forecast Rate at 3 Months and Current Skin (q@ 3 Months) -14.0 m3/dForecast Rate at 6 Months and Current Skin (q@ 6 Months) -12.7 m3/dConstant Rate Forecast Flow Time (Report) (tflow) 8766.00 hForecast Rate at Specified Time and Current Skin (q@ Current Skin) -10.7 m3/dStabilized Injectivity Index @ Current Skin (IIActual) 0.001 (m3/d)/kPaForecast Rate at Specified Time and Skin = 0 (q@ 0 Skin) -9.0 m3/dStabilized Injectivity Index @ Skin = 0 (IIIdeal) 0.001 (m3/d)/kPaForecast Rate at Specified Time and Skin = -4 (q@ -4 Skin) -14.1 m3/d

AOGC Wildling100/01-02-030-04W5/06CadmiumJul 19–23, 2010



Vertical ModelAOGC Wildling100/01-02-030-04W5/06CadmiumJul 19–23, 2010

k = 1.3887 mDsd = -1.777 OIPmodel = 2.80e+02 10

3stm

3

Plan View(Not to scale)

No Flow

No Flow

No

Flow

No

Flow

Xe = 804.672 m

Ye

= 80

4.67

2 m Xw = 402.336

Yw =

402

.336

Side View(Not to scale)

No Flow Top of Reservoir

No Flow Bottom of Reservoir

h =

9.50

0 m



Deliverability Analysis (AOF)y y ( )Diagnostic

Total Test

Diagnostic AOFAOGC W ildling100/01-02-030-04W 5/06CadmiumJul 18–Aug 1, 2010

Alberta Oil & Gas Company2151.0–2158.0 mKBg ,

17000

18000

19000

20000

24

26

28

Calculated Sandface Pressure

t 0.00 h t 0.00 hpdata 20423 kPa(a)

14000

15000

16000

17000

20

22

24

10000

11000

12000

13000

Pres

sure

(kPa

(a))

14

16

18

Gas R

ate (10 3m3/d

6000

7000

8000

9000

P

8

10

12

d)

Used for AOF

t 63.50 h t 63.50 hpdata 450 kPa(a)qg 5.115 103m3/d

2000

3000

4000

5000

2

4

6

0

1000

00 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110

Time (h)

pdata

qgas

Deliverability Analysis (TOF)y y ( )Tubinghead Open Flow

AOGC W ildling100/01-02-030-04W 5/06Cadmium Alberta Oil & Gas Company

Simplified Wellhead AOFCadmiumJul 18–Aug 1, 2010


103

5

6

7

8

AOF 5.117 103m3/dn 1.000C 1.217e-02 (103m3/d)/106(kPa2)n

pi 20506 kPa(a)

2

3

4

5

102

8

2

p2

(106

kPa2

)

3

4

5

6

7

8

2

3

Isochronal PointsExtended Point

101

10-1 1.0 1012 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)

Extended PointStabilized Point

Duration WellheadPressure p2 p2 Gas

Rate

h kPa(a) 106kPa2 106kPa2 103m3/d

Extended Flow 108.53 450 0.2025 420.2771 5.115Stab. Shut-in 20506 420.4796Stab. Flow 450 0.2025 420.2771 5.115

AOF n C

103m3/d (103m3/d)/106(kPa2)n

Stabilized 5.117 1.000 1.217e-02Extended 5.117 1.000 1.217e-02Isochronal 1.000

Simplified Wellhead AOF

AOGC Wildling100/01-02-030-04W5/06CadmiumJul 18–Aug 1, 2010


101

102

103

2

3

5

2

3

5

p2

(106

kPa2

)

10-1 1.0 1012 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)

Isochronal PointsExtended PointStabilized Point

AOF 5.117 103m3/dn 1.000C 1.217e-02 (103m3/d)/106(kPa2)n

pi 20506 kPa(a)


H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\DFIT2 Mini-frac' Fall-off\Wildling 100.01-02-030-04W5.6 Cadmium\100.01-02-030-04W5.6 AOF 10-08-01.FKT 30-May-111

Deliverability Analysis (TOF)

