Executive Summary Welltest Analysis AGC Goldy 100/01–02 ...welltestspecialists.com/wp-content/uploads/2011/06/Welltest-Specialists-PTA1...A synthetic analysis was constructed employing

May 3, 2011

Executive Summary

pi (SYN) = 7 548 kPaa

k = 9.4 mD xf = 48 m sxf = −5.8 sc = 26 qg = 36.5 e3m3/d qs = 8.2 e3m3/d Q = 132 e3m3

eREPORT prepared for: Max Engineer, Alberta Gas Corp. 1000, 200 – 4th Avenue SW, Calgary, Alberta, T2R 3B2

Welltest Analysis AGC Goldy 100/01–02–030–04W5/04 Victoria; Clean-up, Flow & Build-up Test: Apr 11th – 21st, 2010

Objectives

Test objectives were to evaluate reservoir pressure, formation flow characteristics, hydraulic fracture stimulation treatment effectiveness, and stabilized gas deliverability for the /4 Victoria zone. The subject well had been abandoned, and was re-entered to complete and test the subject prospect, which was isolated by a bridge plug below and packers above. The zone was cleaned up to both flare and pipeline, and was tested in-line through 73 mm tubing.

Conclusions

Pressure build-up behaviour suggested wellbore storage transitioning to fracture flow (bi-linear then linear). Radial flow conditions could also be interpreted and boundary flow appeared to materialize. Quantitative analytical results indicated a good matrix permeability (k), a good fracture-half-length (xf), or a negative skin-equivalent-to-xf (sxf), suggestive of a successful stimulation treatment. However, the synthesis indicated a fairly high choked-fracture-skin (sc) implying damage at the fracture face. Pressure magnitudes suggested drainage by offset production such that boundaries could be construed as either “no flow” or “isobaric” in nature. Continued…

AGC Goldy 100/01–02–030–04W5/04 Victoria, Apr 11 – 21, 2010 eREPORT Page 2 of 9

kfw = 898 mD N = 46 m3

Conclusions …continued

Deliverability forecasting was thus considered theoretically approximate only: clean-up of the fracture face could produce an improvement, interference by nearby producers could become a detriment, and no-flow boundaries (i.e. a channel shape) would be a limiting factor. Liquid lift operations could also affect productivity. Confidence in results was good except for the ambivalence of boundary/deliverability relationships.

Background

Re-entry operations commenced on April 7th, 2010. Cement and bridge plugs were drilled out on the 8th and 9th. On April 10th 73 mm tubing, packers, and the TCP gun were installed and the subject /4 Victoria prospect was perforated over a single 2 m interval: Victoria 1679.0 – 1681.0 mKB The wellbore was swabbed dry on the 10th and 11th. On April 12th a 15 t energized N2 hydraulic fracture treatment was successfully conducted and the well was opened to flow on clean-up: 8 h to flare plus 15.5 h to pipeline. On April 13th the well was shut-in, tandem subsurface pressure recorders were installed, and the well was opened to flow in-line for a 45 h single point test period. The well was shut-in on the 15th for a 140 h pressure build-up period. On the 21st the recorders were recovered, pulling a static gradient survey to surface, to conclude testing. Workover operations re-commenced on May 5th, 2010 to install a plunger lift system.


Data Validation

Recorder run-in data exhibited a dry gas above RRD. On bottom shut-in pressures were still building rapidly. Sandface flowing pressures declined throughout the single point test. Sandface build-up pressures were dynamic throughout, ending at a compliant +1.465 kPa/h/6 h. Note it appeared that the wellhead was opened twice during the build-up causing subsurface pressure interference. Flowing temperatures exhibited Joule-Thompson cooling (JT-effects) due to gas influx. The declining nature suggested increasing skin (sc). Differential data demonstrated that the recorders were operating within specifications. The erratic nature of the pressure differential data, through the flow test period, was suggestive of fluid slugging up the wellbore. Post-frac’ clean-up operations commenced on a 4.76 mm choke and 50.8 mm orifice plate, shifting incrementally to a 38.1 mm choke and 38.1 mm orifice. Burnable GTS arrived in two hours. After four hours of GTS clean-up flow was switched down pipeline on a 9.53 mm choke, incrementing to 38.1 mm, through a 38.1 mm orifice. All load oil was recovered within 12 h and new oil continued to be produced. Negligible volumes of sand and water were reported. Single point test operations were conducted down pipeline on a 12.7 mm choke and 38.1 mm orifice plate. New oil continued to be produced consistently. No water or sand returnes were reported. Final reverse static gradient data exhibited a dry gas column above RRD. Note the top gauge failed as the gradient was being pulled.


¥

Methodology

Analytical Preparation

Pressures measured at RRD were corrected to MPP based on final gradient results. Gas rates and volumes were corrected for measured gas properties. Flow times were also corrected.

Pressure Transient Analysis

Primary Pressure Derivative (PPD) data exhibited very little scatter and were indicative of reservoir behavior throughout. Pressure build-up derivative data exhibited a unit slope relationship (1:1) as a function of wellbore storage (afterflow). Bilinear (fracture) flow characteristics were interpreted by the quarter (¼) slope relationship while linear (fracture) flow was interpreted by the half (½) slope relationship. A middle-time radial flow regime was interpreted by the zero slope relationship. Boundary conditions were suggested by the declining terminal trend. Diagnostic analyses (radial, bilinear, and linear) were conducted using the best-fit line through a range of points corresponding with the straight line analytical procedure. A synthetic analysis was constructed employing an Infinite Conductivity Fracture model with changing wellbore storage and boundary parameters. Quantitative analytical results suggested good matrix permeability (k), very good fracture flow conductivity (kfw), a robust fracture-half-length (xf), or a negative skin-equivalent-to-xf (sxf), indicative of a successful stimulation treatment. However, the synthesis also suggested a fairly high choked-fracture-skin (sc) implying damage at the fracture face. Note the boundary trend could only be modeled analytically as “no flow”—implying a fairly narrow reservoir geometry. Pressure magnitudes, however, were suggestive of pool drainage—implying that the boundaries could otherwise be “isobaric” in nature. Confidence in results was good except for the indeterminate nature of the boundaries.


pi (SYN) = 7 548 kPaa

pfinal = 7 087 kPaa

OGIP259 = 12.8 e6m3 OGIP130 = 6.4 e6m3 OGIP65 = 3.2 e6m3

qg = 36.5 e3m3/d ptf = 1 019 kPaa AOF1.0 = 40.7 e3m3/d Q = 132 e3m3

N = 45.6 m3

qs = 8.2 e3m3/d AOF1.0 = 9.2 e3m3/d TOF1.0 = 8.4 e3m3/d q@s=0 = 8.2 e3m3/d

Reservoir Pressures

For purposes of this report the synthetic initial reservoir pressure (pi (SYN)) offered the best estimate of reservoir pressure conditions. Note that pressure magnitudes were low for the reservoir depth. Investigation of public records further suggested Victoria initial pressures were much higher in surrounding wells (17 000 – 18 000 kPa). Thus the subject reservoir appears to have been drained by offset production.

Reserves Analysis

Volumetric reserves were estimated based on a default reservoir area of 259 ha. For auditing or economic evaluation purposes, theoretical reserves are also provided for one-half (½) and one-quarter (¼) of this area.

Production Analysis

On clean-up gas rates and flowing pressures incremented as the well came in, while load oil recovery declined. Turned down pipeline, gas rates and pressures declined while new oil was produced at a fairly consistent GOR. Single point test gas rates and pressures declined steadily, again with a fairly consistent GOR. Insignificant volumes of sand and water were reported.

Deliverability Analysis

Assuming a single section spacing unit (259 ha) a transient deliverability forecast was generated to an essentially stabilized cut-off of one year. Reciprocal slope (n) values of 1.0 were used for the AOF and TOF calculations (i.e. laminar flow). A second case was constructed to evaluate deliverability potential if the fracture face damage cleaned up, resulting in a skin (sc) of zero. Results suggested accelerated depletion only, with a similar stabilized rate at one year.


Deliverability

403–256–5767 403–561–0409

www.welltestspecialists.com Tuesday, May 03, 2011

[email protected]

Further Discussion

Deliverability forecasting was considered hypothetically approximate only: Clean-up of the fracture face could produce an improvement Interference by nearby producers could reduce productivity No-flow boundaries (i.e. a channel shape) could be a controlling factor Liquid influx and lift operations could also affect productivity

Redress

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. P11334 Authored by: David Leech, BTech, PL(Eng) M115837 Co-President


2 10-04-08-09:00 3 10-04-09-09:00 4 10-04-10-08:00 14:00 16:00 5 10-04-11-08:00 09:30 13:00 6 10-04-12-09:15 12:30 14:55 19:00 21:00 7 10-04-13-01:00 12:30 19.5 13:33 15:00 8 10-04-15-12:00 45 9 10-04-21-08:03

LL = — mKB RRD = 1672.7 mKB MPP = 1680 mKB d = 7.3 m gg = 0.579 kPa/m p = 4.23 kPa

Event Sequence

Drill out cement & bridge plugs. Drill out cement & bridge plugs. Install 73 mm tubing, packers, & TCP gun. Perf’ Viking: 1679.0–1681.0 mKB W/ 101 mm TCP, 25 g RDX SDP, 17 SPM, 60°. Swab wellbore dry. Swab wellbore dry. Wireline run in & drop TCP. Swab wellbore dry. Frac’ Viking: 15 t 20/40 Siber in DynaGel H2-N2 Energized, BD @ 35.6 MPa. Open well to flow to flare on clean-up, LOLTR = 37 m3. Burnable GTS. Shut-in to turn down pipeline. Open well to flow in-line on clean-up. Load oil recovered, producing new oil. Shut-in well, end of clean-up. Tandem subsurface pressure recorders on bottom. Open well to flow in-line on single point test. Shut-in well for pressure build-up test. Recorders off bottom, pulling static gradient survey to surface.

Final Pressure Gradient

Measured liquid level. Bottom recorder run depth. Mid-point of perforated interval. RRD–MPP depth increment. Gas gradient (measured). RRD–MPP pressure increment.


General Welltest Program

Wellbore Schematic

Completion Reports

Deviation Survey

Drill Stem Test

Fluids GAN (1004-15)

OAN

WAN

Data Availability

Production Pressure Petrophysical Analyses Clean Up Gradient Before h = 1.0 m HP Gas

Meter Run Transient = 10 % LP Gas

SCADA In Line Surface Sw = 32 % C6+ Liquids

History-Daily Acoustic Well Logs Water

Closed Chamber Gradient After Core Analysis Oil

ERCB.pas File Submissions

Production Gradient Extended Deliverability PRD (10-04-13) GRD (10-04-21) TRG (10-04-21) AOF (10-04-21)

PRD (10-04-15)

Note:

Board G-40 Initial Requirement for a gas sample could not be satisfied as a GAN.pas file was not provided.

Board G-40 Initial Requirements (Pressure, Production, Deliverability) have been satisfied.


p Shut-in Flowing

False Synthetic

Magnitude

q Measured Calculated Theoretical

Inverse slope Cumulative

Fluid properties Petrophysical properties

Permeability Reservoir flow

Fracture flow Horizontal well

Near wellbore condition Change in magnitude

Reserves Equation-of-state

Increments

Sandface Fluid gradient

Elevations and datum Drill Stem Test, Stopcock, Swab

Report Nomenclature

Pressure Initial measured (pi), final measured (pfinal), quiet-side (pq), tubing (pt), casing (pc), gradient (pGRD) Sandface (pwfs), wellhead; tubing (ptf), casing (pcf) Radial or linear extrapolated (p*) Model initial (pi (SYN)), extrapolated or average (p(AVG)) Absolute (kPaa), gauge (kPag) Flow Rate Gas (qg), oil or condensate (qo), water (qw), too small to measure (TSTM) Stabilized (qs), time-to-pseudo-steady-state or stabilization (tpss) Absolute open flow; sandface (AOFn), tubinghead (TOFn), casinghead (COFn) Reciprocal slope value indicated by subscript (n) Gas (Q), oil or condensate (N), water (W), load fluid left to recover (LFLTR) Properties Viscosity (μ), density (), specific gravity () Net pay (h), porosity (), water saturation (Sw), oil saturation (So), gas saturation (Sg) Analytical Homogeneous (k), heterogeneous or composite; inner, outer (k1, k2), horizontal (kh, kx, ky), vertical (kv) Flow capacity (kh), transmissivity (kh/μ), mobility (k/μ) Fracture flow capacity (kfw), fracture half-length (xf), skin-on-the-fracture-face (sc) Effective length (Le), distance from top of zone (Zw), vertical permeability (kz) Apparent or total skin (±s'); damaged (+), improved (–), skin-equivalent-to-xf (sxf) Time (t), pressure (p), temperature (T), volume (v), depth (d) Material balance (p/Z), original gas-in-place (OGIP), recoverable gas-in-place (RGIP) Pressure (p), volume (v), # of moles (n), gas compressibility (Z), gas constant (R), temperature (T); {pv = nZRT} Preparation Recorder run depth (RRD), liquid level (LL), gas/oil, emulsion interface (g/o, g/e), oil/water interface (o/w) mid-point of perforated or productive interval (MPP), open hole (OH) Gas (gg), oil or condensate (go), water (gw), emulsion (ge) Kelly bushing (mKB), casing flange (mCF), depths; measured (mMD), true vertical (mTVD), sub-sea (mSS) (DST), initial shut-in (ISI), final shut-in (FSI), gas, fluid to surface (GTS, FTS), too small to measure (TSTM)

AGC Goldy 100/01–02–030–04W5/04 Victoria, Apr 11 – 21, 2010 eREPORT Section 1 of 11

Section 1

Contents

Data Validation Pressure Transient Analysis Deliverability Analysis Reserves Analysis Production Data Pressure Data Fluid Analyses Completion Data Petrophysical Data Supplemental Data ERCB.pas File Submissions

Data Validation—Production

W espro Production Testing Ltd.

Pressures and Flow Rate vs TimeAGC Goldy100/01-02-030-04W 5/04VictoriaApril 11 - 13, 2010

Alberta Gas Corp.1679.0 - 1681.0 mKBp gp ,

10000

11000

12000

90

100

200

220

240

Date Time 2010-04-13 12:30:00 PMGas Rate (Inst) 52.457Tubing Pres 1520Casing Pres 120STOil Rate 17.568

LegendGas Rate (Inst)Tubing PresCasing PresSTOil RateW ater Rate

8000

9000

70

80

160

180

6000

7000

Tubi

ng P

res

Cas

ing

Pres

(kPa

(a))

50

60 Gas R

ate (Inst) (10 3m3

120

140

STOil R

ateW

ater Rate (m

3/d)

3000

4000

5000

T C

30

40

3/d)

60

80

100

1000

2000

10

20

20

40

0 0008 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14

April 11 2010 (Sunday) April 12 2010 (Monday) April 13 2010 (Tuesday)

Data Validation—Production

W espro Production Testing Ltd.

Pressures and Flow Rate vs TimeAGC Goldy100/01-02-030-04W 5/04VictoriaApr 13 - 15, 2010

Alberta Gas Corp.1679.0 - 1681.0 mKBp gp ,

5000

5500

104

112

120

28

30

32Legend

Gas Rate (Inst)Tubing PresCasing PresW ater RateOil Rate

3500

4000

4500

80

88

96

22

24

26Date Time 2010-04-15 12:00:00 PMOil Rate 10.008Gas Rate (Inst) 36.530Tubing Pres 1112Casing Pres 89

2500

3000

3500

Tubi

ng P

res

Cas

ing

Pres

(kPa

(a))

56

64

72 Gas R

ate (Inst) (10 3m314

16

18

20

Oil R

ateW

ater Rate (m

3/d)

1500

2000

T C

32

40

48

3/d)

8

10

12

14

500

1000

8

16

24

2

4

6

0 0014 16 18 20 22 00 02 04 06 08 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14

April 13 2010 (Tuesday) April 14 2010 (W ednesday) April 15 2010 (Thursday)

Data Validation—Recorders




Data Validation—Differential





Section 2

Contents


Analytical Results Summary

AGC Goldy 100/01-02-030-04W5/04

y yFracture Flow Analysis

Victoria Petrophysical Fluids Reserves

1679.0 – 1681.0 mKB-MD h = 1.0 m Gas = 0.671 SG OGIP = 12.8 e6m3

1679.0 – 1681.0 mKB-TVD = 10 % Oil = 0.834 SG A = 259 ha

1674.8 – 1676.8 mCF-TVD Sw = 32 % Water = 1.050 SGw

Pressures Fracture Model Deliverability Stabilized

pinitial = 6 085 kPaa k = 9.4 mD qg = 36.5 e3m3/d qs = 8.2 e3m3/d

pfinal = 7 087 kPaa kh = 9.4 mDm AOF = 40.7 e3m3/d AOF = 9.2 e3m3/d

p = 7 548 kPa s = 26 TOF = 37 4 e3m3/d TOF = 8 4 e3m3/dpi(syn) = 7 548 kPaa sc = 26 TOF = 37.4 e3m3/d TOF = 8.4 e3m3/d

pwf = 2 417 kPaa xf = 48 m Q = 132 e3m3 sc=0 = 8.2 e3m3/d

pwhd = 6 851 kPaa kfw = 898 mDm N = 83 m3

ptf = 1 019 kPaa rinv = 367 m W = 0.2 m3

Comments May 3, 2011

Quantitative analytical results suggested good matrix permeability (k), very good fracture flow conductivity (kfw), a robust fracture-half-length (xf), or anegative skin-equivalent-to-xf (sxf), indicative of a successful stimulation treatment. However, the synthesis also suggested a fairly high choked-fracture-skin(sc) implying damage at the fracture face.

Note the boundary trend could only be modeled analytically as “no flow” implying a fairly narrow reservoir geometry Pressure magnitudes however wereNote the boundary trend could only be modeled analytically as no flow —implying a fairly narrow reservoir geometry. Pressure magnitudes, however, weresuggestive of pool drainage—implying that the boundaries could otherwise be “isobaric” in nature.

Pressure Transient Analysis—Diagnosticy g

Total TestDiagnostic Analysis—Radial

AGC Goldy100/01-02-030-04W5/04VictoriaApr 11–21, 2010

Alberta Gas Corp.1679.00–1681.00 mKB

7000110

6200

6400

6600

6800

7000

90

95

100

105

t 209.00 h t 139.97 hpdata 7087 kPa(a)

5400

5600

5800

6000

70

75

80

85

4600

4800

5000

5200

Pres

sure

(kPa

(a))

50

55

60

65

Gas R

ate (103m

3/d

3800

4000

4200

4400

P

30

35

40

45

d)

2800

3000

3200

3400

3600

10

15

20

25

t 69.03 h t 45.03 h

2418 kP ( )

2400

2600

2800

0

5

10

0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 205 210

Time (h)

pdata

qgas

pdata 2418 kPa(a)qg 36.520 103m3/d


DerivativeDiagnostic Analysis—Radial



101 104

2

3

4

6

103

2

3

5

1.0

3

4

6

)

102

5

2

3

5

10-1

6

2

3

eriv

ativ

e (1

06kP

a2/

Pa.s

)

101

5

2

3

5

(PPD) ((106kPa

2/P

2

3

4

6

/ De

1.0

5

2

3

Pa.s)/h)

10-2

2

3

4

6

10-1

3

5

2

3

10-3

2

10-2

2

3

10-3 10-2 10-1 1.0 101 102 1032 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 2 3 4 5 6 7 8

Pseudo-Time (h)

data

Derivativedata

PPDdata


DerivativeDiagnostic Analysis—Radial



101

2

3

4

6

1.0

3

4

6

) Storage 1 Radial 0

10-1

6

2

3

eriv

ativ

e (1

06kP

a2/

Pa.s

)

C 0.002 m3/kPaCD 5397.89

k 9.9914 mDs' -5.421p* 7517 kPa(a)

2

3

4

/ De

10-2

2

3

4

6

10-3

2

10-3 10-2 10-1 1.0 101 102 1032 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 2 3 4 5 6 7 8

Radial Pseudo-Time (h)

data

Derivativedata


RadialDiagnostic Analysis—Radial



5.00

4 00

4.20

4.40

4.60

4.80

7000

7500

3.20

3.40

3.60

3.80

4.00

6000

6500 t 139.97 hp 7087 kPa(a)rinv 367.314 m

2 20

2.40

2.60

2.80

3.00

(1

06kP

a2/

Pa.s

)

5500

6000

p (kPa(a))

1.40

1.60

1.80

2.00

2.20

4000

4500

5000

0 40

0.60

0.80

1.00

1.20

2500

3000

3500

Analysis 1

kh 9.99 mD.mk 9.9914 mDs' -5.421p* 7517 kPa(a)

0.00

0.20

0.40

0

1500

2000

1.0101102103104105 23456782345678234567823456782345678

Superposition Radial Pseudo-Time ( ta) (h)

data

Fluid Properties Reservoir Temperature (Tresv) 62.7 °CReservoir Pressure (presv) 7087 kPa(a)Gas Gravity ( g) 0.671N2 1.33 %CO2 0.71 %H2S 0.00 %Critical Temperature (Tc) 209.4 KCritical Pressure (pc) 4572 kPa(a)Gas Viscosity (g) 13.4 Pa.sGas Compressibility (cg) 1.5582e-04 1/kPaGas Compressibility Factor (z) 0.888Gas Formation Volume Factor (Bg) 1.4801e-02 m3/m3

Gas Correlation B.W.R. (Table)Gas Viscosity Correlation Carr et al

Production and Times Corrected Time (tc) 86.24 hTotal Cumulative Production Gas (Cumgas) 0.131 106m3

Final Gas Rate (qg final) 36.520 103m3/d

Reservoir Parameters Net Pay (h) 1.000 mTotal Porosity (t) 10.00 %Gas Saturation (Sg) 68.00 %Oil Saturation (So) 0.00 %Water Saturation (Sw) 32.00 %Formation Compressibility (cf) 7.0522e-07 1/kPaTotal Compressibility (ct) 1.0681e-04 1/kPaWellbore Radius (rw) 0.070 m

Pressures Extrapolated Pressure (p*) 7517 kPa(a)Final Flowing Pressure (pwfo) 2418 kPa(a)Final Measured Pressure (plast) 7087 kPa(a)

Total Skin (s') -5.421Skin Due to Damage (sd) -5.421Skin Due To Inclination (sInc) Skin Due To Partial Penetration (sPP) Pressure Drop Due to Total Skin (pskin) kPa(a)Damage Ratio (DR) 0.306Flow Efficiency (FE) 3.263

Analysis Results

Flow Capacity (kh) 9.99 mD.mEffective Permeability (k) 9.9914 mDEffective Gas Permeability (kg) 9.9914 mDEffective Oil Permeability (ko) mDEffective Water Permeability (kw) mDTotal Fluid Rate (in situ) ((q)t) 540.5 rm3/dTotal Mobility ((k/)t) 0.75 mD/Pa.sTotal Transmissivity ((kh/)t) 0.75 mDm/Pa.sSemi-Log Slope (m) 1.8311 (106kPa2/Pa.s)/cycle

Gas Well Test - BuildupRadial Flow AnalysisAGC Goldy

100/01-02-030-04W5/04VictoriaApr 11–21, 2010


WellTest32 Ver 7.4.2.52 114402TM

H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\PTA1 Comprehensive\Goldy 100.01-02-030-04W5.4 Victoria\100.01-02-030-04W5.4 PBU.AOF 10-04-21.FKT 03-May-111


DerivativeDiagnostic Analysis—Linear



101

2

3

4

6

1.0

3

4

6

) /

10-1

6

2

3

eriv

ativ

e (1

06kP

a2/

Pa.s

) Linear Fracture 1/2

Xf(sqrt(k)) 223.65 mD1/2mk 9.9914 mDXf 70.756 msXf -6.227

Bilinear 1/4

kfW(sqrt(k)) 2839.06 mD3/2mk 9.9914 mDkfW 898.18 mD.m

2

3

4

/ De

10-2

2

3

4

6

10-3

2

10-3 10-2 10-1 1.0 101 102 1032 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 2 3 4 5 6 7 8

Linear Pseudo-Time (h)

data

Derivativedata


BilinearDiagnostic Analysis—Linear



5.00

4 00

4.20

4.40

4.60

4.80

7000

7500

Analysis 1

kfW(sqrt(k)) 2839.06 mD3/2mk 9.9914 mDkfW 898.18 mD.mp* 7872 kPa(a)

3.20

3.40

3.60

3.80

4.00

6000

6500

2 20

2.40

2.60

2.80

3.00

(1

06kP

a2/

Pa.s

)

5500

6000

p (kPa(a))

