daily completion and workover -...

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Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM

Report Printed: 22/01/2014www.peloton.com

Daily Completion and Workover

UWI

102/10-01-011-27W1/00Surface Location

12-06-11-26Field Name

VIRDENLicense #

9680State/Province

ManitobaWell Configuration Type

HorizontalOriginal KB Elevation (m)

473.20KB-Tubing Head Distance (m) Spud Date

10/12/2013 20:00Rig Release Date

15/12/2013 12:00PBTD (All) (mKB) Total Depth All (TVD) (mKB)

Report # 1.0, Report Date: 16/12/2013

Primary Job Type

Initial CompletionSecondary Job Type

WHITEWATER COMPLETIONObjective

Contractor

Canyon Technical ServicesRig Number

138105Contractor

Essential CoilRig Number

2146Contractor

Eagle Well ServicingRig Number

56AFE Number

C13-VIR-07Total AFE + Supp Amount (Cost)

590,000.00Daily Field Est Total (Cost)

18,498.94Cum Field Est To Date (Cost)

18,498.94Operations Summary

Install production head, frac sleeve and valve. Move In 7 Dragon Tanks. 1 400 bbl and 1 Open Top Tank. 4 Light Towers, 1 Toilet and 1 Shower. Heat Frac Fluid. MIRU coil rig, Function Test BOP's and Rig in pump truck. Rig In Testers. Install Internal Dimple Connector. Pull Test to 21,000 daN. Pressure Test to 35 mpa. Tool up with NCS Insta Frac BHA

Operations at Report Time

Installing NCS Insta Frac BHAOperations Next Report Period

Fracturing

Daily ReadingsWeather

Cloudy. Winds 26 kmh WTemperature (°C)

-3Road Condition Tubing Pressure (kPa) Casing Pressure (kPa)

0Rig Time (hr)

Daily Contacts

Job Contact Title Mobile

Mike Smith Completions Sup 403-801-0828

Karl Menzies Wellsite Supervisor 306-278-8576

Scott Kingdon Wellsite Supervisor 306-457-8250

Time Log

Start Time End Time Dur (hr) Code 1 Code 2 Com

12:00 16:00 4.00 401 Rig Up/Rig Out: Stimulation

Move In 7 Spearing Dragon Tanks. Fill with Pipestone Water. 1 Open Top, 1 400 bbl Tank. 4 Light Towers, 1 Shower Unit and 1 Toilet moved In

Canyon Technical Services MIRU CTU. Stab Pipe. Function Test BOP's

16:00 18:00 2.00 101 Install or Change Wellhead

Weatherford install production head, frac sleeve and valve. Test seals. All good


Install BOP's On Wellhead. TP Rigged into Coil Reel. Testers Rigged Into Wellhead. Lube Up. Rangeview Oilfield Sales Install's New Internal Dimple Connector. Tool O/D: 72.920 mm, Tool I/D: 47.730 mm. Length: 0.08 m, 60.3 EUE Pin Connection

Pull Test Coil Connector to 7000 daN, 14,000 daN, and 21,000 daN. Good Test

Spearing Arrived. Started Heating Recycle Tank to 70 oC. 6 Frac Tanks To 35 oC.

Fill Coil with 60 L Methanol and 8.2 m3 70 oC Water, Circulate Till Flow Back Iron was Warm. Returns to Open Top and Recycle Tank

23:30 23:45 0.25 403 Pressure Test: Stimulation

Pressure Test Coil Connector to 20 mpa Low Test. 35 mpa High Test. Good Test. Bleed off


Make up NCS Instafrac tool as follows: Total length 6.78 metersShear sub 79.0 mm OD, 0.305 meter lengthCentralizer 98.0 mm OD, 0.915 meter lengthBall seat 1.375 " 78.0 mm OD, 0.11 meter lengthCentralizer 98.0 mm OD, 0.915 meter lengthJet body 98.0 mm OD, 0.236 meter lengthInstafrac tool 78.0 mm OD, 1.58 meter lengthPacker 98.0 mm OD, 0.53 meter length

Report Fluids Summary

Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)

Water 550.00 0.00

Safety Checks

Time Des Type Com

12:30 Spotting Frac Tanks Safety Meeting Safety Metting with Spearing. Hazards. Spotter

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UWI



VIRDENLicense #

9680State/Province







Safety Checks

Time Des Type Com

22:00 Filling Coil, Pressure Testing Safety Meeting Coil, TP Pump and Testers. Possible Ice Plugs. Iron Safety Cables attached. Communication

Logs

Time Type Top (mKB) Btm (mKB) Cased?

Perforations

Time Zone Top (mKB) Btm (mKB) Current Status

Stimulations & TreatmentsTime Zone Type Delivery Mode Stim/Treat Company

Stg # Stage Type Top (mKB) Btm (mKB) Vol Clean Pump (m³)

Tubing RunRun Time Tubing Description Set Depth (mKB) String Max Nominal OD (mm) Weight/Length (kg/m) String Grade

Tubing PulledPull Time Tubing Description Set Depth (mKB) String Max Nominal OD (mm) Weight/Length (kg/m) String Grade

Other in Hole Run (Bridge Plugs, etc)

Run Time Des OD (mm) Top (mKB) Btm (mKB)

Other in Hole Pulled (Bridge Plugs, etc)

Pull Time Des Top (mKB) Btm (mKB) OD (mm)

Cement

Start Time Des Type String Cement Comp

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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Pressure Test Stack to 35 mpa. Open Master Valve. RIH with Opti Frac BHA. Frac 13 Stages out of 17 Stages Whitewater FormationOperations at Report Time

Fracturing Stage # 14 @ 962 mkBOperations Next Report Period

Well Shut In, Monitor Wellbore Pressures


Cloudy. Winds 40 kmh NWTemperature (°C)

-7Road Condition Tubing Pressure (kPa) Casing Pressure (kPa) Rig Time (hr)

Daily Contacts





Time Log



Finish Rigging up Instafrac BHA. Stab on BOP's. Break Circulation back to Recycle Tank. Warm Iron Up. Close in to Testers. Pressure Test Stack to 36 mpa. Good Test. Bleed off. Open Master Valve 39.5 turns. Zero Counters

01:00 03:30 2.50 402 Trip: Stimulation RIH, Fluid rate 100 l /min. Slow Down @ 772.15 mkB for Crossover. No Flicker on Weight Indicator. RIH past Marker Joint @ 1241.69 - 1244.6 mkB. Pull up. Good Locate. Corrolate Counters + 4.29 meters. RIH to Float Collar @ 1425.30 mkB. Tagged with Tool Bottom @ 1427.10 mkB. Pull up and Locate Casing Joint # 02 @ 1414.3 mkB off Casing Tally. Locate with BHA @ 1414.10 mkB. Pull up Cycle Tool. Packer Set @ 1409.10 mkB. Circulate Coil

Frac Equipment arrives on Location. Do Lease Walk around. Spot Equipment. Begin Riggin Up. QC done with Fluid and Additives. Biocide added to Frac Water


Current Conditions on Location are - 7 oC, Wind Gusts from 35 - 60 kmh. Told Frac Supervisor to make sure everything was in place to switch over to Frac Manifold. When I went out to see how things were going. No Iron was in place to do the transition. They Rigged in from Scratch. I talked to the Frac Supervisor after we were down for 1 / 2 hr on Circulating and Said we needed to pick the pace up. Coil Sup came to me saying Coil was getting chilly up top. I felt the Flow back Iron and it was Ice Cold. Told Coil Supervisor he should be Questioning Frac Supervisor about timing. Fluid was out for 70 mins. Set up to Reverse. Fluid was very cold coming out of Coil. Had a Talk with Coil Supervisor and Frac Supervisor about the importance of Working in Cold Weather with Fresh Water.

Rig in to Pump and Dragon Tanks. QC Done with Fluid

06:30 08:00 1.50 17 Waiting Time Coil on bottom, waiting for acid hauler. Circulating on depth.

08:00 08:30 0.50 601 Safety Meeting Hold pre-job safety meeting. Discuss all hazzards and review job parameters.


Prime up and pressure test frac equipment to 55 mpa. All good. Test annulas iron to 40 mpa. All good.

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VIRDENLicense #

9680State/Province







Time Log


09:15 12:30 3.25 404 Fracture: Stimulation Stage # 01 Brazzer Jet @ 1417.0 mkB 08:39 -- Circulate 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 18.7 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 500 kg/m3 over 10.7 m3 and hold stage at 500 kg for 3.7 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 500 kg/m3, Avg Press - 10.1 mpa, ISIP - 9.2 mpa. Total Clean Fluid Injected 42.7 m3. Fluid Injected Moving Tools 0.9 m3

NOTE: Increase prop con to 600 kg.

Stage # 02 Brazzer Jet @ 1382.0 mkB 10:13 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 9.3 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 600 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 600 kg/m3, Avg Press - 9.8 mpa, ISIP - 9.0 mpa. Total Clean Fluid Injected 32.7 m3. Fluid Injected Moving Tools 0.8 m3


12:30 16:00 3.50 404 Fracture: Stimulation Stage # 04 Brazzer Jet @ 1312.0 mkB 12:35 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 14.4 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 600 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 600 kg/m3, Avg Press - 10.3 mpa, ISIP - 9.2 mpa. Total Clean Fluid Injected 32.5 m3. Fluid Injected Moving Tools 0.8 m3



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UWI



VIRDENLicense #

9680State/Province







Time Log


16:00 19:15 3.25 404 Fracture: Stimulation NOTE: Increase prop con to 650 kg.

Stage # 07 Brazzer Jet @ 1207.0 mkB 16:01 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 19 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 650 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 650 kg/m3, Avg Press - 10.3 mpa, ISIP - 9.4 mpa. Total Clean Fluid Injected 32.2 m3. Fluid Injected Moving Tools 0.8 m3


Stage # 09 Brazzer Jet @ 1137.0 mkB 18:13 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 19.7 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 650 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 650 kg/m3, Avg Press - mpa, ISIP - 9.2 mpa. Total Clean Fluid Injected 31.2 m3. Fluid Injected Moving Tools 0.8 m3

19:15 22:30 3.25 404 Fracture: Stimulation Stage # 10 Brazzer Jet @ 1102.0 mkB 19:20 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 17.3 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 650 kg/m3, Avg Press - 10.5 mpa, ISIP - 9 mpa. Total Clean Fluid Injected 31.8 m3. Fluid Injected Moving Tools 0.8 m3


Stage # 12 Brazzer Jet @ 1032.0 mkB 21:34 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 17.6 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 650 kg/m3, Avg Press - mpa, ISIP - 9.4 mpa. Total Clean Fluid Injected 31.4 m3. Fluid Injected Moving Tools m3


Stage # 14 Brazzer Jet @ 962.0 mkB 23:45 --Note: Info on 18 / 12 / 2013

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VIRDENLicense #

9680State/Province









Water 15.00 0.00 150.00 8.00

Safety Checks

Time Des Type Com

07:00 Frac meeting Safety Meeting Pre job meeting before frac.

18:15 Crew Change Safety Meeting Good Switch out. Communication

Logs


Perforations


Stimulations & TreatmentsTime

07:00Zone

Whitewater, Original HoleType

Hydraulic FracDelivery Mode

Coil TubingStim/Treat Company

Canyon Technical Services


1 Treatment 1,417.00 1,417.10 43.60

2 Treatment 1,382.00 1,382.10 33.50

3 Treatment 1,326.50 1,326.60 33.10

4 Treatment 1,312.00 1,312.10 33.30

5 Treatment 1,277.00 1,277.10 33.60

6 Treatment 1,247.50 1,247.60 33.60

7 Treatment 1,207.00 1,207.10 33.00

8 Treatment 1,171.50 1,171.60 31.50

9 Treatment 1,137.00 1,137.10 32.00

10 Treatment 1,107.00 1,107.10 32.60

11 Treatment 1,067.00 1,067.10 33.00

12 Treatment 1,032.00 1,032.10 32.00

13 Treatment 993.50 993.60 32.10

14 Treatment 962.00 962.10 31.80

15 Treatment 927.00 927.10 32.30

16 Treatment 894.00 894.10 32.40

17 Treatment 857.00 857.10 29.90







Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Complete 17 Stage Frac on Whitewater Formation. Rig Out Frac and Coil Services. Monitor shut in pressure.Operations at Report Time

Well shut in, SICP 7746 kpaOperations Next Report Period

Open up well to flowback @ 2 - 3 m3 / hr @ 04:00 hrs.


Flurries. Winds 25 - 53 kmh NWTemperature (°C)


7,700Rig Time (hr)

Daily Contacts




Time Log




Stage # 16 Brazzer Jet @ 894.0 mkB 01:59 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 14 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 1.5 m3 followed by cut sand for next interval.BH Prop. Con - 650 kg/m3, Avg Press - 10.3 mpa, ISIP - 9.8 mpa. Total Clean Fluid Injected 31.6 m3. Fluid Injected Moving Tools 0.8 m3

03:00 04:00 1.00 404 Fracture: Stimulation Stage # 17 Brazzer Jet @ 857.0 mkB 03:06 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 19.9 mpa. Pump 0.3 m3 15% HCL Acid, and a 3 m3 X-Linked pad. Pump 5.0 tonne of 20/40 Proppant with a Scour Stage @ 100 kg/m3 for 3.0 m3, then ramp 100 - 650 kg/m3 over 10.7 m3 and hold stage at 600 kg for 3.0 m3. Flush 9.2 m3 BH Prop. Con - 650 kg/m3, Avg Press - 9.6 mpa, ISIP - 9.2 mpa. Total Clean Fluid Injected 29.2 m3. Fluid Injected Moving Tools 0.7 m3

<<<<<<<<<<<<< FRAC SUMMARY >>>>>>>>>>>

Pumped 17 stage frac treatment. Cutting with 400 kg sand. Injected 6.1 15% HCL and 584.0 m3 of treated gelled frac fluid. Placed 93.5 tonne of 20/40 sand.

04:00 05:30 1.50 402 Trip: Stimulation POOH with TP Injecting down Coil @ 100 l / min.

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Time Log



BHA On Surface. Well Bore Pressure 8200 kPa Close in Master Valve, 39.5 Turns.Circulate to Warm Up Coil.

Break out and lay down NCS frac tools. Loaded out the same.

Purge coil with N2. Talley final fluids and rig out release frac and coil services.

13:30 00:00 10.50 608 SITP / SICP Pressure Well shut in. Monitor pressures for during 24 hr shut in.



Acid 6.10 0.00 6.10 0.00

Water 584.00 0.00 0.00 108.00

Safety Checks

Time Des Type Com

Logs


Perforations


08:00 Whitewater, Original Hole 857.00 857.10 Open - Flowing





08:00 Whitewater, Original Hole 1,032.00 1,032.10 Open - Flowing




















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UWI



VIRDENLicense #

9680State/Province







Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Well Flowing 2.12 m3 / hr Average. Total Flow Time : 20 Hours. Total Fluid Recovered since Opening Well for Flow Test 42.0 m3 water. Salinity 36000 ppm. Choke 12 / 64 "( 6.74 mm ). Operations at Report Time

Well flowing @ 2.18 m3 / hr. Recovered 42.0 m3 water. 6559 kpa.Operations Next Report Period

Continue to flow back well @ 2 - 2.5 m3 / hr


West windsTemperature (°C)


6,559Rig Time (hr)

Daily Contacts




Time Log


00:00 00:00 24.00 502 Testing - Flow to Tank Load fluid to recover= 599.0 m3Load fluid left to recover= 539.76 m3Total accumulated fluid= 59.24 m3Total accumulated water= 59.24 m3Total accumulated oil= 0.0 m3Accumulated fluid in last 12 hours= 26.23 m3Accumulated water in last 12 hours= 26.23 m3Accumulated oil in last 12 hours= 0.0 m3Accumulated flow time hrs = 28 hrsAverage hourly gain in last 12 hours= 2.19 m3Salinity - 42000Casing Pressure = 5645 kpa



Acid 0.00 0.00 0.00 0.00

Water 0.00 26.00 0.00 26.00

Safety Checks

Time Des Type Com

Logs


Perforations






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VIRDENLicense #

9680State/Province











Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Well Flowing 2.15 m3 / hr Average. Total Flow Time : 44 Hours. Total Fluid Recovered since Opening Well for Flow Test 93.52 m3 water. Salinity 46000 ppm. Choke 16 / 64 "Operations at Report Time

Well flowing @ 2.1 m3 / hr. Recovered 93.52 m3 water. 1738 kpa.Operations Next Report Period

Continue to flow back well @ 2 - 2.5 m3 / hr


OvercastTemperature (°C)


1,738Rig Time (hr)

Daily Contacts




Time Log


00:00 00:00 24.00 502 Testing - Flow to Tank ****SUMMARY****

Load fluid to recover= 599.0 m3Load fluid left to recover= 505.48 m3Total accumulated fluid= 93.52 m3Total accumulated water= 93.52 m3Total accumulated oil= 0.0 m3Accumulated fluid in last 12 hours= 25.78 m3Accumulated water in last 12 hours= 25.78 m3Accumulated oil in last 12 hours= 0.0 m3Accumulated flow time hrs = 44 hrsAverage hourly gain in last 12 hours= 2.15 m3Salinity - 46000Casing Pressure = 1738 kpa



Acid 0.00 0.00 0.00 0.00

Water 0.00 49.50 0.00 49.50

Safety Checks

Time Des Type Com

Logs


Perforations





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VIRDENLicense #

9680State/Province












Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Well died off, flowing only 1.18 m3 / hr Average. Total Flow Time : 56 Hours. By trucking total fluid recovered since opening the well 112.0 m3 water. Oil showing up at sample point but no measurable oil was hauled off location. Well shut in.Operations at Report Time

Well shut inOperations Next Report Period

Waiting for service rig


ClearTemperature (°C)


23Rig Time (hr)

Daily Contacts




Time Log


00:00 12:00 12.00 502 Testing - Flow to Tank Well died off thru the night. Trace oil @ 01:00 hrs. Flowed till noon then shut in, 20 kpa. By trucking we recovered 112 m3 of water.

12:00 18:00 6.00 501 Rig Up/Rig Out: Testing Rig out testers and clean out flow back tank with vac truck and steamer.



Acid 0.00 0.00 0.00 0.00

Water 0.00 37.00 0.00 37.00

Safety Checks

Time Des Type Com

Logs


Perforations










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VIRDENLicense #

9680State/Province







Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Cleaning flow back tankOperations at Report Time

Wating for service rigOperations Next Report Period

Waiting for service rig


NW windsTemperature (°C)

-29Road Condition Tubing Pressure (kPa) Casing Pressure (kPa) Rig Time (hr)

Daily Contacts




Time Log




Acid 0.00 0.00 0.00 0.00

Water 0.00 0.00 0.00 0.00

Safety Checks

Time Des Type Com

Logs


Perforations










Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Well Flowing 1.05 m3 / hr Average. Flow Time Since Re Opened Well Head : 9.5 Hours. Total Flow 65.5 Hours: Total Fluid Recovered for Flow Test 122.05 m3 water. Salinity 52000 ppm. Well Died. Shut In Monitor PressuresOperations at Report Time

Monitor Shut In Pressure. Casing Pressure @ 163 kPaOperations Next Report Period

Monitor Shut In Pressures


Sunny Winds 29 kmh NWTemperature (°C)


163Rig Time (hr)

Daily Contacts




Time Log


07:30 07:45 0.25 601 Safety Meeting Arrive On Lease. Safety Meeting. Discuss Hazards, All Incidents and Accidents are Reportable, Winter Conditions, Ruts Under Snow, Monitors To be Worn. 4 People On Location

07:45 10:30 2.75 501 Rig Up/Rig Out: Testing Move Conly Max Heater to Wellhead. Tarp In Wellhead. Rig Up Testers Iron from Well head to Open Top Flow Back Tank

10:30 20:00 9.50 502 Testing - Flow to Tank 10:29 1897 kPa Opening Pressure10:35 1602 kPa10:40 1596 kPa10:45 1420 kPa11:00 895 kPa

****SUMMARY****Load fluid to recover= 599.0 m3Load fluid left to recover= 477.45 m3Total accumulated fluid= 122 m3Total accumulated water= 121.55 m3Total accumulated oil= 0.45 m3Accumulated fluid in last 9.5 hours= 10 m3Accumulated water in last 9.5 hours= 9.55 m3Accumulated oil in last 9.5 hours= 0.45 m3Accumulated flow time hrs = 65.5 hrsAverage hourly gain in last 9.5 hours= 1.05 m3Salinity= 52000 ppmCasing Pressure 20 kPa

20:00 00:00 4.00 608 SITP / SICP Pressure 20:00 20 kPa Shut Well In Monitor Pressures20:30 42 kPa21:00 56 kPa21:30 75 kPa22:00 100 kPa22:30 128 kPa23:00 145 kPa23:30 155 kPa24:00 163 kPa



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.45

Water 0.00 9.55 0.00 4.50

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VIRDENLicense #

9680State/Province







Safety Checks

Time Des Type Com

07:35 Cold Weather, Hazards Safety Meeting Pre - Job Safety Meeting

Logs


Perforations










Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number







Monitor Wellbore Pressures. Casing Pressure @ 984 kPaOperations Next Report Period



Overcast Winds 33 - 42 kmh NW Windchill -48 o C

Temperature (°C)


984Rig Time (hr)

Daily Contacts




Time Log


00:00 00:00 24.00 608 SITP / SICP Pressure Monitor Wellbore Pressures

00:00 163 kPa 12:00 779 kPa 24:00 984 kPa 00:30 222 kPa 12:30 791 kPa01:00 281 kPa 13:00 803 kPa01:30 320 kPa 13:30 813 kPa02:00 371 kPa 14:00 825 kPa02:30 410 kPa 14:30 833 kPa03:00 445 kPa 15:00 849 kPa03:30 481 kPa 15:30 859 kPa04:00 500 kPa 16:00 874 kPa04:30 520 kPa 16:30 888 kPa05:00 532 kPa 17:00 899 kPa05:30 542 kPa 17:30 915 kPa06:00 560 kPa 18:00 932 kPa06:30 565 kPa 18:30 945 kPa07:00 575 kPa 19:00 951 kPa07:30 590 kPa 19:30 961 kPa08:00 605 kPa 20:00 970 kPa08:30 622 kPa 20:30 971 kPa09:00 633 kPa 21:00 972 kPa09:30 655 kPa 21:30 973 kPa10:00 680 kPa 22:00 975 kPa10:30 715 kPa 22:30 976 kPa11:00 754 kPa 23:00 980 kPa11:30 760 kPa 23:30 982 kPa



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.50

Water 0.00 0.00 0.00 1.50

Safety Checks

Time Des Type Com

01:00 Cold Weather, Hazards Winter conditions -50 oC Windchill

07:00 Crew Change, Cold Weather, Hazards Winter conditions -50 oC Windchill

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VIRDENLicense #

9680State/Province







Logs


Perforations










Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Monitor Shut In Pressures. Opened Well Up. Flowed 0.5 m3. Well Died. Close In Monitor Build Up Pressures



Coil Tubing Cleanout


Overcast Winds 24 - 31 kmh NW Windchill -46 o C

Temperature (°C)


888Rig Time (hr)

Daily Contacts




Time Log


00:00 08:30 8.50 608 SITP / SICP Pressure Monitor Wellbore Pressures. Pressure Guage was Checked is Not Frozen

00:00 984 kPa 00:30 988 kPa 01:00 992 kPa 01:30 996 kPa 02:00 1001 kPa 02:30 1006 kPa 03:00 1010 kPa 03:30 1013 kPa 04:00 1017 kPa 04:30 1079 kPa 05:00 1020 kPa 05:30 1022 kPa 06:00 1025 kPa 06:30 1029 kPa 07:00 1033 kPa 07:30 1036 kPa 08:00 1040 kPa

08:30 09:00 0.50 502 Testing - Flow to Tank Open Well to Flow Through a 19.05 mm ( 48 / 64 ) Choke

08:35 Pressure 255 kPa08:40 Pressure 152 kPa08:45 Pressure 88 kPa09:00 Pressure 21 kPa

Well Shut In

Recovered 0.5 m3 H2O

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UWI



VIRDENLicense #

9680State/Province







Time Log


09:00 00:00 15.00 608 SITP / SICP Pressure Monitor Wellbore Pressures. Pressure Guage was Checked is Not Frozen

09:00 21 kPa Well Shut In 09:30 243 kPa 17:00 817 kPa 10:00 509 kPa 17:30 823 kPa 10:30 560 kPa 18:00 831 kPa 11:00 592 kPa 18:30 840 kPa 11:30 619 kPa 19:00 846 kPa 12:00 651 kPa 19:30 855 kPa 12:30 688 kPa 20:00 859 kPa13:00 717 kPa 20:30 863 kPa13:30 732 kPa 21:00 868 kPa14:00 751 kPa 21:30 875 kPa14:30 770 kPa 22:00 878 kPa15:00 789 kPa 22:30 880 kPa15:30 813 kPa 23:00 883 kPa16:00 833 kPa 23:30 886 kPa16:30 823 kPa 24:00 888 kPa



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.00 0.00 0.00

Water 0.00 0.00 0.00 0.00

Safety Checks

Time Des Type Com

Logs


Perforations










Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Monitor Shut In Pressures. MIRU CTU. Electronic Issues with Picker. Shut Down for Day. Monitor Wellbore PressuresOperations at Report Time


Coil Tubing Cleanout


Overcast Winds 18 kmh NW Windchill -38 o C

Temperature (°C)


1,015Rig Time (hr)

Daily Contacts




Time Log


00:00 09:00 9.00 608 SITP / SICP Pressure Monitor Wellbore Pressures.

00:00 888 kPa 05:00 911 kPa 00:30 890 kPa 05:30 913 kPa 01:00 891 kPa 06:00 915 kPa 01:30 893 kPa 06:30 916 kPa 02:00 895 kPa 07:00 917 kPa 02:30 899 kPa 07:30 919 kPa 03:00 903 kPa 08:00 922 kPa03:30 906 kPa 08:30 925 kPa 04:00 909 kPa 09:00 932 kPa 04:30 910 kPa

09:00 09:30 0.50 102 MIRU Essential 2 3/8 " Coil Tubing Unit, Picker, Support Unit, Canyon Technical Services TP Pump Arrive on Location. Tailgate Meeting. Spotting Units, Communication, Hazards

Wellbore Pressures09:00 932 kPa 09:30 940 kPa

09:30 13:00 3.50 14 Rig Repair Hydraulics on Picker Would Not Work. Tried Trouble Shooting On Lease. Picker Released. Went to Virden Manitoba for Mechanics to Look at.

Release Services.

Testers carry on with Pressure Build Ups

Wellbore Pressures09:30 940 kPa 11:00 968 kPa10:00 949 kPa 11:30 974 kPa10:30 961 kPa 12:00 981 kPa

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VIRDENLicense #

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Time Log



13:00 983 kPa 19:00 995 kPa 13:30 986 kPa 19:30 1001 kPa 14:00 987 kPa 20:00 1006 kPa 14:30 983 kPa 20:30 1006 kPa 15:00 984 kPa 21:00 1007 kPa 15:30 985 kPa 21:30 1009 kPa 16:00 987 kPa 22:00 1011 kPa 16:30 988 kPa 22:30 1011 kPa17:00 990 kPa 23:00 1013 kPa17:30 991 kPa 23:30 1014 kPa18:00 992 kPa 24:00 1015 kPa18:30 991 kPa



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.00 0.00 0.00

Water 0.00 0.00 56.00 0.00

Safety Checks

Time Des Type Com

09:00 Tailgate Meeting Safety Meeting Spotting and Rigging Up CTU and TP Pump

Logs


Perforations










Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Monitor Wellbore Pressures. Picker Had Re Gen Issues causing delay in job. Rigged up coil and fluid pumper. Run in and cleaned out lateral section of well bore. @ 1200 mkB, started seeing oil in returns. Estimated 4.0 tonne of sand cleaned out, 12 m3 losses. Pulled coil out of hole and rigging down. SICP 4500 kpa. <<<<<< Essential Coil ticket to be revised in Calgary, 30 hour delay of job >>>>>>Operations at Report Time

Purging coil with N2Operations Next Report Period

Finish rigging out coil and release. Flowing well to tank. Service Rig Operations, run production.