AOGC W ildling100/01-02-030-04W 5/06Cadmium Alberta Oil & Gas Company

y y ( )Tubinghead Open Flow

Simplified Wellhead OPRCadmiumJul 18–Aug 1, 2010


20000

AOF 5.117 103m3/dn 1.000C 1.217e-02 (103m3/d)/106(kPa2)n

pi 20506 kPa(a)

14000

16000

18000

10000

12000

14000

ress

ure

(kPa

(a))

6000

8000

Pr

2000

4000

Deliverability @ 20505.60 kPa(a)

00.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00 4.20 4.40 4.60 4.80 5.00 5.20

Gas Rate (103m3/d)

Deliverability @ 16000.00 kPa(a)Deliverability @ 12000.00 kPa(a)

FlowingPressure

Gas Rate@ 20506 kPa(a)



kPa(a) 103m3/d 103m3/d 103m3/d

0 5.117 3.116 1.753450 5.115 3.113 1.7503000 5.008 3.006 1.6436000 4.679 2.678 1.3149000 4.132 2.130 0.76712000 3.365 1.363 0.000

AlternatePressure

kPa(a)

Stabilized Shut-In Pressure 20506Alternate Shut-In Pressure 1 16000Alternate Shut-In Pressure 2 12000

Simplified Wellhead OPR

AOGC Wildling100/01-02-030-04W5/06CadmiumJul 18–Aug 1, 2010


0

4000

8000

12000

16000

20000

Pres

sure

(kPa

(a))

0.00 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60 1.80 2.00 2.20 2.40 2.60 2.80 3.00 3.20 3.40 3.60 3.80 4.00 4.20 4.40 4.60 4.80 5.00 5.20

Gas Rate (103m3/d)

Deliverability @ 20505.60 kPa(a)Deliverability @ 16000.00 kPa(a)Deliverability @ 12000.00 kPa(a)

AOF 5.117 103m3/dn 1.000C 1.217e-02 (103m3/d)/106(kPa2)n

pi 20506 kPa(a)


H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\DFIT2 Mini-frac' Fall-off\Wildling 100.01-02-030-04W5.6 Cadmium\100.01-02-030-04W5.6 AOF 10-08-01.FKT 30-May-112

Production Data

i fiProduction field notes and data to be collated here

Surface (AWS) Pressure TestBottomhole Pressure Calculations

Company Name Alberta Oil & Gas Company Unique Well ID 100/01-02-030-04W5/06 Start Test Date 2010/07/19 Final Test Date 2010/07/23

Well Name AOGC Wildling Formation Cadmium Pool 2151.0–2158.0 mKB Job Number AWS - DFIT

Company Information

Operating Company Address Well Operator Alberta Oil & Gas Company Street 1 2000, 333 - 4th Avenue SW Street 2 Tall Chrome Tower City Calgary Province Alberta Country Canada Postal Code T2P 4A5

Service Company Contacts Service Company Code WTEST Welltest Specialists Inc. Job Number AWS - DFIT Representative Supervisor Prepared By Welltest Specialists Inc. Qualified By David Leech Report Date 2010/08/17

Well Information Surface Location 01-02-030-04W5 KB Elevation (SL) 1078.40 m CF Elevation (SL) 1073.50 m GL Elevation (SL) 1073.50 m KB-CF Offset 4.90 m KB-GL Offset 4.90 m

Zone Information Formation Cadmium Test/Prod Interval Top KB (LOG) 2151.00000 m Base KB (LOG) 2158.00000 m Test/Prod Interval Top KB (TVD) 2151.00000 m Base KB (TVD) 2158.00000 m MPP(Log KB) 2154.50 m MPP(TVD KB) 2154.50 m

Completion Information Well Type Vertical Casing OD 114.3 mm Casing ID 101.6 mm Tubing OD mm Tubing ID mm

Well Fluid Type 02 Gas Casing Depth(Log KB) 2160.00000 m Casing Depth(TVD KB) 2160.00000 m Tubing Depth(Log KB) m Tubing Depth(TVD KB) m

Operating Company Contact Contact Diana Engineer Phone (403) 222-3456 Fax (403) 222-4567 e-mail [email protected]

Recorder (Gauge) Statistics Gauge Manufacturer CalScan Gauge Model Hawk9000 Gauge Type Electronic Gauge Name AWS1 Recorder Type PAS-AWS