1.40

1.60

1.80

2.00

2.20

4000

4500

5000

0.60

0.80

1.00

1.20

2500

3000

3500

0.00

0.20

0.40

0

1500

2000

0.000.100.200.300.400.500.600.700.800.901.001.101.201.301.401.501.601.701.801.902.002.102.202.302.402.502.602.702.802.903.00

Superposition Bilinear Pseudo-Time ( ta1/4) (h)

data


Linear - FractureDiagnostic Analysis—Linear



5.00

4 00

4.20

4.40

4.60

4.80

7000

7500Analysis 1

Xf(sqrt(k)) 223.65 mD1/2mk 9.9914 mDXf 70.756 msXf -6.227p* 9294 kPa(a)

3.20

3.40

3.60

3.80

4.00

6000

6500

2 20

2.40

2.60

2.80

3.00

(1

06kP

a2/

Pa.s

)

5500

6000

p (kPa(a))

1.40

1.60

1.80

2.00

2.20

4000

4500

5000

0.60

0.80

1.00

1.20

2500

3000

3500

0.00

0.20

0.40

0

1500

2000

3.003.203.403.603.804.004.204.404.604.805.005.205.405.605.806.006.206.406.606.807.007.207.407.607.808.008.208.408.608.809.009.209.409.609.8010.00

Superposition Linear Pseudo-Time ( ta1/2) (h)

data

Pressure Transient Analysis—Modely

Total TestFracture Model



70001.00

6200

6400

6600

6800

7000

0 40

0.60

0.80

5400

5600

5800

6000

0.00

0.20

0.40

4600

4800

5000

5200

Pres

sure

(kPa

(a))

-0.60

-0.40

-0.20

Error (%)

3800

4000

4200

4400

P

-1 20

-1.00

-0.80

2800

3000

3200

3400

3600

-1.60

-1.40

-1.20

p (syn) 7548 kPa(a)

kh 9.40 mD.mh 1.000 mk 9 4016 mD

Xf 47.943 mXe 563.105 mY 1609 344 m

2400

2600

2800

-2.00

-1.80

20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170 175 180 185 190 195 200 205 210

Time (h)

pdata

pmodel

% Error

pi (syn) 7548 kPa(a)pavg 7348 kPa(a)Cumgas 0.131 106m3

GIPmodel 4.464 106m3

k 9.4016 mDsc 25.821s' -5.562sXf -5.838

Ye 1609.344 mXw 263.633 mYw 804.672 m

CaD 4061.949CD 3308.32CpD 0.262


DerivativeFracture Model



101 104

2

3

4

6

103

2

3

5

1.0

3

4

6

)

102

5

2

3

5

10-1

6

2

3

eriv

ativ

e (1

06kP

a2/

Pa.s

)

101

5

2

3

5

(PPD) ((106kPa

2/P

2

3

4

/ De

1.0

5

2

3

Pa.s)/h)

10-2

2

3

4

6

10-1

3

5

2

3

data

model

Derivativedata

D i tipi (syn) 7548 kPa(a)

kh 9.40 mD.mh 1.000 mk 9.4016 mD

Xf 47.943 mXe 563.105 mYe 1609.344 m

10-3

2

10-2

2

3

10-3 10-2 10-1 1.0 101 102 1032 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 2 3 4 5 6 7 8

Pseudo-Time (h)

Derivativemodel

PPDdata

PPDmodel

pavg 7348 kPa(a)Cumgas 0.131 106m3


sc 25.821s' -5.562sXf -5.838

Xw 263.633 mYw 804.672 m

CaD 4061.949CD 3308.32CpD 0.262


RadialFracture Model



5.00kh 9.40 mD.m Xf 47.943 m

4 00

4.20

4.40

4.60

4.80

7000

7500

pi (syn) 7548 kPa(a)

kh 9.40 mD.mh 1.000 mk 9.4016 mDsc 25.821s' -5.562sXf -5.838

Xf 47.943 mXe 563.105 mYe 1609.344 mXw 263.633 mYw 804.672 m

3.20

3.40

3.60

3.80

4.00

6000

6500



CaD 4061.949CD 3308.32CpD 0.262

2 20

2.40

2.60

2.80

3.00

(1

06kP

a2/

Pa.s

)

5500

6000

p (kPa(a))

p

1.40

1.60

1.80

2.00

2.20

4000

4500

5000

0 40

0.60

0.80

1.00

1.20

2500

3000

3500

data

0.00

0.20

0.40

0

1500

2000

1.0101102103104105 23456782345678234567823456782345678

Superposition Radial Pseudo-Time ( ta) (h)

modelpavg

Ext. model


Linear - Fracture

Fracture ModelAGC Goldy100/01-02-030-04W 5/04VictoriaApr 11–21, 2010


kh 9.40 mD.m Xf 47.943 m

4 00

4.40

4.80

7000

7500

pi (syn) 7548 kPa(a)



3.20

3.60

4.00

6000

6500

pavg 7348 kPa(a)Cumgas 0.131 106m3


CaD 4061.949CD 3308.32CpD 0.262

2.40

2.80

(1

06kP

a2/

Pa.s

)

5500

6000

p (kPa(a))

1.60

2.00

4000

4500

5000

0.80

1.20

2500

3000

3500

0.00

0.40

0

1500

2000

0.000.501.001.502.002.503.003.504.004.505.005.506.006.507.007.508.008.509.009.5010.00

Superposition Linear Pseudo-Time (ta1/2) (h)

data

model

Ext. model

Fluid Properties Reservoir Temperature (Tresv) 62.7 °CReservoir Pressure (presv) 7087 kPa(a)Gas Gravity ( g) 0.671N2 1.33 %CO2 0.71 %H2S 0.00 %Critical Temperature (Tc) 209.4 KCritical Pressure (pc) 4572 kPa(a)Gas Viscosity (g) 13.4 Pa.sGas Compressibility (cg) 1.5582e-04 1/kPaGas Compressibility Factor (z) 0.888Gas Formation Volume Factor (Bg) 1.4801e-02 m3/m3

Gas Correlation B.W.R. (Table)Gas Viscosity Correlation Carr et al

Synthesis Results Average Error (Eavg) 0.25 %Synthetic Initial Pressure (pi (syn)) 7548 kPa(a)Final Average Reservoir Pressure (pavg) 7348 kPa(a)Pressure Drop Due to Total Skin (pskin) 912 kPa(a)Flow Efficiency (FE) 0.815Damage Ratio (DR) 1.227

Reservoir Parameters Net Pay (h) 1.000 mTotal Porosity (t) 10.00 %Gas Saturation (Sg) 68.00 %Oil Saturation (So) 0.00 %Water Saturation (Sw) 32.00 %Formation Compressibility (cf) 7.0522e-07 1/kPaTotal Compressibility (ct) 1.0681e-04 1/kPaWellbore Radius (rw) 0.070 m

Production and Pressures Final Gas Rate (qg final) 36.520 103m3/dTotal Cumulative Production Gas (Cumgas) 0.131 106m3

Final Flowing Pressure (pwfo) 2418 kPa(a)Final Measured Pressure (plast) 7087 kPa(a)

Fracture Half-Length (Xf) 47.943 mReservoir Length (Xe) 563.105 mReservoir Width (Ye) 1609.344 mWell Location X-Direction (Xw) 263.633 mWell Location Y-Direction (Yw) 804.672 m

Analysis Results

Effective Permeability (k) 9.4016 mDTotal Skin (s') -5.562Choked Fracture Skin (sc) 25.821Skin Equivalent to Xf (sXf) -5.838Wellbore Volume (Vw) 6.952 m3

Dim. Apparent Wellbore Storage Constant (CaD) 4061.949Dim. Wellbore Storage Constant (CD) 3308.325Dim. Wellbore Storage Pressure Parameter (CpD) 0.262

Gas Model - Fracture Model

Forecasts Forecast Flowing Pressure (Report) (pflow) 2418 kPa(a)Forecast Rate at 3 Months and Current Skin (q@ 3 Months) 13.312 103m3/dForecast Rate at 6 Months and Current Skin (q@ 6 Months) 8.655 103m3/dConstant Rate Forecast Flow Time (Report) (tflow) 8766.00 hForecast Rate at Specified Time and Current Skin (q@ Current Skin) 5.093 103m3/dForecast Rate at Specified Time and Skin = 0 (q@ 0 Skin) 5.172 103m3/dForecast Rate at Specified Time and Skin = -4 (q@ -4 Skin) 5.174 103m3/d





Fracture ModelAGC Goldy100/01-02-030-04W5/04VictoriaApr 11–21, 2010

k = 9.4016 mDsc = 25.821 Xf = 47.943 mGIPmodel = 4.464 10

6m

3

Plan View(Not to scale)

No Flow

No Flow

No

Flow

No

Flow

Xe = 563.105 m

Ye

= 16

09.3

44 m Xw = 263.633

Yw =

804

.672

Side View(Not to scale)

No Flow Top of Reservoir

No Flow Bottom of Reservoir

h =

1.00

0 m

Xf = 47.943 m




Section 3

Contents


Deliverability Analysis—Forecasty y

Transient Forecast @ 259 ha Single Section SpacingFracture Forecast



406.00

Rate @ 2418 kPa(a) sc = 25.82 pi (syn) 7542 kPa(a)kh 9 40 mD m Xf 47 943 m C D 4061 949

34

36

38

40

4 80

5.20

5.60

Rate @ 2418 kPa(a) sc 25.82Rate @ 2418 kPa(a) sc = 0.00Cum. Production @ 2418 kPa(a) sc = 25.82Cum. Production @ 2418 kPa(a) sc = 0.00





CaD 4061.949CD 3308.32CpD 0.262

28

30

32

34

4.00

4.40

4.80

22

24

26

28

Rat

e (1

03m

3 /d)

2.80

3.20

3.60 Cum

. Production (106m

16

18

20

1.60

2.00

2.40

m3)

10

12

14

6

0.40

0.80

1.20

Test Sc = 25.8

t 12.00 monthq 8.226 103m3/d

@ Sc = 0.0

t 12.00 monthq 8.198 103m3/d

8 0.000.00 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 10.50 11.00 11.50 12.00 12.50 13.00

Time (month)

q

Time@ 2418 kPa(a)

sc = 25.82

Rate@ 2418 kPa(a)

sc = 25.82

Cum. Prod.@ 2418 kPa(a)

sc = 25.82

PR@ 2418 kPa(a)

sc = 25.82

Pwf@ 2418 kPa(a)

sc = 25.82

Time@ 2418 kPa(a)

sc = 0.00

Rate@ 2418 kPa(a)

sc = 0.00


sc = 0.00

PR@ 2418 kPa(a)

sc = 0.00

Pwf@ 2418 kPa(a)

sc = 0.00

month 103m3/d 106m3 kPa(a) kPa(a) month 103m3/d 106m3 kPa(a) kPa(a)

1 0.000 36.000 0.000 7548.00 7548.00 0.000 36.000 0.000 7548.00 7548.002 0.033 36.000 0.036 7528.93 4478.96 0.033 36.000 0.036 7528.93 5024.953 0.066 36.000 0.072 7509.85 3708.77 0.066 36.000 0.072 7509.85 4350.794 0.099 36.000 0.108 7490.76 3162.31 0.099 36.000 0.108 7490.76 3894.865 0.131 36.000 0.144 7471.66 2703.43 0.131 36.000 0.144 7471.66 3532.136 0.154 36.000 0.168 7458.79 2417.51 0.164 36.000 0.180 7452.56 3220.767 0.164 35.144 0.180 7452.71 2417.50 0.197 36.000 0.216 7433.45 2942.158 0.197 33.716 0.213 7434.81 2417.50 0.230 36.000 0.252 7414.32 2683.189 0.230 32.633 0.246 7417.48 2417.50 0.263 36.000 0.288 7395.20 2434.5510 0.263 31.781 0.278 7400.59 2417.50 0.265 36.000 0.290 7393.89 2418.0111 0.296 31.082 0.309 7384.07 2417.50 0.296 34.755 0.323 7376.68 2418.0012 0.329 30.492 0.339 7367.86 2417.50 0.329 33.843 0.357 7358.68 2418.0013 0.361 29.983 0.369 7351.91 2417.50 0.361 33.113 0.390 7341.06 2418.0014 0.394 29.536 0.399 7336.19 2417.50 0.394 32.501 0.422 7323.76 2418.0015 0.427 29.140 0.428 7320.68 2417.50 0.427 31.974 0.454 7306.74 2418.0016 0.460 28.784 0.457 7305.35 2417.50 0.460 31.513 0.486 7289.95 2418.0017 0.493 28.466 0.485 7290.19 2417.50 0.493 31.104 0.517 7273.38 2418.0018 0.526 28.176 0.514 7275.18 2417.50 0.526 30.736 0.548 7256.99 2418.0019 0.559 27.910 0.541 7260.30 2417.50 0.559 30.401 0.578 7240.78 2418.0020 0.591 27.666 0.569 7245.55 2417.50 0.591 30.099 0.608 7224.72 2418.0021 0.624 27.440 0.597 7230.91 2417.50 0.624 29.819 0.638 7208.81 2418.0022 0.657 27.230 0.624 7216.38 2417.50 0.657 29.562 0.668 7193.03 2418.0023 0.690 27.035 0.651 7201.95 2417.50 0.690 29.322 0.697 7177.37 2418.0024 0.723 26.849 0.678 7187.62 2417.50 0.723 29.097 0.726 7161.82 2418.0025 0.756 26.675 0.704 7173.37 2417.50 0.756 28.887 0.755 7146.38 2418.0026 0.789 26.510 0.731 7159.20 2417.50 0.789 28.688 0.784 7131.04 2418.0027 0.821 26.352 0.757 7145.12 2417.50 0.821 28.499 0.812 7115.80 2418.0028 0.854 26.201 0.783 7131.11 2417.50 0.854 28.318 0.840 7100.65 2418.0029 0.887 26.056 0.809 7117.17 2417.50 0.887 28.146 0.868 7085.59 2418.0530 0.920 25.917 0.835 7103.31 2417.50 0.920 27.981 0.896 7070.60 2418.0431 0.953 25.782 0.861 7089.51 2417.53 0.953 27.821 0.924 7055.70 2418.0332 0.986 25.651 0.887 7075.78 2417.54 0.986 27.665 0.952 7040.88 2418.0233 1.000 25.586 0.898 7069.78 2417.51 1.000 27.586 0.964 7034.41 2418.0134 2.000 22.809 1.592 6696.28 2417.54 2.000 24.393 1.706 6634.47 2418.06



Gas Model - Fracture Model @ 259 ha


H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\PTA1 Comprehensive\Goldy 100.01-02-030-04W5.4 Victoria\100.01-02-030-04W5.4 PBU.AOF 10-04-21.FKT 03-May-118-1

Time@ 2418 kPa(a)

sc = 25.82

Rate@ 2418 kPa(a)

sc = 25.82


sc = 25.82

PR@ 2418 kPa(a)

sc = 25.82

Pwf@ 2418 kPa(a)

sc = 25.82

Time@ 2418 kPa(a)

sc = 0.00

Rate@ 2418 kPa(a)

sc = 0.00


sc = 0.00

PR@ 2418 kPa(a)

sc = 0.00

Pwf@ 2418 kPa(a)

sc = 0.00

month 103m3/d 106m3 kPa(a) kPa(a) month 103m3/d 106m3 kPa(a) kPa(a)

35 3.000 20.281 2.210 6361.15 2417.50 3.000 21.491 2.361 6278.67 2418.0036 4.000 18.106 2.761 6059.40 2417.50 4.000 19.023 2.940 5960.85 2418.0037 5.000 16.226 3.255 5786.81 2417.50 5.000 16.912 3.454 5675.87 2418.0038 6.000 14.595 3.699 5539.77 2417.50 6.000 15.099 3.914 5419.44 2418.0039 7.000 13.171 4.100 5315.27 2417.50 7.000 13.530 4.326 5187.96 2418.0040 8.000 11.924 4.463 5110.71 2417.50 8.000 12.167 4.696 4978.39 2418.0041 9.000 10.826 4.792 4923.86 2417.50 9.000 10.977 5.030 4788.14 2418.0042 10.000 9.854 5.092 4752.82 2417.50 10.000 9.932 5.333 4615.01 2418.0043 11.000 8.993 5.366 4595.93 2417.50 11.000 9.012 5.607 4457.08 2418.0044 12.000 8.226 5.616 4451.72 2417.50 12.000 8.198 5.856 4312.70 2418.00



Gas Model - Fracture Model @ 259 ha


H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\PTA1 Comprehensive\Goldy 100.01-02-030-04W5.4 Victoria\100.01-02-030-04W5.4 PBU.AOF 10-04-21.FKT 03-May-119-1

Deliverability Analysis—AOFy y

Simplified Sandface AOF


Alberta Gas Corp.1679.001681.00 mKB

102AOF Ext 40.695 103m3/d

4

5

6

7

8

AOF Ext 40.695 10 m /dAOF 9.166 103m3/dn 1.000C 1.609e-01 (103m3/d)/106(kPa2)n

pi 7548 kPa(a)

2

3

4

101

8p2

(106

kPa2

)

4

5

6

7

2

3

1.01.0 101 1022 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)

Isochronal PointsExtended PointStabilized Point

Duration SandfacePressure p2 p2 Gas

Rate

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

Extended Flow 45.00 2418 5.8443 51.1280 36.520Stab. Shut-in 139.97 7548 56.9723Stab. Flow 2418 5.8443 51.1280 8.226

AOF n C

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

Stabilized 9.166 1.000 1.609e-01Extended 40.695 1.000 7.143e-01Isochronal 1.000

Simplified Sandface AOF



1.0

101

102

2

3

5

2

3

5

p2

(106

kPa2

)

1.0 101 1022 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)


AOF Ext 40.695 103m3/dAOF 9.166 103m3/dn 1.000C 1.609e-01 (103m3/d)/106(kPa2)n

pi 7548 kPa(a)



Deliverability Analysis—AOFy y

Simplified Sandface IPR



AOF 9.166 103m3/d

6500

7000

7500

AOF 9.166 10 m /dn 1.000C 1.609e-01 (103m3/d)/106(kPa2)n

pi 7548 kPa(a)

5000

5500

6000

3500

4000

4500

Pres

sure

(kPa

(a))

2500

3000

3500P

1000

1500

2000

0

500

0.00 0.40 0.80 1.20 1.60 2.00 2.40 2.80 3.20 3.60 4.00 4.40 4.80 5.20 5.60 6.00 6.40 6.80 7.20 7.60 8.00 8.40 8.80 9.20 9.60

Gas Rate (103m3/d)

Deliverability @ 7548.00 kPa(a)Deliverability @ 6000.00 kPa(a)Deliverability @ 5000.00 kPa(a)

FlowingPressure

Gas Rate@ 7548 kPa(a)



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

0 9.166 5.792 4.0221000 9.005 5.631 3.8612000 8.523 5.148 3.3792418 8.226 4.852 3.0823000 7.718 4.344 2.5744000 6.592 3.218 1.448

AlternatePressure

kPa(a)

Stabilized Shut-In Pressure 7548Alternate Shut-In Pressure 1 6000Alternate Shut-In Pressure 2 5000

Simplified Sandface IPR



0

1000

2000

3000

4000

5000

6000

7000

Pres

sure

(kPa

(a))

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

Gas Rate (103m3/d)


AOF 9.166 103m3/dn 1.000C 1.609e-01 (103m3/d)/106(kPa2)n

pi 7548 kPa(a)



Deliverability Analysis—TOFy y

Simplified Wellhead AOF



102AOF Ext 37.417 103m3/d

4

5

6

7

8

AOF Ext 37.417 10 m /dAOF 8.428 103m3/dn 1.000C 1.946e-01 (103m3/d)/106(kPa2)n

pi 6581 kPa(a)

2

3

4

101

8p2

(106

kPa2

)

4

5

6

7

2

3

1.01.0 101 1022 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)


Duration WellheadPressure p2 p2 Gas

Rate

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

Extended Flow 45.00 1019 1.0384 42.2745 36.520Stab. Shut-in 139.97 6581 43.3129Stab. Flow 1019 1.0384 42.2745 8.226

AOF n C

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

Stabilized 8.428 1.000 1.946e-01Extended 37.417 1.000 8.639e-01Isochronal 1.000

Simplified Wellhead AOF



1.0

101

102

2

3

5

2

3

5

p2

(106

kPa2

)

1.0 101 1022 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9

Gas Rate (103m3/d)


AOF Ext 37.417 103m3/dAOF 8.428 103m3/dn 1.000C 1.946e-01 (103m3/d)/106(kPa2)n

pi 6581 kPa(a)



Deliverability Analysis—TOFy y

Simplified Wellhead OPR



6800 AOF 8.428 103m3/d

5600

6000

6400

6800 AOF 8.428 10 m /dn 1.000C 1.946e-01 (103m3/d)/106(kPa2)n

pi 6581 kPa(a)

4400

4800

5200

3200

3600

4000

Pres

sure

(kPa

(a))

2000

2400

2800

P

800

1200

1600

0

400

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 5.60 5.80 6.00 6.20 6.40 6.60 6.80 7.00 7.20 7.40 7.60 7.80 8.00 8.20 8.40 8.60 8.80

Gas Rate (103m3/d)


FlowingPressure




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

0 8.428 4.865 3.1131000 8.233 4.670 2.9191019 8.226 4.663 2.9112000 7.650 4.086 2.3353000 6.677 3.113 1.3624000 5.315 1.751 0.000

AlternatePressure

kPa(a)

Stabilized Shut-In Pressure 6581Alternate Shut-In Pressure 1 5000Alternate Shut-In Pressure 2 4000

Simplified Wellhead OPR



0

1000

2000

3000

4000

5000

6000

Pres

sure

(kPa

(a))

0.00 0.40 0.80 1.20 1.60 2.00 2.40 2.80 3.20 3.60 4.00 4.40 4.80 5.20 5.60 6.00 6.40 6.80 7.20 7.60 8.00 8.40 8.80

Gas Rate (103m3/d)


AOF 8.428 103m3/dn 1.000C 1.946e-01 (103m3/d)/106(kPa2)n

pi 6581 kPa(a)




Section 4

Contents


Company Metric 73.00Engineer KB CF Difference DatumWell Name 882.60 878.40 4.20 -797.40L ti V ti l D i t d O h l H i t l R E t Tb C

Welltest Specialists Reserves Summary Sheet

Tbg WTTbg ID

Tbg ODAlberta Gas Corp.Max EngineerAGC Goldy100/01 02 030 04W5/04Location Vertical Deviated Openhole Horizontal Re-Entry

Formation 1676.02License # 139.70Completion: Stimulation:

Top-MD (m) Bot-MD (m) Top-TVD (m) Bot-TVD (m) Gross h (m) Net h (m) Porosity (%) Sw (%) So (%) Sg (%)1.00 10.00 32.00 68.00 Csg Cap

Tbg CapTbg End

Csg WTCsg ID

Csg OD101 mm TCP, 25 g RDX SDP, 17 SPM, 60° 15 t 20/40 Siber in DynaGel H2-N2 Energized, BD @ 35.6 MPa

100/01-02-030-04W5/04Victoria432100

1943.003.649

132.0690.274

82.5820 000

total-QOGRtotal-NWGR

g pCsg EndGOR

0.0001.00 10.00 32.00 68.00 0.180

Reservoir Pressure Temperature Recovery Gas Sp. Gravity Gas Z FVF, Bg Surface Loss 223%Properties (kPaa) (*C) (%) Properties (m3/m3) (%) 85%

7 548.00 62.67 80.0 0.671 0.882 0.0138 5.0Volumetrics Area Volume GIP OGIP RGIP MGIP OGIP RGIP MGIP

Ddown

WGRtotal-WLFRec'd

(ha) (ha*m) (e3m3/ha*m) (e6m3) (e6m3) (e6m3) (Bcf) (Bcf) (Bcf)Model 259.00 259.00 49 280 12.763 10.211 9.700 0.453 0.362 0.344Model/2 129.50 129.50 49 280 6.382 5.105 4.850 0.227 0.181 0.172Model/4 64.75 64.75 49 280 3.191 2.553 2.425 0.113 0.091 0.086Transient Line Pwf BH-Pwf MonthsForecast (kPag) (kPaa)Forecast (kPag) (kPaa)Line Case 1Line Case 2Line Case 3q.ab (e3m3/d) Pab (kpaa)Material Pressure Q-cum p/ZB l (kP ) ( 6 3)Balance (kPaa) (e6m3)

Decline CurveAnalogy UWI:

UWI:Infinite Conductivity Boundary Model: Deliverability n 1.000 n 1.000k 9.40 Xf 47.94 q 36.520 AOFext 40.695 T/COFext 37.417kh 9.402 Sc 25.82 qs 8.226 AOFstab 9.166 T/COFstab 8.428Sxf -5.838 Xe 1609A 259.0 Ye 1609 Line Pwf 1 019 q @ 12 Months