Sunny Winds 6 kmh SETemperature (°C)


4,500Rig Time (hr)

Daily Contacts





Time Log



00:00 1015 kPa 05:00 1037 kPa 00:30 1019 kPa 05:30 1040 kPa 01:00 1020 kPa 06:00 1042 kPa 01:30 1022 kPa 06:30 1045 kPa 02:00 1024 kPa 07:00 1047 kPa 02:30 1027 kPa 07:30 1047 kPa 03:00 1031 kPa 08:00 1047 kPa03:30 1032 kPa 04:00 1035 kPa 04:30 1036 kPa

08:00 12:30 4.50 14 Rig Repair Re-gen Issues with Picker. Wellhead Heater Fan Belt Broke. New Wellhead Heater to be Delivered to Lease. Tarped in Picker Truck. Everything Working

Monitor Wellbore Pressures.

08:00 1047 kPa 10:30 1052 kPa08:30 1048 kPa 11:00 1058 kPa09:00 1049 kPa 11:30 1054 kPa09:30 1050 kPa 12:00 1051 kPa10:00 1050 kPa 12:30 1052 kPa

12:30 14:30 2.00 602 Rig Service Bleed Off Wellbore to Open Top Tank

Mechanic Checked Over Picker

14:30 14:45 0.25 601 Safety Meeting Safety Meeting. Discuss Operations, Pressures, Rates. Communication. Gel Pill Mixing, All Incidents and Accidents are Reportable. Nearest Medical Facility. Working In Cold Temperatures. 11 People On Site

14:45 16:45 2.00 604 BOPS-Install / Remove Function Test BOP's

Install BOP's On Wellhead. Lube Up. Stab Onto Bop's

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UWI



VIRDENLicense #

9680State/Province







Time Log


16:45 18:15 1.50 609 Pressure Test Fill Coil 0.200 m3, 6.2 m3 60 oC Produced Water. Circulate Till Flow Back Iron is Warm. Close In to Testers. Pressure Test Main Line to 32 mpa. Close In Reel Valve. Pressure Test Stack to 21 mpa. Changed 2 x 2 Valve on Reel

60.3 mm CoilLength: 2887 metersVolume: 6.37 m3Int Volume: 2.2 L / mExt Displacement: 2.86 L / mWeight: 5.14 kg / mMax Pull: 32.5 daNBurst: 68 mpa

18:15 23:15 5.00 701 Clean-out - Coil Tubing Operations

Running in hole while reverse circulating at 500 Lpm. Adjusting choke according to rate of returns to remain balanced. At 1200 mkB saw 30% sand in returns and slowed run in hole speed to 5 meters / min for remaining of the lateral.

NOTE: 10 - 12 % sand in returns average. Circulating oil around and pressure increased.

At 1300 meters launched a 2.0 m3 gelled pill to sweep liner. Followed by a liner volume and another gel pill. Tagged out at 1435 by coil counter. Pulled back 2 meters and continued pumping till 2nd pill came around plus another 15 m3.

NOTE: Lost 12.0 m3 to well while circulating.

Pull out of hole.

23:15 00:00 0.75 907 Coil Tubing - Install/ Remove

At surface with coil. Purging coil with N2.



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.00 0.00 0.00

Water 12.00 0.00 0.00 2.00

Safety Checks

Time Des Type Com

14:30 Filling Coil, Pressure Testing, Cleanout Safety Meeting Coil, TP Pump and Testers. Possible Ice Plugs. Iron Safety Cables attached. Communication

Logs


Perforations






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UWI



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9680State/Province











Cement


j)core

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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Finish rigging out coil and fluid pumper. Open well and flow to tank @ 2 - 3 m3 / hr. SICP 4840 kpa. Flowed back till 08:00 hrs then shut in with 20 kpa on well. Recovered 13.0 m3 water with some trace oil. MIRU. Remove frac valve. Stump test BOP's. RIH w/ production tbg, Rig out bop's and n/u well head. Rih w/ pump and 95 - 19mm rod's. SDONOperations at Report Time

Rig out testers, MIRU service rigOperations Next Report Period

Rih w/ 25-200 RWAC 16x2 pump on production rod detail. Rig out and move to next lease.


Sunny, No wind chillTemperature (°C)

-13Road Condition Tubing Pressure (kPa)

10,000Casing Pressure (kPa)

10,000Rig Time (hr)

11.00

Daily Contacts





Myles Simonar Production Engineer 403-804-3630

Sandy Angus Eng Tech 403-826-1244

Darrell Wild Completions 204-851-5595

Time Log


00:00 02:00 2.00 907 Coil Tubing - Install/ Remove

Finish purging coil with N2. Rig out Coil unit and fluid pump. Rig testers onto well head.

02:00 08:00 6.00 502 Testing - Flow to Tank Testers open up well to flow @ 02:00 hrs @ 2 - 3 m3 / hr. SICP 4840 kpa.

03:00 hrs 3337 kpa04:00 hrs 2440 kpa05:00 hrs 436 kpa06:00 hrs 50 kpa07:00 hrs 20 kpa08:00 hrs 20 kpa

Shut in well, rig out testers.

Recovered 13.0 m3 water during flow back.Hauled 5m3 of sand from flow back.

08:00 08:30 0.50 601 Safety Meeting Held pre job and procedures meeting with all personnel on lease. Talked about cold weather. Pressure testing the new manifold.

08:30 10:30 2.00 102 MIRU Moved in and rigged up Eagle 56 to Corex and Mb Petroleum branch regulations.Notified Petroleum branch of operations.Pressure tested the new manifold to 21mpa ( Held solid)Stump tested BOPS as followsPipe rams and stabbing valve 1.4 mpa low, 14.0 mpa highBlind rams 1.4 mpa low, 14.0 mpa highAll held 10 min's ea.SICP - 20kpa


Rig in Weatherford to RIH with BIV plug. Removed Frac valve ,Install BOP's. RIH and retrieved BPU plug and hanger100kpa on well head after being shut in for 2.5hrs.

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VIRDENLicense #

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Time Log


12:00 15:00 3.00 904 Tripping Tubing Drift, tally and rih w/ tbg detail from the trailer. Land tbg as follows.KB 4.3mDognut 0.275 - 73mm joints 735.47mNickel coated psn 0.33m2 - 73mm tail joints. 19.51mSaw tooth collar 0.13m

PSN landed @ 739.97mkbTbg intake @759.93mkb


Rig out BOP's and tbg equipment. Install 3k to 3k spacer spool. Land tbg in double bushing dognut.Install 3k adaptor flange to 73mm eue nipple, ratigon, flow t etc.

16:00 17:30 1.50 903 Tripping Rods Suface test and rih w/ pump # CEFV 0814 and rod as follows:Pump 25 200 RSAC 16-1, c/w 1.5" hollow pull tube. 160" stroke. 20 ring plunger33 - 19mm NETB scrapered ( 6 per )62 - 19mm SB ( 6 per )

17:30 18:00 0.50 607 Secure Well & Shut Down for Night

Land rod string over night. Secure well and SDON.Drain pump and lines. Winterize.Well flowed and displaced 6m3 over the day.



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.00 0.00 0.00

Water 0.00 19.00 0.00 44.00

Safety Checks

Time Des Type Com

Logs


Perforations




Tubing RunRun Time

13:00Tubing Description

Tubing - ProductionSet Depth (mKB)

755.63String Max Nominal OD (mm)

73.0Weight/Length (kg/m)

9.673String Grade

J-55






Cement


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UWI



VIRDENLicense #

9680State/Province







Primary Job Type



Contractor


138105Contractor


2146Contractor


56AFE Number





Space out with pump and rod detail. Fill hole, stroke pump to 7mpa ( Held 10 min ). Rig out, clean up and move from location.Operations at Report Time

Space out with rod detailOperations Next Report Period

Move to 4-26-11-26 for pump repair


Sunny.Temperature (°C)


10,000Casing Pressure (kPa)

10,000Rig Time (hr)

3.50

Daily Contacts







Darrell Wild Completions 204-851-5595

Time Log


07:30 08:00 0.50 601 Safety Meeting Held pre job and procedures meeting with all personnel on lease. Talked about tailing rod's. Rigging out. Frost on the roads.

08:00 09:00 1.00 903 Tripping Rods Pooh with ponies and remove rod hanger. Space out with ponies and polish rod. Final rod detail as follows.Suface tested pump.Pump 25 200 RSAC 16-1, c/w 1.5" hollow pull tube. 160" stroke. 20 ring plunger33 - 19mm NETB scrapered ( 6 per )62 - 19mm SB ( 6 per )1 - 19mm x 3.05m SB pony1 - 19mm x 2.44m SB pony1 - 38.1mm x 7.92m VDM polish rod.

09:00 09:30 0.50 609 Pressure Test Seat pump, fill the tbg and stroke the pump to 7mpa. ( Held solid for 10 min ). Left the pump on a light tap. Took 0.5m3 to fill the tbg.

09:30 11:00 1.50 501 Rig Up/Rig Out Rig out rig and equipment. Clean up lease.



0.00 0.00 0.00 0.00

Acid 0.00 0.00 0.00 0.00

Oil 0.00 0.00 0.00 0.00

Water 0.55 0.00 0.00 14.50

Safety Checks

Time Des Type Com

Logs


Perforations



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UWI



VIRDENLicense #

9680State/Province














Cement


j)core

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UWI



VIRDENLicense #

9680State/Province







Primary Job Type

Pump RepairSecondary Job Type

Objective

Contractor

C.D OilwellRig Number

4AFE Number

O14-VIR-07Total AFE + Supp Amount (Cost)




Moved in and rigged up CD Rig #4, POOH pump and rods, sent pump to TSM for teardown inspection.Operations at Report Time

Operations Next Report Period

Run downsized 1.5" pump, rig out


Windy, 50 km hrTemperature (°C)


0Casing Pressure (kPa)

0Rig Time (hr)

4.00

Daily Contacts




Glen Cantelo Wellsite Supervisor 204-748-7767

Time Log


12:30 12:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease

12:45 13:00 0.25 608 SITP / SICP Pressure Read and recorded wellhead pressurersSITP- Slight vacSICP- 70 KPAH2S- 100 PPM

13:00 14:15 1.25 102 MIRU Moved in and rigged up CD Rig #4 to Corex and Mb Petroleum branch regulations. Notified Petroleum branch of operations.

14:15 15:15 1.00 609 Pressure Test Attempted to stroke pump to pressure test, pump not functioning. rigged in pump and lines,pressure tested to 7.0 mpa, held.Hoist on rod string, removed horse head.

15:15 16:15 1.00 903 Tripping Rods Unseated pump at 4000# over string. POOH pump and rods, all appeared in good condition.Sent pummp to TSM Virden for teardown inspection and repair.


Secured wellhead, SDON.



Water 8.00 0.00

Safety Checks

Time Des Type Com

Logs


Perforations






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UWI



VIRDENLicense #

9680State/Province











Cement


j)core

Page 1/2




UWI



VIRDENLicense #

9680State/Province







Primary Job Type

Pump RepairSecondary Job Type

Objective

Contractor

C.D OilwellRig Number

4AFE Number

O14-VIR-07Total AFE + Supp Amount (Cost)




RIH 1.5" pump on original rod string,checked all rods on way in.Rigged out,turned well over to operations.Operations at Report Time

Operations Next Report Period

Job completed


Windy, 60 km hrTemperature (°C)


0Casing Pressure (kPa)

0Rig Time (hr)

4.50

Daily Contacts




Glen Cantelo Wellsite Supervisor 204-748-7767

Time Log


07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease

07:45 08:00 0.25 608 SITP / SICP Pressure Read and recorded wellhead pressurersSITP- Slight vacSICP- TSTMH2S- unable to obtain reading

08:00 09:45 1.75 903 Tripping Rods Surface test and RIH 25-150 RSAC 16-1SN CEFV 79613 Max stroke 160"33-19mm NEXXTB62-19mm Scrapered rods1-22mm x 2.44m pony1-22mm x 1.83m pony1-38.1mm x 7.92m VDMNoted loose rods on way in, stopped at every rod and checked couplings.

09:45 10:45 1.00 609 Pressure Test Filled tubing with 1.2 m3 produced water, very low fluid level.Stroked pump to 7.0 mpa.Force boiler thawed wellhead and flowline,tested pressure switch,functioning properly,cuts out at 2.5 mpa.Installed horse head and hooked up bridle to polished rod,leaving pump on light tag.

10:45 12:00 1.25 501 Rig Up/Rig Out: Rigged out service rig and equipment, cleaned up lease, turned well over to operations.



Water 1.20 0.00

Safety Checks

Time Des Type Com

Logs


Perforations





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VIRDENLicense #

9680State/Province












Cement


O core Daily Completion and Workovereso car

Report ¹ 1.0, Report Date: 7/29/2014Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM

uwt S rises Locaton F aid Name L cense U

102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680State/Pro nce

ManitobatNeti Conrgurat on Type

HonzontalOnenat KB Etevat on (m) KB-7 b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (Ait)(mKB)

12/10/2013 20 00 12/15/2013 12 00Total Depth Ati (TVD)(mKB)

Pnmary Job Type

Pump RepairObiect vs

Secondary Job Type

Contractor

CD OilwellAFE Number

014-VIR-49Total AFE Supp Amount (Cost) Da ty F etd Est Toter (Cost)

25,086.00

Rg Number

4C m F etd Est To Date (Cost)

13,231.00 13,231.00Operat one Summary

Moved in service ng and equipment on soft lease, ngged up on ng matting. Pressure test to 7 0 mpa, held POOH pump and rods, noted moderate wax.Teardown and repair pump at TSM pump shop, pump in good condition, full of wax Sent wax sample to Baker RIH reconditioned pump on anginal rods Rigout,tawed equipment off leaseOperat one at Repen 7'me

Operat one Next Report Penod

Job complete, moved ng to 10-1-11-27 vertical

Daily ReadingstNeather

Overcast

Daily Contacts

Myles Simonar

Glen Cantelo

Sandy Angus

Job C(attest

Temperat re('C) RoadCondton

26

Production Engineer

Wet)site Supervisor

Eng Tech

Tide

403-804-3630

204-748-7767

403-826-1244

Mobrts

Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)0 0 8.00

Time LogSert Time

08 30

08 45

10 45

11 00

12 00

End Time

08 45

10 45

11 00

12 00

13 30

Dur (hr) Cods I

0.25 601

0.25 608

1.00 609

1.50 903

2.00 102

Cods 2

Safety Meeting

M I RU

SITP / SICP Pressure

Pressure Test

Tnpping Rods

Com

Held pre lob safety and procedures meeting with all personal) on lease, discussed ngmove thru high traffic area, crossing ¹1 highway

Wait on Rout)edge tow tractor to assist ng and equipment thru ravines out of VR¹ 2 andonto lease,ngged up to Corex and Mb Petroleum branch regulations. NotifiedPetroleum branch of operations.

Read and record wellhead pressuresSITP-100 kpaSICP-75 KPAH2S 500 ppm

Stroked pump, will not lift fluid, filled tubing with 0 8 m3 produced water, pressuretested against pump to 7.0 mpa, held

Unseated pump, noted moderate wax, POOH pump and rods, stnpped wax form rods.

13 30

14 30

15 30

16 30

14 30

15 30

16 30

17 45

1.00 17

1.00 903

1.00 609

1.25 501

)Naiting Time

Tnpping Rods

Pressure Test

Rig Up/Rig Out:

Took pump into TS&Mpump shop for teardown and repair. all parts were in very goodcondition with no scaling or corrosion, barrel did have soft wax in it. Changed outmandrel, appeared to have been tagged hard.

Flushed tubing with 5.0 m3 produced waterSurface test and RIH 25-150 RSAC 16-1SN CEFV 79613 Max stroke 160"

33-19mm NEXXTB62-19mm Scrapered rodsI-22mm x 2.44m ponyI-22mm x 1.83m pony1-38 1mm x 7 92m VDM

Filled tubing with .8 m3 produced water, stroked pump to 7.0 mpa, held.installed horsehead, spaced out bndle.

Rigged out service ng and equipment, cleaned up lease, turned well over tooperations Tawed equipment off soft lease

Report Fluids SummaryFluid

)Nater

Safety ChecksTime

To well (m')

6.80From well (m')

Type

0.00To tease (m')

14.00

Com

From tasse (m')

7.20

LogsTime Type Top (mxel Btm (mKB) Cesed7

www.peloton.corn Page 1/2 Report Printed: 8/1/2014Page 1/2




UWI102/10-01-011-27W1/00

Surface Location12-06-11-26

Field NameVIRDEN

License #9680

State/ProvinceManitoba

Well Configuration TypeHorizontal

Original KB Elevation (m)473.20

KB-Tubing Head Distance (m) Spud Date12/10/2013 20:00

Rig Release Date12/15/2013 12:00

PBTD (All) (mKB) Total Depth All (TVD) (mKB)


Primary Job TypePump Repair

Secondary Job Type

Objective

ContractorCD Oilwell

Rig Number4

AFE NumberO14-VIR-49

Total AFE + Supp Amount (Cost)25,086.00

Daily Field Est Total (Cost)13,231.00

Cum Field Est To Date (Cost)13,231.00

Operations SummaryMoved in service rig and equipment on soft lease, rigged up on rig matting. Pressure test to 7.0 mpa, held.POOH pump and rods,noted moderate wax.Teardown and repair pump at TSM pump shop, pump in good condition, full of wax. Sent wax sample to Baker . RIH reconditioned pump on original rods.Rig out,towed equipment off lease.Operations at Report Time

Operations Next Report PeriodJob complete, moved rig to 10-1-11-27 verticalDaily ReadingsWeatherOvercast

Temperature (°C)26

Road Condition Tubing Pressure (kPa)0

Casing Pressure (kPa)0

Rig Time (hr)8.00

Daily ContactsJob Contact Title Mobile

Myles Simonar Production Engineer 403-804-3630Glen Cantelo Wellsite Supervisor 204-748-7767Sandy Angus Eng Tech 403-826-1244

Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com

08:30 08:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease, discussed rig move thru high traffic area, crossing #1 highway

08:45 10:45 2.00 102 MIRU Wait on Routledge tow tractor to assist rig and equipment thru ravines out of VR# 2 and onto lease ,rigged up to Corex and Mb Petroleum branch regulations. Notified Petroleum branch of operations.

10:45 11:00 0.25 608 SITP / SICP Pressure Read and record wellhead pressuresSITP-100 kpaSICP-75 KPAH2S 500 ppm

11:00 12:00 1.00 609 Pressure Test Stroked pump, will not lift fluid, filled tubing with 0.8 m3 produced water, pressure tested against pump to 7.0 mpa, held.

12:00 13:30 1.50 903 Tripping Rods Unseated pump, noted moderate wax, POOH pump and rods, stripped wax form rods.

13:30 14:30 1.00 17 Waiting Time Took pump into TS&M pump shop for teardown and repair. all parts were in very good condition with no scaling or corrosion, barrel did have soft wax in it.Changed out mandrel, appeared to have been tagged hard.

14:30 15:30 1.00 903 Tripping Rods Flushed tubing with 5.0 m3 produced waterSurface test and RIH 25-150 RSAC 16-1SN CEFV 79613 Max stroke 160"33-19mm NEXXTB62-19mm Scrapered rods1-22mm x 2.44m pony1-22mm x 1.83m pony1-38.1mm x 7.92m VDM

15:30 16:30 1.00 609 Pressure Test Filled tubing with .8 m3 produced water, stroked pump to 7.0 mpa, held.Installed horse head, spaced out bridle.

16:30 17:45 1.25 501 Rig Up/Rig Out: Rigged out service rig and equipment, cleaned up lease, turned well over to operations.Towed equipment off soft lease.

Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)

Water 6.80 0.00 14.00 7.20

Safety ChecksTime Des Type Com

LogsTime Type Top (mKB) Btm (mKB) Cased?



UWI S rises Locaton F aid Name L cense ¹102/10-01-011-27VV1/00 12-06-11-26 VIRDEN 9680

StatelPro nce

Manitobal¹ell Conrgurat on Type

HonzontalOngnal KB Elevat on (m) KB-T b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (All)(mKB)

12/10/2013 20 00 12/15/2013 12 00Total Depth All (TVD)(mKB)

PerforationsTime Sorts Top (mKB) Btm (mKB) Current SteWs

Stimulations 8, TreatmentsTme

Stg¹

Zone

Stegrr Typtr

Ti'pe

Top (mKS)

Del very Mode

Btm (mKB)

St mr Treat Company

Vol Clean Pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth (mKB) Stnng Max Nom nal OD (mm) We ghtlLength (kglm) Str ng Grade

Tubing PulledP II Tme Tub ng Descnpton Set Depth (mKB) Strng Max Nom net OD (mm) We ghtlLength (kglm) Str ng Grade

Other in Hole Run (Bridge Plugs, etc)Run Time Des OD (mm) Top (mKB) Btm (mKB)

Other in Hole Pulled (Bridge Plugs, etc)Pull Trms Des Top (mKB) Btm (mKB) OD (mm)

CementSert Time Type Stnhg Cement Comp





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680








PerforationsTime Zone Top (mKB) Btm (mKB) Current Status






Other in Hole Pulled (Bridge Plugs, etc)Pull Time Des Top (mKB) Btm (mKB) OD (mm)

CementStart Time Des Type String Cement Comp

Updated February 20, 2013

TODAY'

DATEDD-MMM-YY

Notification

Submitted By:

(21 characters)

Phone

Number

Well

Licence

number

Surface

Location

Bottom Hole

Location

(if Applicable)

Well Operator

Company Name

(60 characters)

Service

Rig Company

(40 characters)Rig

No.

JOB TYPE WORK

DATE

DD-MMM-YY

5/Feb/13

2014/11/12

Joe Smith

Glen Cantelo

204-555-5555

204-748-7767

9999

9680

10-10-10-28

12-06-11-26

11-10-10-28 ACME Oil Co.

10-01-11-27 Co rex Resources

Oilfield Services

CD Oilwell

12 Acid Job

Recompletion

5/Feb/13

12/N ov/14

INSTRUCTIONS:

—FILL IN ALL FIELDS AS SHOWN IN THE EXAMPLE IN RED (Please use 2 digit numbers in the location boxes. For example, if it is a 2, put 02)

—JOB TYPE MUST BE FILLED IN EXACTLYAS CHOICES ON RIGHT

—EMAIL COMPLETED FORM TO: etroleum ov.mb.ca

SUBJECT LINE OF EMAIL, MUST INCLUDE WELL LICENCE, OIL COMPANY, LOCATIONOF JOB AND TYPE OF OPERATION

—To print, please print on legal size paper in landscape

Updated February 20, 2013

TODAY'S Notification Well Bottom Hole Well Operator Service JOB TYPE WORKDATE Submitted By: Phone Licence Surface Location Company Name Rig Company Rig DATE

DD-MMM-YY (21 characters) Number number Location (If Applicable) (60 characters) (40 characters) No. DD-MMM-YY5/Feb/13 Joe Smith 204-555-5555 9999 10-10-10-28 11-10-10-28 ACME Oil Co. Oilfield Services 12 Acid Job 5/Feb/13

2014/11/12 Glen Cantelo 204‐748‐7767 9680 12‐06‐11‐26 10‐01‐11‐27 Corex Resources CD Oilwell 4 Recompletion 12/Nov/14

INSTRUCTIONS:

- FILL IN ALL FIELDS AS SHOWN IN THE EXAMPLE IN RED (Please use 2 digit numbers in the location boxes. For example, if it is a 2, put 02)

- JOB TYPE MUST BE FILLED IN EXACTLY AS CHOICES ON RIGHT

- EMAIL COMPLETED FORM TO: [email protected]

SUBJECT LINE OF EMAIL, MUST INCLUDE WELL LICENCE, OIL COMPANY, LOCATION OF JOB AND TYPE OF OPERATION

‐ To print, please print on legal size paper in landscape


Report¹ 1.0, Report Date: tt/12/2014Well Name: COREXVIRDEN HZNTL 10-Ot-tt-27WPM

uwt S rises Locaton F aid Name L cense ¹102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680

State/Pro nce

Manitobalseg Conrguraton Type

HonzontalOnenal KB Elevat on (m) KB-7 b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (AU)(mKB)

12/10/2013 20 00 12/15/2013 12 00Total Depth AU (TVD)(mKB)

Pnmary Job Type

RecompletionObiect vs

Secondary Job Type

Contractor

C.D OilwellAFE Number

W14-VIR-31

Rg Number

4Total AFE Supp Amount (Cost) Da ly F eld Est Total (Cost) C m F eld Est To Date (Cost)

208,822.00 4,285.00 4,285.00Operat one Summary

MIRU, Pressure tested tubing, removed horse head and unseated pump Flushed waxy rods with 15 0 m3 hot produced waterOperat one at Repen 7'me


POOH and lay out rod stnng, pull, inspect and lay out production tubing. Pickup and RIH scraper on frac stnng, scrape to 860.0 mkb POOH tubing, MU RIH 1mTCP 25gr SDP 20 S PM 60 deg phasing

Daily Readingslseather

Cool, windy

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Time Log

Job C(attest

Temperat re('C) RoadCondton-11

Production Engineer

Eng Tech

INellsite Supervisor

Tide

403-804-3630

403-826-1244

204-748-7767

Mobrls


Sert Time

14 00

14 15

14 30

16 00

17 00

18 00

End Time

14 15

14 30

16 00

17 00

18 00

18 15

Dur (hr)

0.25

0.25

1.50

1.00

1.00

0.25

Cods I

601

608

102

609

801

607

Cods 2

Safety Meeting


M IRU

Pressure Test

Circulate / Reverse Well

Secure INell & ShutDown for Night

Com

Held pre lob safety and procedures meeting, discussed moving thru high traffic area

SITP-650 KPASICP- TSTMH26 - 500 KPA

Moved in and ngged up CD Rig ¹4 and assoaated equipment to Corex and MbPetroleum branch regulations Notified Petroleum branch of operations

Stroked pump to pressure test, would not build pressure, removed horse head Pumpeddown tubing against pump to pressure test to 7.0 mpa, held. Unseated pump, pooh toprod and ponies,re landed pohshed rod

Rigged in Silverhne truck with 15.0 m3 hot produced water, pumped down tubing toflush rods, no returns to ng tank

Secured well, SDON.


INater

Safety ChecksTime

To well (m')

15.00From well (m')

Type

0.00To lease (m')

Com

From tasse (m')

LogsTime Type Top (mkel Btm (mKB) Cesed7

PerforationsTime Zolre Top (mKB) Btm (mKB) Current SteWs

Stimulations &,TreatmentsTme

stg¹

Zone

Stegrr Typtr

TI'pe

Top (mke)

Del very Mode

Btm (mKB)

St m/Treat Company

Vol Clean pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth ImKB) Stnng Max Nom nal OD (mm) We ght/Length (kg/m) Str ng Grade

Tubing PulledP U 1 me Tub ng Descnpton Set Depth (mKB) Strng Max Nom net OD (mm) We ghtrLength (kglm) Str ng Grade





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680








Primary Job TypeRecompletion

Secondary Job Type

Objective

ContractorC.D Oilwell

Rig Number4

AFE NumberW14-VIR-31




Operations SummaryMIRU, Pressure tested tubing, removed horse head and unseated pump.Flushed waxy rods with 15.0 m3 hot produced waterOperations at Report Time

Operations Next Report PeriodPOOH and lay out rod string, pull, inspect and lay out production tubing.Pickup and RIH scraper on frac string, scrape to 860.0 mkb.POOH tubing, MU RIH 1m TCP 25gr SDP 20 SPM 60 deg phasingDaily ReadingsWeatherCool, windy

Temperature (°C)-11



Rig Time (hr)4.00


Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767


14:00 14:15 0.25 601 Safety Meeting Held pre job safety and procedures meeting, discussed moving thru high traffic area14:15 14:30 0.25 608 SITP / SICP Pressure SITP-650 KPA

SICP- TSTMH2S - 500 KPA

14:30 16:00 1.50 102 MIRU Moved in and rigged up CD Rig #4 and associated equipment to Corex and Mb Petroleum branch regulations. Notified Petroleum branch of operations

16:00 17:00 1.00 609 Pressure Test Stroked pump to pressure test, would not build pressure, removed horse head.Pumped down tubing against pump to pressure test to 7.0 mpa, held.Unseated pump, pooh top rod and ponies,re landed polished rod

17:00 18:00 1.00 801 Circulate / Reverse Well Rigged in Silverline truck with 15.0 m3 hot produced water, pumped down tubing to flush rods , no returns to rig tank.


Secured well, SDON.