Gauge Serial Number 6956 Maximum Recorder Range 40000.00 kPa Resolution (% of Full Scale) 0.00030 Accuracy (% of Full Scale) 0.02400 Run Depth (Log KB) 4.90 m

Recorder (Gauge) Information Date of Last Calibration 2010/01/01 Gauge Start Date 2010/07/19 Gauge Stop Date 2010/07/23 Date Gauge On Bottom 2010/07/19 Date Gauge Off Bottom 2010/07/23

Gauge Start Time 09:21:00 Gauge Stop Time 10:24:00 Time Gauge On Bottom 17:01:00 Time Gauge Off Bottom 08:14:00

Well, Completion, & Zone Information

Recorder Statistics & Run Information

Test Information & Results

Production Data Gas Production Rate Prior to Test 0.000 103m3/d Oil Production Rate Prior to Test 1.000 m3/d Water Production Rate Prior to Test 0.000 m3/d Flow Duration h

Pressure Data Initial Casing Pressure 31582.84 kPa(a) Final Casing Pressure 10462.77 kPa(a) Last Measured Pressure at Run Depth 10462.77 kPa(a) Representative Pressure at MPP 25091.83 kPa(a) Pressure Correction 14629.06 kPa

Test Information Test Purpose Initial Test Pressure Test Type 06 Bottom Hole - Fall-Off Time/Date Well Shut-In 2010/07/19 17:42:00 Flow Path Casing

Remarks PID Test, Mini-frac' Fall-off Test (DFIT), Frac' Clean-up & Single Point AOF Test

Validata Ver 7.3.0.44 114400TM

H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\DFIT2 Mini-frac' Fall-off\Wildling 100.01-02-030-04W5.6 Cadmium\100.01-02-030-04W5.6 AWSX 10-07-23.FKT 30-May-111

Surface (AWS) Pressure TestMini-frac' Fall-off Test (DFIT)

Alberta Oil & Gas Company AOGC Wildling 100/01-02-030-04W5/06 Formation: Cadmium Start Test Date: 2010/07/19 Pool: 2151.0–2158.0 mKB Final Test Date: 2010/07/23 Job Number: AWS - DFIT

AWS1 Serial Number: 6956 Start Date: 2010/07/19 09:21:00 Run Depth: 4.90Gauge 1 Serial Number: Start Date: 2010/07/19 09:21:00 Run Depth: Print Filter: Print every 50th point

AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

16529.9716528.9716528.7116528.4116528.3516528.2916528.2416528.1716528.0316528.0216527.9516528.0016528.0516527.9916528.1716528.0716527.9416528.0816528.0916528.0816528.0316527.9816527.9816527.9816527.91

7.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.647

0.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.00

92.3891.1790.8690.5090.4290.3590.2990.2090.0490.0289.9490.0090.0689.9990.2090.0889.9290.1090.1190.0990.0489.9789.9789.9789.89

0.00000.15220.29110.43000.56890.70780.84670.98561.12441.26331.40221.54111.68001.81891.95782.09672.23562.37442.51332.65222.79112.93003.06893.20783.3467

09:21:0009:30:0809:38:2809:46:4809:55:0810:03:2810:11:4810:20:0810:28:2810:36:4810:45:0810:53:2811:01:4811:10:0811:18:2811:26:4811:35:0811:43:2811:51:4812:00:0812:08:2812:16:4812:25:0812:33:2812:41:48

2010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/19

123456789

10111213141516171819202122232425

Validata Ver TM

H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\DFIT2 Mini-frac' Fall-off\Wildling 100.01-02-030-04W5.6 Cadmium\100.01-02-030-04W5.6 AWSX 10-07-23.FKT 30-May-11Page 1




AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

16527.8816527.9216527.8416527.8916527.8016527.9916528.0616527.9916528.0416527.9316527.8916527.8616527.8416527.7616527.8416527.7016527.8316527.6716527.7516527.6316527.6716527.6616527.6516527.5516527.39

7.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.647

3.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.00

89.8589.9089.8089.8689.7689.9990.0789.9990.0589.9189.8789.8389.8189.7189.8089.6489.7989.6089.7089.5589.6089.5989.5789.4589.26

3.48563.62443.76333.90224.04114.18004.31894.45784.59674.73564.87445.01335.15225.29115.43005.56895.70785.84675.98566.12446.26336.40226.54116.68006.8189