Fracture Model @ 259 haAGC Goldy100/01-02-030-04W5/04VictoriaApr 11–21, 2010

k = 9.4016 mDsc = 25.821 Xf = 47.943 mGIPmodel = 12.746 10

6m

3

Plan View(Not to scale)

No Flow

No Flow

No

Flow

No

Flow

Xe = 1609.344 m

Ye

= 16

09.3

44 m Xw = 804.672

Yw =

804

.672

Side View(Not to scale)

No Flow Top of Reservoir

No Flow Bottom of Reservoir

h =

1.00

0 m

Xf = 47.943 m




Section 5

Contents


eREPORT

Prepared for:Max Engineer

Alberta Gas Corp.1000 200 4th A en e SW 1000, 200 – 4th Avenue SW Calgary, Alberta, T2P 3B1

AGC Goldy100/01–02–030–04W5/04

Victoria OilVictoria OilRecompletion

Apr 11–13, 2010

www.welltestspecialists.com www.wespro.ca

Wespro Production Testing Ltd. Pressures and Flow Rate vs Time

AGC Goldy100/01-02-030-04W5/04VictoriaApril 11 - 13, 2010

Alberta Gas Corp.1679.0 - 1681.0 mKB

0

1000

2000

3000

4000

5000

6000

7000

8000

9000

10000

11000

12000

Tubi

ng P

res

Cas

ing

Pres

(kPa

(a))

0

10

20

30

40

50

60

70

80

90

100

Gas R

ate (Inst) (103m

3/d)

0

20

40

60

80

100

120

140

160

180

200

220

240

STOil R

ateW

ater Rate (m

3/d)

08 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14

April 11 2010 (Sunday) April 12 2010 (Monday) April 13 2010 (Tuesday)

Date Time 2010-04-13 12:30:00 PMGas Rate (Inst) 52.457Tubing Pres 1520Casing Pres 120STOil Rate 17.568

LegendTubing PresGas Rate (Inst)Casing PresSTOil RateWater Rate

Data Validation--Production

FieldNotes32X Ver 5.1.1.34 114398TM

H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\PTA1 Comprehensive\Goldy 100.01-02-030-04W5.4 Victoria\100.01-02-030-04W5.4 PRD 10-04-13.FLD 03-May-111

General Information

Company: Alberta Gas Corp.Contact: Max EngineerPhone: 403-411-1234Fax: E-Mail:

Street Address: Alberta Gas Corp.Street Address: 1000, 340 - 4th Avenue SWCity: CalgaryProvince/State: AlbertaPostal/Zip Code: T2R 3B2Country: Canada

Contact: Grant ParrottPhone: 780-411-4321Fax: E-Mail:

Well / Lease Name: AGC GoldyOperator: Alberta Gas Corp.Unique Well ID: 100/01-02-030-04W5/04Field: GoldySurface Location: 01-02-030-04W5

Company: WESPR Wespro Wireline ServicesTest Representative: Dave SandlineTest Type: RecompletionStart DateTime: 2010/04/11 07:15End DateTime: 2010/04/13 12:30

Remarks:

Supervisor: John WannabeTest Unit: P-222222Job Number: 22222Report By: Welltest Specialists Inc.Qualified By: David Leech

Client Information

Site Information Well Information

Test Information

Remarks

Company: Alberta Gas Corp.Unique Well ID: 100/01-02-030-04W5/04Start DateTime: 2010/04/11 07:15End DateTime: 2010/04/13 12:30

Well / Lease Name: AGC GoldyFormation: VictoriaPool: 1679.00 – 1681.00 mKBJob Number: 22222



Well / Lease Name: AGC GoldyOperator: Alberta Gas Corp.Unique Well ID: 100/01-02-030-04W5/04Surface Location: 01-02-030-04W5Fluid Type: 02 - Gas

Remarks: Deadweight serial number is 003075.

Well Information

Production Intervals

Remarks

Elevation Referenced From: 878.400 mElevation Referenced To: 882.600 mKB Elevation: 882.600 mGL Elevation: 878.400 mPool Datum: mWell Datum: mOffset: 4.200 m

Perforation Type: Producing Through: TubingTubing Size: 73.000 mmTubing Weight: 9.670 kg/mCasing Size: 139.700 mmCasing Weight: 23.070 kg/m

Field: GoldyPool: 1679.00 – 1681.00 mKBFormation: VictoriaWell Type: Vertical



Well Information

Production IntervalFrom

Production IntervalTo Depth Pressure

m m m kPa

1679.000 1681.000





Meter Report

Orifice Meter

Name: Gas Orifice Meter 1Meter Size: 97.307 mmTap Type: FlangeTap Location: Down stream

Gas Previous Production: 0.0000 103m3

Included in Total: YesMeter Adj. Factor: 1.000

Gas Properties

H2S: 0.00 %CO2: 0.71 %N2: 1.33 %

Gas Gravity(G): 0.671Critical Pressure(Pc): 4571.9 kPa(a)Critical Temperature(Tc): 209.4 K

Produced Volume Meter

Name: Oil Produced Volume Meter 2Meter Adj. Factor: 1.000Measurement Type: Incremental

Oil Previous Production: 0.000 m3

Water Previous Production: 0.000 m3

Included in Total: Yes

Vortex Meter

Flow Prover



Field Measurements

Company: Alberta Gas Corp.Well / Lease Name: AGC GoldyUnique Well ID: 100/01-02-030-04W5/04Test Type: Recompletion

Job Number: 22222Formation: VictoriaField: GoldyPool: 1679.00 – 1681.00 mKB

Wellhead Gas Orifice Meter 1 Oil Produced Volume Meter 2Date Time Cum

TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut

Oil Gain Oil Cum BS&WGain

BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %1 2010/04/11 07:15 0.00 Arrived on location, held a safety meeting.2 07:30 0.25 Spot and rig in the test equipment.3 09:35 2.33 Attend a safety meeting with all personnel on location.4 09:55 2.67 Pressure test the flowline and manifold.5 09:55 2.67 Record the tubing shut in pressure. There is a packer in the hole the casing is on a vac.6 09:55 2.67 0.00 6563 0.00 0 0.00 0 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.0007 09:55 2.67 Open to flow the tubing on a 7.94 mm (20/64") adjustable choke to bleed the tubing off.8 09:55 2.67 Gas Flared9 10:00 2.75 0.08 7.940 5042 8810 10:05 2.83 0.17 315911 10:05 2.83 Switch to flow on a 12.7 mm (1/2") choke.12 10:10 2.92 0.25 12.700 119313 10:11 2.93 Switch to flow on a 25.4 mm (1") choke.14 10:15 3.00 0.33 25.400 17315 10:15 3.00 Switch to flow on the 38.1 mm (1.5") gutline.16 10:20 3.08 0.42 38.100 13117 10:25 3.17 0.50 123 8818 10:25 3.17 Run in to start swabbing.19 10:45 3.50 0.83 11820 11:05 3.83 1.17 38.100 324 88 0.120 100.0 0.000 0.000 0.120 0.120 0.021 11:31 4.27 1.60 214 0.060 100.0 0.000 0.000 0.060 0.180 0.022 11:32 4.28 Wait one hour before pulling the next swab.23 12:00 4.75 1.60 131 0.000 0.000 0.000 0.000 0.18024 12:38 5.38 2.23 38.100 159 88 0.000 0.000 0.000 0.000 0.18025 12:40 5.42 Pulled a dry swab, rig out the swab equipment. Total water recovered while swabbing = 0.180 m 3.26 12:41 5.43 93 8827 12:45 5.50 Secure the test equipment for the night.28 14:00 6.75 Return to Pokono for the night.29 2010/04/12 06:30 23.25 Arrived on location, held a safety meeting.30 06:49 23.57 93 8831 06:50 23.58 6868 5132 06:51 23.60 93 5133 08:30 25.25 Rig the flowline into the choke on IES's wellhead saver tool.34 09:08 25.88 Attend the prefrac safety meeting with all personnel on location.35 10:13 26.97 The frac is complete.36 10:15 27.00 Load fluid to recover from the frac = 37.0 m3, including the 1.0 m3 of acid. API of the frac oil = 46.8 @ 16 degrees.37 10:30 27.25 Rig Cal Frac off the wellhead.38 10:40 27.42 Rig out the IES wellhead saver tool.39 10:49 27.57 93 5140 10:50 27.58 Rig up the deadweight and start recording the shut in pressures.41 10:50 27.58 10943 395242 10:55 27.67 10851 391543 11:00 27.75 10762 3891

Company: WESPR Wespro Wireline ServicesTest Type: Recompletion


H:\Davids Documents\My Business\Business Marketing\#Marketing Samples - Engineering\PTA1 Comprehensive\Goldy 100.01-02-030-04W5.4 Victoria\100.01-02-030-04W5.4 PRD 10-04-13.FLD 03-May-115-1


TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %44 2010/04/12 11:15 28.00 38.100 10515 3738 0.00 100.045 11:30 28.25 10245 365046 11:45 28.50 10073 357547 12:00 28.75 9829 351548 12:15 29.00 9651 342149 12:20 29.08 Attend a safety meeting with all personnel on location.50 12:30 29.25 2.23 9413 3421 0.00 0 0.00 0 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.18051 12:30 29.25 Pressure test the flowline and manifold.52 12:30 29.25 Open to flow the tubing on a 9.53 (24/64") mm choke. Fluid is at surface.53 12:35 29.33 2.32 9.530 7163 342954 12:37 29.37 Switch to flow on a 4.76 (12/64") mm choke.55 12:40 29.42 2.40 4.760 8 7018 3385 0.056 12:45 29.50 2.48 6 6761 3369 0.057 12:50 29.58 2.57 6 6276 3349 0.058 12:51 29.60 Switch to flow on a 6.35 mm (16/64") choke.59 13:00 29.75 2.73 6.350 8 5103 3323 3.694 0.0 3.694 3.694 0.000 0.180 0.060 13:15 30.00 2.98 8 3718 3282 0.561 13:30 30.25 3.23 8 2547 3236 1.974 0.0 1.974 5.668 0.000 0.180 0.162 13:37 30.37 Switch to flow on a 12.7 mm (1/2") choke.63 13:55 30.67 3.65 12.700 729 0.064 13:55 30.67 Switch to flow on the 38.1 mm gutline.65 14:00 30.75 3.73 38.100 8 329 3145 2.721 0.0 2.721 8.389 0.000 0.180 0.066 14:30 31.25 4.23 10 830 3090 3.161 0.0 3.161 11.550 0.000 0.180 0.067 14:55 31.67 Traces of burnable gas to surface.68 15:00 31.75 4.73 9 975 3045 0.00 0 0.00 0 0.00 0.000 0.000 4.627 0.0 4.627 16.177 0.000 0.180 0.069 15:25 32.17 The flare is more gas than N2 now, put the meter into service with a 50.8 mm (2.0") orifice plate.70 15:30 32.25 5.23 38.100 9 1135 2981 0.50 435 13.94 18 50.80 46.494 0.969 3.882 0.0 3.882 20.059 0.000 0.180 0.071 16:00 32.75 5.73 8 1279 2958 1.00 556 17.43 18 57.717 2.054 2.928 0.0 2.928 22.987 0.000 0.180 0.072 16:30 33.25 6.23 9 1274 2933 1.50 571 21.41 17 64.889 3.331 1.687 0.0 1.687 24.674 0.000 0.180 0.073 17:00 33.75 6.73 9 1523 2904 2.00 599 23.90 17 70.038 4.737 2.070 0.0 2.070 26.744 0.000 0.180 0.074 17:00 33.75 Starting to see some formation oil in the fluid returns.75 17:30 34.25 7.23 9 1342 2874 2.50 602 25.65 17 72.734 6.224 1.445 0.0 1.445 28.189 0.000 0.180 0.076 17:35 34.33 Switch to a 38.1 mm orifice plate and increase the back pressure to equal the pipeline pressure.77 18:00 34.75 7.73 38.100 9 1614 2846 3.00 1069 47.56 17 38.10 70.264 7.714 1.758 0.0 1.758 29.947 0.000 0.180 0.078 18:30 35.25 8.23 9 1623 2816 3.50 1089 47.81 17 71.066 9.186 0.970 0.0 0.970 30.917 0.000 0.180 0.079 19:00 35.75 8.73 9 1621 2793 4.00 1087 47.81 17 38.10 71.006 10.666 0.854 0.854 31.771 0.000 0.18080 19:00 35.75 Shut well in to rig in to pipe line, began to monitor build ups.81 19:05 35.83 4272 279082 19:10 35.92 5130 277483 19:15 36.00 5522 276284 19:30 36.25 5942 274185 19:45 36.50 6157 272186 20:00 36.75 0 6255 2703

Field Measurements






TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %87 2010/04/12 20:30 37.25 38.100 6349 2671 38.10 0.0 0.088 20:50 37.58 Pressure tested line to pipe line.89 21:00 37.75 8.73 6195 2652 4.00 0 0.00 0 0.00 0.000 10.666 0.000 0.000 31.771 0.000 0.18090 21:00 37.75 Opened well on a 9.53 mm bean choke to flow to pipe line.91 21:00 37.75 Gas Produced to Pipeline92 21:05 37.83 8.82 9.530 5 5439 2646 0.000 0.0 0.000 31.771 0.000 0.180 0.093 21:06 37.85 Increased to a 12.70 mm (32/64") bean choke.94 21:10 37.92 8.90 12.700 5 4258 2652 0.000 0.0 0.000 31.771 0.000 0.180 0.095 21:11 37.93 Increased to 38.10mm (gut line).96 21:15 38.00 8.98 38.100 0 2210 265097 21:16 38.02 Meter in service with a 38.10mm (1.500") orifice plate.98 21:20 38.08 9.07 5 2070 2651 4.33 1562 47.81 10 38.10 85.692 11.856 0.099 21:30 38.25 9.23 38.100 5 1992 2647 4.50 1527 38.84 10 76.299 12.418 0.0

100 22:00 38.75 9.73 38.100 5 1941 2640 5.00 1497 33.86 10 38.10 70.507 13.948 1.687 0.0 1.687 33.458 0.000 0.180 0.0101 22:30 39.25 10.23 38.100 5 1882 2615 5.50 1442 31.87 10 38.10 67.144 15.381 0.0102 23:00 39.75 10.73 6 1910 2597 6.00 1492 29.88 10 66.094 16.769 0.747 0.0 0.747 34.205 0.000 0.180 0.0103 23:30 40.25 11.23 6 1883 2579 6.50 1468 31.87 11 67.598 18.162 0.0104 2010/04/13 00:00 40.75 11.73 38.100 6 1846 2553 7.00 1434 31.87 12 38.10 66.693 19.561 2.141 0.0 2.141 36.346 0.000 0.180 0.0105 00:30 41.25 12.23 7 1784 2533 7.50 1384 31.87 12 65.550 20.938 0.0106 01:00 41.75 12.73 38.100 8 1772 2518 8.00 1387 32.37 12 38.10 66.136 22.310 2.560 0.0 2.560 38.906 0.000 0.180 0.0107 01:30 42.25 13.23 8 1773 2495 8.50 1364 31.87 12 65.088 23.677 0.0108 02:00 42.75 13.73 38.100 8 1759 2475 9.00 1362 31.87 12 38.10 65.042 25.033 1.880 0.0 1.880 40.786 0.000 0.180 0.0109 02:30 43.25 14.23 8 1766 2457 9.50 1383 29.88 12 63.433 26.371 0.0110 03:00 43.75 14.73 38.100 8 1753 2440 10.00 1377 29.38 12 38.10 62.763 27.685 1.997 0.0 1.997 42.783 0.000 0.180 0.0111 2010/04/13 03:30 44.25 15.23 8 1737 2421 10.50 1361 31.87 12 65.019 29.016 0.0112 04:00 44.75 15.73 38.100 8 1696 2404 11.00 1318 29.88 12 38.10 61.969 30.339 1.043 0.0 1.043 43.826 0.000 0.180 0.0113 04:30 45.25 16.23 8 1672 2391 11.50 1294 29.88 12 61.421 31.624 0.0114 05:00 45.75 16.73 38.100 8 1661 2373 12.00 1282 29.38 12 38.10 60.627 32.896 1.213 0.0 1.213 45.039 0.000 0.180 0.0115 05:30 46.25 17.23 8 1671 2350 12.50 1311 27.89 12 59.700 34.149 0.0116 06:00 46.75 17.73 38.100 8 1678 2340 13.00 1328 26.89 12 38.10 58.979 35.385 1.546 0.0 1.546 46.585 0.000 0.180 0.0117 06:30 47.25 18.23 8 1662 2321 13.50 1318 25.90 12 57.660 36.600118 07:00 47.75 18.73 38.100 8 1634 2303 14.00 1290 26.89 12 38.10 58.159 37.807 1.654 0.0 1.654 48.239 0.000 0.180119 07:30 48.25 19.23 8 1612 2287 14.50 1269 26.89 12 57.700 39.014120 08:00 48.75 19.73 38.100 8 1596 2273 15.00 1253 26.64 12 57.081 40.209 1.078 0.0 1.078 49.317 0.000 0.180 0.0121 08:15 49.00 The rig bled the casing off.122 08:30 49.25 20.23 8 1592 93 15.50 1254 26.15 12 56.562 41.393123 09:00 49.75 20.73 38.100 8 1629 108 16.00 1296 24.15 12 38.10 55.221 42.558 1.091 0.0 1.091 50.408 0.000 0.180 0.0124 09:30 50.25 21.23 8 1605 118 16.50 1264 24.65 13 55.014 43.706125 10:00 50.75 21.73 38.100 8 1664 123 17.00 1355 21.91 14 38.10 53.518 44.836 1.081 0.0 1.081 51.489 0.000 0.180 0.0126 10:30 51.25 22.23 8 1657 122 17.50 1350 21.41 14 52.809 45.944127 11:00 51.75 22.73 38.100 8 1632 121 18.00 1318 21.91 13 38.10 52.908 47.045 0.944 0.0 0.944 52.433 0.000 0.180128 11:30 52.25 23.23 8 1570 121 18.50 1246 23.41 14 53.126 48.150129 12:00 52.75 23.73 10 1577 121 19.00 1258 23.41 14 53.372 49.259 1.032 0.0 1.032 53.465 0.000 0.180

Field Measurements






TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %130 2010/04/13 12:30 53.25 24.23 38.100 10 1520 120 19.50 1187 23.90 14 38.10 52.457 50.361 0.366 0.0 0.366 53.831 0.000 0.180131 12:30 53.25 Shut the well in to rig up slickline.132 12:30 53.25 Starting a new report for the flow test.133134135136137138139

Field Measurements





eREPORT

Prepared for:Max Engineer

Alberta Gas Corp.1000 200 4th A en e SW 1000, 200 – 4th Avenue SW Calgary, Alberta, T2P 3B1

AGC Goldy100/01–02–030–04W5/04

Victoria OilVictoria OilIn-line Single Point Test

Apr 13–15, 2010

www.welltestspecialists.com www.wespro.ca

Wespro Production Testing Ltd. Pressures and Flow Rate vs Time

AGC Goldy100/01-02-030-04W5/04VictoriaApr 13 - 15, 2010

Alberta Gas Corp.1679.0 - 1681.0 mKB

0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

5500

Tubi

ng P

res

Cas

ing

Pres

(kPa

(a))

0

8

16

24

32

40

48

56

64

72

80

88

96

104

112

120

Gas R

ate (Inst) (103m

3/d)

0

2

4

6

8

10

12

14

16

18

20

22

24

26

28

30

Oil R

ateW

ater Rate (m

3/d)

12 14 16 18 20 22 00 02 04 06 08 10 12 14 16 18 20 22 00 02 04 06 08 10 12 14

April 13 2010 (Tuesday) April 14 2010 (Wednesday) April 15 2010 (Thursday)

Date Time 2010-04-15 12:00:00 PMOil Rate 10.008Gas Rate (Inst) 36.530Tubing Pres 1112Casing Pres 89

LegendGas Rate (Inst)Tubing PresCasing PresWater RateOil Rate

Data Validation--Production



General Information

Company: Alberta Gas Corp.Contact: Max EngineerPhone: 403-411-1234Fax: E-Mail: [email protected]

Street Address: Alberta Gas Corp.Street Address: 1000, 200 - 4th Avenue SWCity: CalgaryProvince/State: AlbertaPostal/Zip Code: T2R 3B1Country: Canada

Contact: Grant ParrottPhone: 780-411-4321Fax: E-Mail: [email protected]

Well / Lease Name: AGC GoldyOperator: Alberta Gas Corp.Unique Well ID: 100/01-02-030-04W5/04Field: GoldySurface Location: 01-02-030-04W5

Company: WESPR Wespro Wireline ServicesTest Representative: Dave SandlineTest Type: In-line TestStart DateTime: 2010/04/13 13:57End DateTime: 2010/04/15 15:30

Remarks:

Supervisor: John WannabeTest Unit: P-22222Job Number: 222222Report By: Welltest Specialists Inc.Qualified By: David Leech

Client Information

Site Information Well Information

Test Information

Remarks


Well / Lease Name: AGC GoldyFormation: VictoriaPool: 1679.0 – 1681.0Job Number: 222222



Well / Lease Name: AGC GoldyOperator: Alberta Gas Corp.Unique Well ID: 100/01-02-030-04W5/04Surface Location: 01-02-030-04W5Fluid Type: 02 - Gas

Remarks: Deadweight serial number 0030750. Inline flow test

Well Information

Production Intervals

Remarks

Elevation Referenced From: 878.400 mElevation Referenced To: 882.600 mKB Elevation: 882.600 mGL Elevation: 878.400 mPool Datum: mWell Datum: mOffset: 4.200 m

Perforation Type: Producing Through: TubingTubing Size: 73.000 mmTubing Weight: 9.670 kg/mCasing Size: 139.700 mmCasing Weight: 23.070 kg/m

Field: GoldyPool: 1679.0 – 1681.0Formation: VictoriaWell Type: Vertical



Well Information

Production IntervalFrom

Production IntervalTo Depth Pressure

m m m kPa

1679.000 1681.000





Meter Report

Orifice Meter

Name: Gas Orifice Meter 1Meter Size: 97.307 mmTap Type: FlangeTap Location: Down stream

Gas Previous Production: 0.0000 103m3

Included in Total: YesMeter Adj. Factor: 1.000

Gas Properties

H2S: 0.00 %CO2: 0.71 %N2: 1.33 %

Gas Gravity(G): 0.671Critical Pressure(Pc): 4571.9 kPa(a)Critical Temperature(Tc): 209.4 K

Produced Volume Meter

Name: Oil Produced Volume Meter 2Meter Adj. Factor: 1.000Measurement Type: Incremental

Oil Previous Production: 0.000 m3

Water Previous Production: 0.000 m3

Included in Total: Yes

Vortex Meter

Flow Prover



Field Measurements

Company: Alberta Gas Corp.Well / Lease Name: AGC GoldyUnique Well ID: 100/01-02-030-04W5/04Test Type: In-line Test