Water 15.00 0.00










Uwt S rises Locaton F aid Name L cense d

102/10-01-011-27)/g1/00 12-06-11-26 )/IRDEN 9680State/pro nce

ManitobalNell Conf gurat on Type

HonzontalDngnal KB Eleuat on (m) KB-T hng Head D stance (m)



Other in Hole Run (Bridge Plugs, etc)Run Time Des DD (mm) Top (mKB) Btm (mKB)

Other in Hole Pulled (Bridge Plugs, etc)Pull Trms Des Top (mKB) Btm (mKB) DD (mm)

CementSert Time Type Sthhg Cement Comp





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680















ManitobaINeh Conrguraton Type

HonzontalOnenal KB Elevat on (m) KB-T b ng Head D stance (m)



Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



Pulled and laid out rod stnng, installed BOPS, pulled inspected and laid out production tubing MU RIH casing scraper on workstnng to 860.0 mkb Pulledscraper, MU RIH and perforate 835 0 - 836.0 mkb with I m 25 gr SDP 60 deg phasing. POOH tubing and gun, MU RIH scraper on 30 lt kill stnngOperat one at Repen 2'me


Run scraper over new perf interval. RIH set WR bndge plug with tandem recorders at 850 0 mkb.Run and set QDG to pressure test BP, set QDG packer at630 0 mkb

Daily ReadingsINeather

Cool

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Time Log

Job C(attest


Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Moor(a


Sert Time End Time Dur (hr) Cods 1 Cods 2 Com

07 30

07 45

08 00

09 15

10 15

11 45

13 15

07 45

08 00

09 15

10 15

11 45

13 15

14 15

0.25 601

0.25 608

1.25 903

1.00 604

1.50 904

1.50 904

1.00 801

Safety Meeting


Tnpping Rods

BOPS-Install / Remove

Tnpping Tubing

Tnpping Tubing


Held pre lob safety and procedures meeting with all personell on lease, discussedtubing handhng procedures

SITP- TSTMSICP- TSTMH2S 500 ppm

POOH and laid out rod stnng,

Stump tested and installed BOPSPipe rams 1.4m pa low, 14 0 mpa highBhnd rams 1 4 mpa low, 14.0 mpa highAll held 10 mine ea.

Inspected and laid out 73mm production tubing77- Yellow band its

MU RIH 114 3mm casing scraper15-73mm its cw slim eau phngs73-73mm EUE its

INorked scraper to 863 33 mkb

Reverse arculated well with 25.0 m3 hot produced water heated to 65 C, weak returns

14 15

15 15

16 45

17 15

18 30

15 15

16 45

17 15

18 30

19 15

1.00 904

1.50 904

0.50 305

1.25 904

0.75 904

Tnpping Tubing

Tnpping Tubing

Perforate Zone

Tnpping Tubing

Tnpping Tubing

POOH tubing and scraper

MU RIH 86mm ERHSC 25gr SDP 60 DEG phasing on 1m tubing conveyed gun1-60 3mm handhng pup lt 3 18m1-60 3mm x 73mm XO82-73MM eue itsI-73mm pup lt 3.05mI-73mm pup lt 0.62mI -73mm eue itLanded with 0 82 m stickup to position gun over 835.0- 836.0 mkb

Rigged in pump line, filled tubing with2.05 m3 produced water, pressured tubing to 11.7mpa and fired perforating gun

POOH tubing, inspected gun on surface,all shots fired

MU RIH 114.3 mm casing scraper on 30 lt kill stnng


INater

Safety ChecksTime

To well (m')

25.00From well (m')

Type

0.00To lease (m')

25.00

Com

From tasse (m')

0.00





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryPulled and laid out rod string, installed BOPS, pulled inspected and laid out production tubing. MU RIH casing scraper on workstring to 860.0 mkb. Pulled scraper, MU RIH and perforate 835.0 - 836.0 mkb with 1m 25 gr SDP 60 deg phasing.POOH tubing and gun, MU RIH scraper on 30 jt kill string.Operations at Report Time

Operations Next Report PeriodRun scraper over new perf interval. RIH set WR bridge plug with tandem recorders at 850.0 mkb.Run and set QDG to pressure test BP, set QDG packer at 630.0 mkbDaily ReadingsWeatherCool




Rig Time (hr)12.00




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease, discussed tubing handling procedures

07:45 08:00 0.25 608 SITP / SICP Pressure SITP- TSTMSICP- TSTMH2S 500 ppm

08:00 09:15 1.25 903 Tripping Rods POOH and laid out rod string ,09:15 10:15 1.00 604 BOPS-Install / Remove Stump tested and installed BOPS

Pipe rams 1.4mpa low, 14.0 mpa highBlind rams 1.4 mpa low, 14.0 mpa highAll held 10 mins ea.

10:15 11:45 1.50 904 Tripping Tubing Inspected and laid out 73mm production tubing 77- Yellow band jts

11:45 13:15 1.50 904 Tripping Tubing MU RIH 114.3mm casing scraper 15-73mm jts cw slim couplings 73-73mm EUE jtsWorked scraper to 863.33 mkb

13:15 14:15 1.00 801 Circulate / Reverse Well Reverse circulated well with 25.0 m3 hot produced water heated to 65 C, weak returns

14:15 15:15 1.00 904 Tripping Tubing POOH tubing and scraper.15:15 16:45 1.50 904 Tripping Tubing MU RIH 86mm ERHSC 25gr SDP 60 DEG phasing on 1m tubing conveyed gun

1-60.3mm handling pup jt 3.18m1-60.3mm x 73mm XO82-73MM eue jts1-73mm pup jt 3.05m1-73mm pup jt 0.62m1-73mm eue jtLanded with 0.82 m stickup to position gun over 835.0 - 836.0 mkb

16:45 17:15 0.50 305 Perforate Zone Rigged in pump line, filled tubing with2.05 m3 produced water, pressured tubing to 11.7 mpa and fired perforating gun

17:15 18:30 1.25 904 Tripping Tubing POOH tubing, inspected gun on surface ,all shots fired18:30 19:15 0.75 904 Tripping Tubing MU RIH 114.3 mm casing scraper on 30 jt kill string


Water 25.00 0.00 25.00 0.00




uwt S rises Locaton F aid Name L cense ¹102/10-01-011-27VV1/00 12-06-11-26 VIRDEN 9680

StatelPro nce


HonzontalOngnal KB Brevet on (m) KB-7 b ng Head D stance (m)



LogsTime Type Top (mKS) Btm (mKB) Cesed7

PerforationsTime

08 00Sorts

<zonsname>, Onginal HoleTop (mKB)

835.00Btm (mKB) Current SteWs

836.00 Open - Flowing


Stg¹

Zone

Stegrr Typrr

Ti'pe

Top (mKS)

Del very Mode

Btm (mKB)

St mr Treat Company

Vol Clean Pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth (mKB) Stnng Max Nom nal OD (mm) We ghtlLength (kglm) StrngGrade

Tubing PulledP II Tme Tub ng Descnpton

09 00 Tubing - Production


Set Depth (mKB) Stnng Max Nom net DD (mm) i¹eghtlLength (kglm) Stnng Grade

755.63 73.0 9 673 J-55








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680










08:00 <zonename>, Original Hole 835.00 836.00 Open - Flowing




Tubing PulledPull Time

09:00Tubing DescriptionTubing - Production

Set Depth (mKB)755.63

String Max Nominal OD (mm)73.0

Weight/Length (kg/m)9.673

String GradeJ-55




O core Daily Completion and Workovereso cet



102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680StatelPro nce

ManitobalNeh Conrguraton Type

HonzontalOnnnal KB Elevat on (m) KB-7 b ng Head D stance (m)



Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



RIH 114.3mm scraper over new perf interval 835.0 - 836 0 mkb to 860.0 mkb,POOH,run bndge plug to 850.84 mkb. RIH QDG packer and pressure testedagainst BP to 21.0 mpa, bleeds to 16.0 mpa in 5 mine Repositioned packer 3 times and repeated test with same results. Pulled packer above perfs and pressuretested annulus, held. POOH packer, RIH unset bndge plug and reset at 826 0 mkb, above perfs and pressure tested to 14.0 mpa, bleeds to 10.0 mpa in 5

mine. Surfaced BP and sent to Estevan for tear down inspection. Ran 30 it kill stnng.Operat one at Repen 7'me


Run new bndge plug to 850.0 mkb.Run frac packer and PT against plug, reset packer in frac position.

Daily ReadingslNeather

Cool, cloudy

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantata

Time Log

Job C(attest


Production Engineer

Eng Tech

)Net)site Supervisor

Tide

403-804-3630

403-826-1244

204-748-7767

Moot)a


Sert Time

07 30

07 45

08 00

10 00

End Time

07 45

08 00

10 00

10 45

Dur (hr)

0.25

0.25

2.00

0. 75

Cods 1

601

608

904

801

Cods 2

Safety Meeting


Tnpping Tubing


Com

Held pre lob safety and procedures meeting with all personal) on lease. Discussedtubing handhng, bottom 15 its have speaal clearance couphngs to run in 114 hner

6 IT P-T ST M

SICP-TSTMH2S 200 ppm

RIH casing scraper, worked scraper to 860 0 mkb

Reverse arculate with 15 0 m3 produced water, broke arculation after 13.5 m3

10 45

11 45

17 45

19 15

11 45

17 45

19 15

19 45

1.00

6.00

1.50

0.50

904

904

904

904

Tnpping Tubing

Tnpping Tubing

Tnpping Tubing

Tnpping Tubing

POOH tubing and scraper

MU RIH 114 3mm ULBP set at 850.84 mkb to CE,rotate to set, overpull to 35000¹, setstnng weight on packer, repeated and shngshot weight onto packer to confirm set asplug is sitting at 89 degrees. POOH tubing and on/off.MU RIH 114 3 mm QDG packer set packer at 845 78 mkbPT- between packer and BP to 21.0 mpa, bleeds to 16.0 mpa in 5 mineMoved packer to 844 78 mkb and repeated test with same reultsMoved packer to 843 78 mkb, repeated with same resultsMoved packer to 826 77 mkb, pressure tested annulus to 7.0 mpa, held.RIH set packer at 841.3 mkb, pressure tested against bndge plug to 21.0 mpa, bleedsto 16 0 mpa in 15 minePOOH tubing and QDG packer, packer was in new conditionMU RIH overshot, latch onto and release bndge plug, pulled and laid out 3 its, resetbndge plug at 826.0 mkbPressure tested against bndge plug to 14.0 mpa, slow bleed to 10 0 mpa, reset bndgeplug and repeat test with same bleed off

Unset bndge plug, POOH tubing and bndge plug, RIH 30 it kill stnng.

Secured wellhead, wintenzed equipment. SDON


)Nater

Safety ChecksTime

To well (m')

0.00From well (m')

Type

0.00To lease (m')

0.00

Com

From tasse (m')

0.00

LogsTime Type Top (mka) Btm (mKB) Cesed7





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryRIH 114.3mm scraper over new perf interval 835.0 - 836.0 mkb to 860.0 mkb,POOH,run bridge plug to 850.84 mkb. RIH QDG packer and pressure tested against BP to 21.0 mpa, bleeds to 16.0 mpa in 5 mins.Repositioned packer 3 times and repeated test with same results. Pulled packer above perfs and pressure tested annulus , held. POOH packer, RIH unset bridge plug and reset at 826.0 mkb , above perfs and pressure tested to 14.0 mpa, bleeds to 10.0 mpa in 5 mins. Surfaced BP and sent to Estevan for tear down inspection.Ran 30 jt kill string.Operations at Report Time

Operations Next Report PeriodRun new bridge plug to 850.0 mkb.Run frac packer and PT against plug, reset packer in frac position.Daily ReadingsWeatherCool,cloudy




Rig Time (hr)12.00




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease.Discussed tubing handling, bottom 15 jts have special clearance couplings to run in 114 liner

07:45 08:00 0.25 608 SITP / SICP Pressure SITP-TSTMSICP-TSTMH2S 200 ppm

08:00 10:00 2.00 904 Tripping Tubing RIH casing scraper, worked scraper to 860.0 mkb10:00 10:45 0.75 801 Circulate / Reverse Well Reverse circulate with 15.0 m3 produced water, broke circulation after 13.5 m3

10:45 11:45 1.00 904 Tripping Tubing POOH tubing and scraper11:45 17:45 6.00 904 Tripping Tubing MU RIH 114.3mm ULBP set at 850.84 mkb to CE ,rotate to set, overpull to 35000#, set

string weight on packer, repeated and slingshot weight onto packer to confirm set as plug is sitting at 89 degrees.POOH tubing and on/off.MU RIH 114.3 mm QDG packer set packer at 845.78 mkbPT- between packer and BP to 21.0 mpa, bleeds to 16.0 mpa in 5 minsMoved packer to 844.78 mkb and repeated test with same reultsMoved packer to 843.78 mkb, repeated with same resultsMoved packer to 826.77 mkb, pressure tested annulus to 7.0 mpa, held.RIH set packer at 841.3 mkb, pressure tested against bridge plug to 21.0 mpa, bleeds to 16.0 mpa in 15 minsPOOH tubing and QDG packer, packer was in new condition. MU RIH overshot , latch onto and release bridge plug, pulled and laid out 3 jts, reset bridge plug at 826.0 mkbPressure tested against bridge plug to 14.0 mpa, slow bleed to 10 .0 mpa, reset bridge plug and repeat test with same bleed off

17:45 19:15 1.50 904 Tripping Tubing Unset bridge plug, POOH tubing and bridge plug, RIH 30 jt kill string.19:15 19:45 0.50 904 Tripping Tubing Secured wellhead, winterized equipment. SDON


Water 0.00 0.00 0.00 0.00






StatelPro nce


HonzontalOngnal KB Elevat on (m) KB-T b ng Head D stance (m)





Stg¹

Zone

Stegrr Typtr

Ti'pe

Top (mKS)

Del very Mode

Btm (mKB)

St mr Treat Company

Vol Clean Pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth (mKB) Stnng Max Nom nal OD (mm) We ghtlLength (kglm) Str ng Grade

Tubing PulledP II Tme Tub ng Descnpton Set Depth (mKB) Strng Max Nom net OD (mm) We ghtlLength (kglm) Str ng Grade








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680


















uwt S rises Locaton F aid Name L cense S

102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680StatelPro nce

ManitobaIsed Conrguraton Type




Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



MU RIH 114 3 mm ULBP cw pressure recordersSet BP above perfs at 825.45 mkb on 83 its, rotational set, overpulled then set stnng weight on to compression set plug- PT to 14.0 mpa held solidUnset BP, added 3 its to reset bndge plug at 849.00 mkb to CERelease off plug, POOH tubing and on offMU RIH QDG- on 86-73mm its Set packer at 845.48 mkb,pressure test thru tubing against Bp to 21 0 MPA, heldUnset QDG packer, pull 2 its and set at 828.18 PT annulus held 8.0 mpaPT down tbg against perfs, feeding 40 L min at 17.0 mpaStnp off BOPS, Installed frac valve, wintenzed wellheadRig out service ngOperat one at Repen 7'me


Move in Millenium and assoaated equipment for N2 sand frac


Cool, windy

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantata

Time Log

Job C(sttect


Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Moot(a



07 30

07 45

08 00

10 00

12 30

13 30

07 45

08 00

10 00

12 30

13 30

14 45

0.25 601

0.25 608

2.00 904

2.50 904

1.00 604

1.25 501

Safety Meeting


Tnpping Tubing

Tnpping Tubing


Rig Up/Rig Out Testing

Held pre lob safety and procedures meeting with all personal)

SITP-TSTMSICP-TSTMH26 200 PPM

POOH 30 lt kill stnng

MU RIH 114 3 mm ULBP cw pressure recordersSet BP above perfs at 825.45 mkb on 83 its, rotational set, overpulled then set stnngweight on to compression set plug- PT to 14.0 mpa held sohdUnset BP, added 3 its to reset bndge plug at 849.00 mkb to CERelease off plug, POOH tubing and on offMU RIH QDG- on 8673mm its Set packer at 845 48 mkb pressure test thru tubingagainst Bp to 21 0 MPA, heldUnset QDG packer, pull 2 its and set at 828.18 PT annulus held 8.0 mpaPT down tbg against perfs, feeding 40 L min at 17.0 mpa

Landed dognut in 70000¹ compressionStnpped off BOPSINintenzed wellhead with diesel.

Rig out service ng and equipment, Move to 12-24-10-26


INater

Safety ChecksTime

To well (m')

11.50From well (m')

Type

0.00To lease (m')

15.00

Com

From tasse (m')

0.00

LogsTime Type Top (mkal Btm (mKB) Cesed7

PerforationsTime Zorte Top (mKB) Btm (mKB) Current SteWs





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryMU RIH 114.3 mm ULBP cw pressure recordersSet BP above perfs at 825.45 mkb on 83 jts, rotational set, overpulled then set string weight on to compression set plug- PT to 14.0 mpa held solidUnset BP, added 3 jts to reset bridge plug at 849.00 mkb to CERelease off plug, POOH tubing and on offMU RIH QDG- on 86-73mm jts Set packer at 845.48 mkb,pressure test thru tubing against Bp to 21.0 MPA, heldUnset QDG packer, pull 2 jts and set at 828.18 PT annulus held 8.0 mpaPT down tbg against perfs, feeding 40 L min at 17.0 mpaStrip off BOPS, Installed frac valve, winterized wellheadRig out service rigOperations at Report Time

Operations Next Report PeriodMove in Millenium and associated equipment for N2 sand fracDaily ReadingsWeatherCool, windy




Rig Time (hr)6.00




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell07:45 08:00 0.25 608 SITP / SICP Pressure SITP-TSTM

SICP-TSTMH2S 200 PPM

08:00 10:00 2.00 904 Tripping Tubing POOH 30 jt kill string10:00 12:30 2.50 904 Tripping Tubing MU RIH 114.3 mm ULBP cw pressure recorders

Set BP above perfs at 825.45 mkb on 83 jts, rotational set, overpulled then set string weight on to compression set plug- PT to 14.0 mpa held solidUnset BP, added 3 jts to reset bridge plug at 849.00 mkb to CERelease off plug, POOH tubing and on offMU RIH QDG- on 86-73mm jts Set packer at 845.48 mkb,pressure test thru tubing against Bp to 21.0 MPA, heldUnset QDG packer, pull 2 jts and set at 828.18 PT annulus held 8.0 mpaPT down tbg against perfs, feeding 40 L min at 17.0 mpa

12:30 13:30 1.00 604 BOPS-Install / Remove Landed dognut in 10000# compressionStripped off BOPSWinterized wellhead with diesel.

13:30 14:45 1.25 501 Rig Up/Rig Out: Testing Rig out service rig and equipment, Move to 12-24-10-26


Water 11.50 0.00 15.00 0.00






uwt S rises Locaton F aid Name L cense ¹102/10-01-011-27VV1/00 12-06-11-26 V)RDEN 9680

State/Pro nce

Manitobal¹er Conf gurat on Type

HonzontalCngnal KB Elevat on (m) KB-T b ng Head D stance (m)


12/10/2013 20 00 12/15/2013 12 00Total Depth Ar (TVD)(mKB)


Stg¹

Zone

Stegrr Typrr

TI'pe

Top (mke)

Del very Mode

Btm (mKB)

St m/Treat Company

Vol Clean Pump (m')

Tubing RunR ~ t'me Tub ng Descnpton

11 00 Tubing - Vyorkstnng


Set Depth (mKB)

Set Depth (mKB)

Stnng Max Nom net DD (mm) I¹eghtlLength (kg/m) Stnng Grade

828.79 73.0 9673 J-55

Strng Max Nom net DD (mm) We ghtrLength (kglm) Str ng Grade


09 00 Bndge Plug - Temporary 1 14.3 848.66 849.84

Other in Hole Pulled (Bridge Plugs, etc)Pull Time Des Top (mKB) Btm (mKB) DD (mm)






UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680










Tubing RunRun Time

11:00Tubing DescriptionTubing - Workstring




String GradeJ-55



09:00 Bridge Plug - Temporary 114.3 848.66 849.84







ManitobaINed Conrguraton Type




Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



Moved in Millenium frac unit and assosated services, held pre lob safety meetingSpotted asd at 18.0 mpa soaked for 5 mine, Achieved breakdown at 20.8 mpaPumped pad at avg 15.8 mpa 0.51 m3 /minStarted pumping N2 and sandPlaced 4.0 t sand in formation when well sanded off to max pressure 34.9 mpa. shut in 5 mine, attempted to bump with no success. Approx 1.6 t sand in tubing.Max concentration at perfs 500 KG/M3Flushed surface Uncs, shut in. Rigged out MilleniumMoved in and ngged up CD Rig ¹ 4Operat one at Repen 7'me


Rig up with Mission shps to remove dognut, install BOPS, install JUH, pressure annulus to 7 0 mpa unset packer and reverse srculate POOH packer, RIHovershot and srculate onto bndge plug


Cloudy, windy

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Time Log

Job C(sttect

Temperat re('C) RoadCondton

9

Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Mobrls

Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)0 0 8. 50

Sert Time

07 30

07 45

09 45

12 45

13 45

End Time

07 45

09 45

12 45

13 45

15 45

Dur (hr)

0.25

2.00

3.00

1.00

2.00

Cods 1

601

401

404

401

102

Cods 2

Safety Meeting

Rig Up/Rig Out:Stimulation

Fracture: Stimulation

Rig Up/Rig Out:Stimulation

M IRU

Com

Held pre lob safety and procedures meeting with all persons)I on lease

Rig in IES tubing isolation toolMoved in and ngged in Millenium frac unit and support equipment.lNait on pressureU Ill h

Spotted asd at 18.0 mpa soaked for 5 mine, Achieved breakdown at 20 8 mpaPumped pa at avg 15.8 mpa 51 m3 /minStarted pumping N2 and sandPlaced 4.0 t sand in formation when well sanded off to max pressure 34.9 mpa shut in

5 mine, attempted to bump with no success Approx 1.6 t sand in tubing. Maxconcentration at perfs 500 KG/M3Flushed surface Uncs, shut in. Rigged out Millenium

Rig out Millenium and other services, emptied flow back tank and sent water to K)IN),

Move in and ng up CD Oilwell Rig ¹4 and assosated equipment to Corex and MbPetroleum branch regulations. Notified Petroleum branch of operations Stump testedBORS.


Free Fluid

INater

Safety ChecksTime

To well (m')

15.10From well (m')

Type

0.00To lease (m')

30.00

Com

From tasse (m')

14.90


PerforationsTime Torte Top (mKB) Btm (mKB) Current SteWs

Stimulations 8, TreatmentsTme Zone

15 43 INhitewater, Onginal HoleTi'pe

Sand FracDelves Mode

TubingSt mr Treat Company

Millenium





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryMoved in Millenium frac unit and associated services, held pre job safety meeting.Spotted acid at 18.0 mpa soaked for 5 mins, Achieved breakdown at 20.8 mpaPumped pad at avg 15.8 mpa 0.51 m3 /minStarted pumping N2 and sand Placed 4.0 t sand in formation when well sanded off to max pressure 34.9 mpa. shut in 5 mins, attempted to bump with no success. Approx 1.6 t sand in tubing. Max concentration at perfs 500 KG/M3Flushed surface lines, shut in.Rigged out MilleniumMoved in and rigged up CD.Rig # 4Operations at Report Time

Operations Next Report PeriodRig up with Mission slips to remove dognut , install BOPS , install JUH , pressure annulus to 7.0 mpa unset packer and reverse circulate.POOH packer, RIH overshot and circulate onto bridge plug.Daily ReadingsWeatherCloudy , windy

Temperature (°C)-9



Rig Time (hr)8.50




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell on lease07:45 09:45 2.00 401 Rig Up/Rig Out:

StimulationRig in IES tubing isolation toolMoved in and rigged in Millenium frac unit and support equipment.Wait on pressure unit.

09:45 12:45 3.00 404 Fracture: Stimulation Spotted acid at 18.0 mpa soaked for 5 mins, Achieved breakdown at 20.8 mpaPumped pa at avg 15.8 mpa .51 m3 /minStarted pumping N2 and sand Placed 4.0 t sand in formation when well sanded off to max pressure 34.9 mpa. shut in 5 mins, attempted to bump with no success. Approx 1.6 t sand in tubing. Max concentration at perfs 500 KG/M3Flushed surface lines, shut in.Rigged out Millenium


Rig out Millenium and other services, emptied flow back tank and sent water to KIWI,

13:45 15:45 2.00 102 MIRU Move in and rig up CD Oilwell Rig #4 and associated equipment to Corex and Mb Petroleum branch regulations. Notified Petroleum branch of operations.Stump tested BOPS.


Frac Fluid 15.10 0.00Water 30.00 14.90




Stimulations & TreatmentsTime

15:43ZoneWhitewater, Original Hole

TypeSand Frac

Delivery ModeTubing

Stim/Treat CompanyMillenium

O core Daily Completion and Workoversso car



State/Pro nce

Manitobal¹ell Conf gurat on Type

HonzontalOngnal KB Eleuat on (m) KB-T b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (Ag) (mKB)


Stg¹ Stegrr Typtr Top (mKS) Btm (mKB) Vol Clean Pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth (mKB) Stnng Max Nom nal OD (mm) We ght/Length (kg/m) Str ng Grade

Tubing PulledP II Tme Tub ng Descnpton Set Depth (mKB) Strng Max Nom net OD (mm) We ghtrLength (kg/m) Str ng Grade








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680


















ManitobalNeh Conrguraton Type




Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



Bled down well pressures, stump tested and installed BOPS Pulled tubing and QDH frac packer, RIH overshot, srculated sand out of casing from 652 0 mkb toULBP at 848 0 mkb Circulated onto bndge plug, cleaned up sand, Recovered approx. 2.0 m3 sand. Unset and POOH tubing and bndge plug. RIH 30 it kill

stnng.SDONOperat one at Repen 7'me


RIH 60.3mm tubing and 73mm frac stnng to clean out to TD.Circulate wellbore clean. POOH,)ay out 73mm frac stnng,pull and lay down 60.3mm work stnng RIH73mm production tubing

Daily Readingslseather

Cloudy

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Time Log

Job C(sttect


Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Mobrls

Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)14,000 0 11.00

Sert Time

07 30

07 45

08 00

09 00

10 00

13 00

14 30

17 00

18 15

End Time

07 45

08 00

09 00

10 00

13 00

14 30

17 00

18 15

19 00

Dur (hr)

0.25

0.25

1.00

1.00

3.00

1.50

2. 50

1.25

0. 75

Cods 1

601

608

604

904

801

904

904

904

904

Cods 2

Safety Meeting



Tnpping Tubing


Tnpping Tubing

Tnpping Tubing

Tnpping Tubing

Tnpping Tubing

Com

Held pre lob safety and procedures meeting, discussed shut in procedures

SITP 14.0 MPASICP-TSTMH2S- 500 ppm

Stump tested and installed BOPS

Bled down tubing pressure to flow back tank, flowed back N2 gas head then approx150 L water and foam. Tubing bled to zero. Bled off casing, no pressure or flow. Boileron wellhead to ensure no hnes were frozen.Unset QDH Packer

Reverse arculate to attempt to clean sand from tubing, pumping 40 L min at 7000 kpa,approx 200 L returns then lost arc.

Installed JUH and pulled tubing and QDH packer while maintaining full casing. Tubingpulled dry

RIH over shot, tagged sand at 652.0 mkb, ng in srculating equipment JUH, reversesrculated sand to bndge plug, latched onto bndge plug, reverse arculated 30 mine untilreturns were clean.Recovered approx 2.0 m3 sand

POOH 83-73mm EUE its and ULBP, laid out 15-73mm with shm couphngs

RIH 30)t kill stnng, SDON.