12:50:0812:58:2813:06:4813:15:0813:23:2813:31:4813:40:0813:48:2813:56:4814:05:0814:13:2814:21:4814:30:0814:38:2814:46:4814:55:0815:03:2815:11:4815:20:0815:28:2815:36:4815:45:0815:53:2816:01:4816:10:08

2010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/19

26272829303132333435363738394041424344454647484950

Validata Ver TM





AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

16527.2116527.4416526.8816527.1416531.7716531.8617704.0117708.66

17036.1321850.7928737.1237760.5943179.3441439.6341612.1141220.2441059.4439267.2938488.0838040.1737583.7337070.4236457.23

7.6477.6477.6477.6477.6477.6477.5307.530

7.5977.1166.4825.8995.7815.8005.7985.8045.8075.8495.8745.8895.9065.9275.953

3.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.00

89.0489.3288.6488.9694.5694.67

1517.511523.17

23.4317.27

706.216553.39

14718.1424322.7729686.0027963.1928133.9227746.0627586.9325814.5225044.5924601.0424146.1723631.1423010.97

6.95787.09677.23567.37447.51337.65227.79117.93008.06898.20788.31258.32648.34038.35428.37538.43038.48698.55258.62618.71038.80508.91149.03069.16339.3128

16:18:2816:26:4816:35:0816:43:2816:51:4817:00:0817:08:2817:16:4817:25:0817:33:2817:39:4517:40:3517:41:2517:42:1517:43:3117:46:4917:50:1317:54:0917:58:3418:03:3718:09:1818:15:4118:22:5018:30:4818:39:46

2010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/19

51525354555657585960616263646566676869707172737475

Validata Ver TM





AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

35802.3635095.1234418.8533734.9733092.5832499.6431985.9931555.7131154.3430746.2230377.5829989.3929815.9929584.5329334.4829073.7628800.4328527.4928252.7927990.2827707.5527475.5327258.8127006.2726776.19

5.9856.0216.0606.1016.1446.1856.2236.2566.2876.3196.3486.3796.3936.4126.4336.4546.4776.5006.5236.5466.5706.5906.6096.6316.652

3.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.00

22342.6821613.9320910.1920191.5819510.1018875.4618321.2917853.8617415.2016966.5216558.9416127.3515933.7715674.6015393.6215099.5414790.0114479.6714166.0513865.1613539.7613271.6913020.4712726.6812458.05

9.48179.66929.8808

10.118110.383610.682811.017811.393311.815812.289212.820013.415614.084214.834715.676116.620617.680018.868120.202221.698623.377225.260627.373329.744432.4042

18:49:5419:01:0919:13:5119:28:0519:44:0120:01:5820:22:0420:44:3621:09:5721:38:2122:10:1222:45:5623:26:0300:11:0501:01:3401:58:1403:01:4804:13:0505:33:0807:02:5508:43:3810:36:3812:43:2415:05:4017:45:15

2010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/192010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/202010/07/20

767778798081828384858687888990919293949596979899

100

Validata Ver TM





AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

26546.3726296.5426095.5125909.2225742.8225591.2125452.4525331.2325236.1825159.4925092.6316526.4116526.6116526.3916526.1916527.0816525.8016525.4716523.9216523.5316527.7016527.8916527.9616527.9216528.07

6.6726.6956.7136.7306.7456.7596.7726.7836.7926.7996.8057.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.6477.647

3.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.003.00

12188.7811895.0211657.8411437.4011239.9611059.6510894.2510749.4710635.7710543.9010463.72

88.0788.3188.0587.8188.8887.3386.9385.0684.5989.6489.8689.9589.9090.08

35.389738.739742.498146.715651.446956.755862.711469.395076.893685.307294.747295.006195.145095.283995.422895.561795.700695.839495.978396.117296.256196.395096.533996.672896.8117

20:44:2300:05:2303:50:5308:03:5612:47:4918:06:2100:03:4106:44:4214:14:3722:39:2608:05:5008:21:2208:29:4208:38:0208:46:2208:54:4209:03:0209:11:2209:19:4209:28:0209:36:2209:44:4209:53:0210:01:2210:09:42

2010/07/202010/07/212010/07/212010/07/212010/07/212010/07/212010/07/222010/07/222010/07/222010/07/222010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/232010/07/23

101102103104105106107108109110111112113114115116117118119120121122123124125

Validata Ver TM





AWS1

Calculated

Pres.@ MPP

kPa

AWS1

Water

Gradient

kPa/m

AWS1

Oil

Gradient

kPa/m

AWS1

Gas

Gradient

kPa/m

AWS1

Fluid

Level

(LOG)

m

AWS1

Csg

Temp.