Job Number: 222222Formation: VictoriaField: GoldyPool: 1679.0 – 1681.0


TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %1 2010/04/13 13:57 0.00 Recorders were landed @ 1668.5 mGL.2 13:57 0.00 50743 14:35 0.63 Rig slickline off the well.4 14:45 0.80 Rig the deadweight into the well. Monitor the pressure.5 14:45 0.80 5238 456 14:50 0.88 5253 457 14:55 0.97 5266 448 14:55 0.97 Pressure test the flowline and manifold.9 15:00 1.05 0.00 5283 43 0.00 0 0.00 0 0.00 0.000 0.000 0.000 0.000 0.000 0.000 0.00010 15:00 1.05 Open to flow the tubing on a 12.7 mm (1/2") choke.11 15:00 1.05 Gas Produced to Pipeline12 15:05 1.13 0.08 12.700 404213 15:06 1.15 Switch to flow on the 38.1 mm gutline.14 15:06 1.15 Fluid to surface.15 15:08 1.18 Put the meter into service with a 38.1 mm orifice plate.16 15:08 1.18 0.1317 15:10 1.22 0.17 38.100 6 2049 43 0.17 1327 77.69 10 38.10 101.308 0.70418 15:15 1.30 0.25 8 1930 49 0.25 1363 79.68 10 103.953 1.06019 15:20 1.38 0.33 8 1895 51 0.33 1384 61.25 11 91.407 1.39920 15:30 1.55 0.50 8 1829 56 0.50 1388 49.55 11 82.200 2.00221 15:45 1.80 0.75 8 1716 58 0.75 1323 38.35 12 70.408 2.79722 16:00 2.05 1.00 38.100 8 1648 63 1.00 1267 34.86 12 38.10 65.715 3.506 0.784 0.0 0.784 0.784 0.000 0.000 0.023 16:30 2.55 1.50 8 1557 68 1.50 1196 31.37 11 60.732 4.82324 17:00 3.05 2.00 8 1572 71 2.00 1240 25.90 12 55.987 6.039 1.086 0.0 1.086 1.870 0.000 0.000 0.025 17:30 3.55 2.50 8 1525 78 2.50 1197 24.90 12 53.971 7.18426 18:00 4.05 3.00 8 1512 83 3.00 1186 24.40 12 53.189 8.300 0.708 0.0 0.708 2.578 0.000 0.000 0.027 18:30 4.55 3.50 8 1557 85 3.50 1251 21.91 12 51.693 9.39328 19:00 5.05 4.00 38.100 8 1516 96 4.00 1207 21.91 12 38.10 50.808 10.461 1.119 0.0 1.119 3.697 0.000 0.000 0.029 19:30 5.55 4.50 38.100 8 1483 97 4.50 1166 22.91 12 38.10 51.107 11.52230 20:00 6.05 5.00 8 1469 109 5.00 1151 22.91 12 50.794 12.584 1.212 0.0 1.212 4.909 0.000 0.000 0.031 20:30 6.55 5.50 8 1463 109 5.50 1149 22.91 12 50.752 13.64132 21:00 7.05 6.00 38.100 8 1453 109 6.00 1139 22.91 12 38.10 50.541 14.697 0.957 0.0 0.957 5.866 0.000 0.000 0.033 21:30 7.55 6.50 8 1482 111 6.50 1181 21.91 12 50.281 15.74734 22:00 8.05 7.00 8 1410 111 7.00 1088 23.41 12 49.993 16.791 0.822 0.0 0.822 6.688 0.000 0.000 0.035 22:30 8.55 7.50 8 1355 112 7.50 1079 22.91 12 49.259 17.82536 23:00 9.05 8.00 38.100 8 1353 109 8.00 1023 24.40 12 38.10 49.585 18.855 0.912 0.0 0.912 7.600 0.000 0.000 0.037 23:30 9.55 8.50 8 1342 110 8.50 1016 23.41 12 48.404 19.87538 2010/04/14 00:00 10.05 9.00 8 1327 110 9.00 995 23.90 12 48.435 20.884 0.728 0.0 0.728 8.328 0.000 0.00039 00:30 10.55 9.50 8 1302 108 9.50 968 24.40 12 48.317 21.89240 01:00 11.05 10.00 38.100 8 1286 104 10.00 948 25.40 12 38.10 48.828 22.904 1.094 0.0 1.094 9.422 0.000 0.000 0.041 01:30 11.55 10.50 8 1314 104 10.50 993 22.91 12 47.369 23.90642 02:00 12.05 11.00 8 1310 105 11.00 997 22.69 12 47.228 24.891 0.366 0.0 0.366 9.788 0.000 0.000 0.043 02:30 12.55 11.50 7 1347 97 11.50 1049 20.92 12 46.434 25.867

Company: WESPR Wespro Wireline ServicesTest Type: In-line Test




TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %44 2010/04/14 03:00 13.05 12.00 38.100 7 1318 90 12.00 1015 20.42 12 38.10 45.165 26.821 0.731 0.0 0.731 10.519 0.000 0.000 0.045 03:30 13.55 12.50 7 1334 88 12.50 1037 19.92 11 45.145 27.76246 04:00 14.05 13.00 7 1321 87 13.00 1022 20.92 11 45.955 28.711 0.849 0.0 0.849 11.368 0.000 0.000 0.047 04:30 14.55 13.50 6 1353 84 13.50 1065 19.92 11 45.717 29.66648 05:00 15.05 14.00 38.100 5 1361 78 14.00 1076 18.92 10 38.10 44.852 30.609 0.599 0.0 0.599 11.967 0.000 0.000 0.049 05:30 15.55 14.50 6 1333 108 14.50 1051 18.92 10 44.356 31.53850 06:00 16.05 15.00 38.100 6 1385 110 15.00 1117 17.93 11 38.10 44.351 32.462 0.936 0.0 0.936 12.903 0.000 0.000 0.051 06:30 16.55 15.50 6 1354 109 15.50 1086 18.92 11 44.967 33.39352 07:00 17.05 16.00 8 1288 109 16.00 1001 19.92 10 44.486 34.325 0.843 0.0 0.843 13.746 0.000 0.000 0.053 07:30 17.55 16.50 8 1280 108 16.50 995 19.42 10 43.799 35.24454 08:00 18.05 17.00 38.100 8 1279 108 17.00 994 19.42 11 38.10 43.694 36.156 0.732 0.0 0.732 14.478 0.000 0.000 0.055 08:30 18.55 17.50 8 1260 103 17.50 968 19.92 11 43.708 37.06656 09:00 19.05 18.00 8 1225 101 18.00 927 20.92 11 43.899 37.979 0.488 0.0 0.488 14.966 0.000 0.000 0.057 09:30 19.55 18.50 8 1220 101 18.50 923 20.42 11 43.283 38.88758 10:00 20.05 19.00 38.100 8 1253 98 19.00 967 19.92 12 38.10 43.603 39.792 0.731 0.0 0.731 15.697 0.000 0.000 0.059 10:30 20.55 19.50 9 1272 98 19.50 977 18.92 12 42.697 40.69160 11:00 21.05 20.00 9 1217 97 20.00 972 18.43 12 42.028 41.573 0.608 0.0 0.608 16.305 0.000 0.000 0.061 11:30 21.55 20.50 9 1289 97 20.50 1001 17.93 12 42.028 42.44962 12:00 22.05 21.00 38.100 9 1267 92 21.00 975 17.93 12 38.10 41.512 43.319 0.725 0.0 0.725 17.030 0.000 0.000 0.063 12:30 22.55 21.50 10 1259 92 21.50 968 17.93 14 41.216 44.18164 13:00 23.05 22.00 12 1259 93 22.00 968 17.93 15 41.138 45.039 0.598 0.0 0.598 17.628 0.000 0.000 0.065 13:30 23.55 22.50 12 1242 92 22.50 950 18.18 15 41.063 45.89566 14:00 24.05 23.00 38.100 14 1263 91 23.00 978 18.18 16 41.546 46.756 0.710 0.0 0.710 18.338 0.000 0.000 0.067 14:30 24.55 23.50 15 1246 92 23.50 978 18.18 16 41.546 47.62168 15:00 25.05 24.00 15 1265 90 24.00 983 17.43 17 40.700 48.478 0.599 0.0 0.599 18.937 0.000 0.000 0.069 15:30 25.55 24.50 13 1264 93 24.50 992 16.43 17 39.683 49.31570 16:00 26.05 25.00 38.100 12 1272 89 25.00 1000 16.18 16 38.10 39.602 50.141 0.493 0.0 0.493 19.430 0.000 0.000 0.071 16:30 26.55 25.50 12 1256 93 25.50 985 16.18 15 39.396 50.96472 17:00 27.05 26.00 12 1255 96 26.00 979 16.43 15 39.586 51.787 0.507 0.0 0.507 19.937 0.000 0.000 0.073 17:30 27.55 26.50 14 1292 93 26.50 1025 15.94 15 39.829 52.61474 18:00 28.05 27.00 12 1279 91 27.00 1014 15.94 15 39.627 53.442 0.379 0.0 0.379 20.316 0.000 0.000 0.075 18:30 28.55 27.50 12 1274 88 27.50 1006 15.94 15 39.480 54.26676 19:00 29.05 28.00 38.100 12 1265 88 28.00 999 15.94 15 38.10 39.355 55.087 0.392 0.0 0.392 20.708 0.000 0.000 0.077 19:30 29.55 28.50 11 1251 87 28.50 987 15.94 15 39.133 55.90478 20:00 30.05 29.00 11 1203 86 29.00 924 16.43 15 38.528 56.713 0.389 0.0 0.389 21.097 0.000 0.000 0.079 20:30 30.55 29.50 11 1215 87 29.50 950 16.93 15 39.622 57.52780 21:00 31.05 30.00 38.100 11 1209 82 30.00 939 16.93 15 38.10 39.407 58.351 0.509 0.0 0.509 21.606 0.000 0.000 0.081 21:30 31.55 30.50 8 1162 75 30.50 882 17.93 13 39.548 59.17382 22:00 32.05 31.00 8 1142 74 31.00 859 17.93 14 38.995 59.991 0.508 0.0 0.508 22.114 0.000 0.000 0.083 22:30 32.55 31.50 5 1132 75 31.50 847 17.93 11 38.963 60.80384 23:00 33.05 32.00 38.100 5 1123 75 32.00 840 17.93 11 38.10 38.814 61.614 0.385 0.0 0.385 22.499 0.000 0.000 0.085 23:30 33.55 32.50 5 1175 74 32.50 911 16.93 11 39.151 62.42686 2010/04/15 00:00 34.05 33.00 5 1140 74 33.00 842 17.93 11 38.857 63.238 0.382 0.0 0.382 22.881 0.000 0.000 0.0

Field Measurements






TimeFlowTime

ChokeSize

TubingTemp

TubingPres

CasingPres

FlowTime

StaticPres

DiffPres

MeterTemp

PlateSize

Gas Rate(Inst)

Gas Cum IncVolume

BS&WCut


BS&WCum

Sand

YYYY/MM/DD HH:mm h h mm °C kPa(a) kPa(a) h kPa(g) kPa °C mm 103m3/d 103m3 m3 % m3 m3 m3 m3 %87 2010/04/15 00:30 34.55 33.50 38.100 5 1102 73 33.50 816 18.43 11 38.10 38.835 64.048 0.088 01:00 35.05 34.00 38.100 6 1163 73 34.00 896 16.93 11 38.10 38.850 64.857 0.734 0.0 0.734 23.615 0.000 0.000 0.089 01:30 35.55 34.50 6 1157 71 34.50 891 16.93 10 38.823 65.66690 02:00 36.05 35.00 6 1154 69 35.00 888 16.43 10 38.183 66.468 0.381 0.0 0.381 23.996 0.000 0.000 0.091 02:30 36.55 35.50 5 1147 67 35.50 880 16.93 10 38.601 67.26892 03:00 37.05 36.00 38.100 5 1197 65 36.00 941 14.94 10 38.10 37.397 68.059 0.621 0.0 0.621 24.617 0.000 0.000 0.093 03:30 37.55 36.50 5 1198 50 36.50 944 14.94 10 37.452 68.83994 04:00 38.05 37.00 5 1200 52 37.00 931 14.44 10 36.580 69.610 0.389 0.0 0.389 25.006 0.000 0.00095 04:30 38.55 37.50 6 1205 51 37.50 956 13.94 10 36.386 70.37096 05:00 39.05 38.00 38.100 5 1197 51 38.00 942 14.19 10 38.10 36.460 71.129 0.269 0.0 0.269 25.275 0.000 0.000 0.097 05:30 39.55 38.50 5 1177 49 38.50 921 13.94 10 35.758 71.88198 06:00 40.05 39.00 4 1206 55 39.00 954 14.18 10 36.668 72.636 0.512 0.0 0.512 25.787 0.000 0.00099 06:30 40.55 39.50 5 1189 63 39.50 934 13.94 10 35.986 73.393

100 07:00 41.05 40.00 38.100 6 1151 65 40.00 886 15.68 8 38.10 37.397 74.157 0.506 0.0 0.506 26.293 0.000 0.000101 07:30 41.55 40.50 5 1128 66 40.50 854 15.94 9 37.004 74.932102 08:00 42.05 41.00 6 1201 68 41.00 945 13.95 10 36.202 75.695 0.485 0.0 0.485 26.778 0.000 0.000103 08:30 42.55 41.50 6 1221 69 41.50 962 13.95 10 36.506 76.452104 09:00 43.05 42.00 38.100 6 1164 72 42.00 891 14.44 10 38.10 35.840 77.206 0.483 0.0 0.483 27.261 0.000 0.000105 09:30 43.55 42.50 6 1146 73 42.50 866 15.43 12 36.429 77.958106 10:00 44.05 43.00 8 1139 75 43.00 858 15.93 14 36.719 78.720 0.617 0.0 0.617 27.878 0.000 0.000107 10:30 44.55 43.50 10 1129 83 43.50 847 15.93 15 36.433 79.482108 11:00 45.05 44.00 38.100 10 1140 85 44.00 859 15.93 15 38.10 36.670 80.244 0.456 0.0 0.456 28.334 0.000 0.000109 11:30 45.55 44.50 10 1102 87 44.50 811 16.42 15 36.272 81.004110 11:45 45.80 Took 2 H.P. Agat gas samples #12345 & 23456 and H.P. Oil samples #112233 & 556677.111 12:00 46.05 45.00 10 1112 89 45.00 827 16.42 16 36.530 81.762 0.417 0.0 0.417 28.751 0.000 0.000 0.0112 12:00 46.05 Shut well in and record 1 hr. of buildups.113 12:05 46.13 2202114 12:10 46.22 2845115 12:15 46.30 3055116 12:30 46.55 3236117 12:45 46.80 3390118 13:00 47.05 45.00 3548 45.00 0 0.00 0 0.00 0.000 81.762 0.000 0.0 0.000 28.751 0.000 0.000119 13:00 47.05 Finished buildups, continue to rig out equipment.120 15:30 49.55 Finished rigging, Return to base.121 Job Complete.

Field Measurements






Section 6

Contents


Storm Ventures International Inc.

100/06-22-040-01W5/4 Recorder: 9499 [TOP]SVI GILBY 06-22-040-01

Page: 1

ELECTRONIC SUBSURFACE PRESSURE MEASUREMENTS

Tel (403) 279-8895Fax (403) 236-4698

Basic Data

Well Name: Location:

Status:

Producing Through:

Tubing Depth:

Pool Datum:

AGC Goldy100/01-02-030-04W5/4

Gas

Tubing

(subsea)

Company: Address:

Type of Test:

Field and Pool:

Elevation:

Perforated Interval:

Mid-Point of Prod Interval:

Shut-In Date Prior to Test:

Test Summary

Alberta Gas Corp.

1000, 200 - 4th Avenue, SW

Flow & Build Up

Goldy/Victoria

(GL) 878.40 (KB) 882.60

1679.00-1681.00 m KB

1680.00 m KB

13 Apr 2010 12:30

TOP

73.0mm

Date of Test: 13 Apr 2010 Run Depth Temperature: 62.68 °C

On Bottom: 13 Apr 2010 13:57 Off Bottom: 21 Apr 2010 08:03

DWG Pressure kPaa Date: 13 Apr 2010 INITIAL: Tubing: 5074 Casing: 120

Date: 21 Apr 2010 FINAL: Tubing: 6109 Casing: 941

Test Purpose: Initial

License # 432100 Direction: Vertical

Electronic Recorder #: 9499 9500

Run Depth From: 1671.7 m KB 1672.7 m KB

Pressure at Run Depth (kPaa): 7075.21 7082.12

Gradient at Run Depth (kPa/m): 0.470 0.470

Pressure at MPP (kPaa): 7079.11 7085.55

Pressure at Datum Depth (kPaa):

Remarks:

Depth reported in m KB and pressures in ABSOLUTE (Gauge + 93 kpa).

Top Bottom

Alberta Gas Corp.

100/01-02-030-04W5/4 Recorder: 9499 [TOP]AGC Goldy 01-02-030-04

Page: 2

Time Duration Pressure Temphours kPaa ºC

10/04/1314:30:10 0.553 5964.24 61.8615:03:30 1.108 5459.63 61.2115:36:50 1.664 3634.44 61.2616:10:10 2.219 3451.62 61.2916:43:30 2.775 3342.50 61.2717:16:50 3.331 3321.20 61.2717:50:10 3.886 3266.81 61.2618:23:30 4.442 3241.59 61.2718:56:50 4.997 3212.33 61.2619:30:10 5.553 3165.27 61.2520:03:30 6.108 3131.65 61.2620:36:50 6.664 3105.47 61.2521:10:10 7.219 3102.17 61.2621:43:30 7.775 3070.45 61.2622:16:50 8.331 2997.44 61.2422:50:10 8.886 2967.10 61.2123:23:30 9.442 2942.22 61.2123:56:50 9.997 2922.06 61.1910/04/1400:30:10 10.553 2892.11 61.1801:03:30 11.108 2866.54 61.1701:36:50 11.664 2871.08 61.1802:10:10 12.219 2890.22 61.1902:43:30 12.775 2871.41 61.1903:16:50 13.331 2863.59 61.1903:50:10 13.886 2853.42 61.1904:23:30 14.442 2852.76 61.2004:56:50 14.997 2852.49 61.2105:30:10 15.553 2836.63 61.2006:03:30 16.108 2852.27 61.2206:36:50 16.664 2826.05 61.2107:10:10 17.219 2789.48 61.2007:43:30 17.775 2772.15 61.1908:16:50 18.331 2763.91 61.1908:50:10 18.886 2729.98 61.1609:23:30 19.442 2706.41 61.1409:56:50 19.997 2715.41 61.1510:30:10 20.553 2713.65 61.1511:03:30 21.108 2705.55 61.1511:36:50 21.664 2709.08 61.1512:10:10 22.219 2695.00 61.1512:43:30 22.775 2686.40 61.1413:16:50 23.331 2675.91 61.1313:50:10 23.886 2660.45 61.1314:23:30 24.442 2651.98 61.1214:56:50 24.997 2664.52 61.1215:30:10 25.553 2663.83 61.1316:03:30 26.108 2660.19 61.1316:36:50 26.664 2654.91 61.1317:10:10 27.219 2656.04 61.1317:43:30 27.775 2660.74 61.1318:16:50 28.331 2654.70 61.1318:50:10 28.886 2646.82 61.1319:23:30 29.442 2636.86 61.1219:56:50 29.997 2605.14 61.1120:30:10 30.553 2599.83 61.1021:03:30 31.108 2584.68 61.0921:36:50 31.664 2559.92 61.0722:10:10 32.219 2540.67 61.06


22:43:30 32.775 2527.57 61.0423:16:50 33.331 2541.88 61.0523:50:10 33.886 2528.02 61.0010/04/1500:23:30 34.442 2498.17 60.9600:56:50 34.997 2515.63 60.9701:30:10 35.553 2514.17 60.9602:03:30 36.108 2513.95 60.9602:36:50 36.664 2508.63 60.9503:10:10 37.219 2533.04 60.9703:43:30 37.775 2534.54 60.9704:16:50 38.331 2528.83 60.9604:50:10 38.886 2536.77 60.9805:23:30 39.442 2526.78 60.9705:56:50 39.997 2518.12 60.9706:30:10 40.553 2508.73 60.9607:03:30 41.108 2498.56 60.9607:36:50 41.664 2481.42 60.9408:10:10 42.219 2504.33 60.9608:43:30 42.775 2501.13 60.9609:16:50 43.331 2480.75 60.9409:50:10 43.886 2464.57 60.9210:23:30 44.442 2448.73 60.9210:56:50 44.997 2443.59 60.9111:30:10 45.553 2414.25 60.9012:03:30 46.108 2478.61 60.9112:36:50 46.664 4063.04 61.9013:10:10 47.219 4369.57 61.8113:43:30 47.775 4573.26 61.7814:16:50 48.331 4726.00 61.9314:50:10 48.886 4848.52 62.0415:23:30 49.442 4950.82 62.1015:56:50 49.997 5038.78 62.1316:30:10 50.553 5116.44 62.1617:03:30 51.108 5186.43 62.1817:36:50 51.664 5250.72 62.2018:10:10 52.219 5310.90 62.2218:43:30 52.775 5367.52 62.2419:16:50 53.331 5420.71 62.2519:50:10 53.886 5471.38 62.2720:23:30 54.442 5514.97 62.1620:56:50 54.997 5562.77 62.2821:30:10 55.553 5607.56 62.3122:03:30 56.108 5650.18 62.3322:36:50 56.664 5690.94 62.3423:10:10 57.219 5729.78 62.3523:43:30 57.775 5767.52 62.3610/04/1600:16:50 58.331 5803.36 62.3600:50:10 58.886 5838.05 62.3601:23:30 59.442 5871.44 62.3701:56:50 59.997 5903.47 62.3702:30:10 60.553 5934.42 62.3803:03:30 61.108 5964.00 62.3803:36:50 61.664 5992.41 62.3804:10:10 62.219 6020.13 62.3904:43:30 62.775 6046.61 62.3905:16:50 63.331 6072.06 62.4005:50:10 63.886 6096.70 62.4006:23:30 64.442 6120.27 62.40


06:56:50 64.997 6143.13 62.4107:30:10 65.553 6165.17 62.4208:03:30 66.108 6186.41 62.4208:36:50 66.664 6206.85 62.4309:10:10 67.219 6226.52 62.4309:43:30 67.775 6245.70 62.4410:16:50 68.331 6264.07 62.4410:50:10 68.886 6281.69 62.4411:23:30 69.442 6298.84 62.4511:56:50 69.997 6315.51 62.4512:30:10 70.553 6331.67 62.4613:03:30 71.108 6347.19 62.4613:36:50 71.664 6362.33 62.4614:10:10 72.219 6376.92 62.4614:43:30 72.775 6390.98 62.4615:16:50 73.331 6404.83 62.4615:50:10 73.886 6418.15 62.4716:23:30 74.442 6431.07 62.4716:56:50 74.997 6443.78 62.4717:30:10 75.553 6455.97 62.4718:03:30 76.108 6468.02 62.4818:36:50 76.664 6479.52 62.4719:10:10 77.219 6490.81 62.4819:43:30 77.775 6501.69 62.4820:16:50 78.331 6512.42 62.4820:50:10 78.886 6522.79 62.4821:23:30 79.442 6532.99 62.4821:56:50 79.997 6542.95 62.4922:30:10 80.553 6552.73 62.4923:03:30 81.108 6562.14 62.4923:36:50 81.664 6571.27 62.4910/04/1700:10:10 82.219 6580.49 62.5000:43:30 82.775 6589.15 62.5001:16:50 83.331 6597.74 62.5001:50:10 83.886 6606.15 62.5102:23:30 84.442 6614.50 62.5102:56:50 84.997 6622.74 62.5103:30:10 85.553 6630.46 62.5104:03:30 86.108 6638.29 62.5104:36:50 86.664 6645.77 62.5105:10:10 87.219 6653.20 62.5205:43:30 87.775 6660.52 62.5206:16:50 88.331 6667.55 62.5306:50:10 88.886 6674.45 62.5207:23:30 89.442 6681.44 62.5307:56:50 89.997 6687.96 62.5308:30:10 90.553 6694.61 62.5309:03:30 91.108 6701.09 62.5309:36:50 91.664 6707.27 62.5310:10:10 92.219 6713.69 62.5410:43:30 92.775 6719.67 62.5411:16:50 93.331 6725.55 62.5511:50:10 93.886 6731.39 62.5512:23:30 94.442 6737.01 62.5512:56:50 94.997 6742.71 62.5513:30:10 95.553 6748.08 62.5514:03:30 96.108 6753.33 62.5514:36:50 96.664 6758.70 62.5515:10:10 97.219 6763.86 62.55

Alberta Gas Corp.