Free Fluid

INater

Safety ChecksTime

To well (m')

0 00

35.00

From well (m')

Type

0.00

28.00

To lease (m')

0.00

35.00

Com

From tasse (m')

0.00

0.00

LogsTime Type Top (mksl Btm (mKB) Cesed7

PerforationsTime Torte Top (mKB) Btm (mKB) Current SteWs

Stimulations 8, TreatmentsTme Zone Ti'pe Der very Mode St m/Treat Company





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations Summary Bled down well pressures, stump tested and installed BOPS.Pulled tubing and QDH frac packer , RIH overshot, circulated sand out of casing from 652.0 mkb to ULBP at 848.0 mkb. Circulated onto bridge plug, cleaned up sand,Recovered approx. 2.0 m3 sand. Unset and POOH tubing and bridge plug. RIH 30 jt kill string.SDONOperations at Report Time

Operations Next Report PeriodRIH 60.3mm tubing and 73mm frac string to clean out to TD.Circulate wellbore clean.POOH ,lay out 73mm frac string,pull and lay down 60.3mm work string.RIH 73mm production tubing.Daily ReadingsWeatherCloudy


Road Condition Tubing Pressure (kPa)14,000


Rig Time (hr)11.00




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting, discussed shut in procedures07:45 08:00 0.25 608 SITP / SICP Pressure SITP 14.0 MPA

SICP-TSTMH2S- 500 ppm

08:00 09:00 1.00 604 BOPS-Install / Remove Stump tested and installed BOPS09:00 10:00 1.00 904 Tripping Tubing Bled down tubing pressure to flow back tank, flowed back N2 gas head then approx

150 L water and foam.Tubing bled to zero.Bled off casing, no pressure or flow. Boiler on wellhead to ensure no lines were frozen.Unset QDH Packer

10:00 13:00 3.00 801 Circulate / Reverse Well Reverse circulate to attempt to clean sand from tubing, pumping 40 L min at 7000 kpa, approx 200 L returns then lost circ.

13:00 14:30 1.50 904 Tripping Tubing Installed JUH and pulled tubing and QDH packer while maintaining full casing. Tubing pulled dry.

14:30 17:00 2.50 904 Tripping Tubing RIH over shot, tagged sand at 652.0 mkb, rig in circulating equipment JUH , reverse circulated sand to bridge plug,latched onto bridge plug, reverse circulated 30 mins until returns were clean.Recovered approx 2.0 m3 sand

17:00 18:15 1.25 904 Tripping Tubing POOH 83-73mm EUE jts and ULBP, laid out 15-73mm with slim couplings18:15 19:00 0.75 904 Tripping Tubing RIH 30 jt kill string, SDON.


Frac Fluid 0.00 0.00 0.00 0.00Water 35.00 28.00 35.00 0.00








State/Pro nce

Manitobal¹ell Conf gurat on Type

HonzontalOngnal KB Eleuat on (m) KB-T b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (Ag) (mKB)


Stg¹ Stegrr Typtr Top (mKS) Btm (mKB) Vol Clean Pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth (mKB) Stnng Max Nom nal OD (mm) We ght/Length (kg/m) Str ng Grade

Tubing PulledP II Tme Tub ng Descnpton Set Depth (mKB) Strng Max Nom net OD (mm) We ghtrLength (kg/m) Str ng Grade








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680
















uwt S rises Locaton F aid Name L cense ¹102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680

StatelPro nce

ManitobaiNeti Conrgurat on Type

HonzontalOnenat KB Etevat on (m) KB-7 b ng Head D stance (m)

473.20Sp d Date R g Release Date PBTD (Ait)(mKB)

12/10/2013 20 00 12/15/2013 12 00Total Depth Ati (TVD)(mKB)

Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number

4Total AFE Supp Amount (Cost) Da ty F etd Est Tote) (Cost) C m F etd Est To Date (Cost)


POOH and laid out kill stnng to be able to arculate down with sing)sits, changed tubing handhng euipment to 2 3/8, Tally, dnft and RIH 75-2 3/8 its off Rout)edgetrailer. Change handling equipment to 2 7/8, RIH tubing, tagged sand at 981 0 mkb Rigged in JUH and kelly hose and began arculating sand out of hnerCirculated singles to tag TD at 1427 10 mkb by tally, there were several breaks but mostly arculated singles all the way to TD.Reverse arculated at TD for 30 mineOperat one at Repen 7'me


Pull and lay out 60.3mm tubing, run production tubing and rods

Daily ReadingsiNeather

Clear

Daily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Time Log

Job C(attest


Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Mobrts



07 30

07 45

08 00

16 00

17 45

07 45

08 00

16 00

17 45

18 00

0.25 601

0.25 608

8.00 904

1.75 904

0.25 607

Safety Meeting


Tnpping Tubing

Tnpping Tubing

Secure Well & ShutDown for Night

Held pre lob safety and procedures meeting with all personal), discussed laying downand picking up tubing handhng procedures

SITP- TSTMSICP- TSTMH2S - 500 ppm

POOH and laid out kill stnng to be able to arculate down with single its, changed tubinghandhng euipment to 2 3/8, Tally, dnft and RIH 75-2 3/8 its off Rout)edge trailer. Changehandhng equipment to 2 7/8, RIH tubing, tagged sand at 981 0 mkb Rigged in JUH andkelly hose and began orculating sand out of hnerCirculated singles to tag TD at 1427.10 mkb by tally, there were several breaks butmostly orculated singles all the way to TD.Reverse arculated at TD for 30 mine

POOH and lay out 73mm free stnng on Rout)edge trailer

Lost 31.7 m3 fluid while orculating, approximately 3 5 m3 sand in returns.


Free Fluid

INater

Safety ChecksTime

To well (m')

0 00

49.00

From well (m')

Type

0.00

18.00

To tease (m')

0.00

15.00

Com

From tasse (m')

0.00

18.00



Stimulations &,TreatmentsTme

stg¹

Zone

Stegrr Typtr

Ti'pe

Top (mke)

De)very Mode

Btm (mKB)

St mr Treat Company

Vot Clean pump (m')

Tubing RunR n Tme Tub ng Descnpton Set Depth ImKBI Stnng Max Nom nat OD (mm) We ghtlLength (kglm) Str ng Grade





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryPOOH and laid out kill string to be able to circulate down with single jts, changed tubing handling euipment to 2 3/8, Tally, drift and RIH 75-2 3/8 jts off Routledge trailer.Change handling equipment to 2 7/8, RIH tubing, tagged sand at 981.0 mkb. Rigged in JUH and kelly hose and began circulating sand out of linerCirculated singles to tag TD at 1427.10 mkb by tally, there were several breaks but mostly circulated singles all the way to TD.Reverse circulated at TD for 30 mins.Operations at Report Time

Operations Next Report PeriodPull and lay out 60.3mm tubing, run production tubing and rods.Daily ReadingsWeatherClear

Temperature (°C)-2



Rig Time (hr)10.50




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting with all personell, discussed laying down and picking up tubing handling procedures

07:45 08:00 0.25 608 SITP / SICP Pressure SITP- TSTMSICP- TSTMH2S - 500 ppm

08:00 16:00 8.00 904 Tripping Tubing POOH and laid out kill string to be able to circulate down with single jts, changed tubing handling euipment to 2 3/8, Tally, drift and RIH 75-2 3/8 jts off Routledge trailer.Change handling equipment to 2 7/8, RIH tubing, tagged sand at 981.0 mkb. Rigged in JUH and kelly hose and began circulating sand out of linerCirculated singles to tag TD at 1427.10 mkb by tally, there were several breaks but mostly circulated singles all the way to TD.Reverse circulated at TD for 30 mins.

16:00 17:45 1.75 904 Tripping Tubing POOH and lay out 73mm frac string on Routledge trailer17:45 18:00 0.25 607 Secure Well & Shut

Down for NightLost 31.7 m3 fluid while circulating, approximately 3.5 m3 sand in returns.


Frac Fluid 0.00 0.00 0.00 0.00Water 49.00 18.00 15.00 18.00









uwt S rises Locaton F aid Name L cense d

102/10-01-011-27)/g1/00 12-06-11-26 )/)RDEN 9680State/Pro nce

ManitobaINell Conf gurat on Type

HonzontalDngnal KB Eleuat on (m) KB-T hng Head D stance (m)



Tubing PulledP II Tme Tuhng Descnpton Set Depth (mKB) Stnng Max Nom net DD (mm) INeghtlLength (kg/m) Stnng Grade

08 00 Tubing - I/gorkstnng 828.79 73.0 9673 J-55








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680








Tubing PulledPull Time

08:00Tubing DescriptionTubing - Workstring




String GradeJ-55








Manitobalaed Conrguraton Type

HonzontalOnanal KB Elevat on (m) KB-7 b ng Head D stance (m)



Pnmary Job Type


Secondary Job Type

Contractor


W14-VIR-31

Rg Number



Cleaned ice off dernck and trailers. POOH and laid out 60 3mm tubing, changed tubing handling equipment to 73mm, PU and RIH 75-73mm EUE its,stnppedoff BOPS,NU wellhead, surface test reconditioned 25-150 RSAC 16-3 BHP on anginal rods Picked up and ran in rod stnng off ground.Operat one at Repen 7'me


Turned well over to operations.Job complete

Daily Readingslaeather

FoggyDaily Contacts

Myles Simonar

SandyAngus

Glen Cantelo

Job C(attest


Production Engineer

Eng Tech


Tide

403-804-3630

403-826-1244

204-748-7767

Moot)a

Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)0 0 9. 50

Time LogSert Time End Time Dur (hr) Cods 1 Cods 2 Com

07 30

07 45

08 00

09 00

10 30

12 00

13 00

14 30

07 45

08 00

09 00

10 30

12 00

13 00

14 30

15 30

0.25 601

0.25 608

1.00 17

1.50 904

1.50 904

1.00 604

1.50 903

1.00 609

Safety Meeting


INaiting Time

Tnpping Tubing

Tnpping Tubing


Tnpping Rods

Pressure Test

Held pre lob safety and procedures meeting, discussed working in icy conditionsfollowing freezing rain on weekend. Cleaned ice and snow from trailer decks

SITP-TSTMSICP-TSTMH2S- 500 ppm

Stnpped ice off dernck and Uncs

POOH and laid out 75-60 3mm its EUE tubing on Rout)edge trailer. Changed handhngequipment over to 73mm

MU RIH 73mm production tubing,anginalI-dognut 0.20m75-73mm EUE its 735 68mI-73mm ENC PSN 0.33mI-73mm tail it cw bar collar 9.89mKB-DN 4. 30mLanded depth 750.40 mkb

Stnpped off BOPS, landed tubing in dognut, nippled up pumping wellhead.Flushed tubing with 4.0 m3 produced water

Surface tested and RIH 25-150 RSAC 16-1 ¹ CEFV 79613RIH on anginal rods33-19mm NEXXTB62-19mm scraperedI-22mm x 3.05m ponyI-22mm x 2.44m pony1-38 1mm x 7 92m VDM

Filled tubing with produced water, stroked pump to 7.0 mpa, held. Installed horse head.

15 30 16 45 1.25 501 Rig Up/Rig Out: Testing Rigged out service ng and equipment Cleaned up lease, turned well over to operations.


Free Fluid

INater

Safety ChecksTime

To well (m')

0 00

0.00

From well (m')

Type

0.00

0.00

To lease (m')

0.00

0.00

Com

From tasse (m')

0.00

0.00

LogsTime Type Top (mxa) Btm (mKB) Cesed7





UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680









Secondary Job Type

Objective


Rig Number4





Operations SummaryCleaned ice off derrick and trailers. POOH and laid out 60.3mm tubing, changed tubing handling equipment to 73mm , PU and RIH 75-73mm EUE jts,stripped off BOPS,NU wellhead, surface test reconditioned 25-150 RSAC 16-3 BHP on original rods. Picked up and ran in rod string off ground.Operations at Report Time

Operations Next Report PeriodTurned well over to operations.Job completeDaily ReadingsWeatherFoggy




Rig Time (hr)9.50




07:30 07:45 0.25 601 Safety Meeting Held pre job safety and procedures meeting, discussed working in icy conditions following freezing rain on weekend.Cleaned ice and snow from trailer decks

07:45 08:00 0.25 608 SITP / SICP Pressure SITP-TSTMSICP-TSTMH2S- 500 ppm

08:00 09:00 1.00 17 Waiting Time Stripped ice off derrick and lines09:00 10:30 1.50 904 Tripping Tubing POOH and laid out 75-60.3mm jts EUE tubing on Routledge trailer. Changed handling

equipment over to 73mm10:30 12:00 1.50 904 Tripping Tubing MU RIH 73mm production tubing,original

1-dognut 0.20m75-73mm EUE jts 735.68m1-73mm ENC PSN 0.33m1-73mm tail jt cw bar collar 9.89mKB-DN 4.30mLanded depth 750.40 mkb

12:00 13:00 1.00 604 BOPS-Install / Remove Stripped off BOPS, landed tubing in dognut , nippled up pumping wellhead.Flushed tubing with 4.0 m3 produced water.

13:00 14:30 1.50 903 Tripping Rods Surface tested and RIH 25-150 RSAC 16-1 # CEFV 79613RIH on original rods33-19mm NEXXTB62-19mm scrapered 1-22mm x 3.05m pony1-22mm x 2.44m pony1-38.1mm x 7.92m VDM

14:30 15:30 1.00 609 Pressure Test Filled tubing with produced water, stroked pump to 7.0 mpa, held. Installed horse head.

15:30 16:45 1.25 501 Rig Up/Rig Out: Testing Rigged out service rig and equipment.Cleaned up lease, turned well over to operations.


Frac Fluid 0.00 0.00 0.00 0.00Water 0.00 0.00 0.00 0.00



O core Daily Completion and Workoveraso car


uwt S rises Locaton F aid Name L cense ¹102/10-01-011-27VV1/00 12-06-11-26 VIRDEN 9680

StatelPro nce


HonzontalCngnal KB Brevet on (m) KB-T b ng Head D stance (m)





Stg¹

Zone

Stegrr Typtr

Ti'pe

Top (mKS)

Del very Mode

Btm (mKB)

St mr Treat Company

Vol Clean Pump (m')

Tubing RunR ~ t'me Tub ng Descnpton

10 30 Tubing - Production


Set Depth (mKB)

Set Depth (mKB)

Stnng Max Nom net DD (mm) i¹eghtlLength (kglm) Stnng Grade

750.40 73.0 9673 J-55

Strng Max Nom net DD (mm) We ghtlLength (kglm) Str ng Grade








UWI102/10-01-011-27W1/00


Field NameVIRDEN

License #9680











Tubing RunRun Time

10:30Tubing DescriptionTubing - Production




String GradeJ-55





Corex Virden HZNTL 102.10-01-011-27 WPM

December, 2013 Geological Report

SURFACE LOCATION: 12C-06-11-26 WPM LICENCE NUMBER: 9680 U.W.I. 102/10-01-011-27W1/00

Prepared for: Bob McAuley Prepared by: Joe Steranko, Rich Kulach


RESERVOIR DOGS GEOLOGICAL 1

TABLE OF CONTENTS

GENERAL WELL DATA ......................................................................................... 2

OPERATIONS ........................................................................................................... 3

GEOLOGICAL MARKERS ..................................................................................... 4

DAILY MUD PROPERTIES .................................................................................... 5

BIT RECORD ............................................................................................................ 5

DAILY DRILLING SUMMARY.............................................................................. 5

DIRECTIONAL ......................................................................................................... 6

SURVEYS ................................................................................................................. 6

SAMPLE DESCRIPTIONS .....................................................................................10

WELL SUMMARY .................................................................................................21

GEOLOGY ..............................................................................................................21

STRUCTURE PROFILE .........................................................................................23

RESERVOIR INTERVALS ....................................................................................24

RESERVOIR EVALUATION ................................................................................27

STRIP LOGS IN BACK POCKET



GENERAL WELL DATA OPERATOR: Corex Resources Ltd. WELL NAME: Corex Virden HZNTL 102.10-01-011-27 WPM WELL LOCATION: 12C-06-11-26 WPM CO-ORDINATES: 467.94 m South of North Boundary of Section 6

194.45 m East of West Boundary of Section 6 ELEVATIONS: Ground: 468.90 m Kelly Bushing: 473.20 m LICENSE NUMBER: 9680 UWI: 102/10-01-011-27W1/00 PRIMARY OBJECTIVE: Whitewater Oil Production CONTRACTOR: Precision Drilling, Rig #205; Tool Push: Clint Newby SPUD DATE: 13-12-10-2000 hrs KICK-OFF POINT: 344.0 m MD TOTAL DEPTH: 1441.0 m MD Date and Time: 13-12-14-2030 hrs HOLE SIZE: Surface: 349 mm; Intermediate: 222 mm; Lateral: 200 mm SURFACE CASING: Ran 13 joints of 244.5 mm, 48.07 kg/m, H-40, Conestoga casing with

guide shoe & float collar. Casing landed @ 146.5 m MD. Plug down: 13-12-11-0652 hrs. Drilled out: 13-12-11-1945 hrs.

SAMPLES: One set of five meter samples from 550 m to 845 m and ten meter

samples from 850 m to 1441 m for Corex Resources Ltd. One set of five meter samples from 550 m to 845 m and ten meter samples from 850 m to 1441 m for Manitoba Innovation, Energy, and Mines.



OPERATIONS DATE TIME OPERATION

13-12-10 2000 Spud well.

13-12-10 2245 Reach surface casing point at 146.5 m.

13-12-11 0652 Plug down on 244.5 mm surface casing.

13-12-11 1945 Drilled out surface casing plug, start drilling 222 mm vertical section with Cathedral Directional Energy Service Ltd. Mud motor set at 2.38°.

13-12-11 2400 Reach 344.0 m MD and begin build section. 13-12-12 0245 Mud up ~ 425 m MD. 13-12-12 0630 Reach sample point at 550 m MD. 13-12-13 0015 Reach Lateral Heel at 842.0 m MD. 13-12-13 0035 Reach 847.5 m MD and prepare to pull out of hole to pick up 200 mm bit and

motor. Circulate hole and condition mud. 13-12-13 0130 Start tripping out of hole to change mud motor and bit. 13-12-13 1045 Back on bottom drilling 200 mm lateral section. Mud motor set at 1.83°. 13-12-14 2030 Reach total depth at 1441.0 m MD. Drilling Supervisor: Adam Russell



GEOLOGICAL MARKERS

GROUND ELEVATION: 468.90 m K. B. ELEVATION: 473.20 m

Formation Measured

Depth (m)

True Vertical Depth

(m)

Subsea (m)

Isopach (m)

Kick Off Point 344.0 344.0 +129.2 -

Upper Amaranth Anhydrite 658.6 605.5 -132.3 29.9 Lower Amaranth (Spearfish) 733.5 635.4 -162.2 7.4

Flossie Lake 755.9 642.8 -169.6 9.0 Whitewater Lake 794.6 651.8 -178.6 -

Lateral Heel 842.0 656.0 -182.8 -

Extrapolated Total Depth 1441.0 656.0 -182.8 -



DAILY MUD PROPERTIES

DATE TIME

DEPTH (m)

DENSITY VISCOSITY WATER LOSS

pH CHLOR. CALC.

13-12-11-0645 146.5 1000 28 - 7.5 280 130 13-12-12-0815 578 1085 44 10.9 9.0 1250 120 13-12-13-1045 849 1110 45 9.4 8.0 1800 620 13-12-14-0930 1241 1120 42 9.4 9.0 2200 680

Note: Mud up at approximately 425 m MD, 13-12-12-0245 hrs.

BIT RECORD

BIT #

MAKE TYPE SIZE (mm)

DEPTH IN (m)

DEPTH OUT (m)

METERS DRILLED

ROTATING HOURS

AVERAGE ROP

(m/hr) 1A Smith Button 349 0 146.5 146.5 2.75 53.3

2 Security FX54R 222 146.5 847 700.5 22.50 31.1 3 Ulterra U413S 200 847 1441 594 23.25 25.5

DAILY DRILLING SUMMARY

Date Depth @ 2400 hrs

(m)

Daily Progress

(m)

Rotating Hours

Rate (m/hr)

Drilling Activity

13-12-10 146.5 146.5 2.75 53.3 Condition mud & circulate

prior to POOH. 13-12-11 343 196.5 2.75 71.5 Drilling 222 mm vertical

section. 13-12-12 847 504 19.75 25.5 Circulating prior to pulling

out of hole. 13-12-13 1069 222 9.50 23.4 Drilling 200 mm lateral

section. 13-12-14 1441 372 13.75 27.1 Total Depth @ 2030 hrs.

TOTAL ROTATING HOURS: 48.50 hrs



DIRECTIONAL

Directional Company: Cathedral Energy Services Ltd. Directional Hands: Day: Cory Paul Night: Colin Masko

MWD Operators: Day: Scott Masko Night: Kevin Bewcyk Motors: Vertical / Build 2.38° Lateral 1.83°

SURVEYS Job Number: 133494 Province / Country: Manitoba / Canada Company: Corex Resources Ltd. Declination: 6.48° Lease / Well: Corex Virden (10C-01) Grid: -1.55° Location: 12C-06-11-26 WPM File name: C:\133494.SVY Rig Name: Precision Drilling #205 Date/Time: 13-12-14-2030 hrs RKB: 473.20 m Curve Name: Corex Virden HZNTL (10C-01) G.L. or M.S.L.: 468.90 m

WINSERVE SURVEY CALCULATIONS Minimum Curvature Method

Vertical Section Plane: 267.40° Vertical Section Referenced to offset from Wellhead: EW =.00 Meters, NS=.00 Meters

Rectangular Coordinates Referenced to Wellhead

Measured Inclination Drift True Subsea North/ East/ Vertical Dogleg Depth Angle Direction Vertical TVD South West Section Severity Meters Degrees Degrees Depth Meters Meters Meters Meters Degrees/30

0.00 0.00 0.00 0.00 473.20 0.00 0.00 0.00 0.00 Surface Casing

146.50 0.00 0.00 146.50 326.70 0.00 0.00 0.00 0.00 185.50 1.00 6.90 185.50 287.70 0.34 0.04 -0.06 0.76 289.40 0.40 42.40 289.39 183.81 1.51 0.39 -0.46 0.21 328.70 0.50 46.50 328.69 144.51 1.73 0.61 -0.69 0.08 341.60 0.50 328.40 341.59 131.61 1.82 0.62 -0.70 1.47

Kick Off Point 344.00 0.92 296.82 343.99 129.21 1.83 0.60 -0.68 7.02 354.50 3.30 276.50 354.48 118.72 1.91 0.22 -0.31 7.02 367.50 6.60 268.80 367.43 105.77 1.93 -0.89 0.81 7.75 380.70 9.00 268.60 380.51 92.69 1.89 -2.69 2.60 5.45 393.70 11.10 262.40 393.31 79.89 1.70 -4.94 4.86 5.44 406.30 13.90 259.10 405.61 67.59 1.25 -7.63 7.57 6.88 419.40 15.90 257.00 418.27 54.93 0.55 -10.93 10.89 4.74 432.70 17.60 257.70 431.00 42.20 -0.28 -14.67 14.66 3.86




445.90 19.50 259.70 443.52 29.68 -1.10 -18.78 18.81 4.55 458.80 21.70 261.20 455.59 17.61 -1.85 -23.26 23.32 5.26 471.80 24.40 261.50 467.55 5.65 -2.62 -28.29 28.38 6.24 484.70 25.90 261.30 479.23 -6.03 -3.44 -33.71 33.83 3.49 497.80 27.40 261.80 490.94 -17.74 -4.30 -39.52 39.68 3.47 510.90 29.30 259.90 502.46 -29.26 -5.29 -45.66 45.86 4.82 524.00 32.60 259.00 513.70 -40.50 -6.53 -52.28 52.53 7.63 537.20 35.30 259.10 524.65 -51.45 -7.93 -59.52 59.82 6.14 550.30 38.10 259.90 535.15 -61.95 -9.35 -67.22 67.57 6.50 563.30 40.30 261.70 545.22 -72.02 -10.66 -75.33 75.74 5.72 576.50 42.70 262.60 555.11 -81.91 -11.86 -83.99 84.44 5.62 589.50 46.20 263.80 564.39 -91.19 -12.93 -93.03 93.52 8.31 602.50 49.40 264.80 573.12 -99.92 -13.89 -102.61 103.14 7.58 615.70 51.90 264.20 581.49 -108.29 -14.87 -112.77 113.33 5.78 628.90 54.30 262.70 589.41 -116.21 -16.07 -123.26 123.86 6.10 642.00 57.00 262.50 596.80 -123.60 -17.46 -133.98 134.64 6.19 655.10 59.30 261.70 603.72 -130.52 -19.00 -145.00 145.72 5.49

Upper Amaranth Anhydrite 658.63 60.00 261.43 605.50 -132.30 -19.44 -148.02 148.75 6.28 668.20 61.90 260.70 610.15 -136.95 -20.74 -156.28 157.06 6.28 681.10 64.30 260.20 615.98 -142.78 -22.65 -167.62 168.48 5.68 694.90 66.80 260.40 621.69 -148.49 -24.77 -180.01 180.94 5.45 708.60 69.30 261.00 626.81 -153.61 -26.82 -192.54 193.56 5.61 711.00 69.90 261.00 627.65 -154.45 -27.17 -194.77 195.80 7.50 722.30 69.90 260.80 631.53 -158.33 -28.85 -205.24 206.34 0.50

Lower Amaranth (Spearfish) 733.53 69.82 261.04 635.40 -162.20 -30.51 -215.65 216.81 0.65 736.10 69.80 261.10 636.29 -163.09 -30.89 -218.04 219.22 0.65 745.00 69.80 261.20 639.36 -166.16 -32.17 -226.29 227.52 0.32 749.90 71.80 261.20 640.97 -167.77 -32.88 -230.86 232.12 12.24

Flossie Lake 755.90 72.76 260.89 642.80 -169.60 -33.77 -236.51 237.80 5.04 763.60 74.00 260.50 645.00 -171.80 -34.96 -243.79 245.13 5.04 777.40 76.90 260.50 648.47 -175.27 -37.17 -256.96 258.39 6.30 791.20 80.00 261.00 651.23 -178.03 -39.34 -270.31 271.81 6.82

Whitewater Lake 794.60 80.71 261.05 651.80 -178.60 -39.86 -273.62 275.14 6.32 805.00 82.90 261.20 653.28 -180.08 -41.45 -283.79 285.38 6.32




818.80 85.60 262.00 654.66 -181.46 -43.46 -297.37 299.04 6.12 832.50 87.00 263.10 655.55 -182.35 -45.23 -310.93 312.66 3.90 834.40 87.20 263.10 655.64 -182.44 -45.46 -312.81 314.55 3.16

Lateral Heel 842.00 88.06 263.65 655.96 -182.76 -46.33 -320.35 322.12 4.03 846.80 88.60 264.00 656.10 -182.90 -46.85 -325.12 326.91 4.03 859.80 88.90 264.20 656.38 -183.18 -48.19 -338.05 339.89 0.83 872.80 89.50 265.10 656.56 -183.36 -49.40 -350.99 352.87 2.50 886.10 89.10 267.30 656.73 -183.53 -50.28 -364.26 366.17 5.04 899.20 88.40 268.60 657.01 -183.81 -50.75 -377.35 379.26 3.38 912.30 89.10 268.90 657.30 -184.10 -51.03 -390.44 392.36 1.74 925.00 90.30 269.30 657.36 -184.16 -51.23 -403.14 405.05 2.99 937.80 90.50 268.50 657.28 -184.08 -51.48 -415.94 417.85 1.93 951.00 91.10 269.20 657.09 -183.89 -51.74 -429.13 431.04 2.10 963.70 90.50 268.90 656.91 -183.71 -51.95 -441.83 443.73 1.58 976.80 90.80 267.90 656.77 -183.57 -52.32 -454.92 456.83 2.39 989.70 89.40 269.30 656.74 -183.54 -52.63 -467.82 469.73 4.60

1002.90 89.60 269.90 656.86 -183.66 -52.73 -481.02 482.92 1.44 1016.00 89.30 271.50 656.98 -183.78 -52.57 -494.12 495.99 3.73 1029.00 89.30 270.00 657.14 -183.94 -52.40 -507.11 508.97 3.46 1041.90 89.30 270.10 657.30 -184.10 -52.39 -520.01 521.86 0.23 1054.80 89.30 269.30 657.46 -184.26 -52.45 -532.91 534.74 1.86 1068.00 89.30 269.40 657.62 -184.42 -52.60 -546.11 547.93 0.23 1081.00 90.00 268.60 657.70 -184.50 -52.83 -559.11 560.93 2.45 1093.60 91.10 270.10 657.58 -184.38 -52.97 -571.71 573.52 4.43 1106.80 91.60 269.60 657.27 -184.07 -53.01 -584.90 586.71 1.61 1120.00 91.50 269.30 656.91 -183.71 -53.13 -598.10 599.89 0.72 1133.20 91.00 270.40 656.62 -183.42 -53.17 -611.29 613.08 2.75 1146.20 91.60 271.00 656.33 -183.13 -53.01 -624.29 626.05 1.96 1159.10 89.40 272.00 656.21 -183.01 -52.67 -637.18 638.92 5.62 1172.00 88.90 272.70 656.41 -183.21 -52.14 -650.07 651.77 2.00 1185.10 88.70 271.50 656.68 -183.48 -51.66 -663.16 664.82 2.79 1198.30 89.60 271.10 656.88 -183.68 -51.36 -676.35 677.99 2.24 1211.40 90.70 272.20 656.84 -183.64 -50.99 -689.45 691.05 3.56 1224.50 91.50 271.60 656.59 -183.39 -50.55 -702.54 704.11 2.29 1237.60 91.10 271.70 656.29 -183.09 -50.18 -715.63 717.17 0.94 1250.60 89.00 270.90 656.28 -183.08 -49.88 -728.63 730.14 5.19 1263.80 88.70 270.00 656.55 -183.35 -49.78 -741.82 743.32 2.16




1276.80 88.50 269.20 656.86 -183.66 -49.87 -754.82 756.30 1.90 1289.90 88.90 269.50 657.16 -183.96 -50.02 -767.91 769.39 1.14 1303.00 89.90 269.80 657.30 -184.10 -50.10 -781.01 782.48 2.39 1316.20 90.50 270.50 657.25 -184.05 -50.06 -794.21 795.67 2.10 1329.30 90.50 270.60 657.14 -183.94 -49.94 -807.31 808.75 0.23 1342.50 90.40 269.30 657.03 -183.83 -49.95 -820.51 821.93 2.96 1355.50 90.40 268.80 656.94 -183.74 -50.16 -833.51 834.93 1.15 1368.50 90.40 269.90 656.85 -183.65 -50.31 -846.51 847.92 2.54 1382.20 90.20 270.80 656.78 -183.58 -50.23 -860.21 861.60 2.02 1396.00 90.50 270.90 656.70 -183.50 -50.02 -874.00 875.37 0.69 1409.80 91.00 271.20 656.52 -183.32 -49.77 -887.80 889.14 1.27 1423.50 90.90 270.00 656.29 -183.09 -49.63 -901.50 902.82 2.64 1426.00 91.10 270.20 656.24 -183.04 -49.62 -904.00 905.32 3.39

Extrapolated Total Depth 1441.00 91.10 270.20 655.96 -182.76 -49.57 -919.00 920.30 0.00



SAMPLE DESCRIPTIONS

Interval Descriptions

545 - 555 Sandstone(75%), clear to light grey, off white in part, buff in part, quartzose, 75% very fine to part fine-lower consolidated grains with calcareous cement, 25% unconsolidated, occasional pyrite stringers, subangular to subround, moderately well sorted, tight to poor to inferred fair intergranular porosity, no shows; Shale/Marlstone(25%), light to medium grey, occasional grey-green, micromicaceous, silty in part, calcareous to very calcareous, subfissile to blocky.