°C

AWS1

Casing

Pressure

kPa(a)

AWS1

Time

hr

AWS1

Clk Time

hh:mm:ss

AWS1

Date

yyyy/mm/dd

16527.5616527.62

7.6477.647

3.003.00

89.4789.53

96.950697.0544

10:18:0210:24:16

2010/07/232010/07/23

126127

Validata Ver TM


Completion Reportsp p

& iWellbore & completion reports to be collated here

Company Alberta Oil & Gas Company Metric FieldEngineer Diana Engineer KB GR Difference Datum PTA LevelWell Name AOGC Wildling 1078.40 1073.50 4.90 -1076.10 2Location 100/01-02-030-04W5/06 Vertical Deviated Openhole Horizontal In-LineFormation Cadmium Re-completion Gross h Net h Ø Sw RwLicense # 3456789 7.00 9.5 9.3 33.4 0.05715 114.30Perforations ° Gas Density Gas Z 17.30Stimulation Mini-frac' BD @ 33.2 Mpa N2 CO2 H2S pPc pTc 101.60Perforations 2151.00 2158.00 2146.10 2153.10 0.0081MPP 2154.50 KB 2149.60 CF Oil Density 870.0 °API 2160.00Tests: Date Clock Hours Tubing Casing Gas Rate Cum Gas Sandface Cum OilPRD Start 2010-07-18 13:00Clean-up Start 2010-07-24 12:45 24420.00Clean-up End 2010-07-26 16:00 45.02 591.00 5.871 18.894 82.210Test Start 2010-07-27 21:30 7593.00 7693.00Used for AOF 2010-07-30 13:00 108.53 450.00 1975.00 5.115 39.842 95.196Test End 2010-07-31 21:00 131.53 20505.60 1955.00 4.926 46.477 24858.00 97.116PRD End 2010-08-01 9:00 5 117

Tbg ODWelltest Specialists Working Data Sheet

Tbg WT

Csg OD

Csg End

Tbg IDTbg Cap

Csg Cap

Tbg End

Csg WTCsg ID

PRD End 2010 08 01 9:00 5.117Increments GRD-UWI RRD, KB

RRD MPP Δd Gradient Δp Date RRD, CFPressure CF LL, KBPressure RRD O/W, KBPressure MPP LL, CF

RRD–MPP Δp Mean Gas AOF Δp Calc Mean Gas p1: p2:(PRCOR) 2.025 4352.40 d1: d2: 4.9

TRG #RR-6956 Surface Range 93- TRG # Top Range 93- No DHDStart 2010-07-19 9:21 RRD, KB 4.90 Start RRD, KB ProvidedEnd 2010-07-23 10:24 RRD, CF 0.00 End RRD, CFUse Gauge: #1, Surface RRD, KB 4.90 Pr (LMP) 10462.77 94.8700 25091.83 (REPMPP)On Bottom 2010-07-19 17:01 RRD, CF 0.00 Pwf 27496.86 40968.42Off Bottom 2010-07-23 8:14 Temp. 67.64 Pr (–6 h) 10506.00 88.8700 -7.205 kPa/h /4 CadmiumPerf's MD: 2151.00 2154.00 3.00 2152.50 BHP Surface ∆p Gradient 2151.00

2156.00 2158.00 2.00 2157.00 Breakdown 45092.99 31582.84 13510.15 6.285 2154.50Final Injection 40968.42 27496.86 13471.56 6.267 2158.00

Expected BHP: 24310.00 Initial Shut-in 40231.72 26768.06 13463.66 6.263Pi (Syn) - PFO 24858.00 Pressure Anomaly 29819.44 15937.63 13881.81 6.458p* - PITA 24411.00 p* - Slug 24410.00 Final Pressure 25091.83 10462.77 14629.06 6.805