100/01-02-030-04W5/4 Recorder: 9499 [TOP]AGC Goldy 01-02-030-04

Page: 3


15:43:30 97.775 6768.88 62.5516:16:50 98.331 6773.88 62.5616:50:10 98.886 6778.64 62.5517:23:30 99.442 6783.45 62.5517:56:50 99.997 6787.99 62.5518:30:10 100.553 6792.69 62.5619:03:30 101.108 6797.15 62.5619:36:50 101.664 6801.55 62.5620:10:10 102.219 6805.84 62.5620:43:30 102.775 6810.14 62.5621:16:50 103.331 6814.19 62.5621:50:10 103.886 6818.32 62.5622:23:30 104.442 6822.33 62.5722:56:50 104.997 6826.17 62.5623:30:10 105.553 6830.14 62.5710/04/1800:03:30 106.108 6833.93 62.5700:36:50 106.664 6837.61 62.5701:10:10 107.219 6841.38 62.5801:43:30 107.775 6844.90 62.5702:16:50 108.331 6848.58 62.5802:50:10 108.886 6852.00 62.5803:23:30 109.442 6855.47 62.5803:56:50 109.997 6858.74 62.5804:30:10 110.553 6862.10 62.5805:03:30 111.108 6865.49 62.5805:36:50 111.664 6868.72 62.5906:10:10 112.219 6871.89 62.5906:43:30 112.775 6875.00 62.5907:16:50 113.331 6878.15 62.5907:50:10 113.886 6881.21 62.5908:23:30 114.442 6884.29 62.5908:56:50 114.997 6887.24 62.5909:30:10 115.553 6890.12 62.5910:03:30 116.108 6893.06 62.6010:36:50 116.664 6895.90 62.6011:10:10 117.219 6898.73 62.6011:43:30 117.775 6901.45 62.6012:16:50 118.331 6904.23 62.6012:50:10 118.886 6906.84 62.6013:23:30 119.442 6909.53 62.6013:56:50 119.997 6912.14 62.6114:30:10 120.553 6914.73 62.6015:03:30 121.108 6917.04 62.6015:36:50 121.664 6919.61 62.6016:10:10 122.219 6922.15 62.6116:43:30 122.775 6924.41 62.6017:16:50 123.331 6926.80 62.6117:50:10 123.886 6929.18 62.6118:23:30 124.442 6931.39 62.6118:56:50 124.997 6933.62 62.6119:30:10 125.553 6935.98 62.6120:03:30 126.108 6938.02 62.6120:36:50 126.664 6940.26 62.6121:10:10 127.219 6942.45 62.6121:43:30 127.775 6944.51 62.6122:16:50 128.331 6946.48 62.6122:50:10 128.886 6948.71 62.6223:23:30 129.442 6950.57 62.6223:56:50 129.997 6952.54 62.61


10/04/1900:30:10 130.553 6954.56 62.6201:03:30 131.108 6956.61 62.6201:36:50 131.664 6958.41 62.6202:10:10 132.219 6960.32 62.6202:43:30 132.775 6962.34 62.6203:16:50 133.331 6964.09 62.6303:50:10 133.886 6965.92 62.6204:23:30 134.442 6967.75 62.6204:56:50 134.997 6969.42 62.6205:30:10 135.553 6971.33 62.6306:03:30 136.108 6972.98 62.6306:36:50 136.664 6974.81 62.6307:10:10 137.219 6976.48 62.6307:43:30 137.775 6978.13 62.6308:16:50 138.331 6979.80 62.6308:50:10 138.886 6981.54 62.6309:23:30 139.442 6982.76 62.6409:56:50 139.997 6983.83 62.6310:30:10 140.553 6985.82 62.6411:03:30 141.108 6987.56 62.6411:36:50 141.664 6989.27 62.6412:10:10 142.219 6990.96 62.6412:43:30 142.775 6992.30 62.6413:16:50 143.331 6993.79 62.6413:50:10 143.886 6995.44 62.6414:23:30 144.442 6996.90 62.6414:56:50 144.997 6998.39 62.6415:30:10 145.553 6999.91 62.6416:03:30 146.108 7001.20 62.6416:36:50 146.664 7002.62 62.6417:10:10 147.219 7004.01 62.6517:43:30 147.775 7005.50 62.6518:16:50 148.331 7006.76 62.6418:50:10 148.886 7008.16 62.6519:23:30 149.442 7009.43 62.6419:56:50 149.997 7010.64 62.6520:30:10 150.553 7011.99 62.6521:03:30 151.108 7013.35 62.6521:36:50 151.664 7014.58 62.6522:10:10 152.219 7015.78 62.6522:43:30 152.775 7017.02 62.6523:16:50 153.331 7018.36 62.6523:50:10 153.886 7019.52 62.6510/04/2000:23:30 154.442 7020.84 62.6500:56:50 154.997 7021.88 62.6501:30:10 155.553 7023.12 62.6502:03:30 156.108 7024.31 62.6502:36:50 156.664 7025.48 62.6503:10:10 157.219 7026.64 62.6503:43:30 157.775 7027.81 62.6604:16:50 158.331 7028.88 62.6604:50:10 158.886 7029.90 62.6505:23:30 159.442 7031.17 62.6605:56:50 159.997 7032.17 62.6506:30:10 160.553 7033.36 62.6607:03:30 161.108 7034.34 62.6607:36:50 161.664 7035.46 62.6608:10:10 162.219 7036.60 62.66


08:43:30 162.775 7037.82 62.6609:16:50 163.331 7038.73 62.6609:50:10 163.886 7039.90 62.6610:23:30 164.442 7040.95 62.6610:56:50 164.997 7041.97 62.6611:30:10 165.553 7043.03 62.6612:03:30 166.108 7043.99 62.6612:36:50 166.664 7044.99 62.6613:10:10 167.219 7045.94 62.6713:43:30 167.775 7047.01 62.6614:16:50 168.331 7047.98 62.6614:50:10 168.886 7048.88 62.6715:23:30 169.442 7049.92 62.6715:56:50 169.997 7050.73 62.6716:30:10 170.553 7051.69 62.6717:03:30 171.108 7052.61 62.6717:36:50 171.664 7053.57 62.6718:10:10 172.219 7054.41 62.6718:43:30 172.775 7055.32 62.6719:16:50 173.331 7056.16 62.6719:50:10 173.886 7057.07 62.6720:23:30 174.442 7058.06 62.6720:56:50 174.997 7058.81 62.6721:30:10 175.553 7059.66 62.6722:03:30 176.108 7060.56 62.6722:36:50 176.664 7061.50 62.6723:10:10 177.219 7062.29 62.6723:43:30 177.775 7063.11 62.6710/04/2100:16:50 178.331 7064.02 62.6700:50:10 178.886 7064.73 62.6701:23:30 179.442 7065.57 62.6701:56:50 179.997 7066.38 62.6702:30:10 180.553 7067.26 62.6703:03:30 181.108 7067.99 62.6703:36:50 181.664 7068.90 62.6704:10:10 182.219 7069.67 62.6804:43:30 182.775 7070.39 62.6805:16:50 183.331 7071.13 62.6705:50:10 183.886 7071.94 62.6706:23:30 184.442 7072.92 62.6806:56:50 184.997 7073.58 62.6807:30:10 185.553 7074.48 62.68

Alberta Gas Corp.AGC Goldy 01-02-030-04 (100/01-02-030-04W5/4)Probe: 9499 [top]

0 20 40 60 80 100 120 140 160 180 20059

60

61

62

63

2000

2500

3000

3500

4000

4500

5000

5500

6000

6500

7000

7500

Time (Hours)

Pres

sure

(kPa

a)Te

mp

(C)

10/04/13 15:006063 kPaaWell open to flow at approx.

10/04/15 12:022410 kPaaShut well in for final build-up at approx.

10/04/21 08:037075 kPaaOff Bottom.


100/06-22-040-01W5/4 Recorder: 9500 [BOTTOM]SVI GILBY 06-22-040-01

Page: 1


Tel (403) 279-8895Fax (403) 236-4698

Basic Data


Status:

Producing Through:

Tubing Depth:

Pool Datum:

AGC Goldy100/01-02-030-04W5/4

Gas

Tubing

(subsea)

Company: Address:

Type of Test:

Field and Pool:

Elevation:




Test Summary

Alberta Gas Corp.

1000, 200 - 4th Avenue, SW

Flow & Build Up

Goldy/Victoria

(GL) 878.40 (KB) 882.60

1679.00-1681.00 m KB

1680.00 m KB

13 Apr 2010 12:30

BOTTOM

73.0mm

Date of Test: 13 Apr 2010 Run Depth Temperature: 62.67 °C












Remarks:


Top Bottom

Alberta Gas Corp.

100/01-02-030-04W5/4 Recorder: 9500 [BOTTOM]AGC Goldy 01-02-030-04

Page: 2


10/04/1314:30:10 0.553 5974.53 61.8415:03:30 1.108 5402.49 61.2915:36:50 1.664 3635.90 61.2816:10:10 2.219 3455.16 61.3116:43:30 2.775 3347.20 61.2817:16:50 3.331 3325.58 61.2717:50:10 3.886 3270.80 61.2818:23:30 4.442 3248.52 61.2818:56:50 4.997 3216.75 61.2719:30:10 5.553 3169.70 61.2720:03:30 6.108 3136.36 61.2720:36:50 6.664 3109.36 61.2621:10:10 7.219 3107.41 61.2821:43:30 7.775 3074.04 61.2622:16:50 8.331 3001.14 61.2422:50:10 8.886 2971.74 61.2323:23:30 9.442 2946.92 61.2323:56:50 9.997 2925.84 61.2010/04/1400:30:10 10.553 2896.33 61.1901:03:30 11.108 2870.64 61.1901:36:50 11.664 2875.58 61.1802:10:10 12.219 2894.36 61.2002:43:30 12.775 2875.25 61.2003:16:50 13.331 2867.83 61.2003:50:10 13.886 2858.00 61.2004:23:30 14.442 2858.28 61.2204:56:50 14.997 2856.78 61.2205:30:10 15.553 2840.29 61.2206:03:30 16.108 2856.40 61.2306:36:50 16.664 2829.80 61.2207:10:10 17.219 2793.28 61.2107:43:30 17.775 2776.43 61.2008:16:50 18.331 2768.29 61.1908:50:10 18.886 2733.68 61.1709:23:30 19.442 2709.96 61.1609:56:50 19.997 2719.24 61.1610:30:10 20.553 2717.65 61.1611:03:30 21.108 2709.71 61.1611:36:50 21.664 2713.17 61.1612:10:10 22.219 2698.75 61.1612:43:30 22.775 2690.23 61.1513:16:50 23.331 2680.41 61.1413:50:10 23.886 2665.32 61.1414:23:30 24.442 2655.98 61.1314:56:50 24.997 2668.44 61.1415:30:10 25.553 2668.23 61.1416:03:30 26.108 2663.70 61.1416:36:50 26.664 2659.09 61.1417:10:10 27.219 2661.50 61.1517:43:30 27.775 2665.01 61.1518:16:50 28.331 2658.66 61.1418:50:10 28.886 2650.88 61.1419:23:30 29.442 2640.89 61.1319:56:50 29.997 2608.75 61.1220:30:10 30.553 2603.73 61.1121:03:30 31.108 2588.48 61.1021:36:50 31.664 2563.50 61.0822:10:10 32.219 2544.27 61.07


22:43:30 32.775 2531.34 61.0623:16:50 33.331 2545.06 61.0523:50:10 33.886 2531.37 61.0110/04/1500:23:30 34.442 2502.24 60.9700:56:50 34.997 2519.26 60.9801:30:10 35.553 2518.06 60.9702:03:30 36.108 2517.82 60.9702:36:50 36.664 2513.23 60.9603:10:10 37.219 2537.44 60.9803:43:30 37.775 2538.36 60.9904:16:50 38.331 2532.83 60.9804:50:10 38.886 2540.41 60.9905:23:30 39.442 2530.58 60.9805:56:50 39.997 2522.43 60.9806:30:10 40.553 2513.10 60.9707:03:30 41.108 2502.34 60.9707:36:50 41.664 2485.27 60.9508:10:10 42.219 2508.65 60.9708:43:30 42.775 2504.76 60.9709:16:50 43.331 2484.44 60.9509:50:10 43.886 2468.46 60.9410:23:30 44.442 2452.78 60.9310:56:50 44.997 2447.34 60.9211:30:10 45.553 2418.34 60.9012:03:30 46.108 2659.63 61.0312:36:50 46.664 4074.69 61.8913:10:10 47.219 4378.57 61.8013:43:30 47.775 4580.73 61.7714:16:50 48.331 4734.02 61.9414:50:10 48.886 4856.27 62.0515:23:30 49.442 4958.07 62.1115:56:50 49.997 5046.01 62.1516:30:10 50.553 5123.44 62.1717:03:30 51.108 5193.68 62.2017:36:50 51.664 5258.09 62.2218:10:10 52.219 5317.92 62.2318:43:30 52.775 5374.20 62.2519:16:50 53.331 5427.64 62.2719:50:10 53.886 5478.51 62.2920:23:30 54.442 5521.92 62.1520:56:50 54.997 5569.58 62.2821:30:10 55.553 5614.29 62.3322:03:30 56.108 5657.15 62.3422:36:50 56.664 5697.80 62.3523:10:10 57.219 5736.95 62.3623:43:30 57.775 5774.35 62.3610/04/1600:16:50 58.331 5810.33 62.3700:50:10 58.886 5845.06 62.3701:23:30 59.442 5878.45 62.3801:56:50 59.997 5910.58 62.3802:30:10 60.553 5941.37 62.3803:03:30 61.108 5971.08 62.3903:36:50 61.664 5999.53 62.4004:10:10 62.219 6027.13 62.4004:43:30 62.775 6053.61 62.4005:16:50 63.331 6079.24 62.4105:50:10 63.886 6103.64 62.4106:23:30 64.442 6127.30 62.41


06:56:50 64.997 6150.07 62.4207:30:10 65.553 6172.18 62.4208:03:30 66.108 6193.53 62.4308:36:50 66.664 6213.87 62.4309:10:10 67.219 6233.71 62.4409:43:30 67.775 6252.74 62.4410:16:50 68.331 6271.04 62.4410:50:10 68.886 6288.81 62.4511:23:30 69.442 6306.00 62.4511:56:50 69.997 6322.59 62.4612:30:10 70.553 6338.73 62.4613:03:30 71.108 6354.33 62.4613:36:50 71.664 6369.30 62.4614:10:10 72.219 6384.07 62.4714:43:30 72.775 6398.17 62.4615:16:50 73.331 6411.98 62.4715:50:10 73.886 6425.33 62.4716:23:30 74.442 6438.39 62.4716:56:50 74.997 6450.85 62.4717:30:10 75.553 6463.21 62.4818:03:30 76.108 6475.03 62.4818:36:50 76.664 6486.66 62.4819:10:10 77.219 6497.91 62.4819:43:30 77.775 6508.88 62.4820:16:50 78.331 6519.66 62.4820:50:10 78.886 6530.07 62.4921:23:30 79.442 6540.18 62.4921:56:50 79.997 6550.17 62.4922:30:10 80.553 6559.93 62.4923:03:30 81.108 6569.38 62.5023:36:50 81.664 6578.50 62.5010/04/1700:10:10 82.219 6587.57 62.5000:43:30 82.775 6596.47 62.5001:16:50 83.331 6605.01 62.5101:50:10 83.886 6613.56 62.5102:23:30 84.442 6621.76 62.5102:56:50 84.997 6629.88 62.5103:30:10 85.553 6637.78 62.5104:03:30 86.108 6645.48 62.5204:36:50 86.664 6653.11 62.5205:10:10 87.219 6660.54 62.5205:43:30 87.775 6667.71 62.5206:16:50 88.331 6674.92 62.5306:50:10 88.886 6681.75 62.5207:23:30 89.442 6688.77 62.5307:56:50 89.997 6695.43 62.5308:30:10 90.553 6701.96 62.5409:03:30 91.108 6708.49 62.5309:36:50 91.664 6714.77 62.5410:10:10 92.219 6721.00 62.5410:43:30 92.775 6727.08 62.5411:16:50 93.331 6732.87 62.5411:50:10 93.886 6738.69 62.5412:23:30 94.442 6744.42 62.5412:56:50 94.997 6750.00 62.5513:30:10 95.553 6755.47 62.5514:03:30 96.108 6760.85 62.5514:36:50 96.664 6766.10 62.5515:10:10 97.219 6771.17 62.55

Alberta Gas Corp.

100/01-02-030-04W5/4 Recorder: 9500 [BOTTOM]AGC Goldy 01-02-030-04

Page: 3


15:43:30 97.775 6776.33 62.5516:16:50 98.331 6781.30 62.5516:50:10 98.886 6786.10 62.5617:23:30 99.442 6790.88 62.5517:56:50 99.997 6795.56 62.5618:30:10 100.553 6800.17 62.5619:03:30 101.108 6804.62 62.5619:36:50 101.664 6808.93 62.5620:10:10 102.219 6813.29 62.5620:43:30 102.775 6817.51 62.5621:16:50 103.331 6821.71 62.5621:50:10 103.886 6825.65 62.5622:23:30 104.442 6829.74 62.5722:56:50 104.997 6833.79 62.5723:30:10 105.553 6837.47 62.5610/04/1800:03:30 106.108 6841.44 62.5700:36:50 106.664 6845.07 62.5701:10:10 107.219 6848.86 62.5801:43:30 107.775 6852.47 62.5702:16:50 108.331 6855.87 62.5702:50:10 108.886 6859.44 62.5803:23:30 109.442 6862.83 62.5803:56:50 109.997 6866.29 62.5804:30:10 110.553 6869.71 62.5805:03:30 111.108 6872.92 62.5805:36:50 111.664 6876.31 62.5906:10:10 112.219 6879.51 62.5806:43:30 112.775 6882.61 62.5807:16:50 113.331 6885.77 62.5907:50:10 113.886 6888.78 62.5908:23:30 114.442 6891.71 62.5908:56:50 114.997 6894.83 62.5909:30:10 115.553 6897.69 62.5910:03:30 116.108 6900.66 62.6010:36:50 116.664 6903.47 62.5911:10:10 117.219 6906.23 62.6011:43:30 117.775 6909.01 62.5912:16:50 118.331 6911.71 62.6012:50:10 118.886 6914.52 62.6013:23:30 119.442 6917.01 62.6013:56:50 119.997 6919.57 62.6014:30:10 120.553 6922.19 62.6015:03:30 121.108 6924.67 62.6015:36:50 121.664 6927.10 62.6016:10:10 122.219 6929.68 62.6016:43:30 122.775 6931.97 62.6017:16:50 123.331 6934.35 62.6017:50:10 123.886 6936.80 62.6118:23:30 124.442 6938.97 62.6018:56:50 124.997 6941.37 62.6119:30:10 125.553 6943.56 62.6020:03:30 126.108 6945.61 62.6020:36:50 126.664 6947.89 62.6121:10:10 127.219 6949.98 62.6121:43:30 127.775 6952.08 62.6122:16:50 128.331 6954.15 62.6022:50:10 128.886 6956.28 62.6123:23:30 129.442 6958.31 62.6223:56:50 129.997 6960.28 62.61


10/04/1900:30:10 130.553 6962.22 62.6101:03:30 131.108 6964.20 62.6101:36:50 131.664 6966.11 62.6102:10:10 132.219 6967.98 62.6202:43:30 132.775 6969.78 62.6203:16:50 133.331 6971.65 62.6203:50:10 133.886 6973.59 62.6204:23:30 134.442 6975.39 62.6204:56:50 134.997 6977.14 62.6205:30:10 135.553 6978.95 62.6206:03:30 136.108 6980.65 62.6206:36:50 136.664 6982.29 62.6207:10:10 137.219 6984.11 62.6207:43:30 137.775 6985.84 62.6308:16:50 138.331 6987.48 62.6308:50:10 138.886 6989.22 62.6309:23:30 139.442 6990.40 62.6309:56:50 139.997 6991.55 62.6310:30:10 140.553 6974.91 62.6411:03:30 141.108 6995.25 62.6411:36:50 141.664 6996.85 62.6312:10:10 142.219 6998.42 62.6312:43:30 142.775 6999.90 62.6313:16:50 143.331 7001.59 62.6313:50:10 143.886 7003.00 62.6314:23:30 144.442 7004.54 62.6314:56:50 144.997 7006.12 62.6315:30:10 145.553 7007.45 62.6316:03:30 146.108 7008.90 62.6316:36:50 146.664 7010.21 62.6417:10:10 147.219 7011.70 62.6417:43:30 147.775 7013.09 62.6418:16:50 148.331 7014.45 62.6418:50:10 148.886 7015.84 62.6419:23:30 149.442 7017.18 62.6419:56:50 149.997 7018.51 62.6420:30:10 150.553 7019.70 62.6421:03:30 151.108 7021.00 62.6421:36:50 151.664 7022.35 62.6522:10:10 152.219 7023.47 62.6522:43:30 152.775 7024.80 62.6423:16:50 153.331 7026.05 62.6523:50:10 153.886 7027.23 62.6510/04/2000:23:30 154.442 7028.51 62.6500:56:50 154.997 7029.78 62.6501:30:10 155.553 7030.78 62.6502:03:30 156.108 7031.98 62.6502:36:50 156.664 7033.08 62.6403:10:10 157.219 7034.35 62.6503:43:30 157.775 7035.52 62.6504:16:50 158.331 7036.65 62.6504:50:10 158.886 7037.68 62.6505:23:30 159.442 7038.80 62.6505:56:50 159.997 7039.98 62.6506:30:10 160.553 7041.16 62.6507:03:30 161.108 7042.14 62.6507:36:50 161.664 7043.26 62.6508:10:10 162.219 7044.45 62.65


08:43:30 162.775 7045.54 62.6509:16:50 163.331 7046.61 62.6509:50:10 163.886 7047.64 62.6510:23:30 164.442 7048.70 62.6510:56:50 164.997 7049.71 62.6511:30:10 165.553 7050.86 62.6512:03:30 166.108 7051.74 62.6512:36:50 166.664 7052.86 62.6613:10:10 167.219 7053.70 62.6613:43:30 167.775 7054.75 62.6614:16:50 168.331 7055.66 62.6614:50:10 168.886 7056.68 62.6615:23:30 169.442 7057.55 62.6615:56:50 169.997 7058.53 62.6616:30:10 170.553 7059.42 62.6617:03:30 171.108 7060.44 62.6617:36:50 171.664 7061.36 62.6618:10:10 172.219 7062.25 62.6618:43:30 172.775 7063.16 62.6619:16:50 173.331 7064.04 62.6619:50:10 173.886 7064.92 62.6620:23:30 174.442 7065.77 62.6720:56:50 174.997 7066.53 62.6621:30:10 175.553 7067.43 62.6622:03:30 176.108 7068.42 62.6622:36:50 176.664 7069.15 62.6723:10:10 177.219 7069.98 62.6623:43:30 177.775 7070.95 62.6710/04/2100:16:50 178.331 7071.65 62.6700:50:10 178.886 7072.58 62.6701:23:30 179.442 7073.44 62.6701:56:50 179.997 7074.25 62.6702:30:10 180.553 7075.01 62.6703:03:30 181.108 7075.85 62.6703:36:50 181.664 7076.63 62.6704:10:10 182.219 7077.40 62.6704:43:30 182.775 7078.22 62.6705:16:50 183.331 7078.92 62.6705:50:10 183.886 7079.77 62.6706:23:30 184.442 7080.58 62.6706:56:50 184.997 7081.29 62.6707:30:10 185.553 7082.18 62.67

Alberta Gas Corp.AGC Goldy 01-02-030-04 (100/01-02-030-04W5/4)Probe: 9500 [bottom]

0 20 40 60 80 100 120 140 160 180 20059

60

61

62

63

2000

2500

3000

3500

4000

4500

5000

5500

6000

6500

7000

7500

Time (Hours)

Pres

sure

(kPa

a)Te

mp

(C)

10/04/13 15:006077 kPaaWell open to flow at approx.

10/04/15 12:022413 kPaaShut well in for final build-up at approx.

10/04/21 08:037082 kPaaOff Bottom.


100/06-22-040-01W5/4SVI GILBY 06-22-040-01

Page: 1


Tel (403) 279-8895Fax (403) 236-4698

Basic Data


Status:

Producing Through:

Tubing Depth:

Pool Datum:

AGC Goldy100/01-02-030-04W5/4

Gas

Tubing

(subsea)

Company: Address:

Type of Test:

Field and Pool:

Elevation:




Test Summary

Alberta Gas Corp.

1000, 200 - 4th Avenue, SW

Static Gradient

Goldy/Victoria

(GL) 878.40 (KB) 882.60

1679.00-1681.00 m KB

1680.00 m KB

13 Apr 2010 12:30

TOP

73.0mm

Date of Test: 21 Apr 2010 06:01 Run Depth Temperature: 62.68 °C










Remarks:


Top Bottom



Alberta Gas Corp.

100/01-02-030-04W5/4AGC Goldy 01-02-030-04

Page: 2

Time Stop PressureTemperaturekPaaºC

GradientkPa/m

Depth mKB measStopsSurface 6109.519.010:55 - 11:05

171.7 6211.811.110:42 - 10:52 0.607321.7 6302.516.510:31 - 10:41 0.605471.7 6391.521.810:20 - 10:30 0.594621.7 6479.026.910:08 - 10:18 0.583771.7 6568.632.209:56 - 10:06 0.598921.7 6652.836.509:44 - 09:54 0.561

1071.7 6740.341.009:33 - 09:43 0.5841221.7 6826.046.209:21 - 09:31 0.5711371.7 6901.950.009:09 - 09:19 0.5061521.7 7001.957.508:56 - 09:06 0.6671671.7 7072.562.706:01 - 08:02 0.470

Temperature on Bottom: 62.68Recorder # 9499 [TOP]

Pressure - kPaa7,0006,8006,6006,4006,200

Wel

l Dep

th -

(mKB

- M

easu

red)

1,700

1,600

1,500

1,400

1,300

1,200

1,100

1,000

900

800

700

600

500

400

300

200

100

0

Alberta Gas Corp.AGC Goldy 01-02-030-04 (100/01-02-030-04W5/4)Probe: 9499 [top] Gradient On/Off Bottom Plot

0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.262.7

62.7

62.7

62.7

62.7

7072

7072.5

7073

7073.5

7074

7074.5

7075

7075.5

7076

Time (Hours)

Pres

sure

(kPa

a)Te

mp

(C)


100/06-22-040-01W5/4SVI GILBY 06-22-040-01

Page: 1


Tel (403) 279-8895Fax (403) 236-4698

Basic Data


Status:

Producing Through:

Tubing Depth:

Pool Datum:

AGC Goldy100/01-02-030-04W5/4

Gas

Tubing

(subsea)

Company: Address:

Type of Test:

Field and Pool:

Elevation:




Test Summary

Alberta Gas Corp.