555 - 570 Shale(65%), medium to light grey, grey-green in part, occasional red-brown to brown,

micromicaceous, silty in part grading to argillaceous siltstone in part, calcareous to very calcareous, subfissile to blocky; Sandstone(35%), clear to light grey, off white in part, buff in part, quartzose, 75% very fine to part fine-lower consolidated grains with calcareous cement, 25% unconsolidated, common to abundant micritic limestone stringers with minor to occasional sandy inclusions, occasional pyrite stringers, subangular to subround, moderately well sorted, tight to poor to inferred fair intergranular porosity, no shows.

570 - 580 Sandstone(60%), as above, quartzose, 60% very fine to part fine-lower consolidated grains

with calcareous cement, 40% unconsolidated, occasional pyrite stringers, subangular to subround, moderately well sorted, tight to poor to inferred fair intergranular porosity, no shows; Shale/Marlstone(30%), as above; Limestone(10%), off white, predominantly micritic mudstone, cryptocrystalline in part, common very fine sandy inclusions grading to calcareous sandstone in part, tight, no shows.

580 - 590 Sandstone(70%), clear to translucent light grey, buff in part, frosted in part, quartzose,

90% fine-upper to medium-lower unconsolidated grains, 10% very fine grains consolidated with calcareous cement, minor pyrite stringers, subangular to subround, moderately well sorted, tight to fair to inferred good intergranular porosity, no shows; Shale/Marlstone(20%), medium to dark grey, grey-brown in part, occasional yellow-green, micromicaceous, silty in part, calcareous, subfissile to blocky; Limestone(10%), as above, tight, no shows.

590 - 600 Sandstone(100%), clear to translucent white to translucent buff, minor buff-tan, quartzose,

95% fine-upper to medium-lower unconsolidated grains, 5% consolidated with calcareous cement, subangular to subround, well sorted, tight to fair to inferred good intergranular porosity, no shows; minor shale.

600 - 610 Sandstone(100%), as above, increasingly common calcareous cement, occasionally

grading to siltstone, tight to poor to inferred good intergranular porosity, no shows; occasional shale.

610 - 620 Sandstone(100%), clear to translucent buff, light grey in part, buff-tan in part, quartzose,

80% very fine consolidated grains with calcareous cement, 20% fine to part medium grains, common micritic limestone stringers, subangular to subround, moderately well sorted, tight to poor to inferred good intergranular porosity, no shows; occasional shale cavings.




620 - 630 Sandstone(80%), as above, decreasingly common calcareous cement (35% consolidated), tight to poor to inferred good intergranular porosity, no shows; Shale(20%), light to medium grey, grey-green in part, grey-brown in part, micromicaceous, silty in part, calcareous, blocky to part subfissile.

630 - 640 Sandstone(90%), clear to translucent buff, buff-tan in part, quartzose, fine-upper to

medium-lower unconsolidated grains, calcareous in part, subangular to subround, well sorted, fair to inferred good intergranular porosity, no shows; Shale(10%), as above.

640 - 650 Shale(70%), light to medium to dark grey, grey-green in part, occasional red-brown,

micromicaceous, silty in part, calcareous, blocky to part subfissile; Sandstone(30%), clear to translucent buff, buff-orange in part, 50% fine consolidated grains with calcareous cement, 50% fine to medium unconsolidated grains, subangular to subround, moderately well sorted, tight to poor to inferred good intergranular porosity, no shows.

658.6 Upper Amaranth Anhydrite (605.5 m TVD, -132.2 m MSL)

650 - 660 Dolomitic Limestone(60%), light grey to buff-grey, off white to cream, micritic mudstone

in part, occasional cryptocrystalline, occasional sandy inclusions, dolomitic, argillaceous in part, tight, no shows; Shale(40%), light to medium grey, minor dark grey, micromicaceous, silty in part, dolomitic grading to argillaceous dolomite in part, blocky to part subfissile.

660 - 670 Dolomitic Limestone(90%), light grey, cream, off white in part, part buff-tan to buff-grey,

part micritic mudstone, commonly cryptocrystalline + dense, minor lower microcrystalline to microcrystalline with micritic matrix, minor to occasional silty inclusions in part, dolomitic, tight, no shows; Shale(10%), as above; occasional unconsolidated sand grains.

670 - 680 Calcareous Dolomite(90%), buff-tan to buff-grey, light grey, off white in part, part

cryptocrystalline, part micritic mudstone, rare anhydrite inclusions, anhydritic in part, calcareous to very calcareous, argillaceous to very argillaceous in part, tight, no shows; Anhydrite(10%), clear to translucent white to white, microcrystalline in part, minor cryptocrystalline, dolomitic in part, tight, no shows; occasional shale.

680 - 690 Dolomite(80%), buff-tan to buff-grey, light grey, off white in part, part cryptocrystalline,

part micritic mudstone, rare anhydrite inclusions, anhydritic in part, calcareous in part, argillaceous to very argillaceous in part grading to dolomitic shale in part, tight, no shows; Anhydrite(20%), as above, tight, no shows; occasional shale.

690 - 700 Dolomite(65%), as above, tight, no shows; Anhydrite(30%), white to translucent white,

clear in part, part cryptocrystalline, part microcrystalline with in part cryptocrystalline matrix, dolomitic in part, tight, no shows; Shale(5%), light to medium grey, minor dark grey, micromicaceous, silty in part, dolomitic grading to argillaceous dolomite in part, blocky to part subfissile.




700 - 710 Shale(40%), as above, minor red-brown; Anhydrite(35%), clear, translucent white, white in part, microcrystalline in part, cryptocrystalline in part, dolomitic in part, tight, no shows; Dolomite(25%), buff-tan to buff-grey, light grey, off white in part, part cryptocrystalline, part micritic mudstone, rare anhydrite inclusions, anhydritic in part, calcareous in part, argillaceous to very argillaceous in part grading to dolomitic shale in part, tight, no shows.

710 - 720 Anhydrite(65%), clear to translucent white, white in part, predominantly microcrystalline,

cryptocrystalline in part, dolomitic in part, tight, no shows; Shale(20%), predominantly red-brown, occasional light to medium grey, micromicaceous, dolomitic in part, blocky, subfissile in part; Dolomite(15%), as above, tight, no shows.

720 - 730 Anhydrite(80%), as above, minor to occasional anhydrite inclusions, tight, no

shows; Shale(10%), predominantly red-brown, light grey in part, micromicaceous, silty in part, dolomitic in part, blocky to part subfissile; Dolomite(10%), cream to buff-tan to buff-white, micritic mudstone, argillaceous in part, anhydritic in part, tight, no shows.

733.5 Lower Amaranth (Spearfish) (635.4 m TVD, -162.2 m MSL)

730 - 735 Anhydrite(65%), as above, tight, no shows; Shale(20%), red-brown, medium to part light

grey, micromicaceous, silty in part, dolomitic in part, blocky to part subfissile; Dolomite(15%), as above, tight, no shows.

735 - 745 Shale(65%), red-brown, occasionally dark red, micromicaceous in part, silty in part,

dolomitic to calcareous in part, blocky to part subfissile; Anhydrite(35%), clear to translucent white to white in part, predominantly microcrystalline with cryptocrystalline matrix in part, cryptocrystalline in part, tight, no shows; minor dolomite.

745 - 750 Shale(70%), as above; Anhydrite(20%), as above, increasingly cryptocrystalline,

increasingly dolomitic grading to anhydritic dolomite, tight, no shows; Sandstone(10%), clear to frosted light grey, translucent buff in part, quartzose, medium to part fine unconsolidated grains, subround to part subangular, well sorted, fair to inferred good intergranular porosity, no shows.

750 - 755 Sandstone(60%), translucent orange to clear, occasionally frosted, quartzose, 90% very

fine to medium unconsolidated quartz grains, 10% with silica to dolomitic cement, tight with inferred poor to fair intergranular porosity, no visible shows or cut; Anhydrite(30%), white to off white, occasionally light grey, predominantly cryptocrystalline, trace dolomitic in part, tight, no shows; Shale(10%), reddish brown to dark orange, micromicaceous, trace dolomitic in part, subfissile to blocky.




755.9 Flossie Lake (642.8 m TVD, -169.6 m MSL)

755 - 760 Anhydrite(70%), off white to light grey, as above, tight, no shows; Dolomite(20%), cream-buff to off white, commonly pale pink, predominantly cryptocrystalline, part microcrystalline to lower microcrystalline, part recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, trace micritic mudstone, commonly anhydritic, trace argillaceous in part, tight, no visible shows or cut; Sandstone(10%), translucent to clear, occasional frosted, as above, tight with inferred poor to fair intergranular porosity, no visible shows or cut.

760 - 770 Dolomite(100%), cream-buff to off white, commonly light tan, rare pale pink to maroon-

pink, predominantly as above, decreasingly anhydritic, tight to trace very poor interfragmental + intercrystalline porosity, shows patchy, light tan oil stain (<10%) with moderate yellow fluorescence associated with slow to slightly moderate, weak to moderate, yellow-white cut.

770 - 780 Dolomite(100%), cream-buff to off white, trace light tan, rare pale pink, predominantly as

above, decreasingly anhydritic , trace calcareous in part, tight to trace very poor intercrystalline + interfragmental porosity, shows patchy, light tan oil stain (<10%) with moderate to in part bright yellow fluorescence associated with slow to moderate, weak to moderate, yellow-white cut.

780 - 785 Dolomite(100%), cream-buff to off white, trace light tan, decreasingly common pale pink,

as above, tight to trace very poor intercrystalline + interfragmental porosity, shows patchy, light tan oil stain (>10%) with moderate to in part bright yellow fluorescence associated with slow to moderate, weak to moderate, yellow-white cut.

794.6 Whitewater Lake (651.8 m TVD, -178.6 m MSL)

785 - 795 Dolomite(100%), cream-buff to off white, increasingly light tan, rare pale pink,

predominantly cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline, trace micritic mudstone, argillaceous in part, anhydritic in part, tight to increasingly very poor intercrystalline + interfragmental porosity, shows patchy, light tan oil stain (15%) with moderate to part bright yellow fluorescence associated with slow to moderate, weak to moderate, yellow-white cut.

795 - 805 Dolomite(100%), cream-buff to off white, occasionally light tan to tan, decreasingly pale

pink, as above, tight to very poor intercrystalline + interfragmental porosity, shows patchy, light tan oil stain (10%) with moderate to part bright yellow fluorescence associated with slow to moderate, weak to moderate, yellow-white cut.




805 - 815 Dolomite(100%), cream-buff to off white, increasingly light tan, rare pale pink, predominantly cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline, rare micritic mudstone, argillaceous in part, anhydritic in part, rare very fine to fine vugs, tight to very poor to trace poor intercrystalline + interfragmental porosity with trace vuggy porosity, shows patchy, light tan oil stain (30%) with moderate to part bright yellow fluorescence associated with slow to increasingly moderate, weak to increasingly moderate, yellow-white cut.

815 - 825 Dolomite(100%), cream-buff to off white, increasingly light tan, as above, tight to very

poor to rare poor intercrystalline + interfragmental porosity with trace vuggy porosity, shows patchy, light tan oil stain (20%) with moderate to part bright yellow fluorescence associated with slow to increasingly moderate, weak to increasingly moderate, yellow-white cut.

825 - 835 Dolomite(100%), cream-buff to off white, light tan to in part tan, predominantly

cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline, rare micritic mudstone, argillaceous in part, anhydritic in part, rare very fine to fine vugs, tight to very poor to trace poor intercrystalline + interfragmental porosity with trace vuggy porosity, shows patchy, light tan to in part tan oil stain (35%) with moderate to part bright yellow fluorescence associated with slow to increasingly moderate, weak to increasingly moderate, yellow-white cut; rare free oil.

842.0 Lateral Heel (656.0 m TVD, -182.8 m MSL)

835 - 847 Dolomite(100%), cream-buff to off white, light tan to in part tan, part cryptocrystalline,

part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline, rare micritic mudstone, trace anhydritic inclusions + stringers, argillaceous in part, anhydritic in part, rare very small vugs, tight to very poor to trace poor intercrystalline + interfragmental porosity with trace vuggy porosity, shows patchy, light tan to in part tan oil stain (50%) with moderate to part bright yellow fluorescence associated with slow to increasingly moderate, weak to increasingly moderate, yellow-white cut; rare free oil.

847 - 860 Dolomite(100%), off white to buff-tan to tan, light tan, predominantly cryptocrystalline,

part recrystallized very fine to fine grained biofragmental wackestone with predominantly cryptocrystalline matrix, rare lower microcrystalline with cryptocrystalline to part micritic matrix, minor to occasional anhydrite inclusions plugging vuggy porosity in part, occasional very small to small vugs, anhydritic in part argillaceous in part, tight to very poor to part fair intercrystalline, interfragmental + part vuggy porosity, shows patchy tan to light tan oil stain (30%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut.




860 - 870 Dolomite(100%), as above, increasingly common anhydrite inclusions + stringers, tight to poor intercrystalline, interfragmental, + part vuggy porosity, shows patchy tan to light tan oil stain (35%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut.

870 - 890 Dolomite(100%), tan to light tan to part light brown, off white to cream in part, part

cryptocrystalline, part fine to part very fine grained biofragmental wackestone with cryptocrystalline matrix, rare microcrystalline to lower microcrystalline with cryptocrystalline matrix, rare small vugs, occasional anhydrite inclusions + stringers, anhydritic in part, argillaceous in part, tight to poor intercrystalline, interfragmental, + rare vuggy porosity shows patchy tan to light tan to light brown oil stain (45%) with moderate yellow fluorescence associated with moderate, moderate to slightly weak yellow-white cut.

890 - 910 Dolomite(100%), light tan to tan to light brown, off white to cream, part very fine to fine

grained biofragmental recrystallized wackestone with cryptocrystalline matrix, part cryptocrystalline, rare lower microcrystalline with cryptocrystalline matrix, occasional anhydrite inclusions + minor stringers, rare small to very small vugs, anhydritic in part, argillaceous in part, tight to poor to very rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy tan to light brown to light tan oil stain (55%) with moderate yellow fluorescence associated with moderate, moderate yellow-white cut.

910 - 930 Dolomite(100%), light tan to tan to light brown, off white to cream in part, predominantly

recrystallized very fine to fine grained biofragmental wackestone with cryptocrystalline matrix, rare lower microcrystalline with cryptocrystalline matrix, occasional to common anhydrite inclusions + stringers, trace very small vugs, anhydritic in part, argillaceous in part, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy tan to light brown to light tan oil stain (65%) with moderate yellow fluorescence associated with moderate, moderate yellow-white cut; occasional free oil.

930 - 960 Dolomite(100%), light tan to tan, cream-buff to off white, occasionally light brown in

part, predominantly very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part cryptocrystalline, part microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, trace anhydritic inclusions + stringers, argillaceous to very argillaceous in part, anhydritic in part, trace very small vugs, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (>60%) with moderate to part bright yellow fluorescence associated with moderate speed, moderate strength, yellow-white cut; trace free oil.

960 - 980 Dolomite(100%), light tan to decreasingly tan, increasingly cream-buff to off white,

predominantly as above, increasingly cryptocrystalline, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy, light tan oil stain (<50%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; trace free oil.




980 - 1000 Dolomite(100%), light tan to tan, cream-buff to off white, rare light brown in part, rare pale pink, predominantly cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, trace anhydritic inclusions + stringers, argillaceous to very argillaceous in part, anhydritic in part, rare very small vugs, tight to poor to decreasingly fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (40%) with moderate to in part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.

1000 - 1020 Dolomite(100%), light tan to in part tan, commonly cream-buff to off white, rare light

brown, predominantly as above, increasingly anhydritic, tight to poor to decreasingly fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy, light tan oil stain (35%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare to trace free oil.

1020 - 1040 Dolomite(100%), light tan to in part tan, commonly cream-buff to off white, increasingly

light brown, as above, tight to poor to decreasingly fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy, light tan oil stain (>40%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare to trace free oil.

1040 - 1060 Dolomite(100%), cream-buff to off white, commonly light tan to tan, rare light brown in

part, rare pale pink in part, predominantly cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, occasional anhydritic inclusions + stringers, argillaceous in part, anhydritic in part, rare very small vugs, tight to poor to very rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (35%) with moderate to in part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.

1060 - 1080 Dolomite(100%), light tan to in part tan, commonly cream-buff to off white, rare light

brown, as above, tight to poor to rare fair intercrystalline + interfragmental porosity with very rare vuggy porosity, shows patchy, light tan to tan oil stain (40%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare to trace free oil.

1080 - 1100 Dolomite(100%), cream-buff to off white, increasingly light tan to tan, trace light brown

in part, pale pink in part, part cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, occasional anhydritic inclusions + stringers, argillaceous in part, anhydritic in part, rare very small vugs, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (<50%) with moderate to in part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.




1100 - 1120 Dolomite(100%), light tan to in part tan, cream-buff to off white, rare light brown, predominantly as above, increasingly cryptocrystalline, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy, light tan to tan oil stain (>40%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare to trace free oil.

1120 - 1140 Dolomite(100%), light tan to in part tan, cream-buff to off white, rare light brown, as

above, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy, light tan to buff-tan oil stain (50%) with moderate to part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.

1140 - 1160 Dolomite(100%), cream-buff to off white, increasingly light tan to tan, trace light brown

in part, pale pink in part, part cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with micritic to cryptocrystalline matrix, part microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, occasional anhydritic inclusions + stringers, argillaceous in part, anhydritic in part, rare very small vugs, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (<60%) with moderate to in part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.

1160 - 1170 Dolomite(100%), as above, increasingly tan, increasingly cryptocrystalline, decreasingly

common lower microcrystalline to microcrystalline, increasingly argillaceous, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy to even tan to light tan to part medium brown oil stain (65%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1170 - 1180 Dolomite(100%), tan to light tan to light brown, off white to cream, part cryptocrystalline,

part very fine to fine grained biofragmental recrystallized wackestone with cryptocrystalline matrix, occasional lower microcrystalline to microcrystalline with cryptocrystalline matrix, rare micritic stringers, trace anhydrite inclusions + stringers, anhydritic in part, argillaceous in part, very rare very small vugs, tight to poor to rare vuggy porosity, shows patchy to part even tan to light tan to light brown oil stain (55%) with fluorescence and cut as above; rare free oil.

1190 - 1210 Dolomite(100%), as above, increasingly off white, increasingly common anhydrite

stringers, tight to poor to very rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy tan to light tan to light brown oil stain (50%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.




1210 - 1230 Dolomite(100%), cream-buff to off white, light tan to tan to light brown, part cryptocrystalline, part very fine to fine recrystallized biofragmental wackestone with cryptocrystalline matrix, minor microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, rare micritic stringers, occasional anhydritic inclusions + stringers, argillaceous in part, anhydritic in part, rare very small vugs, tight to poor to rare fair intercrystalline + interfragmental porosity with rare vuggy porosity, shows patchy to even, light tan to tan oil stain (<50%) with moderate to in part bright yellow fluorescence associated with moderate, moderate, yellow-white cut; rare free oil.

1230 - 1240 Dolomite(100%), tan to light brown, light tan in part, off white to cream, trace pale pink,

part very fine to fine grained recrystallized biofragmental wackestone with cryptocrystalline matrix, part cryptocrystalline, part lower microcrystalline to microcrystalline with cryptocrystalline to part microcrystalline matrix, minor to occasional anhydritic inclusions + stringers, rare very small to small vugs, anhydritic in part, argillaceous in part, tight to poor to rare fair intercrystalline, interfragmental, + vuggy porosity, shows patchy tan to light brown to light tan oil stain (60%), with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1240 - 1250 Dolomite(100%), as above, increasingly light brown, occasional medium brown,

occasional to common micritic stringers, tight to poor to rare fair intercrystalline, interfragmental, + vuggy porosity, shows patchy tan to light brown to light tan oil stain (60%), with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1250 - 1270 Dolomite(100%), tan to light brown to part medium brown, off white to cream, minor pale

pink, part very fine to fine recrystallized biofragmental wackestone with cryptocrystalline matrix, part cryptocrystalline, minor microcrystalline to lower microcrystalline with cryptocrystalline to part micritic matrix, occasional micritic stringers, minor to occasional anhydrite inclusions + stringers, anhydritic in part, argillaceous in part, rare to trace very small to small vugs, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy to even tan to light brown to part medium brown oil stain (>60%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1270 - 1290 Dolomite(100%), tan to light brown to increasingly medium brown, off white to cream,

minor pale pink, part very fine to fine recrystallized biofragmental wackestone with cryptocrystalline matrix, part cryptocrystalline, minor microcrystalline to lower microcrystalline with cryptocrystalline to part micritic matrix, occasional micritic stringers, minor to occasional anhydrite inclusions + stringers, anhydritic in part, argillaceous in part, rare to trace very small to small vugs, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy to even tan to light brown to part medium brown oil stain (<65%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.




1290 - 1310 Dolomite(100%), as above, increasingly pale pink, increasingly cryptocrystalline, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy to even tan to light brown to part medium brown oil stain (<60%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1310 - 1330 Dolomite(100%), tan to light brown to increasingly medium brown, off white to cream,

minor pale pink, part very fine to fine recrystallized biofragmental wackestone with cryptocrystalline matrix, part cryptocrystalline, minor microcrystalline to lower microcrystalline with cryptocrystalline to part micritic matrix, occasional micritic stringers, minor to occasional anhydrite inclusions + stringers, anhydritic in part, argillaceous in part, rare to trace very small to small vugs, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, shows patchy to even tan to light brown to part medium brown oil stain (<60%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; rare free oil.

1330 - 1350 Dolomite(100%), as above, increasingly tan to light brown to medium brown, increasingly

common very fine to fine grained recrystallized biofragmental wackestone with cryptocrystalline matrix, tight to poor to trace fair intercrystalline, interfragmental, + trace vuggy porosity, shows patchy tan to light brown to medium brown oil stain (<65%) with moderate to part bright yellow fluorescence associated with moderate, moderate yellow-white cut; trace free oil.

1350 - 1370 Dolomite(100%), tan to light brown to medium brown, off white to cream, increasingly

pale pink, part recrystallized very fine to fine grained biofragmental wackestone with cryptocrystalline matrix, occasional lower microcrystalline to microcrystalline with cryptocrystalline to micritic matrix, occasional anhydrite inclusions, rare very small vugs, anhydritic in part, argillaceous in part, tight to poor to rare fair intercrystalline, interfragmental, + rare vuggy porosity, show patchy tan to light brown to medium brown oil stain (60%) with fluorescence and cut as above; rare free oil.

1370 - 1390 Dolomite(100%), tan to light tan, trace cream-buff to off white, trace pale pink, part very

fine to fine biofragmental wackestone with micritic to cryptocrystalline matrix, part cryptocrystalline, occasionally microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, trace anhydritic inclusions + stringers, trace micritic stringers, anhydritic in part, argillaceous in part, rare very small to small vugs, tight to poor to rare fair interfragmental + intercrystalline porosity with trace vuggy porosity, shows even to patchy, tan to light tan oil stain (65%) with moderate to bright yellow fluorescence associated with moderate speed, moderate strength, yellow-white cut; rare free oil.

1390 - 1410 Dolomite(100%), tan to light tan, decreasingly cream-buff to off white, trace light brown

in part, as above, tight to poor to increasingly fair interfragmental + intercrystalline porosity with trace vuggy porosity, shows even to in part patchy, light tan oil stain (<70%) with moderate to bright yellow fluorescence associated with moderate speed, moderate strength, yellow-white cut; trace free oil.




1410 - 1441 Dolomite(100%), tan to light tan, cream-buff to off white, occasionally light brown, increasingly pale pink, part very fine to fine biofragmental wackestone with micritic to cryptocrystalline matrix, part cryptocrystalline, occasionally microcrystalline to lower microcrystalline with micritic to cryptocrystalline matrix, trace anhydritic inclusions + stringers, trace micritic stringers, anhydritic in part, argillaceous in part, rare very small to small vugs, tight to poor to rare fair interfragmental + intercrystalline porosity with trace vuggy porosity, shows even to patchy, tan to light tan oil stain (50%) with moderate to bright yellow fluorescence associated with moderate speed, moderate strength, yellow-white cut; rare to trace free oil.

1441.0 Extrapolated Total Depth (656.0 m TVD, -182.8 m MSL)



WELL SUMMARY Corex Virden HZNTL 102.10-01-011-27 WPM was drilled as a horizontal well to further develop the Whitewater Lake beds in Virden region. The Flossie Lake was encountered at 755.9 m MD (642.8 m TVD, -169.6 m MSL) and the Whitewater Lake was encountered at 794.6 m MD (651.8 m TVD, -178.6 m MSL). The Lateral Heel was set 4.2 m into the Whitewater Lake at 842.0 m MD (656.0 m TVD, -182.8 m MSL) at 88.1° with the intention of targeting approximately 3.0 m into the zone. The wellbore was drilled along a vertical section plane of 267.40° to a total measured depth of 1441.0 m MD (656.0 m TVD, -182.8 m MSL).

GEOLOGY

Flossie Lake The Flossie Lake was encountered at 755.9 m MD (642.8 m TVD, -169.6 m MSL). The Flossie Lake was described as a dolomite that was predominately cryptocrystalline, part microcrystalline to lower microcrystalline, part very fine to fine recrystallized biofragmental wackestone with cryptocrystalline to micritic matrix and trace micritic mudstone. Also noted was a part anhydritic and part argillaceous composition. The intercrystalline and interfragmental porosity was rated as tight to trace very poor. Oil staining was described as patchy light tan in colour with percentages typically ranging from <10% to 15%. Gas reading ranged from 15 units to 135 units per 10000. Gamma counts ranged from 12 cps to 48 cps. The Flossie Lake was only drilled in the build section and is rated as very poor reservoir.