1000, 200 - 4th Avenue, SW

Static Gradient

Goldy/Victoria

(GL) 878.40 (KB) 882.60

1679.00-1681.00 m KB

1680.00 m KB

13 Apr 2010 12:30

BOTTOM

73.0mm

Date of Test: 21 Apr 2010 06:01 Run Depth Temperature: 62.67 °C










Remarks:


Top Bottom



Alberta Gas Corp.

100/01-02-030-04W5/4AGC Goldy 01-02-030-04

Page: 2

Time Stop PressureTemperaturekPaaºC

GradientkPa/m

Depth mKB measStopsSurface 6117.718.810:55 - 11:05

172.7 6219.911.110:42 - 10:52 0.607322.7 6310.316.410:31 - 10:41 0.602472.7 6399.621.610:20 - 10:30 0.596622.7 6486.926.710:08 - 10:18 0.582772.7 6576.532.109:56 - 10:06 0.597922.7 6660.836.409:44 - 09:54 0.562

1072.7 6748.240.909:33 - 09:43 0.5831222.7 6834.046.109:21 - 09:31 0.5721372.7 6910.850.009:09 - 09:19 0.5121522.7 7009.457.308:56 - 09:06 0.6571672.7 7080.262.706:01 - 08:02 0.472

Temperature on Bottom: 62.67Recorder # 9500 [BOTTOM]

Pressure - kPaa7,0006,8006,6006,4006,200

Wel

l Dep

th -

(mKB

- M

easu

red)

1,700

1,600

1,500

1,400

1,300

1,200

1,100

1,000

900

800

700

600

500

400

300

200

100

0

Alberta Gas Corp.AGC Goldy 01-02-030-04 (100/01-02-030-04W5/4)Probe: 9500 [bottom] Gradient On/Off Bottom Plot

0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.262.7

62.7

62.7

62.7

62.7

7079.5

7080

7080.5

7081

7081.5

7082

7082.5

7083

7083.5

Time (Hours)

Pres

sure

(kPa

a)Te

mp

(C)


Section 7

Contents


Container Identification

Operator Name

Unique Well Identifier Well Name

Name of Sampler

Sampling Point

Date Sampled Date Received Date Reported Entered By

Elevation

KB m GRD m

Field or Area Pool or Zone Sampler's Company

Test Type Test No.

Test Interval or Perfs mKB

Pressure (kPa)

Temperature

Separator Source Sampled Received

Other Information

Reservoir

Certified By

Laboratory Number

Well License

Date Analyzed

0.671 0.665

4571.9 209.4 4552.0 208.7

19.4 105.2

RELATIVE DENSITY (CALCULATED)

Moisture &Acid Gas Free

PSEUDO CRITICAL PROPERTIES (CALCULATED)

As Sampled Acid Gas Free

RELATIVE MOLECULAR MASSTotal Gas C +

pPc (abs) kPa pPc (abs) kPapTc K pTc K

43.4543.15

Moisture &Acid Gas Free

Air Free AsReceived

GROSS HEATING VALUE MJ/m³15º C AND 101.325 kPa

88.03 kPa 0.00

H S g/m³2VAPOUR PRESSURE

(Pentanes +)

3.632

C7+, MoistureFree

0.30

C7+, Air Free AsReceived

0.005

C7+, PortionWhole Density

DENSITY

695.1

C7+ Density(kg/m3)

0.822

Total SampleDensity(kg/m3)

MoistureFree

COMP MOLE FRACTIONPETROLEUM

LIQUID

H2

He

N2

CO2

H2S

C1

C2

C3

IC4

NC4

IC5

NC5

C6

C7+

Total

Container Identification

Operator Name

Unique Well Identifier Well Name

Name of Sampler

Sampling Point

Date Sampled Date Received Date Reported Entered By

Elevation

KB m GRD m

Field or Area Pool or Zone Sampler's Company

Test Type Test No.

Test Interval or Perfs mKB

Pressure (kPa)

Temperature

Separator Source Sampled Received

Other Information

Reservoir

Certified By

Laboratory Number

Well License

Date Analyzed

Density Relative Density API @ 15°

Relative Molecular Mass

Density Relative Density API @ 15°

Relative Molecular Mass Gas Equivalency

COMP.MOLE

FRACTIONMASS

FRACTIONVOLUME

FRACTION


Section 8

Contents


Vertical

WELL NAME DATE Apr/10/10UWI License # 432100

KB ELEV (m) GL ELEV (m) KB TO THF (m) KB TO SCF (m) KB TO GL (m) PBTD (m)882.6 878.4 3.7 4.2 1857

OD (mm) LANDED DEPTH WEIGHT (kg/m) TOP OF (mKB)219.1 325 35.7 Surface139.7 1943 23.1 Surface

Perf Date Zones Top Shot Bottom Shot Status Gun DataSurface Csg Unknown Cardimon 1871.50 1880.00 P/A Unknown219.1kg/m Unknown Coloraby 1589.00 1594.00 Isolated UnknownJ55 landed @ Unknown Sec White Spot 1552.00 1557.00 Isolated Unknown325mKB Apr/10/10 Victoria 1679.00 1681.00 Open 25gr/SDP/17spm

DOWNHOLE DESCRIPTION FROM BOTTOM UP (Tubing String / Incl. Tubing Pumps)ITEM # DESCRIPTION LENGTH TOP OF (mKB)

1 0.55 1675.472 0.64 1674.833 0.20 1674.634 3.07 1671.565 0.29 1671.27

Production Csg 6 3.08 1668.19139.7mm 7 0.34 1667.8523.10kg/m J55 8 2.12 1665.73Landed @ 9 0.48 1665.251943mKB 10 3.08 1662.17

11 9.52 1652.6512 1.23 1651.4213 47.32 1604.1014 7.84 1596.2615 9.54 1586.7216 1.23 1585.49

Tryton Cup 17 19.04 1566.45Type Csg Patch 18 7.20 1559.25

Second White 1550.25mKB 19 9.54 1549.71Spot Perfs 20 1.23 1548.481552.0mKB 21 1536.39 12.09

22 0.46 11.63Isolated Perfs 23 9.61 2.02

24 0.25 1.771557.0mKB -1.51 -

-1558.78mKB -

Downhole Well ProfileAGC Goldy

CASING DESCRIPTION

100/01-02-30-4W5/04

SurfaceProduction

(4)73mmJ55 EUE Pup Joints(3.08m, 2.47m, 1.87m, 0.42m)139.7mm x 101.6mm Tryton Cup type Csg Patch tool

73mm Owen 57.10mm Seperation Sub73mm J55 EUE Pup Joint

73mm Voltage Fill Flow Sub73mm J55 EUE Pup Joint

73mm Baker 57.15mm "R" nipple c/w 55.8mm No/Go73mm J55 EUE Pup Joint

73mm 57.91mm API PSN(2.280")139.7mm x 73mm Tyton TX-10k Mech Dbl grip Packer139.7mm x 73mm Tryton On/Off tool(full bore slick jnt)

73mm J55 EUE Pup Joint(1)73mm 9.67kg/m J55 EUE Tubing Joint

73mm J55 EUE Pup Joint(5)73mm 9.67kg/m J55 EUE Tubing Joints

73mm J55 EUE Pup Joint(2)73mm 9.67kg/m J55 EUE Tubing Joint

(4)73mmJ55 EUE Pup Joints(3.08m, 2.47m, 1.22m, 0.43m)139.7mm x 101.6mm Tryton Cup type Csg Patch tool

73mm J55 EUE Pup Joint(159)73mm 9.67kg/m J55 EUE Tubing Joints

73mm J55 EUE space out nipples(1)73mm 9.67kg/m J55 EUE Tubing Joint

73mm x 179.4mm Barber Tbg Hanger(BPV)Wireline/Tbg Tally Correction

---

Tryton Cup -Type Csg Patch -

1587.26mKB -Coloraby Perfs -1589.0mKB -

-Isolated Perfs -

-1594.0mKB -

-1595.79mKB WEIGHT OF TUBING STRING (daN) 14 TOTAL STRING LENGTH 1672.74

TENSION/COMPRESSION (+/- daN) -6 STRETCH/SLACKOFF (+/- m) -0.42LANDED STRING WEIGHT (daN) 8 TUBING BOTTOM (mKB) 1676.02

Tryton 10k TX-10 DOWNHOLE DESCRIPTION FROM BOTTOM UP (Rod String)Dbl Grip Packer AMOUNT DESCRIPTION LENGTH TOTAL (m)

1666.44mKB -2.280" -

API PSN -1667.85mKB -

Baker "R" -1671.27mkB -

--

Victoria Perfs INSERT PUMP DESCRIPTION PUMPJACK DESCRIPTIONBHP: 7800kPa Tbg BtmBHT: 62'c 1676.02mKB1679.9mKB

LANDED DEPTH (mKB)WELL HEAD DESCRIPTION

1681.0mKB ITEM # DESCRIPTION SERIAL # MWP SIZE1 3000.00 73.002 3000.00 179.40

Cement top @1857mKB

10K Bridge Plug set @ 1865mKB

Cardimon Perfs1871.5mkB

REMARKS1880.0mKB

PBTD: 1857.0mKB

Stream-Flo Flowing style wellheadBarber Type "A"

Preformed 15tonne CalFrac Dyna-Gel-H2 N2 Energized Fracture Treatement April/12/2010Dropped Voltage TCP assembly as follows: 1-101mm x 2m, 17spm, 25gr, RDX SDP, 60' phasing TCP, 1-73mm Mechanical Firing head, 1-73mm J55 eue x 2.45m pup jnt

TD: 1943.0mKB

WELL COMPLETION / WORKOVER REPORT

WEST ROCK ENERGY CONSULTANTS LTD.1110, 910-7TH. AVE SW. CALGARY ALBERTA . T2P-3N8

Company Name:Well Name:UWI:Date: 2010 Apr 07 Day #: 1 AFE #:License #: AFE Amt:Purpose of Job:KBE: CFE: GLE: m PBTD: mKB TD: 1943 mKB H2S: %(0800 hrs) SITP: kPa SICP: kPa

FROM TO08:00

10:0010:00

10:3010:30

13:3013:30

14:3014:30

16:3016:30

18:30

Oil m³ Water m³

Weather: Temp.: 12 oC Conditions:Conditions: Road:Service Rig:Toolpush: Daily TotalReport From: Previous TotalReported To: Cumulative Total

v.1.14

Well Servicing 6 707.50$

-$

-$ -$

RentalsCompletion Fluids

WirelineSlickline

3 160.00$

mm API PSN nipple, 1-60.3mm 6.99kg/m J55 eue tbg jnt c/w 60.3m Re-Entry guide. Tbg appears to be in good shape. Inform Calgary office on well status. Total jnts pulled 161-60.3mm tbg jnts. Make MT & have tubing put into AGC Stock.

Press test blind rams, 1400kPa low test &21000kPa high test(ok). Press test 60.3mm pipe rams, 1400kPa low test and 21000kPa pipe rams, 1400kPa low test and 21000kPa high test (ok). Nipple up Class 2-BOPs. Press test BOP ring BOP ring seal to 1400kPa low test and 21000kPa high test (ok). Held pre-job safety and risk assessment meeting w/rig crew. Discuss pulling 60.3mm tbg. Hoist and break out 60.3mm x 179.4mm tbg hanger. POOH and lay down 60.3mm as follows: 1-60.3mm 6.99kg/m J55 eue tbg jnt,

M/I Spot power swivel, mobile catwalk c/w pipe racks. Orion rental package. Wellsite trailer, 1-20kw light tower and Enviro bin.M/I off load 30m3 fresh water into rig tank. M/I and and off load +/- 1700m of 73mm 9.67kg/m J55 eue tbg onto pipe racks. R/U pump line to wellhead (SITP: 2000kPa), bleed off tbg at controlled rate to rig tank through degasser, bleed down to 100kPa and

M/I spot TreeTop mobile free standing class 2 service rig, pump & tank, doghouse, junkbox truck and auxillary support equip.

3-60.3mm J55 eue pup jnts(1.2m, 1.8m, 2.5m). 159-60.3mm 6.99kg/m J55 eue tbg jnts, 1- 60.3mm 6.99kg/m J55 eue tbg jnt, 1-60.3

Nipple down pumping style wellhead. Install 60.3mm pup jt into tbg hanger c/w safety valve inplace. Function & stump test BOPs.

started to slug gassey oil/water, shut in tbg. (SICP: 4000kPa). bleed off csg at controlled rate to rig tank through degasser, bleddown tbg TSTM in 25min. Bring rig pump online @ 350liters/min, fill tbg with 2m3 fresh water, pump total 4m3 fresh water away.

MIRU service rig & support equip. Kill well. Nipple up Class-2 BOPs. POOH sideways w/60.3mm tbg. SDFN.Summary of todays op's:

Victoria Oilwell Recompletion

Shut down rig pump. Moniter tbg and csg for 5min. Strong vac on tbg, TSTM on csg, leave csg open to rig tank to vent.

to Completion Dept. Notify land owner of pending operations. Check wellhead press: SITP: 2000kPa, SICP: 4000kPa. Conduct surface casing vent flow check, 10min bubble test, gas flow present. Inform Calgary office on well status. TreeTop mobile rig & support equip arrive's on location. Held pre-job safety & risk assessment meeting with all onsite personell.Outline objectives & AGC polices & procedures. Conduct AGC Safety Orientation with all onsite personell.

R/U service rig, pump & tank, doghouse & related auxillary support equip to AGC, OH&S and ERCB regulations.

Alberta Gas Corp.AGC Goldy

Forecasted op's for next 24 hrs:

Contact AGC Production Dept on pending operations. Meet with Operator & obtain safe work permit and turn site over

1585

RIH with drilling assembly.Dill out cement and BP. Run bit to 1700m. POOH with drilling assembly. RIH with bit and scraper.

Op's at 08:00 hrs next day:

DETAILED DESCRIPTION OF OPERATION

4321001000001

Interval (mKB) Status

$500 000

Cardimon 1871.5-1880.0 P/AColoraby

Formation

878.4

2000 4000

100/01-02-30-4W5/041552.0-1557.0

P/ASecond White Spot

882.6 0.0

Prod. Testing & Misc. Costs

Overcast

Downhole Equipment

Lease & Road Costs

WEATHER & ROAD CONDITIONS

777Lease: Good

Max Engineer (403)411-2222Contact:Phone: (780)411-1111Grant Parrott

3 552.50$ Stimulations & CementingTrucking

New Production:Cum Fluid Rec'd:

Daily Recovery:Cum Load Rec'd:Load Remaining:

(780)411-5555Curt Rowboat

GoodTreeTop Rig Nbr.:

Phone:

-$

DAILY COST ANALYSISService

-$

Amount

3 075.00$

Tubing, Rods & WellheadsSafetySupervision & Engineering

-$

-$

54 705.10$

-$ 54 705.10$

-$

38 210.10$

Open1589.0-1594.0

Load Volume:Fluid Volume m³

FLUID RECORD

David

Highlight

FROM TO18:30

19:0019:00

19:30

v.1.14

Shut in and secure well. Purge and drain pump lines and rig pump. Close and lock pipe rams. Lock out rig and support equip. Release rig crew and support services. Shut down for night. Inform Calgary office on well status.

OPERATIONS SUMMARYDETAILED DESCRIPTION OF OPERATION Day #: 1

Change over 73mm handling equip, install 73mm pipe rams. MU and land 73mm x 179.4 tbg hanger on landing jnt. Press Press test 73mm pipe rams, 1400kPa low test and 21000kPa. Held steady for 10min(ok). Hoist & break out 73mm x 179.4mm tbg hanger. Prep drilling equip (drill collars, bit and bit sub, remove 73mm tbg protectors on pipe rack, tally tbg and confirm tbg count.



Company Name:Well Name:UWI:Date: 2010 Apr 08 Day #: 2 AFE #:License #: AFE Amt:Purpose of Job:KBE: CFE: GLE: m PBTD: mKB TD: 1943 mKB H2S: 0.0 %(0800 hrs) SITP: kPa SICP: kPa

FROM TO07:30

08:0008:00

09:0009:00

13:0013:00

13:3013:30

19:0019:00

19:30

Oil m³ Water m³


v.1.14

w/ drilling operations. Drill out retainer in 1.5hrs, took small gas/oil kick at rig tank. Shut down rig pump, moniter tbg & csg for

R/U power swivel on drill jnt 161, strip on pack-off head, make up tbg connection and bolt down pack-off head to BOPs.Held pre-job safety and risk assessment meeting with rig crew. Outline job objectives, roles off each crew member. Discuss AGC polices and drilling procedures. Inform Calgary office on well status. Bring rig pump online @ 400liters/min @ 2000kPa and break reverse circulation back to rig tank, 2m3 to fill hole. Circulate hole

1585

Formation

0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

Wireline

Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SICP: TSTM.

0

1679.0-1681mKB (ok). Inform Calgary office on well status. Hoist tbg jnt, strip off pack -off head. Prep rig and equip to POOH.

00


882.6

R/U Weatherford 85tonne power swivel c/w drill collars & handling equip. Tally & record all downhole drilling equip(OD's & ID's). M/U and RIH with drilling assembly as follows; 1-120.7mm Smith drill bit, 1-88.9mm bit sub, 3-88.9mm drill collars, 1-88.9mmx 73mm cross-over sub, 1-73mm J55 eue x 3m pup jnt, 1-73mm 58.75mm "F" nipple(torqued all drilling connections to API spec's). Tally, drift, pick up & RIH with 73mm 9.67kg/m J55 eue tbg jnts. RIH and tag top of cement on jnt 161 @ 1581.11mKB(tbg tally).

0.00

-$

Release rig crew and support services. Shut down for night. Inform Calgary office on well status.


Drill out +/-4m of cement and tag top of BP @ 1586.39mkB (tbg tally). Set 1000-2000DaN of collar weight on retainer and continue

Shut in and secure well. Purge and drain pump lines and rig pump. Close and lock pipe rams. Lock out rig and support equip.POOH and stand total of 91-73mm9.67kg/m J55 eue tbg jnts in derrick, total tbg left in well 82-jnts and drilling assembly.

over to fresh water(hole 17.74m3), Circulated total of 20m3 of fresh water and recovered +/-15m3 light oil. Start & engage power swivel, set rotational torque @ 1300ft/lbs. Drill/circulate green cement down to hard cement @ 1582.6mKB

15min (tbg & csg dead). Pick 3-73mm 9.67kg/m J55 eue tbg jnts with power swivel to ensure BP is past open Coloraby perfs at1589.0-1594mKB (tbg btm @ 1616.66mkB). R/O power swivel and rack back drilling equip. Tally, drift, pick up & RIH with 9-more73mm 9.67kg/m J55 eue tbg jnts, postion tbg btm @ 1704.52mKB to ensure csg is free off drilling debris across proposed perfs at

67 170.10$

-$

12 465.00$ 54 705.10$

-$

-$ -$

1 530.00$

-$

-$

DAILY COST ANALYSISService Amount

Tubing, Rods & Wellheads-$

Lease: GoodWindy

Safety

Supervision & Engineering

Grant Parrott

Good Lease & Road Costs

Max Engineer (403)411-2222Contact:Phone: (780)411-1111Phone:

33

FLUID RECORDFluid Volume m³

New Production:

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment



1 075.00$

1 770.00$

Completion FluidsStimulations & CementingTrucking

-$


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04



RIH w/drilling assembly. Pick up & RIH w/73mm tbg jnts. R/U power swivel, drill out retainer. POOH tbg. SDFNPOOH 73mm tbg and bit & collars. RIH w/ bit & scraper. Circulate well clean. POOH. M/U & RIH with Voltage TCP and Tryton packer assmbly.

0

1871.5-1880.0 P/AColoraby 1589.0-1594.0 OpenCardimon

Cum Fluid Rec'd:

00

Summary of todays op's:Op's at 08:00 hrs next day:

Load Volume:Daily Recovery:Cum Load Rec'd:Load Remaining:

Open0432100

Second White Spot0

1552.0-1557.00.00

1000001

David

Highlight

David

Highlight




FROM TO07:30

08:0008:00

10:0010:00

12:3012:30

13:3013:30

15:3015:30

16:0016:00

Oil m³ Water m³


v.1.14

-$ 250.00$

0 0.00

Cardimon 1871.5-1880.0

Second White Spot 1552.0-1557.0

Status

000

00

Open0

Interval (mKB)Formation

POOH 73mm tbg & bit & collars. RIH bit & scraper on 73mm tbg. Circulate well.. POOH 73mm tbg. RIH w/TCP. MIRU Voltage wireline unit. RIH and log TCP on depth.Press test packer. Nipple up wellhead. Swab tbg dry. Perforate well. Swab/flow & evaluate.




Alberta Gas Corp.AGC Goldy100/01-02-30-4W5/04


1000001432100 $500 000

882.6 0.0 878.41585

0

0.00

0

0.00

0.000.00

0

Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SITP: TSTM. SICP: Vac.POOH and stand remaining 82-73mm 9.67kg/m J55 eue tbg jnts in derrick(ok). Change over to 88.9mm drill collar handling equip.POOH and break down drilling assembly as follows: 1-73mm 58.74mm "F" nipple, 1-73mm x 3m J55 pup jnt, 1-73mm cross-over,

Wireline

-$

8 613.30$

Downhole Equipment

Lease & Road Costs

Safety


Max EngineerGrant Parrott

Cum Load Rec'd:

GoodTreeTop

Load Volume:Daily Recovery:

Windy

Rig Nbr.:

(780)411-1111Phone:

Lease: Good


SlicklineRentals

Trucking

Well Servicing

Completion FluidsStimulations & Cementing

3-88.9mm drill collars, 1-88.9mm bit sub and 1-Smith 120.7mm drill bit (Drill bit appears to be in good shape). R/O power swivel andsupport auxillary drilling equip. Release and haul out mobile power swivel. Inform Calgary office on well status. M/U bit and scraper and RIH as follows: 1-120.7mm Smith drill bit, 1-139.7mm csg scraper, 1-73mm cross-over sub, 1-73mm x 3m

Fluid Volume m³

J55 eue pup jnt, 1-58.75mm "F" nipple. RIH scraper assembly 73mm 9.67kg/m J55 eue tbg from derrick. Double scrape csg, openexsiting perfs and proposed packer depth on jnts 160 and 161(1550.15-1559.93mKB) and jnts 164- 165(1589.20-1598.94mkB) &jnts 172-174 (1667.54-1686.93mKB). Ran total of 176-73mm 9.67kg/m J55 eue tbg jnts, position tbg btm @ 1706.37mkB. R/U circulating equip, bring rig pump online @ 500liters/min @ 6000kpa, and reverse circulate well over to clean fresh water.

DAILY COST ANALYSISService

Pump 1.5 hole volumes (28.75m3), recoverd +/- 4m3 of light oil, good clean returns to surface, shut down rig pump & moniter tbgand csg for 5min (ok). R/O circulating equip. Prep rig to POOH with 73mm tbg. POOH, laid 5-73mm 9.67kg/m J55 eue tbg jnts on pipe racks, Pull & stand remaining 171-73mm 9.67kg/m J55 eue tbg jts in derrick.

1-101mm x 2m, 17spm, 25gr, RDX SDP, 60' phasing TCP, 1-73mm Mechanical Firing head, 1-73mm J55 eue x 2.45m pup jnt,

1 530.00$

-$ -$

-$ 19 913.70$

FLUID RECORD

-$

Load Remaining:Cum Fluid Rec'd:New Production:

-$

33

67 170.10$


(403)411-2222Contact:Phone:

Amount8 880.00$

-$ 640.40$

Tubing, Rods & Wellheads

87 083.80$

P/AColoraby 1589.0-1594.0 Open

1-73mm Owen 57.15mm Seperation Sub (shift up), 1-1-73mm J55 eue pup jnt x 0.64m, 1-73mm Ported fill flow sub, 1-73mm J55eue pup jnt x 3.07m, 1-57.15mm "R" c/w 55.8mm no/go nipple, 1-73mm J55 eue pup jnt x 3.07m, 1-73mm 57.9mm API PSN,

Break down bit and scraper assembly and send back to Weatherman rentals. (BHA appears to be in good shape). Held pre-job safety and risk assessment meeting with rig crew, Tryton tool hand, Voltage TCP hand and WSS. Discuss BHA andoutline job objecties and AGC policies and procedures. Conduct AGC Safety Orientation w/new personell.Tally, drift, pick up and RIH with Voltage TCP/Tryton frac packer/Tryton cup type casing isolation patch assembly as follows:

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20:3020:30

21:00

v.1.14

tool (8.53m), 1-73mm J55 eue pup jnt x 1.23m handling pup jnt. RIH 73mm 9.67kg/m J55 eue tbg from derrick at redused running


land TCP assembly and postion top shot @ 1680.3mKB (tbg tally). Install 73mm safety valve. Laud down 3-73mm tbg from derrick.