Whitewater Lake

The Whitewater Lake was encountered at 794.6 m MD (651.8 m TVD, -178.6 m MSL) and the well was planned to target ~3.0 m into the formation. The Whitewater Lake encountered while drilling this well can be broken up as follows: From ~0.0 m to ~1.1 m below the top of the Whitewater Lake the samples were described as a dolomite that was predominately cryptocrystalline, part lower microcrystalline to microcrystalline, part very fine to fine recrystallized biofragmental wackestone with a micritic to cryptocrystalline matrix and trace micritic mudstone. Samples were also noted to have a part anhydritic and argillaceous composition. The intercrystalline and part interfragmental porosity was rated as tight to very poor. Oil staining was described as patchy light tan in colour with percentages typically ranging from 10% to 15%. Gas readings ranged from 80 units to 125 units per 10000. Gamma counts ranged from ~12 cps to ~16 cps. This interval is rated as very poor reservoir. From ~1.1 m to ~3.5 m below the top of Whitewater Lake the samples were described as a dolomite that was predominately cryptocrystalline, part recrystallized very fine to fine grained biofragmental wackestone with a cryptocrystalline to micritic matrix, part lower microcrystalline to microcrystalline with a cryptocrystalline matrix to part micritic matrix and rare micritic mudstone. Samples were also noted to have rare very small to small vugs and have an anhydritic to argillaceous composition in part. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to very poor to poor to rare fair. Oil staining was described as patchy to light tan to tan to light brown in colour with percentages ranging from 15% to 50%. Gas readings ranged from 125 units to 300 units. Gamma fluctuated between ~12 cps and ~30 cps. This interval is rated as poor reservoir.



From ~3.5 m to ~4.0 m below the top of the Whitewater Lake the samples were described as a dolomite that was part cryptocrystalline, part recrystallized very fine to fine grained biofragmental wackestone with a cryptocrystalline matrix, and occasionally lower microcrystalline to microcrystalline with cryptocrystalline to part micritic matrix. Samples were also noted to contain minor to occasional anhydrite inclusions, rare to trace very small to small vugs, as well as having an anhydritic and argillaceous composition in part. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to poor to rare fair. Oil staining was described as patchy light tan to tan to light brown to part medium brown in colour with percentages ranging from 50% to 70%. Gas readings ranged from 280 units to 490 units. Gamma fluctuated predominately between ~10 cps and ~30 cps. This interval is rated as poor to fair reservoir. From ~4.0 m to ~5.0 m below the top of the Whitewater Lake the samples were described as a dolomite that was predominately cryptocrystalline, part recrystallized very fine to fine grained biofragmental wackestone with a cryptocrystalline matrix, and rare to occasional lower microcrystalline to microcrystalline with cryptocrystalline to part micritic matrix. Samples were also noted to contain minor to occasional anhydrite inclusions, very rare to rare very small to small vugs, as well as having an anhydritic and argillaceous composition in part. The intercrystalline, part interfragmental, and rare vuggy porosity was rated as tight to poor to rare fair. Oil staining was described as patchy light tan to part tan to part light brown in colour with percentages ranging from 30% to 55%. Gas readings ranged from 110 units to 300units. Gamma fluctuated between ~15 cps and ~45 cps. This interval is rated as poor reservoir. The lateral section was interpreted to have been drilled between 2.5 m to 5.0 m below the Whitewater Lake top.



STRUCTURE PROFILE



RESERVOIR INTERVALS 794.6 m – 827.0 m MD (32.4 m): Very Poor Reservoir This interval began with the wellbore entering the Whitewater Lake member at 794.6 m MD (651.8 m TVD, -178.6 m MSL). The wellbore would drop 3.4 m in TVD to end the interval at 827.0 m MD (655.2 m TVD, -182.0 m MSL). This interval was interpreted to be drilled between 0.0. m and 3.4 m below the Whitewater Lake top. Samples were described as a dolomite that was predominately cryptocrystalline, part recrystallized very fine to fine grained biofragmental wackestone with a cryptocrystalline to micritic matrix, part lower microcrystalline to microcrystalline with cryptocrystalline matrix to part micritic matrix and rare micritic mudstone. Samples were also noted to have rare very small to small vugs and have an anhydritic to argillaceous composition in part. The intercrystalline, interfragmental and very rare vuggy porosity was rated as tight to very poor to trace poor. Oil staining was described as patchy to light tan to tan in colour with percentages ranging from 15% to 30%. Gas readings ranged from 130 units to 200 units. Gamma fluctuated between ~10 cps and ~16 cps.

842.0 m MD Lateral Heel (656.0 m TVD, -182.8 m MSL) 827.0 m – 921.0 m MD (94.0 m): Poor Reservoir After entering this interval at 827.0 m MD (655.2 m TVD, -182.0 m MSL) the wellbore would fall a total of 2.2 m in TVD until the end of this interval at 921.0 m MD (657.4 m TVD, -184.2 m MSL). This interval was interpreted to be drilled 3.0 m and 4.5 m below the Whitewater Lake top. Samples were described as a dolomite that was part very fine to fine grained recrystallized biofragmental wackestone with a cryptocrystalline matrix, part cryptocrystalline, and occasionally lower microcrystalline to microcrystalline with cryptocrystalline matrix to part micritic matrix. Also noted was occasional anhydrite inclusions and stringers, rare small vugs, as well as having an argillaceous and anhydritic composition in part. The porosity of the interval was described as intercrystalline, interfragmental, and rare vuggy and was rated as tight to poor to rare fair. Oil staining was described as patchy light tan to tan to light brown in colour with percentages of 35% to 55%. Gas readings ranged from 120 units to 290 units per 10000. Gamma counts ranged from ~18 cps to ~36 cps. 921.0 m – 960.0 m MD (39.0 m): Poor to Fair Reservoir Upon entering this interval at 921.0 m MD (657.4 m TVD, -184.2 m MSL) the wellbore would rise 0.6 m in TVD to end the interval at 960.0 m MD (657.0 m TVD, -183.8 m MSL). This interval was interpreted to be drilled 3.0 m and 4.0 m below the Whitewater Lake top. Samples were described as a dolomite that was increasingly very fine to fine grained recrystallized biofragmental wackestone with a cryptocrystalline matrix, part cryptocrystalline, and minor to occasional lower microcrystalline to microcrystalline with a cryptocrystalline to part micritic matrix. Also noted was trace to occasional anhydrite inclusions, rare small vugs, as well as having an argillaceous and anhydritic composition in part. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to poor to part fair. Oil staining was described as patchy to even light tan to tan to light brown in colour with percentages typically ranging from 60% to 65%. Gas readings increased and ranged from 250 units to 490 units per 10000. Gamma counts ranged from ~16 cps to ~46 cps (predominately between 16 cps and 26 cps).



960.0m – 1137.5 m MD (177.5 m): Poor Reservoir This interval began at 960.0 m MD (657.0 m TVD, -183.8 m MSL) with the wellbore rising a total of 0.5 m in TVD to end the interval at 1137.5 m MD (656.5 m TVD, -183.3 m MSL). This interval was interpreted to be drilled 3.5 m and 5.0 m below the Whitewater Lake top. Samples were described as a dolomite that was part cryptocrystalline, part very fine to fine grained recrystallized biofragmental wackestone with cryptocrystalline matrix, and part lower microcrystalline to microcrystalline with a cryptocrystalline to part micritic matrix. Rare very small to part small vugs, occasional anhydrite inclusions and stringers, as well as a part anhydritic and part argillaceous composition was also noted. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to poor to rare fair. Oil staining was described as patchy light tan to tan in colour with percentages typically ranging from 35% to 50%. Gas readings typically ranged from 150 units to 315 units per 10000. Gamma counts ranged from ~13 cps to ~47 cps. 1137.5 m – 1171.0 m MD (33.5 m): Poor to Fair Reservoir Upon entering this interval at 1137.5 m MD (656.5 m TVD, -183.3 m MSL) the wellbore would rise 0.1 m in TVD to end the interval at 1171.0 m MD (656.4 m TVD, -183.2 m MSL). This interval was interpreted to be drilled 3.5 m and 4.0 m below the Whitewater Lake top. Samples were described as a dolomite that was part cryptocrystalline, part very fine to fine grained recrystallized biofragmental wackestone with a cryptocrystalline matrix, and part lower microcrystalline to microcrystalline with a cryptocrystalline to micritic matrix. Also noted was occasional anhydrite inclusions and stringers, rare very small vugs, as well as having an anhydritic and argillaceous composition in part. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to poor to rare fair. Oil staining was described as patchy to even light tan to tan to part light brown in colour with percentages typically ranging from 60% to 65%. Gas readings ranged from 260 units to 460 units per 10000. Gamma counts ranged from ~11 cps to ~16 cps with two gamma anomalies occurring in between 1161 m MD and 1170 m MD peaking at 114 cps. 1171.0 m – 1328.0 m MD (157.0 m): Poor Reservoir This interval began at 1171.0 m MD (656.4 m TVD, -183.2 m MSL) with the wellbore dropping a total of 0.8 m in TVD to end the interval at 1328.0 m MD (657.2 m TVD, -184.0 m MSL). This interval was interpreted to be drilled 3.5 m and 5.0 m below the Whitewater Lake top. Samples were described as a dolomite that was part cryptocrystalline, part a very fine to fine grained recrystallized biofragmental wackestone with cryptocrystalline matrix, and decreasingly common lower microcrystalline to microcrystalline with a cryptocrystalline to part micritic matrix. Occasional micritic stringers, occasional anhydrite inclusions and stringers, rare very small to small vugs, as well as a part anhydritic and part argillaceous composition was also noted. The intercrystalline, interfragmental, and rare vuggy porosity was rated as tight to poor rare fair. Oil staining was described as patchy to even tan to light brown to part medium brown in colour with percentages typically ranging from 50% to 60%. Gas readings typically ranged from 145 units to 285 units per 10000, peaking at 420 units. Gamma counts ranged from ~10 cps to ~30 cps.



1328.0 m – 1417.0 m MD (89.0 m): Poor to Fair Reservoir Upon entering this interval at 1328.0 m MD (657.2 m TVD, -184.0 m MSL) the wellbore rise 0.8 m in TVD to end the interval at 1417.0 m MD (656.4 m TVD, -183.2 m MSL). This interval was interpreted to be drilled 3.0 m and 4.0 m below the Whitewater Lake top. Samples were described as a dolomite that was part very fine to fine grained recrystallized biofragmental wackestone with a cryptocrystalline matrix, part cryptocrystalline, and occasionally lower microcrystalline to microcrystalline with a cryptocrystalline to micritic matrix. Also noted was occasional micritic stringers, occasional anhydrite inclusions and stringers, rare to trace very small to small vugs, as well as having an anhydritic and argillaceous composition in part. The intercrystalline, interfragmental, and rare to trace vuggy porosity was rated as tight to poor to part fair. Oil staining was described as patchy to even light tan to tan to part light brown in colour with percentages typically ranging from 60% to 65%. Gas readings decreased and ranged from 235 units to 370 units per 10000. Gamma counts generally ranged from ~12cps to ~20 cps peaking at 35 cps. 1417.0 m – 1441.0 m MD (24.0 m): Poor Reservoir After entering this interval at 1417.0 m MD (656.4 m TVD, -183.2 m MSL) the wellbore would rise a total of 0.4 m in TVD until the end of this interval at an Extrapolated Total Depth of 1441.0 m MD (656.0 m TVD, -182.8 m MSL). This interval was interpreted to be drilled 2.5 m and 3.0 m below the Whitewater Lake top. Samples were described as a dolomite that was part cryptocrystalline, part very fine to fine grained recrystallized biofragmental wackestone with a cryptocrystalline matrix, and occasionally lower microcrystalline to microcrystalline with cryptocrystalline to micritic matrix. Also noted was trace micritic stringers, minor to occasional anhydrite inclusions and stringers, rare very small to small vugs as well as having an anhydritic and argillaceous composition in part. The porosity of the interval was described as intercrystalline, interfragmental, and rare vuggy was rated as tight to poor to rare fair. Oil staining was described as patchy to even light tan to tan colour with percentages of 50%. Gas readings ranged from 160 units to 250 units per 10000. Gamma counts ranged from ~18 cps to ~26 cps.

1441.0 m MD: Extrapolated Total Depth (656.0 m TVD, -182.8 m MSL)



RESERVOIR EVALUATION

Total Section Drilled: 646.4 m 100.0% Total Reservoir Drilled: 646.4 m 100.0% 6 - Good Reservoir: 0.0 m 0.0% 5 - Fair Reservoir: 0.0 m 0.0% 4 - Poor to Fair Reservoir: 161.5 m 25.0% 3 - Poor Reservoir: 452.5 m 70.0% 2 - Very Poor Reservoir: 32.4 m 5.0% 1 - Non Reservoir: 0.0 m 0.0%

The reservoir intervals were broken down into seven different reservoir qualities. The seven qualities are as follows: 1) Non reservoir: Oil staining <5% and gas values generally less than 50 units. 2) Very poor reservoir: Oil staining up to 30%. Gas values generally less than 150 units. 3) Poor reservoir: Oil staining ranging between 30% and less than 55%. Gas values generally between 150 and 300 units. 4) Poor to fair reservoir: Oil staining ranging between 55% and 75%. Gas values generally ranging between 300 units and 600 units. 5) Fair reservoir: Oil staining between 75% and 90% with gas values ranging from 600 to 800 units. 6) Good reservoir: Oil staining >90% with gas values generally >800 units. Considering the above mentioned reservoir intervals, Corex Virden HZNTL 102.10-01-011-27 WPM should be a moderately successful horizontal oil producer after fracture stimulation.

Joe Steranko, B.Sc.

j)core

-100

0

100

Sout

h(-)

/Nor

th(+

) (40

m/c

m)

-900 -800 -700 -600 -500 -400 -300 -200 -100 0

West(-)/East(+) (40 m/cm)

BHL (12C-6) 10C-1

Heel (12C-6) 10C-1

10-1-11-27WPM/Ass'd Vt

Surface Casing @ 146m

KOP @ 344mStart of Tangent @ 711m

End of Tangent @ 745m

Cross Hard Boundary @ 831.1m (Approximate)

Landing Pt @ 842m

Last Survey @ 1426m

Extrapolation to Final TD @ 1441m

400

500

600

True

Ver

tical

Dep

th (4

0 m

/cm

)

0 100 200 300 400 500 600 700 800 900 1000

Vertical Section at 267.40° (40 m/cm)Heel (12C-6) 10C-1 BHL (12C-6) 10C-1

KOP @ 344m

Start of Tangent @ 711m



Landing Pt @ 842mLast Survey @ 1426m


Azimuths to True NorthMagnetic North: 6.47°

Magnetic FieldStrength: 57280.6snT

Dip Angle: 74.65°Date: 10/30/2013Model: IGRF2010

T M

12C-6-11-26WPM Corex Virden Prov Hzntl 10C-1-11-27WPM Final Survey (Lic#: 9680)

Created By: Mike Fitzpatrick Date: 9:58, December 15 2013

ID # 344533Land Survey Revision: 1

Actual KBE @ 473.20m (PD 205)

Target Azimuth Origin Type N/S E/W From TVDBHL (12C-6) 10C-1 267.40 Slot 0.00 0.00 0.00

Sec 111-27WPM

Project: VirdenSite: 12C-6-11-26WPMWell: Corex Virden Prov Hzntl 10C-1-11-27WPM

Wellbore: 102/10-01-011-27W1/00 Final Survey (Lic#: 9680)

100m

Har

d B

ound

ary

Roa

d A

llow

ance

100m

Har

d B

ound

ary

Sec 611-28WPM

LSD 15 LSD 16

LSD 10 LSD 9

LSD 13

LSD 12

Standard Survey Report

15 December, 2013

Survey: Final Survey (Lic#: 9680)

Corex Resources Ltd.Virden

12C-6-11-26WPM

Corex Virden Prov Hzntl 10C-1-11-27WPM

102/10-01-011-27W1/00

Cathedral Energy Services

Survey Report

Well Corex Virden Prov Hzntl 10C-1-11-27WPMLocal Co-ordinate Reference:Corex Resources Ltd.Company:

Actual KBE @ 473.20m (PD 205)TVD Reference:VirdenProject:

Actual KBE @ 473.20m (PD 205)MD Reference:12C-6-11-26WPMSite:

Corex Virden Prov Hzntl 10C-1-11-27WPMWell: TrueNorth Reference:

Minimum CurvatureSurvey Calculation Method:102/10-01-011-27W1/00Wellbore:

Design: Final Survey (Lic#: 9680) Database: EDM R5000 CATHEDRAL Multi Users

Map System:

Geo Datum:

Project

Map Zone:

System Datum:Universal Transverse Mercator

North American Datum 1983

Virden

Zone 14N (102 W to 96 W)

Mean Sea Level

Site Position:

From:

Site

Latitude:

Longitude:

Position Uncertainty:

Northing:

Easting:

Grid Convergence:

12C-6-11-26WPM

Map

Slot Radius:0.00 m

m

m

mm °

5,529,170.30

354,084.81

0.00

49° 53' 49.60 N

101° 1' 54.31 W

-1.55

Well

Well Position

Longitude:

Latitude:

Easting:

Northing:

+E/-W

+N/-S

Position Uncertainty Ground Level:

Corex Virden Prov Hzntl 10C-1-11-27WPM

Wellhead Elevation:0.00

0.00

0.00

5,529,170.30

354,084.81

0.00

49° 53' 49.60 N

101° 1' 54.31 W

468.90

m

m

m

m

m

m m

Wellbore

Declination

(°)

Field Strength

(nT)

Sample Date Dip Angle

(°)

102/10-01-011-27W1/00

Model NameMagnetics

IGRF2010 10/30/2013 6.48 74.65 57,281

Phase:Version:

Audit Notes:

Design Final Survey (Lic#: 9680)

1.0 ACTUAL

Vertical Section: Depth From (TVD)

(m)

+N/-S

(m)

Direction

(°)

+E/-W

(m)

Tie On Depth: 0.00

0.00 0.00 0.00 267.40

From

(m)

Survey Program

DescriptionTool NameSurvey (Wellbore)

To

(m)

Date 12/15/2013

ISCWSA MWD MWD - ISCWSAFinal Survey (Lic#: 9680) (102/10-01-011-2146.00 1,441.00

Measured

Depth

(m)

Inclination

(°)

Azimuth

(°)

+E/-W

(m)

Vertical

Section

(m)

Dogleg

Rate

(°/30m)

+N/-S

(m)

Build

Rate

(°/30m)

Turn

Rate

(°/30m)

Survey

Vertical

Depth

(m)

Subsea

(m)

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00473.20

Surface Casing @ 146m

146.00 0.00 0.00 146.00 0.00 0.00 0.00 0.00 0.00 0.00327.20

185.50 1.00 6.90 185.50 0.34 0.04 -0.06 0.76 0.76 0.00287.70

289.40 0.40 42.40 289.39 1.51 0.39 -0.46 0.21 -0.17 10.25183.81

328.70 0.50 46.50 328.69 1.73 0.61 -0.69 0.08 0.08 3.13144.51

341.60 0.50 328.40 341.59 1.82 0.62 -0.70 1.47 0.00 -181.63131.61

KOP @ 344m

344.00 0.92 296.82 343.99 1.83 0.60 -0.68 7.02 5.28 -394.77129.21

354.50 3.30 276.50 354.48 1.91 0.22 -0.31 7.02 6.79 -58.05118.72

12/15/2013 10:02:59AM COMPASS 5000.1 Build 70 Page 2


Survey Report







Measured

Depth

(m)

Inclination

(°)

Azimuth

(°)

+E/-W

(m)

Vertical

Section

(m)

Dogleg

Rate

(°/30m)

+N/-S

(m)

Build

Rate

(°/30m)

Turn

Rate

(°/30m)

Survey

Vertical

Depth

(m)

Subsea

(m)

367.50 6.60 268.80 367.43 1.93 -0.89 0.81 7.75 7.62 -17.77105.77

380.70 9.00 268.60 380.51 1.89 -2.69 2.60 5.45 5.45 -0.4592.69

393.70 11.10 262.40 393.31 1.70 -4.94 4.86 5.44 4.85 -14.3179.89

406.30 13.90 259.10 405.61 1.25 -7.63 7.57 6.88 6.67 -7.8667.59

419.40 15.90 257.00 418.27 0.55 -10.93 10.89 4.74 4.58 -4.8154.93

432.70 17.60 257.70 431.00 -0.28 -14.67 14.66 3.86 3.83 1.5842.20

445.90 19.50 259.70 443.52 -1.10 -18.78 18.81 4.55 4.32 4.5529.68

458.80 21.70 261.20 455.59 -1.85 -23.26 23.32 5.26 5.12 3.4917.61

471.80 24.40 261.50 467.55 -2.62 -28.29 28.38 6.24 6.23 0.695.65

484.70 25.90 261.30 479.23 -3.44 -33.71 33.83 3.49 3.49 -0.47-6.03

497.80 27.40 261.80 490.94 -4.30 -39.52 39.68 3.47 3.44 1.15-17.74

510.90 29.30 259.90 502.46 -5.29 -45.66 45.86 4.82 4.35 -4.35-29.26

524.00 32.60 259.00 513.70 -6.53 -52.28 52.53 7.63 7.56 -2.06-40.50

537.20 35.30 259.10 524.65 -7.93 -59.52 59.82 6.14 6.14 0.23-51.45

550.30 38.10 259.90 535.15 -9.35 -67.22 67.57 6.50 6.41 1.83-61.95

563.30 40.30 261.70 545.22 -10.66 -75.33 75.73 5.72 5.08 4.15-72.02

576.50 42.70 262.60 555.11 -11.86 -83.99 84.44 5.62 5.45 2.05-81.91

589.50 46.20 263.80 564.39 -12.93 -93.03 93.52 8.31 8.08 2.77-91.19

602.50 49.40 264.80 573.12 -13.89 -102.61 103.14 7.58 7.38 2.31-99.92

615.70 51.90 264.20 581.49 -14.87 -112.77 113.33 5.78 5.68 -1.36-108.29

628.90 54.30 262.70 589.41 -16.07 -123.26 123.86 6.10 5.45 -3.41-116.21

642.00 57.00 262.50 596.80 -17.46 -133.98 134.64 6.19 6.18 -0.46-123.60

655.10 59.30 261.70 603.72 -19.00 -145.00 145.71 5.49 5.27 -1.83-130.52

668.20 61.90 260.70 610.15 -20.74 -156.28 157.06 6.28 5.95 -2.29-136.95

681.10 64.30 260.20 615.98 -22.65 -167.62 168.48 5.68 5.58 -1.16-142.78

694.90 66.80 260.40 621.69 -24.77 -180.01 180.94 5.45 5.43 0.43-148.49

708.60 69.30 261.00 626.81 -26.82 -192.54 193.56 5.61 5.47 1.31-153.61

Start of Tangent @ 711m

711.00 69.41 260.96 627.66 -27.17 -194.76 195.79 1.38 1.31 -0.44-154.46

722.30 69.90 260.80 631.59 -28.85 -205.22 206.32 1.38 1.31 -0.44-158.39

736.10 69.80 261.10 636.34 -30.89 -218.02 219.19 0.65 -0.22 0.65-163.14


745.00 71.09 261.16 639.32 -32.18 -226.30 227.53 4.35 4.35 0.22-166.12

749.90 71.80 261.20 640.88 -32.89 -230.89 232.15 4.35 4.35 0.22-167.68

763.60 74.00 260.50 644.91 -34.98 -243.82 245.16 5.04 4.82 -1.53-171.71

777.40 76.90 260.50 648.38 -37.18 -256.99 258.42 6.30 6.30 0.00-175.18

791.20 80.00 261.00 651.14 -39.35 -270.34 271.84 6.82 6.74 1.09-177.94

805.00 82.90 261.20 653.19 -41.46 -283.82 285.41 6.32 6.30 0.43-179.99

818.80 85.60 262.00 654.57 -43.47 -297.40 299.06 6.12 5.87 1.74-181.37


831.07 86.85 262.99 655.38 -45.07 -309.54 311.26 3.90 3.07 2.41-182.18

832.50 87.00 263.10 655.46 -45.24 -310.96 312.69 3.90 3.07 2.41-182.26

Landing Pt @ 842m



Survey Report







Measured

Depth

(m)

Inclination

(°)

Azimuth

(°)

+E/-W

(m)

Vertical

Section

(m)

Dogleg

Rate

(°/30m)

+N/-S

(m)

Build

Rate

(°/30m)

Turn

Rate

(°/30m)

Survey

Vertical

Depth

(m)

Subsea

(m)

842.00 88.06 263.70 655.87 -46.33 -320.38 322.15 3.85 3.36 1.89-182.67

846.80 88.60 264.00 656.01 -46.85 -325.15 326.94 3.85 3.36 1.89-182.81

859.80 88.90 264.20 656.29 -48.18 -338.08 339.92 0.83 0.69 0.46-183.09

872.80 89.50 265.10 656.47 -49.40 -351.02 352.90 2.50 1.38 2.08-183.27

886.10 89.10 267.30 656.63 -50.28 -364.29 366.20 5.04 -0.90 4.96-183.43

899.20 88.40 268.60 656.92 -50.75 -377.38 379.29 3.38 -1.60 2.98-183.72

912.30 89.10 268.90 657.21 -51.03 -390.47 392.39 1.74 1.60 0.69-184.01

925.00 90.30 269.30 657.27 -51.23 -403.17 405.08 2.99 2.83 0.94-184.07

937.80 90.50 268.50 657.18 -51.48 -415.97 417.88 1.93 0.47 -1.88-183.98

951.00 91.10 269.20 657.00 -51.74 -429.17 431.07 2.10 1.36 1.59-183.80

963.70 90.50 268.90 656.82 -51.95 -441.86 443.76 1.58 -1.42 -0.71-183.62

976.80 90.80 267.90 656.67 -52.32 -454.96 456.86 2.39 0.69 -2.29-183.47

989.70 89.40 269.30 656.65 -52.63 -467.85 469.76 4.60 -3.26 3.26-183.45

1,002.90 89.60 269.90 656.77 -52.72 -481.05 482.95 1.44 0.45 1.36-183.57

1,016.00 89.30 271.50 656.89 -52.56 -494.15 496.02 3.73 -0.69 3.66-183.69

1,029.00 89.30 270.00 657.05 -52.39 -507.15 509.00 3.46 0.00 -3.46-183.85

1,041.90 89.30 270.10 657.21 -52.38 -520.05 521.89 0.23 0.00 0.23-184.01

1,054.80 89.30 269.30 657.37 -52.45 -532.94 534.77 1.86 0.00 -1.86-184.17

1,068.00 89.30 269.40 657.53 -52.60 -546.14 547.97 0.23 0.00 0.23-184.33

1,081.00 90.00 268.60 657.61 -52.83 -559.14 560.96 2.45 1.62 -1.85-184.41

1,093.60 91.10 270.10 657.48 -52.97 -571.74 573.55 4.43 2.62 3.57-184.28

1,106.80 91.60 269.60 657.17 -53.00 -584.93 586.74 1.61 1.14 -1.14-183.97

1,120.00 91.50 269.30 656.82 -53.13 -598.13 599.92 0.72 -0.23 -0.68-183.62

1,133.20 91.00 270.40 656.53 -53.17 -611.33 613.11 2.75 -1.14 2.50-183.33

1,146.20 91.60 271.00 656.23 -53.01 -624.32 626.08 1.96 1.38 1.38-183.03

1,159.10 89.40 272.00 656.12 -52.67 -637.22 638.95 5.62 -5.12 2.33-182.92

1,172.00 88.90 272.70 656.31 -52.14 -650.10 651.80 2.00 -1.16 1.63-183.11

1,185.10 88.70 271.50 656.59 -51.66 -663.19 664.85 2.79 -0.46 -2.75-183.39

1,198.30 89.60 271.10 656.78 -51.36 -676.39 678.02 2.24 2.05 -0.91-183.58

1,211.40 90.70 272.20 656.75 -50.98 -689.48 691.08 3.56 2.52 2.52-183.55

1,224.50 91.50 271.60 656.50 -50.55 -702.57 704.14 2.29 1.83 -1.37-183.30

1,237.60 91.10 271.70 656.20 -50.17 -715.66 717.20 0.94 -0.92 0.23-183.00

1,250.60 89.00 270.90 656.19 -49.88 -728.66 730.17 5.19 -4.85 -1.85-182.99

1,263.80 88.70 270.00 656.45 -49.77 -741.85 743.35 2.16 -0.68 -2.05-183.25

1,276.80 88.50 269.20 656.77 -49.86 -754.85 756.33 1.90 -0.46 -1.85-183.57

1,289.90 88.90 269.50 657.07 -50.01 -767.95 769.42 1.14 0.92 0.69-183.87

1,303.00 89.90 269.80 657.21 -50.09 -781.04 782.51 2.39 2.29 0.69-184.01

1,316.20 90.50 270.50 657.16 -50.06 -794.24 795.70 2.10 1.36 1.59-183.96

1,329.30 90.50 270.60 657.05 -49.93 -807.34 808.78 0.23 0.00 0.23-183.85

1,342.50 90.40 269.30 656.94 -49.94 -820.54 821.96 2.96 -0.23 -2.95-183.74

1,355.50 90.40 268.80 656.85 -50.16 -833.54 834.96 1.15 0.00 -1.15-183.65

1,368.50 90.40 269.90 656.76 -50.31 -846.54 847.95 2.54 0.00 2.54-183.56

1,382.20 90.20 270.80 656.69 -50.22 -860.24 861.63 2.02 -0.44 1.97-183.49



Survey Report







Measured

Depth

(m)

Inclination

(°)

Azimuth

(°)

+E/-W

(m)

Vertical

Section

(m)

Dogleg

Rate

(°/30m)

+N/-S

(m)

Build

Rate

(°/30m)

Turn

Rate

(°/30m)

Survey

Vertical

Depth

(m)

Subsea

(m)

1,396.00 90.50 270.90 656.60 -50.02 -874.04 875.41 0.69 0.65 0.22-183.40

1,409.80 91.00 271.20 656.42 -49.77 -887.83 889.18 1.27 1.09 0.65-183.22

1,423.40 90.90 270.00 656.20 -49.62 -901.43 902.75 2.66 -0.22 -2.65-183.00

Last Survey @ 1426m

1,426.00 91.10 270.20 656.15 -49.62 -904.03 905.35 3.26 2.31 2.31-182.95


1,441.00 91.10 270.30 655.86 -49.55 -919.03 920.33 0.20 0.00 0.20-182.66

Target Name

- hit/miss target

- Shape

TVD

(m)

Northing

(m)

Easting

(m)

+N/-S

(m)

+E/-W

(m)

Design Targets

LongitudeLatitude

Dip Angle

(°)

Dip Dir.