1-139.7mm x 73mm Tryton TX-10k Mechanical Dbl grip packer, 1-139.7mm x 73mm Tryton TL on/off tool, 1-73mm J55 eue pup jnt x 3.08m, 1-73mm 9.67kg/m J55 eue tbg jnt, 1-73mm J55 eue x 1.23m marker pup jnt, 5-73mm 9.76kg/m J55 eue tbg jnts, 4-73mm J55 eue pup jnts(7.87m), 1-139.7mm x 101.6mm x 73mm Tryton Cup type csg patch tool(8.53m), 1-73mm J55 eue pup jntx 1.23m,2-73mm 9.67kg/m J55 eue tbg jnts, 4-73mm J55 eue pup jnts(7.20m), 1-139.7mm x 101.6mm x 73mm Tryton Cup type csg patch

speed as per Tryton tool hands request. Tryton cup tool haning up on csg collars, had to work tbg up and down several times gentley to ensure not tear or rip isolation cups. Ran total of 168-73mm 9.67kg/m J55 eue tbg jnts. M/U 73mm x 179.4mm tbg hanger

Shut in and secure well. Purge and drain pump lines and rig pump. Close and lock pipe rams. Lock out rig and support equip.Release rig crew and support services. Shut down for night. Inform Calgary office on well status.




FROM TO07:30

08:0008:00

12:3012:30

14:00

Oil m³ Water m³


v.1.14

IsolatedOpen432100

Second White SpotVictoria

1552.0-1557.01679.0-1681.0

1000001

00



1871.5-1880.0 P/AColoraby 1589.0-1594.0 IsolatedCardimon


Log TCP on depth. Press csg & packer(ok). Swab tbg dry. Perforate well. Flow/swab and evaluate. SDFN.MIRU slickline unit(drop perf gun).R/U p-tank and testing equip. Flow/swab & evaluate. Preform 15tonne DynaGel-H2 Energized Fracture.

Cum Fluid Rec'd:

Cum Load Rec'd:Load Remaining:

0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


250.00$

4 755.00$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




New Production:


33Lease: Good

Windy

23 660.30$

Safety


Grant Parrott


-$

3 815.77$



POOH with logging tools, R/O Voltage wireline equip and Release E-line unit. Fill csg with fresh water and press test packer and Tryton Cup Type csg patch tools to 7000kPa (held steady for 10min). Bled off and press test packer down tbg to 7000kPa (held

129 157.87$

-$

42 074.07$ 87 083.80$

-$

-$ -$

1 530.00$

Pick up on 73mm tbg string, soft set Tryton 10k frac packer in 6000DaN compression(ok). MIRU Voltage E-line unit c/w 5k 88.9mmlubricator, wireline BOPs and misc support auxillary equip. R/U equip to AGC, OH&S and ERCB regulations. RIH w/ GammaRay/CCL logging tool @ 70m/min, down to 1668mKB. Attempt to pull corrolation log, logging tool fails (shuts down).Tried several times to reboot system and restart logging tools (no luck). POOH. Tools to surface, discovered short in sinker bar

secure leg screws. R/U Voltage e-line and support auxillary equip. RIH w/ GammaRay/CCL logging tool @ 70m/min, down to 1700

flowing style wellhead. R/U rig floor and 73mm swabbing equip (swab tree, lubricator and swab line back to rig tank). Held R/O power tongs, 73mm handling equip, slips and rig floor. Nipple down class 2 BOPs, nipple up Stream-Flo 73mm x 21Mpa x 179

RIH with 73mm 9.67kg/m J55 eue tbg jnt, land 179.4mm x 73mm tbg hanger and set Tryton 10k frac packer in 6000Dan compression, pull 10000Dan tension to ensure packer is set and elements are energized (ok). Reland 179.4mm tbg hanger and

Neutron Open hole log dated Mar/15/98. Confirmation log good, TCP assmbly is on depth (Victoria perfs 1679.0-1681.0mKB).

0.00

-$

pre job safety & risk assessment meeting w/ rig crew. Outline job objectives & AGC polices on swabbing operations.

Well Servicing 8 063.00$ Wireline

Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SITP: TSTM. SICP: Vac.

0

steady for 10min). Bleed of press bact to rig tank. Inform Calgary office on well status. Packer and cups tools press tests solid.

00


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

mKB. Pull and log GR/CCL strip from 1700-1550mKB. Corralate 73mm marker pup/TCP assembly on depth to BPB Dual Spaced

connection above CCL. Break out and install new logging tools (ok). RIH w/ GammaRay/CCL logging tool @ 70m/min, down to 1668mKB. Pull & log GR/CCL strip from 1668-1550mKB. Corralate 73mm marker pup/TCP assembly on depth to BPB PDDSN/Open hole dated Jan/12/10. POOH with logging tools and rig down Voltage E-line equip. Hoist and unset Tryton 10k Frac packer, let rubbers relax for 10min. Pull 179.4mm tbg hanger & 1-73mm 9.67kg/m J55 eue tbg jnt, break out and M/U .45m of 73mm space out nipples.

1585

Formation

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16:0016:00

19:0019:00

19:30

v.1.14


line back to rig tank). RIH and tag fluid @ 1500m, pulled from nipple @ 1667.85mKB, recovered 400liters of fresh water. RIH and(no fluid tag) pulled from nipple dry swab. Inform Calgary office on well status. R/O 73mm swab equip, methanol wellhead. Shut in and secure well. Purge and drain pump lines and rig pump. Lock out rig and support auxillary equip.Release rig crew and support services. Shut down for night. Inform Calgary office on well status.

1681.0mKB) with 101mm x 2m, 17spm, 25gr, RDX SDP, 60' phasing TCP(45sec). Inform Calgary office on well status.Read and record build ups for 1hr, results as follows: 16:03: 19kPa--16:04: 35kPa--16:05: 85kPa--16:10: 339kPa--16:15: 810kPa--16:20: 1266kPa--16:25: 1763kPa--16:40: 2757kPa--16:55: 3598kPa--17:00: 3830kPa (SICP: TSTM) Inform Calgary office on well status. Install adjustable choke and flow line back to rig tank. SITP: 4830kPa. Open tbg on adjustable choke to rig tank deggasser atcontroled rate, bled down to TSTM in 20min. FTP: TSTM, SICP slight vac. R/U 73mm swab equip (swab tree, lubricator and swab

Pulled total of 8-swabs and recoverd 4.65m3 of fresh water. Swabbed tbg dry to PSN @ 1667.85mkB. R/O 73mm swabbing equip(swab tree, lubricator and swab line back to rig tank). Drop Voltage perforating bar and perforate Zone on interest (Victoria 1679.0-

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FROM TO07:30

08:0008:00

09:3009:30

13:0013:30

14:00

Oil m³ Water m³

Weather: Temp.: -8 oC Conditions:Conditions: Road:Service Rig:Toolpush: Daily TotalReport From: Previous TotalReported To: Cumulative Total

v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00



6540



MIRU slickline equip & Well testing equip. RIH and drop perf gun. Flow/swab and evaluate well. SDFN.Pre-heat Frac oil. MIRU Calfrac and supprt equip. Preform 15tonne DynaGel-H2 Energized Fracture. Conduct post frac cleanup.

Cum Fluid Rec'd:


0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


350.00$

1 175.00$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




New Production:


33Lease: Good

Clearskys

-$

Safety


Grant Parrott


-$

-$



Release rig crew and support services. Shut down for night. Inform Calgary office on well status.

140 544.62$

-$

11 386.75$ 129 157.87$

-$

-$ 2 793.00$

1 530.00$

MIRU Quicksilver slickline unit c/w 5K BOPs, 5K lubricator and N2 purging system. MIRU Wespro p-tank & support auxillary testingequip. R/U wireline & test equip to AGC, OH&S and ERCB regulations. Conduct AGC Safety Orientation withnew personell. Purge and press test lubricator to 14000kPa with N2 (oK). RIH 73mm Otis "B" shifting c/w 53.84mm selective keys on .108 slickline @ 100m/min. Locate 73mm x 57.10mm Owen Seperation sub @ 1675.46mKB, shift sub up and drop 2m perf gun.

office on well status, No inflow of fluid (recovered 120 liters of load water, Sal: 2%, Ph: 7). Blow on tbg (burnable gas (TSTM).

line back to p-tank tank). RIH & tag fluid @ 1640m, pulled from nipple @ 1667.85mKB, recovered 120liters of fresh water. RIH and(no fluid tag) pulled from nipple dry swab. Wait and pull swab in 1hr. RIH no fluid tag pulled from nipple dry swab. Inform Calgary

Shut in and secure well. Purge and drain pump lines and rig pump. Lock out rig and support auxillary equip.

0.00

1 420.75$


Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SITP: 6540kPa. SICP: Slight vac.

000


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

R/O 73mm swab equip, rig floor and flow line back to p-tank. Rig crew slips and cuts drill line.

RIH with slickline past perf inteval and confirm perf gun has dropped (ok). POOH. Tools to surface, Shut in master valve, bleed off lubricator to rig tank and purge with N2 (oK). R/O slickline equip (lubricator, wireline BOPs and flow-tee). Release Slickline unit.R/U flow line back to p-tank , purge and press test line & p-tank with wellbore gas. SITP: 6500kPa. Open tbg on adjustable choketo p-tank ad flare off gas. FTP: TSTM(no fluid to surface). SICP slight vac. R/U 73mm swab equip (swab tree, lubricator and swab

1585

Formation

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FROM TO05:30

07:3007:30

08:0008:00

09:0009:00

09:1509:15

Oil m³ Water m³


v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00



6775



MIRU Frac equip and support auxillary services. Frac well. R/O frac equip. Conduct Post Frac clean up.Flow & Evaluate well. R/O rig and support equip. Land pressure recorders. Flow & evaluate.

Cum Fluid Rec'd:


0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


3 300.00$

1 871.00$


40 000.00$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




0.32

37.00

New Production:


33Lease: Good

Overcast

-$

Safety


Grant Parrott


3 327.50$

-$



Hold safety and procedural meeting with all personnel on loc (25). Discuss all hazards and outline AGC policies and procedures involved with Fracturing as well as daily operations. Identify all hazards on loc (such as lease, escape routes,

234 733.44$

37 968.32$

94 188.82$ 140 544.62$

-$

-$ 2 862.00$

1 530.00$

to AGC, OH&S and ERCB regulations. Heat 45m3 Synoil RF-100 frac oil to 20'c(ok). R/O and release hotoiler unit. Frac crew and support services on location. Conduct lease inspection with Supervisor. Check SITP: 6775kPa & SICP: Vac.Service, start and warm up support auxillary equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline job objectives and AGC policies and procedures on spotting heavy equip on tight location

R/U flow line back to p-tank and 2" shipping line to 400bbl flow back tank. R/U equip to AGC, OH&S & ERCB regulations.

5min. All press test's satisfactory. (Max for job = 45MPa). Open well. SITP: 7000kPa. Bring on Calfrac fluid & N2 pumpers @ a Press test Calfrac main treatment & N2 lines to 50MPa & wellhead isolation valve. flow line back to p-tank to 28MPa. Held steady

Move in and spot CalFrac fracing equip (3-Twin pumpers, 3-N2 pumpers 1-Blender, 1-Iron truck, 1-Chemical van, 1-Sand can, 1-Frac data van and misc support fracing equip. R/U Calfrac main treatment line to wellhead isolation tool (IES).

Victoria Oil formation (1679.0 - 1681.0mKB) CalFrac program # FCA0222LK. Total Fluid on location 45m3 Synoil RF-100.

0.00

-$

combined rate 2.5m3/min & perform 15 tonne DynaGel Fracture Treatment. w/1.0m3 15HCL acid spearhead (Victoria Formation).

Well Servicing 3 330.00$ 36.68 Wireline

Held pre-job safety and risk assessment meeting with all onsite personell. Outline job objectives and AGC polices andprocedures on heating Synoil RF-100 frac oil. MIRU Dalamc hotoiler unit & Hellfire combo fire suppression/shower unit. R/U equip

0

flammable liquids, high pressure lines, Acid, etc). Inform Calgary office on well status.

00


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

All Frac equip rigged up as per regulations and ready to pump a 15 tonne DynaGel -H2 N2 Energized Fracture Treatment into

Move In spot IES Wellhead isolation equip. Nipple down 73mm flow-tee ontop of master valve. Nipple up Stinger 70Mpa full driftwellhead duel cup isolation tool. Check and confirm size of Csg isolation sleeve (Cups are sized for 73mm 19.67kg/m J55 tbg). Check & open master valve. Scope tool into 73.mm tbg (ok), Scope tool out of tbg . Check surface area of duel cup isolationsleeve, cups appear to be in good shape. Reland isolation tool. MIRU Neway mobile steamer, heat wellhead assembly.

1585

Formation

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10:3011:30

12:3012:30

13:3013:30

14:3014:30

15:3015:30

16:3016:30

17:3017:30

18:3018:30

21:00

v.1.14


Fluid Rec': 28.189m³--Total Fluid Left to Recover: 8.11m³--100% Frac Oil--API: 42.7--Gas Rate: 73.853 10³m³Inform form Calgary office on well status. Shut in well, record builds up for 2hrs and R/U test equip to conduct inline flow test.Release rig crew and support services. Purge and drain pump lines and rig pump. Lock out rig and support auxillary equip.Continue Post Frac clean up, flow well as directed by Calgary office through out the night. See test notes for detailed flow data.

Fluid Rec': 20.059m³--Total Fluid Left to Recover: 16.941m³--Put gas meter in service--100% Frac Oil--API: 46.0FTP: 1181kPa--Choke size: 38.10mm--Csg Flow Temp: 9'c--Load Fluid Rec'/Hr: 4.615m³-- Total Load Fluid Rec': 24.674m³--Total Fluid Left to Recover: 12.326m³--100% Frac Oil--API: 42.7--Gas Rate: 47.222 10³m³FTP: 1249kPa--Choke size: 38.10mm--Csg Flow Temp: 9'c--Load Fluid Rec'/Hr: 3.515m³-- Total Load

Open well on full 38.1mm Gutline and flow well as directed by Calgary office. Results as follows: FTP: 737kPa--Choke size: 38.10mm--Csg Flow Temp: 10'c--Load Fluid Rec'/Hr: 3.161m³-- Total Load Fluid Rec': 11.550m³--Total Fluid Left to Recover: 25.5m³--Burnable gas to surface--100% Frac Oil--API: 46.0FTP: 1042kPa--Choke size: 38.10mm--Csg Flow Temp: 10'c--Load Fluid Rec'/Hr: 8.509m³-- Total Load

Fluid Rec' 5.68m3 100% frac oil, small trace of sand in returns. Increase rate of flow. Step up choke to 1/2 choke(12.7mm), attempt to obtain 10-12m3/hr fluid recovery. Inform Calgary office on well status.Fluid Recovered in last 1/2Hr: 2.72m3, FTP: 636kPa, SICP: 3143kPa. TLFR: 8.389m3, TLFLTR: 28.61m3.

R/O Calfrac frac equip and all related support auxillary services. R/U Wespro test return line to p-tank. R/U 50.8mm shipping line to 400bbl tank farm. Shut in well and let gel break for 2hrs. Read and record tbg & csg press. Prep test equip to Conduct post frac clean up. Press test flow line back to p-tank with wellbore press(ok). SITP: 9320kPa & SICP: 3320kPa. Open well on adjustable choke to p-tank on 12/64(9.53mm Choke).

Ramp 20/40 sand from 100kg/m3-900kg/m3 (Final Conc @ perfs (940kg/m3), (15tonne 20/40 Siber Proppant ). Follow behind

Fluid to surface, 100% Frac oil. Read & Record flow data. Attempt to obtain 4-6m3/hr fluid recovery until 1-tbg volume recovered.

with 4.66m3 oil with 0.5m3 under flush. End frac, Results as follows: Breakdown Press: 35.6MPa. Max press: 33.7MPa. Avg press: 19.1MPa. Min press: 14.8MPa. Avg rate = 2.0m3/min. ISP: 12.3MPa. 1min SIP: 12.6MPa. 5min SIP: 12.5MPa. 10min SIP: 12.0MPa. 15min SIP: 11.4MPa. 30min SIP: 10.8MPa. Load fluid to recover: 37.0m3. For Detailed frac report see Calfrac treatment report # 99999. Inform Calgary office on well status.

Pump 1m3 15%HCL off surface, release Acid hauler. Fill hole 3.8m3, recorded breakdown of 35.6MPa. Spot 0.5m3 acid in perfs w/0.5m3 out. Let acid soak for 10min(31Mpa -14.2Mpa). Resume Frac Pump 8.5m3 pre-pad and establish feed rate of 2.5m3/min.

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FROM TO00:00

07:3007:30

08:0008:00

12:3012:30

Oil m³ Water m³


v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00





Conduct Inline Post Frac Clean Up. R/O rig & support equip. RU Slickline. RIH land recorders. Flow test wel.lContinue with Single Point Flow Test.Continue with Single Point Flow Test.

Cum Fluid Rec'd:


0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


350.00$

6 360.00$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




53.830.00

37.00

New Production:

Max Engineer (403)411-2222Contact:Phone: (780)411-1111

16.83

Phone:

33Lease: Good

Overcast

-$

Safety


Grant Parrott


-$

-$



R/O Treeline moblie class 2 service rig and all related support auxillary equip (pump & tank, doghouse, junk truck and misc equip).Release rig and crew. MIRU Wilco slickline unit c/w 5K BOPs, 5K lubricator and N2 purging system. Shut in well (end test).

253 214.09$

-$

18 480.65$ 234 733.44$

-$

-$ 5 073.15$

1 530.00$

Flowing Tbg on 38.1mm choke(Gut line).Total Flowing time: 18:00hrs.Flow Tbg Press: 1585kPa.Tbg Flow Temp: 8'c.

Produced Fluid/Hr: 1.564m3

1667.85mkB and "R" nipple @ 1671.27mKB, Run nipple brush out btm of tbg landed @ 1676.02mKB and past Victoria perfs @ new personell. Purge and press test lubricator to 14000kPa with N2(oK). RIH 73mm nipple brush on .140 slickline, locate PSN @

Gas Rate: 59.862 10³m³Total Gas Produced: 35.009 10³

objectives and AGC polices and procedures. Inform Calgary office well status. Continue with Inline Post Frac clean up.

0.00

930.00$

1679.0-1681.0mkB (Perfs Open). POOH. Tools to surface, Shut in master valve, bled off lubricator to P- tank and purge with N2


38.00Wireline

Continue Post Frac clean up, flow well as directed by Calgary office.Post Frac Clean up Summary:

0

R/U wireline & test equip to AGC, OH&S and ERCB regulations. Conduct AGC Safety Orientation with

00


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline job

SICP: 2247kPa.Load Fluid Recovered: 46.585m3.Total Load Fluid to Recovered: 37.0m3.Load Fluid Produced 9.585m3.

1585

Formation

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16:00

v.1.14


R/O slickline equip (lubricator, wireline BOPs and flow-tee). Release Slickline unit. Infor Calgary office on well status. Prep test equip to Single Point Flow Test. Press test flow line back to p-tank with wellbore press (ok). SITP: 5455kPa & SICP: 30kPa. Open well and conduct inline test. Flow well as directed by Calgary office. See Wespro field testnote for detailed well information. Wellsite supervisor released. Turn well over to AGC production Dept.

p-tank and purge with N2. Purge and press test lubricator to 14000kPa with N2 (oK). RIH w/Tandem Calscan 6K EMR's c/w 73mmhold down on .140 slickline (batteries on @ 13:30hrs). Landed recorders ontop flow-thru tbg dart set in "R" nipple @ 1671.27mkB.(Recorders on btm @ 13.570hrs). POOH. Tools to surface, Shut in master valve, bled off lubricator tor p-tank and purge with N2.Purge & press test lubricator to 14000kPa with N2 (oK). RIH with 73mm slip-stop on. 140 slickline @ 100m/min, set slip-stop ontop of recorders @ 1670.35mKB (ok). POOH. Tools to surface, Shut in master valve, bled off lubricator tor p-tank and purge with N2.

Purge & press test lubricator to 14000kPa with N2(oK). RIH with 56.88mm flow-thru tbg dart on.140 slickline @ 100m/min. Locate and set tbg dart on 57.15mm "R" nipple @ 1671.27mKB(ok). POOH. Tools to surface, Shut in master valve, bled off lubricator tor

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Company Name:Well Name:UWI:Date: 2010 May 05 Day #: 8 AFE #:License #: AFE Amt:Purpose of Job:KBE: CFE: GLE: m PBTD: mKB TD: 1943 mKB H2S: 0.0 %(0800 hrs) SITP: kPa SICP: kPa

FROM TO08:00

08:3008:30

09:0009:00

12:0012:00

13:3013:30

15:0015:00

Oil m³ Water m³


v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00



2730



MIRU equip. Clear tbg free of Wax. RIH w/gaugering, set tbg plug. Perforate pup jnt. Swab well dry. SDFN.Fill hole with production oil. Install Plunger Lift Assembly.

Cum Fluid Rec'd:


167 0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04

Install Plunger Lift System

-$

382.50$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




New Production:


Lease: GoodSnowing

-$

Safety


Grant Parrott

Soft Lease & Road Costs

-$

-$



Tag and set tool string assembly on 57.91mm API PSN @ 1667.85mB (ok). POOH. Tools to surface. Purge lubricator with N2. RIH with 3-shot mechanical perf gun on .108 slickline tag top of spacer bar assembly @ 1664.55mKB(SITP 1500kPa). Jar down

265 976.59$

-$

12 762.50$ 253 214.09$

-$

-$ 4 190.00$

1 530.00$

MIRU Quicksilver slicline unit c/w 5K BOPs, 5K lubricator and N2 purging system. MIRU Eldorado press truck and support auxillaryequip. R/U wireline & press truck to AGC, OH&S & ERCB regulations. Conduct AGC Safety Orientation. Purge and press test lubricator to 14000kPa with N2(oK). RIH 73mm wax knife, could not get past 5m, POOH. Wax knife & slicklinetoolstring full of wax. Inform Calgary office on well status. Bring fluid pumper online @ 15liters/min and pump 2000liters of Synoil

Bring fluid pumper online @ 300lites/min and fill tbg with 3.5m3 tbg fresh 1% clay stabilzed water (tbg volume 5.16m3). Press test

Purge and press test lubricator to 14000kPa w/N2 (oK) RIH with 73mm "SB" tool on .108 slickline, tag and latch "SB fishneck c/windication perf gun has fired (ok). POOH. Tools to surface. Purge lubricator w/ N2. Check tbg mechanical perf gun, all shots fired.

Purge and press test lubricator to 14000kPa w/N2 (oK). RIH 57.15mm Baker "RZG" tbg plug on 108 slickline @ 100m/min. Locate 57.15mm Baker "R" nipple @ 1671.27mKb and set tbg plug in nipple (ok). POOH. Tools to surface. Purge lubricator with N2 (ok).

Purge and press test lubricator to 14000kPa w/N2 (oK) RIH with 58.59mm tbg plug c/w 3.3m of spacer bar & 73mm "SB" fishneck.

0.00

4 200.00$

spacer bar assembly @ 1664.55mKB(ok). POOH . Tool to surface. Purge lubricator w/ N2. Inform Calgary office on well status.


Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SITP: 2730kPa. SICP: 167kPa.

0

once & perforate 73mm J55 eue pup jnt .70m above Tryton on/off tool with 3-1/4 holes. SITP increased instanly to 1850kPa, good

00


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

tbg and tbg plug to 7000kPa. Held steady for 10min (ok). Positive press test good. Bleed tbg press down to 1500kPa (ok).

Cansol-Wax solven down tbg (ok). SITP: vac. Shut down pumper & let solvet soak for 60min, to ensure tbg is free of wax/paraffindeposits. RIH with 73mm waxknife down to 800mKB, Worked waxknife through all tight spots in tbg. POOH. Tools to surface.Purge lubricator with N2 (ok). RIH with 58.49mm gauge ring down to 1667.85mkB and tag 57.91mm API PSN (ok) POOH. Tools to surface. Purge lubricator with N2 (ok). Inform Calgary office on well status. Tbg is free of wax/paraffin deposits(ok).