(°)

W/H 10-1 -92.51-1.110.00 -836.16 5,529,100.51 353,246.450.00 49° 53' 46.60 N 101° 2' 36.21 W

- survey misses target center by 659.28m at 1363.19m MD (656.80 TVD, -50.28 N, -841.23 E)

- Point

Heel (12C-6) 10C-1 -45.68656.200.00 -319.55 5,529,133.31 353,764.140.00 49° 53' 48.12 N 101° 2' 10.33 W


- Point

BHL (12C-6) 10C-1 -41.72657.200.00 -919.43 5,529,153.54 353,164.580.00 49° 53' 48.24 N 101° 2' 40.39 W


- Point

Measured

Depth

(m)

Vertical

Depth

(m)+E/-W

(m)

+N/-S

(m)

Local Coordinates

Comment

Survey Annotations

146.00 146.00 0.00 0.00 Surface Casing @ 146m

344.00 343.99 1.83 0.60 KOP @ 344m

711.00 627.65 -27.17 -194.77 Start of Tangent @ 711m

745.00 639.36 -32.17 -226.29 End of Tangent @ 745m

831.07 655.47 -45.06 -309.51 Cross Hard Boundary @ 831.1m (Approximate)

842.00 655.96 -46.33 -320.35 Landing Pt @ 842m

1,426.00 656.24 -49.62 -904.00 Last Survey @ 1426m

1,441.00 655.96 -49.56 -918.99 Extrapolation to Final TD @ 1441m

Approved By:Checked By: Date:


New Well Summary - Horizontal

Licence: 9680 Well Name & Location: Corex Virden HZNLT 10-01-11-27 WPM (as noted on well licence) Elevations: Surface Location: 12-C-6-11-26W1 WPM Ground Elev: 469.8 Cut or fill: -.91 Engineer: Dave Shubert With: Corex Resources Revised GE: 468.89 Phone: 306-660-7123 Email/Fax: [email protected] Rig K.B.: 4.3 Push: Clint Newbyt Rig Name: Precision 205 and Number Well KB: 473.19 SPUD DATE & TIME: 12/10/2013 @ 2000 hrs. IE & M notified? Yes SURFACE CASING: IE & M Notified? Yes Surface TD: 146.5m Casing run: 11/12/2013 # of Joints: 13 Size: 244.5mm Weight: 48.07kg/m Grade: H-40 Landed at: 146.5m Cement: 12t of TSC1700 & 3 % CaCl2 Returns: 3m3 Plug Down: 0650 hrs Cement Co: TRICAN. INTERMEDIATE/PRODUCTION CASING: IE & M Notified? Yes TD Date: 14/12/2013 TD: 1441.0 m Casing run: 15/12/2013 # of Joints: 109 Size: 114.3/139.7mm Weight: 17.26/23.07kg/m Grade: l-80 Landed at: 1441.0m Fill: 18t of titanium 1400(_75 % excess) Tail: 20t of T.A.C+ 30% excess Calc. Cement Top: 0 m Cement Co: Trican Returns: 7m Plug Down: 09:00 hrs Frac Ports Used: No Frac Port Type: # of Frac Ports: FIRST LEG: Date: 13/12/2013 Kick-Off Point: 847m TD Date & Time: 14/12/2013 @ 2000hrs TD: 1441.0m TVD: 655.96m Bottom Hole Co-ordinates: 919.00 m West of Surface LSD 49.56 m South Misc. Details:

LINER DETAILS: IE & M Notified? Yes LINER HUNG: No LINER CEMENTED: Yes Liner run: / / # of Joints: Size: mm Weight: kg/m Grade: Liner Top: m MD Liner Bottom: m MD Fill: t of Tail: t of Calc. Cement Top: m Cement Co: Plug Down: hrs Packer Depth: 1. m MD 2. m MD

SECOND LEG: Date: / / Kick-Off Point: m TD Date & Time: / / @ hrs TD: m TVD: m Bottom Hole Co-ordinates: m West of Surface LSD m North Misc. Details: LINER DETAILS: IE & M Notified? Yes LINER HUNG: Yes LINER CEMENTED: Yes

Liner run: / / # of Joints: Size: mm Weight: kg/m Grade: Liner Top: m MD Liner Bottom: m MD Fill: t of Tail: t of Calc. Cement Top: m Cement Co: Plug Down: hrs Packer Depth: 1. m MD 2. m MD

Submit Directional Surveys with tours Fluid Loss: NO Volume: Depth: Displacement Fluid: Bridge Plug Set at: m Rig Release: 15/12/2013 @ 1200hrs Well Status: Drilled & cased (Waiting on Service Rig or Plugged & Abandoned Dry) Rig Moving To: 4-30-9-28W1 Lic # 9658 Weekly Report: / / @ 0800: . (Date) IE & M – Petroleum Branch – Virden (204)748-4260 - Fax (204)748-2208 Waskada (204)673-2472 – Fax (204)673-2767 Email: [email protected] Remarks: Final report Tours Sample Well Check: / /

Z:\_MB_Project\_Data_to_do\ELECTRONIC\D_Manual_Verify\D_9680__521.doc Revised: February 4, 2013

mailto:[email protected]

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Fd. MGSPIn Conc

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13 14 870.723 Fd. MGSP.AZ = 91'21'30e In Conc.

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SEEDETAIL

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SITE PLAN0 25 50 75 700 150 200 m

SCALE- 1:5,000

GrainElevators Site

Fd. MGSP.i

Plan Showing Survey of

I/4 Line

11 -26WPM

CORKXVIRDKNPROV HZNTL 10-1-11-27&PMUWI: COREX VIRDEN PROV HZNTL 102.10.01.011.27WPMWell Site and Access RoadTerminus: 10C-1m11-27WPMWell Site Surface LocationL.S.12C Sec.6 Twp.11 Rge.26 WPMR.M. of Wallace

I certify that the survey represented by this planis correct to the best of my knowledge and wascompleted on the 3rd day of May, 2013.

- Is at least 1.5 km. from the Corporate Limits of a City,Town or Village ja ~

—Is at least 75 m. from any shoreline px ~- Is at least 75 m. from any Surface Improvements- Is at least 45 m. from any Surveyed Road px p- Is at least 75 m. from any Aircraft Runway or Taxiway PX P—Is at least 75 m. from any Water Well—Approximately 6.7 km. from the nearest Urban Centre (Virdsn)- Approximately 0.7 km. from the nearest Residence (SE'/ I-11-27WPM)

Manitoba La d S

Azimuths are NAD 83 (Zone 14) UTMAll distances shown are horizontal and at ground level.Combined Scale factor derived = 0.999787

AREAS: HECTARES ACRES

Well Site 1A40 3BI8Access Road 0.279 0.69Total 1.719

CERTIFICATEOF TITLE:NW 6-11-26WPM CT No. 1565003/2Louis Dreyfus Canada Ltd.

425

OPERATOR:

COREX RESOURCES LTD,

Elevation on ground at well location = 469.81Datum. Elevations shown are referenced to the Provinoe

of Manitoba Mon. 82R746 Vertical Geodetic DatumCGVD28.

NTS Sheet: 62 F/14

Client File No 4 AFE No

Altus Geomatics ~Manitoba LD'/9

REV. Revision: Revised Hot'izontal Leg

Date: Oct. 4, 2013 Job Noz 163863-V

File: 163863W-R11

Initials: DH - CMF- BMToll Flee. Baoteessszss llltlesl

wwwmls metioemo.oom

Legal Survey Posts (found / planted) ---————-—----—--~Planted iyood Hub—Surveyed Well Centre -------0 Produoel'- —~standing well---------——-e Abandoned producer--+Injection well (Former producer) st Abandoned Dry- —4FAbandoned Water Injection —---th Injection Well-- BZSurface Location - Horizontal / Directional / Slant- —--———x-Portions referred to outlined thus ————---—--——Distances are in metres.

/m/ to

acuainollV (Mggt) pact/ iueiuutexo5 9/ I 09pact/ IeAe/5 epw5 wnlpeMI—M—M—M—M—M—M—M—M—M—Mt

—M—M—M—M M—M—M—M—M—

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(Kyl) woce/e2 pe//ng

I I tr8890 0 0 ),.9Ehg.t =ZV 0—ZZ ™2—0—

2/8893 I-28 teeseO Szyt naZ I.

Uwh COREX VIRDEN PROV HZNTL 102.10.01.011.27WPMFacihties shown on this plan are for informational purposes only.prior to any construction on lease or access road, COREXRESOURCES LTD„MTSCommunications Inc., Manitoba Hydro,and Manitoba Hydro/Gas Operations MUST be contacted forlocation of any underground facilnies that may exist.

Client File Nou AFE NouREV. Revision: Revised Horizontal Leg

Date: Oct. 4, 2013

File: 163863W-R11

Job Nou 163863-V

Initio/s: DH - CMF- BM

COREX VlRDEN PROV HZNTL 10-1-11-2TWPM

30.1 5 edi rnGr eG vel oad

Buried Water Line in VicinityOperator. RM of Wallace

Gove nment Road (6 N) Allowance 30.175 Undeveloped Government Road (61N) Allowance 30.175

18.88

e Ore

IV co L,o

~ o Lv

tv I

0'.

Bottom Hole(10C-I)0—

//////////////

//////////

15 16

271 55'55"

599.90

Abnd

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tv'lcc0

Cl

NZ

CIo

Fd. 0.025 ., „-—L ~——15 16Sq.l.B AZ = 271 38'35"

20m MTS Caveat 1175506/2

F(I. MGSPIn Conc

Road Plan34476- BU.O.

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14

165 60I"3 3630,I

I Low Areal 6', (Dry),'o

IQP2 ( / Seasonal

Drainage

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WELL SITE PLAN0 25 50 25 100 t50 200 m

SCALE- 1:5,000

GrainElevators Site

870.723 Fd. MGSP.13 14 AZ = 91 21'30" in Conc.

dlc

11 -27WPM1/4 Line

COREX VIRDEN PROV HZNTL 10-I-11-271VPM A Date: Oct. 4, 2013REV.~UWI.'OREXVIRDEN PROV HZNTL 102.10.01.011.27WPM ~t File: 163863W-R1

Fd. MGSP.P~

Ii

Job Non 163863-V

Initials: DH - CMF - BM

1/4 Line11 -26WPM

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SHEET 4 of 4

coreresources

33

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0 HOSPITAL

Q LIFE FLIGHT EMERGENCY SERVICE

~256 SECONDARY HIGHWAY

2 PRIMARY HIGHWAY

~44N MUNICIPALROAD

TRANSCANADAHIGHWAY

SURFACE DEVELOPMENT0 250 500 1000 1500 2000 2500 m

SCALE - 1:50,000

NOTE:Residences are shown thus: -------—~

ROUTE MAPNOT TD SCALE

VIRDEN

~QQ

RlNN~ilil~mjl~LOCAL

SEC.NAD 83

POWER LINE DETAILNot to Scale

CrossingLocation

~SM.PK~AIIIliiIIIIISIIil~k@N%iNAD 27

N/S

SURFACE (12D-6) 467.94 S of N 194A5 E of W

CASING POINT (9D-I) 513.00 S of N 94.91 W of E

BOTTOM I-IDLE (10C-1) 510.00 3 of N 694.80 W of E

U. T. M.

5529170.305 N354084.810 E

5529133.320 N353764.207 E

5529153.535 N353164.779 E

GEO.

49 53'49.597"101'01'54.313"

49'53'48.1 1 8"

101'02'10.323"

49'53'48.244"101'02'40.378"

U. T. M.

5528950.39T N

3541 13279 E

5528913.412 N

353792.676 E

5528933.626 N

353193249 E

GEO.

49 53'49,593"101'01'52.647"

49'53'48.1 14"

1 01'02'08.656"

49'53'48.240"101'02'38.71 0"

~<"'"'IIIIikI',~'"K"iwsw:,. ~~~~mLI~"~~"~ai"IiiyI~)g)II('IIiIIIIIII'%gR~W'av'i"(IIIII

CASING POINT

BOTTOM HOLE

RE. 100/10-1 Vertical

Abnd. 100/16-1 Vertical

N/S

36.99 South

16.77 South

69.80 South

231.01 North

NAD 83

320.67 West

920.23 West

838.36 West

466.85 West

N/S

45.68 South

41.72 South

92.51 South

21827 North

True North

319.55 West

919A3 West

836.16 West

472.95 West

of surface Location

of surface Location

of surface Locatlorl

of surface Location

- NAD 83 distances shown are cartesian referenced to UTM GRID, NAD 83, ZONE 14

- True North distances shown are cartesian referenced to True North (Grid Convergence = -1.5541 ) Uwb COREX VIRDEN PROV HZNTL 102.10.01.011.27WPM

CORKXVIRDKNPROV HZ)(/TL 10-1-11-2'AVPMClient File No AFE NoREV. Revision: Revised Hodizontal Leg

Date. Oct. 4, 2013 Job Non 163863-VFile: 1 63863W-R1

1Initials: DH - CMF - BM

Plan Showing Photo Mosaic of

CORKXVIRDEN PROV HZNTL 10-1-11-27%PMfrom a Surface Location in

L.S.12C Sec.6 Twp.11 Rge.26 &PMUWI: COREX VIRDEN PROV HZNTL 102.10.01.011.27WPM

Photo Date: 11/05/2012 WELL SITE PHOTO PLAN0 50 100 200 300 400 500

SCALE - 1:10,000

Client File No AFE No

Altus Geomatics QManitoba vsse

REV. Revision: Revised Horizontal Leg

1

Date; Dot. 4, 2013 Jolt Noc 163863-V

File: 163863W-R1 Initials: DH-CMF-BM

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp

Drill Actual Reaming Coring Cond Mud

& Circ Trips Rig Service

RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack

Squeeze Cement Fishing Dir

WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total

DAILY CHECKS OP RM1) Daily Walk Around Inspection2) Detailed Inspection - Weekly (Using Check List)3) H2S Signs Posted if Required4) Well Licence & Stick Diagram Posted5) Flare Lines Staked6) BOP Drills Performed7) Visually Inspected BOPs - Flare Lines & Degasser Lines 1) Rig Site Health & Safety Meeting (one/crew/month)2) CAODC Rig Safety Inspection Checklist (one/rig/month)3) Mast Inspection before Raising or Lowering4) Crown Saver Checked5) Motor Kills Checked

Kelly Bushing Op Fuel

FUEL @ 08:00 HOURSRig Boiler

WE

AT

HE

R Time Temp

Current Conditions

Wind Direction Wind Strength

Road Condition

FRONT PAGE SUMMARYTour Sheet Serial Number Vendor Software Version Year Month Day

Well Type Re-Entry

Spud Date Time

Rig Release Date Time

License No Well Name Surface Location Prov Loc Type Unique Well Id

Contractor Rig No

Contractor’s Job No

Signature of Contractor’s Rig Manager

Operator

Operator’s AFE

Signature of Operator RepresentativePason

TOUR 1 SIGNATURE OF DRILLER START TIME END TIME

Remarks:

TIME LOGFrom To Elapsed Code Details of Operations in Sequence & Remarks

SAFETYSafety Topic MEHL MACP



MUD MATERIALS ADDEDProduct Amount Type

SOLIDS CONTROLEquipment

NameHours Run

Intake Density

Over Flow Density

Under Flow Density

DEVIATION SURVEYSTime Depth Deviation Direction Type

BoilerBoiler # Hours Run pH Stack Temp

V. 1.3

Remarks:



Remarks:



CUTTING STRUCTURETI Gage

TO ODC

MDC Reason Pulled

LOC Total Run (m/hr)BRG

DRILLING ASSEMBLYNo Component OD ID Length

Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal

Weight of DCWeight of String

BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today

Cumulative Hrs RunEntry Date

METRES DRILLEDFrom To D-R-C RPM WOB REDUCED PUMP SPEED

Pump No. Pressure Strokes/min Depth

@ @

@ @

@ @

MUD RECORDMud Type Water Oil

Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT

CIRCULATIONPump# Type Liner Size SPM Pressure Hours Run

Remarks:

HOLE CONDITIONHole Drag Up Down

Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



58

08:00

0

VISUALLY INSPECT, TOP DRIVE, PIPE ARM, IRON ROUGHNECK, SLIPS, PINS, DIES, DOG COLLARS, ANDLINKAGES

349

90

1.00

9680

4

120

19:15

0.25

2112:00

37m

1

20:00

17:00

8.00

23:45

2.75

0

1.00

4.75

135

BELL SUB

CN

3800.00

6M

12

DEVIATION SURVEY/ WORKING STRING / MAKING CONNECTIONS

10

12.00

23:45

1 of 1

1.4298m

CN

0

0

CN

0.25

DRILL

FAIR

19:15

handling drill collar

d13-vir-04

AR

20:00.28

PRE MOVE SAFETY MEETING

CN

Adam Russell

RIG UP START UP BOILER STEAM MUD MOTOR

320

CN205

7

0.25

CNCN

1A

BIT

127

0

9.40m

4500.00

1.63

349

0.25

AR

0m

DLSCorex Virden Hz (12c-6) 10-01-11-27 w1m

17:00

AR

162

0

CLINT NEWBY

Pason

1

1

1.75

AR

1

DC (8.00 IN)

20:00

19:30

31.00kdaN

2.75

OVERCAST

0

0

2.00

7

0.37m

12kdaN

2

-25.00

6.75

DANA GOERTZEN

127

PRE SPUD SAFETY MEETING AND HAND OVER SAFETY MTG

0Y52205_20131210_2A

1

65.75m

146m

7140.00

20:00

RIG SERVICE

1.00

102/10-01-011-27W1/00

SE

58

19:30

1A

0.25

00:00

2013

SAFETY MEETING ON PICKING UP BHA

0

DC (6.25 IN)

21

2

FUNCTIONED CROWN SAVER, PIPE ARM LOCKOUT, AIR HORN

10

DRILL FROM 0 M TO 146.5 M

COREX RESOURCES LTD.

0

12:15

0.25 4.00

125m

CN

CN

4

0.00m

24:00

19:00

0

PRECISION DRILLING, DIV OF PDC

6kdaN

CLINT NEWBY

CN

2013/12/10 20:00

MOVE RIG

0

CN

22:45

127

1.00

0.00m

0

0

21kdaN

6.75

.87

58

19:00

MB

162

MOTOR 8"

HORIZ

AR

0.50

5

0.25

9.5

UP TO 19 KM/H

CN

198

SCOTT COLLEY

22:45

162

12:15

AR

1

109

1

AR

2.75

1.00

08:00

2

109

12-06-011-26W1

61.87m

0kPa

0.25

234

SMITH

5400.00Nm

146.50m

4.30

0.00m

9.5

PICK UP BHA

06:00

21

8.50m

0.61m

.87m

6200

1

24:00

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



83

SHAKER

08:00

CONDITION MUD & CIRCULATE

VISUALLY INSPECT, TOP DRIVE, PIPE ARM, IRON ROUGHNECK, SLIPS, PINS, DIES, DOG COLLARS, ANDLINKAGES

42.4

SHAKER

58

35

222

0.75

2.50

17:45

9680

11.1

2.00

4

2.00

12:15

02.75

02:45

7

13

02:00

21

11.1

08:000

1

73

11.1

185.5m

02:00

1408:30

7

12.00

21

20:30

0.37m

SHAKER

SAFETY MEETING W CEMENTCREW

2.75

325

GAP SUB

73

FUNCTIONED CROWN SAVER, PIPE ARM LOCKOUT, AIR HORN, AND FLARE STACK IGNITOR

24:00

00:00

1720

9.18m

03:45

WAIT ON CEMENT

01:00

0.50

2C

0.25

DC (6.25 IN)

1

sacks

1.25

135

0

07:45

NM FLEX DC

15:30

6A

07:00

SHORT NM FLEX DC

83

CN

320

TRIP OUT OF HOLE

BIT

11.1

21

2250.00

15A83

29.27m3

12

23

TRIP IN HOLE

BOP DRILL CREW IN POSITION IN 91 SECS

11

24.00

HANDLE DIRECTIONAL TOOLS

20:30

0.75

1

05:45

160

RUNNING CASING W CASING SUB

CENT 1

1 of 3

0.5328.7m

CN

135

298.97m

CN

0

0.25

FAIR

DRILL

17:30

12:15

15:15

d13-vir-04

BOP DRILL

AR

20:001

RIG SERVICE

9.5m3

58

Adam Russell

CN

69s/l

CUT CASING, WELD ON FLOAT SHOE, CASING BOWL, NIPPLE UP BOPS.

5

325

21kdaN

CN

1.50

x

18:00

205

146.5m

12221324

1A

153

SHORT NM DC

1

73

FX54R

NM DP NM FLEX DC

10

1

1

0.25

1

0.50

18:30

CN

1

CN

2

RIG UP TO RUN CASING

58

349

BIT

12kdaN

5

127

11.1

44.72m

5400

4.14m

4500.00

GAP SUB

4.14m

200

0.25

1

11.1

01:00

21

1.75

SLIP/CUT DRILLING LINE

AR

00:00

146m

2013/12/11

06:00


11.1

08:30

AR

DC (8.00 IN)

2013/12/11

154

163

3.75

1100

PRESSURE RATING OF 21000KPA, PRECHARGE 7000, PRESS BEFORE TEST 19250,

DANA GOERTZEN

Pason

1

03:00

164

1

1

2.75

200

AR

73

1

FUNCTION HORN, CROWN SAVER, ENGINE KILL.

SAFETY MEETING TO PICK UP BHA

SHORT NM DC

6kdaN

20:00

0.59m

6B

1.00

162

0.25

24.00kdaN

OVERCAST

9.15m

0.25

NM FLEX DC

BIT

0

8

BOP DRILL

3.50

0.25

2

0.750.00m

3.00

0.59m

4

0.25m

0kPa

pail

6kdaN

sacks

150

7

9.18m

349

2.00

0.5065.75m

-25.00

21

0.25

DANA GOERTZEN

22:00

18:30

164

21A

Bentonite

RUN CASING . Ran 13 jts of 244.5mm , 48.068kg/m , H40 . Total csg 147.5m ,

6kdaN

0.00

127

STABBING VALVE, ISBOP, CASING, CASING BOWL, CHOKE LINE, ALL MANIFOLD VALVES

1

0Y52205_20131211_1A

0.75

2Shale sperse


9.15m

343m

0.25m

22:45

150

SAFETY MEETING TO SLIP/CUT

5100.00

146.50m

3.50

20:00

9.40m

29s/l

1000

07:45

61.87m

SHAKER

28.00kdaN

DRILL FROM 146 M TO 343 M.

8.93m

0

83

0.25

17:30 20D

3.00

102/10-01-011-27W1/00

0.50

20:00

SE


CEMENTING . Pumped 12t of TSC 1700 @ 1700 kg/m . Displace with 5.8 m3 of

11.1

02:30

120

12

83

14:00

21

9A

0.25

00:00

11.1

0.00m

SAFETY MEETING TO PRESSURE TEST.

2013

0.75

02:30

0.00m

0.25

1

SMITH

2

NM DP NM FLEX DC

01:30

11.1


2

TRIP OUT OF HOLE/ INSPECT BIT00:30

CHECKED BOP MANIFOLD VALVE ALIGNMENT, FLARE AND DEGASSER CONNECTIONS AND UNIONS

32.96m3

21

4

RIG SERVICE

160

21

0.00m


0

3.50

5

MOTOR 8" 6B

8.00

. Plug down @ 06:52 hr

6.9

11.1

2.00

156

1

18:00

0.25

08:15

1

HWDP(4.5 IN)

2.00

4.00

SAFETY MEETING/CREW CHANGE.

CN

03:00

163

1.75

CN

47s/l

12

0.00m

RECHARGE TIME 1 51S, PRESSURE AFTER 3 FUNCTIONS 11750. N2 2450 KPA, 2400KPA

23:15

73

12:00

7.41m3

03:45

1030

95

146.50m


15A

0.00m

15:15

10kdaN

0.50

SHORT NM FLEXDC

200

CLINT NEWBY

CN

2013/12/10 20:00

1030

SAFETY MEETING TO NIPPLE UP BOPS.

0

06:00

CN

20:15

127

17:45

73

1.50

0.00m

46.5

5

0.25

BOP DRILL

23:15

3.00

58

162.07m

6kdaN

14:00

0.4

83

12:00

1

MB

0.75

29s/l

154

1

1

NM FLEX DC

1

163

MOTOR 7/8-4.8 STAG

x

11.1

V.I. DRILL LINE, TOPDRIVE, BRAKE LINKAGE, PIPEARM, APACHE, SLIPS, DOG COLLAR, LOADER.

1030

01:30

HORIZ

1

AR

251.27m

2.75m

0.25

0.75

V.I. BOPS, CHOKE LINE, MANIFOLD ALIGNMENT, FLARE/DEGASSER LINES AND UNIONS, FLARE TANK, LOAD LINE.

19:15

11.1

0.75

12

0

1.75

1

Polyplus

7.90m

1

UP TO 19 KM/H

12221324

9.5

CN

160

SAFETY MEETING PRIOR TO RUNNING CASING

20:45

SCOTT COLLEY

20:15

153

11.1

9

08:15

AR

15:30

18:15

WORKING PIPE, CIRCULATE AND CONECTION TIMES

BELL SUB

146

1

5

04:30

109

07:00

1

TO A LOW 1400KPA, HIGH 7000KPA FOR MIN 10 MIN EACH.