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Formation

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16:3016:30

17:3017:30

22:0022:00

23:00

v.1.14


Pull 21-swabs & recover 17.56m³ (total hole volume 18.14m3). Pulled two dry swabs, unable to recover remaining 0.58m3 fluid.Empty rig tank & haul fluid to disposal. Shut and seure well. R/O swab rig and all related support swabbing equip. and release allservices. Shut down for night. Inform Calgary office on well status. Swabed tbg and csg dry.

and slickline BOPs. Rig down Quicksilver slickline equp and rack off to side of location. Inform Calgary office on well status.Move in spot Carnwood swab rig & swab tank. Held pre-job safety & risk assessment meeting w/all onsite personell. Outline jobobjectives & AGC polices & procedures. SITP: 1650kPa. SICP: vac. R/U to AGC, OH&S & ERCB regulations.R/U 73mm swabbing equip ( swab tree, lubricator and flow tee). R/U swab line back to Carnwood Mobile rig tank.SITP: 1650kpa. Open tbg to rig tank on full gutline and bleed off tbg press. Rec' 1.95m3 water. Swab well dry results as follows:

Purge and press test lubricator to 14000kPa w/N2(oK) RIH with 59.49mm full drift gauge ring on 108 slickline @ 150m/min downto 57.91mm API PSN(ok). POOH, tbg free off debris and wax build up on tbg wall. Tools to surface. Purge lubricator and flowtee

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09:0009:00

12:3012:30

13:3013:30

Oil m³ Water m³


v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00





Fill tbg with oil. RIH & pull prong. RIH & attempt to pull plug. Swab well dry. RIH pull plug. RIH bumber spring.MIRU Swab rig and swab tank.Turn well over to production.

Cum Fluid Rec'd:


560 0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


-$

-$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




0.55

7.00

New Production:


Lease: GoodCloudy

12 306.11$

Safety


Grant Parrott


-$

-$



Purge and press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SBC" tool on .108 slickline @ 100m/min. Tag and jar down5- times to open lock set with "SBC" tool, to contract collets and ensure positve latch on plug. Jarred on plug & fired jars

287 377.28$

-$

21 400.69$ 265 976.59$

-$

-$ 1 830.00$

1 530.00$

R/U Eldorado press truck to production 400bbl tank. Press test pump line to 14000kPa. Open tbg & fill hole with 7m3 of producedoil (860kg/m). Shut down fluid pumper. Moniter tbg & csg. SITP: vac, SICP: 935kPa. Open & bleed back csg to press truck to allow fluid balance in tbg & csg. Est' fluid level @ +/- 800m. MIRU Quicksilver slickline unit & support auxillary equip. Purge and press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SB" tool on .108 slickline @ 100m/min. Tagged fluid level

probe on .108 slickline. Tag and attempt latch Baker "RZG" tbg plug set in Baker "R" nipple @ 1671.27mKB. Took several times to

7/32 braided line(ok). Held pre-job safety and risk assessment meeting with slickline crew. Outline safety and weight restrictions.Calgary office, decision made to change over to 7/32 braided line as steel shear pins. R/O .108 slickline equip and change over to

surface. Purge lubricator with N2. Inform Calgary office on well status. Confirm BHP: Last recorded data indicates 7000kPa.Install slickline knuckle above "SB" tool. Purge and press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SB" tool c/w "B"

hits. Inform & confer w/Calgary office on well status. Appears there is debris in behind lock set of plug. M/U 73mm "SB" collet tool

0.00

5 734.58$

Purge & press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SBC" tool on 7/32 braided line @ 100m/min. Tag & jar down

Well Servicing -$ 6.45 Wireline

Service, start and warm up rig equip. Held pre-job safety and risk assessment meeting with all onsite personell. Outline jobobjectives and AGC polices and procedures. Inform Calgary office well status. SITP: Vac. SICP: 560kPa.

0

to 800lbs over slickline string weight with .108 slickline, sheared off. POOH. Tools to surface. Purge lubricator with N2. Inform

00


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

hold positive grap, possible tbg perforating debris in fishneck. Jarred on plug & fired skickline jars for about 1Hr with 50-60 solids

600m, contiue to RIH, tag and latch onto Baker "RZG" prong @ 1671.27mKB, jarred up once, pulled free. POOH. Tools to surface.Purge lubricator with N2. (Prong Recovered). SITP: slight vac. SICP: TSTM. Purge & press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SB" tool c/w "B" probe on .108 slickline. Tag and latch Baker "RZG" tbg plug set in Baker "R" nipple @ 1671.27mKB. Jarred on plug and fired skickline jars for about 1Hr with 50-60 solids hits, could not pull plug free, Sheared off. POOH. Tools to

1585

Formation

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14:3014:30

15:3015:30

16:3016:30

17:3017:30

18:3018:30

20:0020:00

20:30

v.1.14


energize 73mm packoff elemet (ok). POOH. Tools to Surface. Purge lubricator with N2. Inform Calgary office on well status. R/O Quicksilver slickline equip and Eldorado press truck. Shut in and secure well. Release all Services. Shut down for night.Inform Calgary office on well status. SITP: 100kPa. SICP: vac. Fluid level @ 1050m.

Purge & press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SB" tool c/w 73mm collar stop down to top of API PSN, pull up and locate top of 73mm perforated pup jnt @ 1662.17mKB, Set collar stop in tbg collar above pup jnt(ok). POOH. Tools to surface. Purge lubricator with N2. RIH 73mm "SB" tool c/w PIT PaceMaker bumperspring slip stop lock assembly. Tag 73mm collarstop @ 1662.17mKB, set down, shear off bumperspring assmbly (ok). Jar down 6-times ontop of bumperspring to set slip lock &

probe on 7/32 braided slickline. Tag and latch Baker "RZG" tbg plug set in Baker "R" nipple @ 1671.27mKB. Jarred on plug and fired jars 3-times to 3000lbs, plug pulled free (ok). POOH. Tools to surface. Purge lubricator with N2. Inspect plug, packingwas swelled and recoverd some debris in fishneck of plug. Infrom Calgary office on well status. Prep to RIH plunger lift equip.

to 3000lbs and sheared steel pin. POOH. Tools to surface. Purge lubricator with N2. R/U 73mm swabbing equip and prep to swab well to onsite production 400bbl tank. Inform Calgary office of results, decision made to swab tbg dry. Pull 7-swabs & recovered 3m³ of load oil. Total Fluid Recovered 6.45m3 load oil Swab tbg and csg dry. POOH. Tools to surface.Purge lubricator with N2. R/O 73mm swabbing equip. M/U 7/32 braided slickline toolstring. Inform Calgary office on well status.

swab well to onsite production 400bbl tank. Inform Calgary office and AGC production dept on well status.

Install slickline knuckle above "SB" tool. Purge and press test lubricator to 14000kPa with N2 (oK). RIH w/73mm "SB" tool c/w "B"

Pull 6-swabs & recovered 3m³ of load oil. Swab fluid level down to 900m (771m fluid above plug). POOH. Tools to surface.Purge lubricator with N2. R/O 73mm swabbing equip. M/U 7/32 braided slickline toolstring. Inform Calgary office on well status.Purge & press test lubricator to 14000kPa with N2(oK). RIH w/73mm "SBC" tool on 7/32 braided line @ 100m/min. Tag & jar down3- times to open lock set with "SBC" tool, to contract collets and ensure positve latch on plug. Jarred on plug & fired jars 30-times

3- times to open lock set with "SBC" tool, to contract collets and ensure positve latch on plug. Jarred on plug & fired jars 30-timesto 3000lbs and sheared steel pin. POOH. Tools to surface. Purge lubricator with N2. R/U 73mm swabbing equip and prep to

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08:0008:00

09:0009:00

09:3009:30

11:30

Oil m³ Water m³


v.1.14

IsolatedOpen432100


1552.0-1557.01679.0-1681.0

1000001

00





Install all plunger lift surface equip. MIRU swab ring. Swab well in. R/O swab rig. Release all services.Job CompleteFinal Report

Cum Fluid Rec'd:


0


0.00$500 000

0

AGC Goldy100/01-02-30-4W5/04


-$

-$


-$

SlicklineRentals

TreeTop Rig Nbr.:

Downhole Equipment




New Production:


Lease: GoodCloudy

-$

Safety


Grant Parrott


-$

-$



289 602.28$

-$

2 225.00$ 287 377.28$

-$

-$ -$

1 530.00$

Wellhead maintance crew break downs flow-tee & flowline back to seperator. Install PIT Punger lift wellhead equip & R/U 50.8mmflowline back to seperator and all related surface production equip. PIT service rep instalsl plunger lift surface equip and panals.M/I spot Carnwood swab rig and support equip. Held pre-job safety & risk assessment meeting w/all onsite personell. Outline jobobjectives & AGC polices & procedures. SITP: 100kPa. SICP: 560. R/U to AGC, OH&S & ERCB regulations.

and release all services. Turn well over to Production job complete. Final Report.

& continue to monter well against line pack press for 30min. Recovered 5.5m3 total oil productio with Est' gas rate of million cubicfeet of gas/day. Inform Calgary office and Production Dept' on well status. R/O swab rig and all related support swabbing equip

0.00

-$

Well Servicing 695.00$ Wireline

Held pre-job safety and risk assessment meeting with all onsite personell. Outline job objectives and AGC polices and procedures. Inform Calgary office well status. SITP: 1000kPa. SICP: 560kPa.

000


882.6 0.0 878.4

0.00 0

Alberta Gas Corp.

0.00

R/U 73mm swabbing equip( swab tree, lubricator and flow tee). R/U swab line back to surface production 400bbl tank. SITP: 1000kpa. Open tbg to tank on full gutline and bleed off tbg press. No fluid recovered. Bled down to TSTM. Swab well in.RIH tag fluid level @ 1050m. Pulled swab from 1650m. Recovered 1.4m3 100% oil. Well flowing. Moniter flow for 30min to surfaceproduction equip. Recoveed total 3.5m3. Turn well over to AGC production dept'. Send flow down production flow line

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Formation

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Section 9

Contents



Section 10

Contents


Company Metric Field 73.00Engineer Max Engineer KB GR Difference Datum PTA LevelWell Name AGC Goldy 882.60 878.40 4.20 -797.40 2

Alberta Gas Corp.Welltest Specialists Working Data Sheet

Tbg WTTbg ID

Tbg OD

yLocation 100/01-02-030-04W5/04 Vertical Deviated Openhole Horizontal Re-EntryFormation Victoria Gross h Net h Ø Sw Rw 1676.02License # 432100 2.00 1 10 32 0.06985 139.70Perforations 101 mm TCP, 25 g RDX SDP, 17 SPM, 60° Gas Density 2010-04-15 0.671 Gas Z 0.882Stimulation 15 t 20/40 Siber in DynaGel H2-N2 Energized, BD @ 35.6 MPa N2 CO2 H2S pPc pTcPerforations 1679 00 1681 00 1674 80 1676 80 1 33 0 71 0 00 4571 90 209 40

Csg ID

gTbg CapTbg End

Csg Cap

Csg WTCsg OD

Perforations 1679.00 1681.00 1674.80 1676.80 1.33 0.71 0.00 4571.90 209.40MPP 1680.00 KB 1675.80 CF Oil Density 833.300 0.8341 °API 38.2 1943.00PRD 1 (Flare) LFLTR 37 Gas 52.436 PRD 2 (In-line) LFLTR -16.831 Gas 36.520 3.649Rig-in 2010-04-11 7:15 net-Q 50.337 Rig-in 2010-04-13 13:57 net-Q 81.732 132.069Open 9:55 Oil 17.568 Open 15:00 Oil 10.008 0.274GTS 2010-04-12 14:55 net-N 53.831 GTS 15:10 net-N 28.751 82.582N Fl id 2010 04 13 1 00 W t 0 000 N Fl id W t 0 000 0 000

total-QOGRtotal-N

GOR

WGR

Csg CapCsg End

New Fluid 2010-04-13 1:00 Water 0.000 New Fluid Water 0.000 0.000Shut-in 2010-04-13 12:30 net-W 0.180 Shut-in 2010-04-15 12:00 net-W 0.000 0.180Rig-out 12:30 LOLTR -16.831 Rig-out 15:30 LOLTR -45.582 223%Flow Time 19.50 26.07 Ptf 1520 Flow Time 45.00 Ptf 1019 85%Initial GRD RRD, KB Final GRD 2010-04-21 8:03 RRD, KB 1672.70Tbg|Csg Press 5074 120 RRD, CF Tbg|Csg Press 6109 941 RRD, CF 1668.50

Ddown

total-WLFRec'd

WGR

Pressure CF LL, KB Pressure CF 6117.70 LL, KBPressure RRD LL, CF Pressure RRD 7080.24 LL, CFPressure MPP MPP-LL Pressure MPP 7084.47 MPP-LLIncrements Δd Gradient Δp Run-in

t1 h11672.70 1680.00 7.30 0.579 4.23 p1 kPa/mp1672.70 1680.00 7.30 0.579 4.23 t2 h2

p2 kPa/m * See DHDRRD–MPP Δp Mean Gas AOF Δp t3 RRD 1672.704.23 0.577 966.75 p3 m/hTRG #9500 Bottom Range 93- 24224 TRG #9499 Top Range 93- 24224Start 2010-04-13 13:33 RRD KB 1672 70 Start 2010-04-13 13:33 RRD KB 1671 70 1595 79Start 2010-04-13 13:33 RRD, KB 1672.70 Start 2010-04-13 13:33 RRD, KB 1671.70 1595.79End 2010-04-21 11:19 RRD, CF 1668.50 End 2010-04-21 11:19 RRD, CF 1667.50Use Gauge: #1, Bottom RRD, KB 1672.70 Pi 6081.16 25.1% 6085.39 Time/DaysOn Bottom 2010-04-13 13:57 RRD, CF 1668.50 Pwf 2413.27 10.0% 2417.50 139.97Off Bottom 2010-04-21 8:03 Temp. 62.67 Pfinal 7083.05 29.2% 7087.28 5.8 /4 VictoriaNotes Perf's: 1679.00I fi it C d ti it B d M d l 1680 00Infinite Conductivity Boundary Model: 1680.00k 9.402 Xf 47.943 qs 8.226 qs@s= 0.0 8.198 Line Pwf 1019.00 1681.00kh 9.402 Sc 25.821 AOFext 40.695 T|COFext 37.417 Pi, MPP 7548.00Sxf -5.838 Xe 1609 AOFstab 9.166 T|COFstab 8.428 Pi, whd 6581.25A 259.0 Ye 1609 n 1.000 n 1.000 Line BHPwf 2417

www.welltestspecialists.com Welltest Submission Form Page 1 of 2

Company Data

Company* Alberta Gas Corp. Engineer Max Engineer

E-mail [email protected] Phone # 403-411-1234

Address 1000, 200 - 4th Avenue SW, Calgary, T2P 3B2 BA Code* AB2C

Units metric

#Paper+CD 1+1

Well Data

Well Name* AGC Goldy Location * 100/01-02-030-04W5/04

Comment Re-entry License #* 432100

Elevations: KB* 882.6 CF* 878.4 * Sending TVD survey for deviated, horizontal or multi-lateral

Zone Data

Formation* Victoria Stimulation Frac'

Perforations* 1679.0 - 1681.0 m KB Open Hole

Net Pay (h) 1.0 Porosity () 10 Saturations: Sw 32 So Sg

Geology (sandstone/carbonate, depositional environment, diagenesis, boundary, trap, seal, drive and basin mechanisms) Sending well logs Lenticular near-shore dune deposites

Units: Depth ID/OD Pressure Temperature Liquid Gas Travel Time Chart Speed Metric (SI) m mm kPaa °C m3/d e3m3/d s cm/s Imperial (field) ft inch psia °F Bbl/d MMscf/d sec inch/sec

www.welltestspecialists.com Welltest Submission Form Page 2 of 2

Fluid Data

* Sending fluid analyses or fill out basic fluid information: Gas Density 0.671 Oil Density 0.834

N2 1.33 CO2 0.71 H2S 0.00 pPc 4571.9 pTc 209.4 Retrograde

Wellbore Data

* Send wellbore schematic if dual, liner, deviated, horizontal, multi-lateral, etc. Completion Perf' Sandscreen

Tubing ID* 62 Tubing OD* 73 Casing OD* 139.7 Liner OD KOP

Packer* 1595.8 Sliding Sleeve Tbg Anchor EOT/PSN PBTD

If dual, other formation: * Perforations*

Welltest Data

Depending on test circumstances and data availability, we might need some of the following information (i.e. if not provided by other data you are sending):

Final Flow Rates: * Gas (qg) Oil (qo) Water (qw)

Flowing Pressures: Tubing Casing Flow Line

Shut-in date & time before initial static gradient* Reservoir Temperature*

AWS Flowing: Joint Count or Travel Time & Chart Speed

AWS Shut-in: Joint Count or Travel Time & Chart Speed Comments (pulling/setting a plug, open/closing a sliding sleeve, anything unusual)

In-line single point test. *Data required for AEUB.pas, BC-OGC, and/or SIR file submissions. Please Zip and e-mail all data and reports to: [email protected]. Fax any other supplemental information to 403–206–7161

Well Summary - Geo Webworks Inc.Well: AGC GOLDY Operator: ALBERTA GAS CORP. Field: GOLDY AB

Location: 00/01-02-030-04W5/00Licensee: ALBERTA GAS CORP. License: 0432100 [1999/02/04]Status: ABANDONED ZONE [2007/03/01]

FORMATION TOPSForm Top

(m)Elev (m)

BFSC 1641.0 -758.8VIC 1667.5 -785.3JOLI 1707.0 -824.8MANN 1722.0 -839.8OST 1861.0 -978.8ELRS 1871.5 -989.3TD 1943.0 -1060.8

Form Top (ft)

Elev (ft)

BFSC 5383.9 -2489.5VIC 5470.8 -2576.4JOLI 5600.4 -2706.0MANN 5649.6 -2755.2OST 6105.6 -3211.3ELRS 6140.1 -3245.7TD 6374.7 -3480.3

Location

UWI Lat, Lon (NAD27) Coord (m)Surface: 00/01-02-030-04W5/00 54.45876, -124.05618 679.3 E421.3Bottom: 00/01-02-030-04W5/00 54.45876, -124.05618 679.3 E421.3

Elevation KB: 882.2 m / 2894.4 ft Ground: 878.3 m / 2881.6 ft

Classification DEVELOPMENT Dates License: 1999/02/04 Spud: 1999/03/17 Final Drill: 1999/03/24 Rig Release: 1999/03/27 Logs

CASING COLLAR LOG, CEMENT BOND VAR DENSITY, COMP NEUTRON FORM DENSITY, DUAL INDUCTION LOG, GAMMA RAY CEMENT BOND, MICRO LOG, SONIC LOG

Completions

1999/04/02 1871.5 - 1880.0 m / 6140.1 - 6168.0 ft JET PERFORATION1999/04/06 1871.5 - 1880.0 m / 6140.1 - 6168.0 ft FRACTURED2007/02/27 1857.0 - 1865.0 m / 6092.5 - 6118.8 ft BRIDGE PLUG CAPPED W/CEMENT2007/02/28 1589.0 - 1594.0 m / 5213.3 - 5229.7 ft JET PERFORATION2007/03/01 1577.0 - 1585.0 m / 5173.9 - 5200.1 ft BRIDGE PLUG CAPPED W/CEMENT2007/03/01 1552.0 - 1557.0 m / 5091.9 - 5108.3 ft JET PERFORATION2007/03/08 1552.0 - 1557.0 m / 5091.9 - 5108.3 ft FRACTURED

Tour Occurrence None Reported

Casings 219.0 mm at 325.0 m, 139.6 mm at 1943.0 m Drill Stem Tests

1. 1898.0 - 1908.0 m / 6227.0 - 6259.8 ft (ELRS), 1998/03/25; STRADDLE DST; Flow2: VO: 60 min, ? - 1451 kPag; SI: ? min, 2578 kPag; Rec: 150 m GC MUD;

2. 1870.0 - 1880.0 m / 6135.2 - 6168.0 ft (OST - ELRS), 1998/03/25; STRADDLE DST; Flow2: VO: 60 min, ? - 2098 kPag; SI: ? min, 12367 kPag; GTS: ? min, 2900 m3/d; Max: 2900 m3/d Gas; Rec: 150 m GC MUD;

Page 1 of 2Well Ticket - Geo Webworks Inc.

2010-05-14http://www2.geowebworks.com/Reports/WellTicket.aspx

Production Tests None Reported

Cores None Reported

00/01-02-030-04W5/00Status History

1999/02/04 UNKNOWN1999/03/24 DRILLED AND CASED1999/04/09 FLOWING GAS

Production

Pool: COMMINGLED POOL 003Note: Well is not currently producing; Last produced on 2008/07/31.

Oil (m3)

Gas (103m3)

Water (m3)

Time On (hrs)

Oil (m3/d)

Gas (103m3/d)

Water (m3/d)

Feb. 2007 0.0 24.2 0.4 340 0.0 1.7 0.0March 2007 0.0 11.9 0.0 172 0.0 1.7 0.0July 2008 0.0 0.0 5.4 24 0.0 0.0 5.4Cumulative 0.0 29892.6 289.5 63204

00/01-02-030-04W5/02Status History

1999/02/04 UNKNOWN1999/03/24 DRILLED AND CASED2007/03/01 ABANDONED ZONE

Production None Reported

00/01-02-030-04W5/03Status History 1999/02/04 UNKNOWN

1999/03/24 DRILLED AND CASEDProduction None Reported

Page 2 of 2Well Ticket - Geo Webworks Inc.

2010-05-14http://www2.geowebworks.com/Reports/WellTicket.aspx


Section 11

Contents


ERCB.pas Files

AGC Goldy 100/01–02–030–04W5/04 Victoria, Apr 11 – 21, 201010 ERCB.pas file submission certificate 1 of 4

From: [email protected] Sent: Tuesday, May 18, 2010 02:01 PM To: David Subject: WTC Production - Tracking Id: 7123456_100.01-02-030-04W5.4 PRD 10-04-13.zip THIS E-MAIL MESSAGE IS FROM THE WTC PRODUCTION SYSTEM Package: 7123456_100.01-02-030-04W5.4 PRD 10-04-13.zip [Tracking Id: 7123456] UWI: 100/01-02-030-04W5/4 The package was successfully submitted Pas File: 7123456_100.01-02-030-04W5.4 PRD 10-04-13.pas Tested Date: 2010 04 13 1230:00 LOG Interval: 1679 - 1681 Package was recorded successfully in the Well Test Capture system.

ERCB.pas Files


From: [email protected] Sent: Tuesday, May 18, 2010 02:01 PM To: [email protected] Subject: WTC Production - Tracking Id: 7123456_100.01-02-030-04W5.4 PRD 10-04-15.zip THIS E-MAIL MESSAGE IS FROM THE WTC PRODUCTION SYSTEM Package: 7123456_100.01-02-030-04W5.4 PRD 10-04-15.zip [Tracking Id: 7123456] UWI: 100/01-02-030-04W5/4 The package was successfully submitted Pas File: 7123456_100.01-02-030-04W5.4 PRD 10-04-15.pas Tested Date: 2010 04 15 1530:00 LOG Interval: 1679 - 1681 Package was recorded successfully in the Well Test Capture system.

ERCB.pas Files


From: [email protected] Sent: Tuesday, May 18, 2010 02:01 PM To: David Subject: WTC Production - Tracking Id: 7123456_100.01-02-030-04W5.4 PBU.AOF 10-04-21.zip THIS E-MAIL MESSAGE IS FROM THE WTC PRODUCTION SYSTEM Package: 7123456_100.01-02-030-04W5.4 PBU.AOF 10-04-21.zip [Tracking Id: 7123456] UWI: 100/01-02-030-04W5/4 The package was successfully submitted Pas File: 7123456_100.01-02-030-04W5.4 PBU.AOF 10-04-21.pas Tested Date: 2010 04 21 0803:00 Test Purpose: Initial TVD Interval: 1679 - 1681 Package was recorded successfully in the Well Test Capture system.

ERCB.pas Files


From: [email protected] Sent: Tuesday, May 18, 2010 02:01 PM To: David Subject: WTC Production - Tracking Id: 7123456_100.01-02-030-04W5.4 GRD 10-04-21.zip THIS E-MAIL MESSAGE IS FROM THE WTC PRODUCTION SYSTEM Package: 7123456_100.01-02-030-04W5.4 GRD 10-04-21.zip [Tracking Id: 7123456] UWI: 100/01-02-030-04W5/4 The package was successfully submitted Pas File: 7123456_100.01-02-030-04W5.4 GRD 10-04-21.pas Tested Date: 2010 04 21 1105:00 Test Purpose: Other TVD Interval: 1679 - 1681 Package was recorded successfully in the Well Test Capture system.