AR

0.25

5

DRILL CEMENT/DRILL OUT CEMENT/DRILL FLOAT&SHOE

0

3.50

00:30

NM FLEX DC

02:45

SECURITY

08:00

2

11.1

109

12-06-011-26W1

146

TRIP IN HOLE

0

X/O FLOAT SUB

0.25

0

0.00m

water . 3 m3 of good cement returns . Bump plug , hold for 5 min , plug held

FX54R

162

0.25 SAFETY MEETING/CREW CHANGE

2.00

6A

0.75

0.75

156

landed @ 146.5

1167kPa

1

0.25

SECURITY

234

5400.00Nm

20:00

0.75

343.69m

0.00m

4.30

VISUALLY INSPECT, TOP DRIVE, PIPE ARM, IRON ROUGHNECK, SLIPS, PINS, DIES, DOG COLLARS, AND LINKAGES

8.93m

45

23:45

X/O FLOAT SUB

12A

PRESSURE TEST ANNULAR, PIPE RAMS, BLIND RAMS, KLVX3, HYD/MAN HCR VALVES,

9

11.1

05:45

1.83m

109

162

06:00

pail

0.61m

1.83m

21

0.50

7.90m

19:15

0.75

222

2.75m

289.4m

4600

198 8.50m

MOTOR 7/8-4.8STAG

1

422

24:00

18:15

08:00

1

Sawdust

160

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1

Type (Ex: Chlorides)

Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS

TOUR MUD TYPE WATER OIL OTHER

Pason

MUD SAMPLE - ADDITIONAL DATATour Sheet Serial No Vendor Software Version Year Month Day


Operator

Operator’s AFE

Signature of Operator Representative

Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

CLINT NEWBY

7.41m3

DLS

2013/12/10 20:00

Adam Russell

Corex Virden Hz (12c-6) 10-01-11-27 w1m

2 of 3

9680 12-06-011-26W1

HORIZ

102/10-01-011-27W1/00

9.5m3

146.5m


00:00

146.50m

205

69s/l

1

Pason

GEL

0Y52205_20131211_1A

04:30

x


234

SHAKER

d13-vir-04

12

47s/l

2013

SHAKER

11

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

CLINT NEWBY

32.96m3

DLS

2013/12/10 20:00

Adam Russell

Corex Virden Hz (12c-6) 10-01-11-27 w1m9680

3 of 3

29s/l

12-06-011-26W1

31.91m3

23:45

1030kg/m3

HORIZ

102/10-01-011-27W1/00

29.27m3

251.27m


331.35m

20:00

SHAKER

162.07m

205

29s/l

3

1030kg/m3

Pason

floc

1030kg/m3

0Y52205_20131211_1A

22:00

x


234

SHAKER

d13-vir-04

12

29s/l

2013

SHAKER

11

MB

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



SHAKER

08:00

35

222

10.00

264.2

9680

11.1

0

19:30

7

07:30

1

11.1

07:30

1

13:00

576.5m

12.00

GAP SUB

73

VISULAY INSPECT BOP STACK, CHOKE LINE, FLARE AND DEGASSER LINES, FLARE TANK AND LOAD LINE

1060

23:45

10:3057

00:00

9.18m

628.9m

SINGLE

Soda ash

651.40m

120

2

83

0.25

11.1


262.4

5500.00

21A

367.5mSLIDE TIME

DRILL FROM 792M TO 847M

NM FLEX DC

52.00kdaN

CENT 1

1 of 6

870

CN

818.8m

73

135

651.40m

369

0.25

0

9.18m

FAIR

DRILL

sacks

0.00m

DRIVING IN WINTER CONDITIONS

AR

20:00

11.1

328.4

80

RIG SERVICE, FUNCTION ANNULAR 8 SEC. TO CLOSE

83

CN

578m

00:15

12kdaN

11.1

12221324

1

FX54R

35

NM DP NM FLEX DC

Shale sperse

1

1

X/O FLOAT SUB

0.5

sacks

02:00

1

2

SAFETY MEETING / CREW CHANGE

45

127

11.1

792.40m

4.14m

CENT 1

GAP SUB

4.14m

1

578m

792.40m

DLS

DIRECTIONAL SURVEYS

11.1

AR

3

SHORT NM DC

419.4m

163

2.25

Pason

1

164

1

11.1

AR


SHORT NM DC

19:45

163

OVERCAST

54.3

12

NM FLEX DC

BIT

0

164

5.25

2

792.40m

sacks

9.18m

0.75

59.3

DANA GOERTZEN

22:00

CENT 1

18.00

127

1

0Y52205_20131212_1A

50

1

847m

10:00

150

21:00

12221324

13200.00

18500.00Nm

20:00

4.14m

SINGLE

46s/l

42.7

1090

0.00m

8.93m

0

10

15.9

2

00:45

262.7

0

83

2

0.25

11.1

00:00

11.1

96.28m

DRILL


2

14cm3

11

2

21

06:45380.7m

11.1

58

DRILL FROM 343 M TO 578M

FUNTION TEST CROWN SAVER, PIPE RAMS CLOSED, ANNULAR CLOSED, HCR OPEN, ENGINE KILLS, FLARE STACK IGNITIOR

589.5m

160

RIG SERVICE

0.00m


0

5

Desco

8.00

261

0.25

0.25

NM FLEX DC

1

259.1

10.00

163

1080

8.00

CN

1000

11.1

23:30

73

18:15

1.83m

134

sacks


58

0.00m

10kdaN

343m 10kdaN

819

Enerpac reg.

CN

1475

08:15

20:15

1.25

127

276.5

0.50

1080

4

642m

42kdaN

0

82.9

18:15

08:00

1

1

NM FLEX DC

1

163

x

MOTOR 7/8-4.8 STAG

46.2


06:45

AR

2.75m

11.10.25

1

12221324

9

02:30

160

13.9

11.1

10


163

SHORT NM FLEXDC

0

23:45

11.1

45

5

657

08:00

7

09:30

146

0

X/O FLOAT SUB

7

FX54R

3.3

156

847.54m

8.93m

22:15

11.1

109

sacks

06:00

1100

262.6

5400.00Nm

160

1030

sacks

222

2.75m

4957

160 7.90m

MOTOR 7/8-4.8STAG

1

1632

Polyplus

44s/l

83

RIG SERVICE

261.2

SHAKER

VISUALY INSPECT TOP DRIVE, PIPE ARM, APACHE, DRIVE LINES AND BREAK LINKAGES, SLIPS, DRILLING LINEAND LOADER

83

1.00

4

1

08:00

1.75

11.1

08:000

73

9

791.2m

150

2

20:00

9cm3

1

SHAKER

0.25m

21:45

3.25

320

262.5

1680

Humalite

0.25

03:45

432

4.75

11.1

NM DP NM FLEX DC

1

268.8

pail

0

20A

NM FLEX DC

SHORT NM FLEX DC

CN

256

MAN DOWN DRILL DISCUSS SITE ERP

BIT

73

341.6m

2013/12/11

83

36.45m3

5

602.5m

50

12

7

12

SHAKER

24.00

0.00m

21:45

6.50

1

160

85.6

CN

08:00

19:30

HWDP(4.5 IN)

d13-vir-04

723

SHAKER

33.31m3

Adam Russell

29s/l

SLIDE TIME

7

655.1m

CN

x

205

467.12m

644.13m

2

153

SHORT NM DC

73

6

1100

1

1

01:15

0.75

CNCN

58

6kdaN

222

BIT

1750

3369

1496.00

Soda ash

sacks

200

11.1

03:45

1

0.25

AR

41

02:00

2013/12/11


13:00

2013/12/11

154

6.6

11.1

2

7200

49.4

DANA GOERTZEN

1

20.00

200

0.59m

73

1

12kdaN

20:00

0.59m

21A

848

393.7m

53.00kdaN

0.25

9.15m

1096kPa

163

8

DRILL

525

0.25

HWDP(4.5 IN)

0.00m

0.59m

4

0.25m

6kdaN

257

150

7

200

9.15m

-25.00

0.25

263.8

164

09:15

Enerpac reg.

6kdaN

SAFETY MEETING / CREW CHANGE

1

6Enerpac lo vis

9.15m


0.25m

pail

10:00

578.00m

43s/l

SHAKER

SLIDE TIME

6

83

1.50

24:00

264.8

102/10-01-011-27W1/00

3.50

SE


11.1

07:45

19:45

1030

156

30.17m3

2013

0.00m

07:45

0.25

11.1

SECURITY

NM DP NM FLEX DC

268.6

6

35.20m3

00:15

2

4

MOTOR 7/8-4.8STAG 2

11.1

354.5m

156

1

08:15

HWDP(4.5 IN)

4.00

Caustic Soda

CN

1

29.88m3

2

36s/l

8.93m

33.99m3

73

1105

401.26m

SHORT NM FLEXDC

8

615.7m

3.00

CLINT NEWBY

2013/12/10 20:00

45

00:00

1105

DRILL FROM 578M - 792.40

0

CN

578.47m73

262

0.00m

8

0.25

BOP DRILL

23:30

x

0.75

83

1690

790.22m

83

1

MB

154

50s/l

1

6.50

45

11.1

1100

HORIZ

1

813.17m

sacks


0.50

11

01:30

1

7.90m

UP TO 19 KM/H

CN

FX54R

1

KYLE WILKINSON

20:00

565

20:15

153

AR

08:15

30

533.28m

146

1

04:00

9

5kdaN

1

AR

51.9

0

19.75

00:15

NM FLEX DC

SECURITY

406.3m

11.1

109

12-06-011-26W1

146

151.42m

08:45

154

GAP SUB

0.25

1067kPa

1

1.25

SECURITY

234

261.7

11500.00Nm

20:00

0.00m

4.30


45

X/O FLOAT SUB

21

1

BOP DRILL, WELL SECURE IN 90 SEC.

1.83m

Humalite

153

sacks

2.75m

1.83m

5

0.25

7.90m 805m

1

24:00

160

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



08:00

261

1.00

10.00

9680

29.3

260.4

03:45

102/10-01-011-27W1/00

261

668.2m

12.00

3.25

00:00

15:15

2013

69.9

0.25

260.8711m

261.5471.8m

261.2

681.1m


8.00

0.25

0.25

445.9m432.7m

0.25

261.3261.8

458.8m

694.9m

4.00

12 12

52.00kdaN

24.00

6.50

2 of 6

0.25

11:15


d13-vir-04


708.6m

257.7

CLINT NEWBY

2013/12/10 20:00

Adam Russell

02:45

12:00

03:15

1.25

259.7

0.50

736.1m

0.25

205

BOP DRILL

0.75

722.3m

MB

04:00

0.75

64.3

17.6

HORIZ

05:00

0.50

04:30

05:15

KYLE WILKINSON

27.4


24.4

510.9m

21.7

2.25

DANA GOERTZEN

66.8

Pason

25.9

69.3

19.75

20:00

08:00

497.8m484.7m

13:45

12-06-011-26W1

53.00kdaN

69.9

1096kPa

12:45

19.5

1067kPa

234

261.1

259.9

69.8

DANA GOERTZEN

260.2

13:30

260.7

0Y52205_20131212_1A

14:15

20:00

24:00

61.9

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



08:00

10.00

1.00

260.5

9680

260.5

06:45

102/10-01-011-27W1/00

745m

12.00

3.25

00:00

2013

0.25

261.7563.3m

259.9

749.9m


8.00

0.25

0.25

537.2m524m

0.25 4.00

550.3m

763.6m

12 12

52.00kdaN

24.00

6.50

3 of 6

0.25

16:15



d13-vir-04

777.4m

259

CLINT NEWBY

2013/12/10 20:00

Adam Russell

05:45

16:30

06:15

1.25

259.1

0.500.25

205

BOP DRILL

0.75

MB

07:30

0.75

71.8

32.6

HORIZ

0.50

KYLE WILKINSON


40.3

38.1

2.25

DANA GOERTZEN

74

Pason

76.9

19.75

20:00

08:00

12-06-011-26W1

53.00kdaN

1096kPa

17:30

35.3

1067kPa

234

DANA GOERTZEN

261.2

18:45

261.2

0Y52205_20131212_1A

20:00

24:00

69.8

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

CLINT NEWBY

33.99m3

DLS

2013/12/10 20:00

Adam Russell


4 of 6

42s/l

12-06-011-26W1

30.29m3

06:00

1070kg/m3

HORIZ

102/10-01-011-27W1/00

33.31m3

467.12m


527.45m

02:00

SHAKER

401.26m

205

29s/l

1

1030kg/m3

Pason

POLYMER

1060kg/m3

0Y52205_20131212_1A

04:00

x


234

SHAKER

d13-vir-04

12

36s/l

2013

SHAKER

12

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

SHAKER

742.74m

5 of 6

9680 12-06-011-26W1

SHAKER

31.69m3

48s/l

1100kg/m3

HORIZ

102/10-01-011-27W1/00

644.13m 683.60m

08:00

578.47m

SHAKER

1080kg/m3

2

44s/l

1110kg/m3

SHAKER

POLYMER

18:00

1100kg/m3


234d13-vir-04

32.10m3

2013

43s/l 40s/l

SHAKER

CLINT NEWBY

30.17m3

DLS

2013/12/10 20:00

44s/l

Adam Russell

16:00


1110kg/m3

44s/l

12:00

32.24m329.88m3

COREX RESOURCES LTD. 205

Pason

714.58m

32.77m3

0Y52205_20131212_1A

10:00

x

765.65m

1100kg/m3

SHAKER

12 12

14:00

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

CLINT NEWBY

10

9cm3

35.20m3

DLS

2013/12/10 20:00

Adam Russell


6 of 6

12-06-011-26W1

HORIZ

14cm3

102/10-01-011-27W1/00

36.45m3


813.17m

20:00

790.22m

205

50s/l

3

1105kg/m3

9

Pason

POLYMER

1100kg/m3

0Y52205_20131212_1A

22:00

x


234

SHAKER

d13-vir-04

12

46s/l

2013

SHAKER

12

MB

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



SHAKER

08:00

30

200

268.6

7.00

9680

9.5

0

19:30

6A

04:15

1

HWDP(4.5 IN)

15:45

859.8m

12.00

GAP SUB

73

VISUALLY INSPECT BOP STACK, CHOKE LINE, MANIFOLD VALVE ALIGNMENT,FLARE AND DEGASSER LINES, FLARE TANK AND LOADLINE

23:45

17:0090.3

00:00

9.18m

sacks

08:00

0

912.3m

SINGLE

Humalite

687.31m

135

6B

NO

83

0.25

9.5


6A

3600.00

7

TRIP OUT OF HOLE W FC @ 805M,424M,45M,OOH, TCV=6.55M3, TMV=7.74m3, DIFF=

DRILL FROM 978M - 1069M

NM FLEX DC

35.00kdaN

CENT 1

1 of 4

1400

CN

1016m270

73

135

687.31m

0.25

0

9.18m

2.75

FAIR

DRILL

DRIVING SAFETY

ds

20:00

11.1

264

89.4

TRIP IN HOLE WITH F.C @ 423M

83

CN

847m

89.3

42kdaN

11.1

a165940

1

sk513m-b2c

NM DP NM FLEX DC1

1

X/O FLOAT SUB

88.6

2.25

1

3

DIRECTIONAL WORK/ CHANGE MOTOR/ CHANGE BIT/ PROGRAM MWD TOOL

127

9.5

978.73m

4.14m

GAP SUB

4.14m

1

978m

DLS

DIRECTIONAL SURVEYS

X

9.5

ds

Enerpac lo vis

SHORT NM DC

163

4.00

Pason

1

164

1

ds


SHORT NM DC

19:45

163

OVERCAST

89.1

12

NM FLEX DC

BIT

0

164

2.00

2

978m

1967kPa

sacks

9.18m

90.5

DANA GOERTZEN

22:00

CENT 1

22:00

7.50

127

0Y52205_20131213_1A

50

1

0.25

1069m

16:15

20:45

150

12221324

10

9900.00

20900.00Nm

20:00

4.14m

48s/l

88.9

1100

151.42m

8.93m

0

9

246.67m

268.9

0

21

83

2

2.75

11.1

00:00

9.5

0.00m

DRILL

CIRCULATE/WORK PIPE/CONNECTION TIME

12cm3

9

3

270.1

21

9.5

58


FUNCTION TEST CROWN SAVER, PIPE RAMS CLOSED 5 SECS, ANNULAR CLOSED 9 SECS, HCR OPEN 2 SECS, FLARE STACK IGNITOR

872.8m

160

RIG SERVICE

0.00m


0

5

Enerpac lo vis

8.00

269.3

2.50

0.25

NM FLEX DC

1

1029m

07:45

114

1110

20.00

CN

11.1

22:45

73

17:45

1.83m

125

337.77m


56

0.00m

10kdaN1031

CN

1080

12:30

20:15

1.75

127

0.25

89.3

1090

2

925m

18kdaN

0

89.6

17:45

12:00

1

NM FLEX DC

1

163

x

MOTOR 7/8-4.8 STAG

89.5


04:15

ds

2.75m

1.00

9.50.25

Humalite

1

a165940

10

160

9.5

9

CIRCULATE/WORK PIPE/CONNECTION TIME

114

SHORT NM FLEXDC

11

23:45

11.1

SINGLE

45

06:45

08:00

6

15:30

847

0

X/O FLOAT SUB

0

sk513m-b2c

156

1069.83m

8.93m

21:30

12

109

sacks

06:00

1110

10cm3

264.2

160

200

2.75m

6125

160 7.90m

MOTOR 7/8-4.8STAG

1

996

45s/l

8

83

RIG SERVICE

269.9

VISUALLY INSPECT TOP DRIVE, PIPE ARM, APACHE, DRIVE LINES AND BREAK LINKAGES, SLIPS, DRILLING LINEAND LOADER

83

0.75

4

1

06:45

0.50

9.5

08:000

73

10

989.7m

150

2

20:00

10cm3

1

0.25m

22:15

2.50

320

269.3

1680

1041.9m

0.25

01:30

701

5.00

11.1

NM DP NM FLEX DC

1 0

20A

NM FLEX DC

SHORT NM FLEX DC

CN

320

SAFETY MEETING W DIRECTIONAL

BIT

73

846.8m

2013/12/11

83

32.09m3

6

886.1m

50

12

8

13

SHAKER

24.00

0.00m

22:15

1

160

HANDLING BHA

114

89.3

CN

269.3

11:30

19:30

HWDP(4.5 IN)

d13-vir-04

940

SHAKER

Dave Shubert

SLIDE TIME

7

320

937.8m

CN

3.75

205

888.47m

2

153

SHORT NM DC

73

1

1110

1

0.75

56

CNCN

56

6kdaN

222

BIT

1750

4526

1303.00

89.3

sacks

200

847

9.5

01:30

1

0.25

ds

50

2013/12/13


15:45

2013/12/13

154

11.1

8100

89.1

DANA GOERTZEN

07:45

1

10.00

200

0.59m

73

1

18kdaN

20:00

0.59m

21

51.00kdaN

0.25

9.15m

1067kPa

163

8

TD

0.25

DP(4.5 IN)

0.00m

0.59m

4

0.25m

4kdaN

150

7

200

9.15m

-25.00

2.25

3

265.1

164

14:30

HAND OVER SAFETY MEETING

4kdaN

CREW CHANGE

1

2Caustic Soda

9.15m


0.25m

14:00

847.54m

10cm3

35.05

46s/l

SHAKER

48.00kdaN

SLIDE TIME

23:15

83

2.00

24:00

267.3

102/10-01-011-27W1/00

1.25

SE

.92m3 fn blind rams while oh

9.5

04:30

19:45

156

30.72m3

2013

0.00m

04:30

1.00

11.1

1054.8m

SECURITY

NM DP NM FLEX DC

4

32.10m3

00:15

2

4

MOTOR 7/8-4.8STAG 5

26

9.5

156

1

10:45

DP(4.5 IN)

4.00

Caustic Soda

CN

1

30.54m3

2

114

G

8.93m

12

0.00m

73

1110

SHORT NM FLEXDC

899.2m

2.75

CLINT NEWBY

2013/12/10 20:00

00:30

45

1110


0

CN

866.37m73

271.5

0.00m

4

0.25

KEY BELIEFS/TARGET ZERO RULES

22:45

x

1

1.25

83

982.81m

83

1

MB

154

47s/l

1

0.00

9.5

1110

HORIZ

1

1027.32m

sacks


1

0.50

0

1

6.50

7.93m

56

UP TO 19 KM/H

CN

FX54R

TRIP IN HOLE W FC @ 145M, 424M

KYLE WILKINSON

20:15

874

20:15

153

ds

10:45

19

35

651.40m

847

1

109

10kdaN

1

ds

88.4

HWDP(4.5 IN)

0

9.50

00:15

NM FLEX DC

REED

9.5

109

12-06-011-26W1

22:45

146

0.00m

13:45

154

GAP SUB

1.00

1067kPa

1

1.75

REED

234

268.5

12550.00Nm

20:00

0.00m

4.30

NO

VISUALLY INSPECT TOP DRIVE, PIPE ARM, APACHE, DRIVE LINES AND BREAK LINKAGES, SLIPS, DRILLING LINE ANDLOADER

45

X/O FLOAT SUB

20

RIG SERVICE, FUNCTION ANNULAR 8 SEC. TO CLOSE

1.83m

153

sacks

2.75m

1.83m

5D

0.25

7.93m 1002.9m

1

24:00

2

160

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



48.00kdaN

08:00

7.00

0.75

9680

267.9

102/10-01-011-27W1/00

951m

12.00

2.50

00:00

2013

1.00

963.7m


8.00

0.25

2.50

0.25 4.00

976.8m

12 13

35.00kdaN

24.00

HANDLING BHA

2 of 4

0.25

18:15

2.75


DRIVING SAFETY

d13-vir-04

CLINT NEWBY

2013/12/10 20:00

Dave Shubert

18:45

1.75 0.25

3.75

0.25

205

KEY BELIEFS/TARGET ZERO RULES

1.25

MB

0.75

90.5

HORIZ

2.25 0.50

6.50

KYLE WILKINSON


4.00

DANA GOERTZEN

90.8

Pason

9.50

20:00

08:00

12-06-011-26W1

51.00kdaN

1067kPa

19:30

1067kPa

234

1967kPa

DANA GOERTZEN

268.9269.2

0Y52205_20131213_1A

20:00

24:00

91.1

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

8

10cm3

SHAKER

3 of 4

9680

10cm3

12-06-011-26W1

32.74m3

1110kg/m3

HORIZ

10cm3

102/10-01-011-27W1/00

888.47m 917.36m

12:00

866.37m

SHAKER

1110kg/m3

2

45s/l

POLYMER

1110kg/m3


234d13-vir-04

2013

46s/l

SHAKER

CLINT NEWBY

10cm3

30.72m3

DLS

2013/12/10 20:00

45s/l

Dave Shubert


45s/l

16:00

32.41m330.54m3


1010

Pason

946.16m

0Y52205_20131213_1A

14:00

x

1110kg/m3

SHAKER

12

10

13

18:00

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

9

10cm3

4 of 4

9680 12-06-011-26W1

32.31m3

1110kg/m3

HORIZ

12cm3

102/10-01-011-27W1/00

1027.32m 1067.37m

20:00

982.81m

SHAKER

1110kg/m3

3

47s/l

POLYMER

1110kg/m3


234d13-vir-04

2013

48s/l

SHAKER

CLINT NEWBY

10cm3

32.10m3

DLS

2013/12/10 20:00

Dave Shubert


48s/l

23:45

32.09m3


10

Pason

x

22:00

0Y52205_20131213_1A

SHAKER

12

10

13

MB

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



SHAKER

5

08:00

270

9.75

9680

0.25

0

18:00

7

07:45

1

HWDP(4.5 IN)

07:45

56

08:15

1224.5m

12.00

GAP SUB

73


1111

13:0088.9

00:00

9.18m

1276.8m

SINGLE

Caustic Soda

687.31m

135

2

83

0.25


270.4

4600.00

5D

1106.8mSLIDE TIME


NM FLEX DC

46.00kdaN

19:45

CENT 1

1 of 6

1460

CN

73

135

687.31m

1074

0.25

0

9.18m

FAIR

0.00m

TRIPPING

ds

20:00

9.5

268.6

RIG SEFVICE, FUNCTION HCR 1 SEC. TO OPEN ANNULAR CLOSED10 SEC PIPE RAMS

83

CN

1213m

01:15

22kdaN

9.5

a165940

1

30

NM DP NM FLEX DC1

HWDP(4.5 IN)

1

X/O FLOAT SUB

90

03:45

1

DP(4.5 IN) 127

9.5

1441.00m

4.14m

CENT 1

GAP SUB

4.14m

11cm3

1

1213m

DLS

SAFETY MEETING W DIRECTIONAL

9.5

ds

SHORT NM DC

1159.1m

163

3.25

Pason

1

164

1

1

91

ds


SHORT NM DC

19:30

163

OVERCAST

88.5

12

NM FLEX DC

BIT

0

164

480.94m

7.25

6B

1441m

1067kPa

sacks

sacks

9.18m

0.75

89.9

DANA GOERTZEN

CENT 1

28.00

127

1

0Y52205_20131214_1A

50

1

12:15

150

a165940

9

10020.00

21500.00Nm

20:00

4.14m

91.5

1090

0.00m

DP(4.5 IN)

8.93m

0

10

89.4

9

01:45

651.4m

269.2

0

83

0.25

9.5

00:00

0.00m

DRILL

SLIDE TIME

6

9cm3

11.75

3

0.25

20A

07:001120m

56

DRILL FROM 1069M-1213M


10

1237.6m

160

RIG SERVICE

0.00m


0

Enerpac reg.

8.00

0.50

A

0.25

NM FLEX DC

1

271

114

1110

17.50

CN

1100

9.5

56

23:30

73

20:00

15:30

1.83m

134

651.4m


23:45

56

0.00m

1069m 10kdaN

1441

CN

1470

09:15

20:15

1.50

127

270.1

0.25

1100

2

1289.9m

31kdaN

0

15:30

08:00

1

2

NM FLEX DC

1

163

x

MOTOR 7/8-4.8 STAG

91.1


07:00

ds

2.75m

9.5

10cm3

0.25

Kelzan XCD

1

10

04:30

160

91.6

9.5

37

10

FN BLIND RAMS WHILE OOH

114

SHORT NM FLEXDC

0

23:30

9.5

SINGLE

SAFETY MEETING/CREW CHANGE

45

5

1028

2013/12/15 12:00

08:00

200

11:30

1

847

0

X/O FLOAT SUB

0

sk513m-b2c

91.1

156

1441.00m

8.93m

8

109

sacks

06:00

1120

9cm3

271.6

17550.00Nm

57.54m

160

1110

200

2.75m

6200

160 7.93m

MOTOR 7/8-4.8STAG

1

1236

Calcium Nitrates

43s/l

0.25

9.5

83

RIG SERVICE

SHAKER

VISUALLY INSPECT TOP DRIVE, PIPE ARM, APACHE, DRIVE LINES AND BREAK LINKAGES, SLIPS, DRILLING LINEAND LOADER

83

0.75

2

1

2.25

08:000

73

150

2

19:45

1

0.25m

SHAKER

21:15

320

269.5

1740

0.25

06:15

366

21

9.5

NM DP NM FLEX DC

1

269.6

sacks

2.25

0

114

21

NM FLEX DC

TD

SHORT NM FLEX DC

CN

320

CREW CHANGE

BIT

73

1081m

2013/12/13

83

7

1250.6m

50

12

10

14

SHAKER

24.00

0.00m

21:15

6.75

1

160

DRIFTING CASING

114

CN

57.54m

08:30

18:00

DP(4.5 IN)

d13-vir-04

1397

X

SHAKER

35.24m3

Dave Shubert

43s/l


7

320

1303m

CN

x

205

1149.51m

1250.93m

3

153

SHORT NM DC

73

2

1120

3

1

02:15

0.75

56

CNCN

56

4kdaN

200

BIT

1750

5693

1061.00

sacks

200

9.5

06:15

1

1.50

ds

50

02:00

2013/12/13


5

154

91.6

9.5

9800

89

DANA GOERTZEN

1

200

0.59m

1

73

31kdaN

20:00

0.59m

211133.2m

59.00kdaN

0.25

10

9.15m

1067kPa

114

8

DRILL

24:00

0.25

DP(4.5 IN)

0.00m

0.59m

4

0.25m

4kdaN

272

150

7

200

9.15m

-25.00

271.7

164

10:45

Enerpac reg.

4kdaN

DIRECTIONAL SURVEYS

1

1Enerpac reg.

9.15m


0.25m

10:00

1213.00m

9cm3

42s/l

46.00kdaN

TRIP OUT OF HOLE W FC @ 1355M,720M,45M,OOH, TCV=8.69M3, TMV=9.17M3 DIFF= .48

83

1.00

594

23:45

270.9

102/10-01-011-27W1/00

6.00

SE

CIRCULATE/WORK PIPE/CONNECTION TIME08:00

19:30

1110

156

36.02m3

2013

0.00m

1.00 0.25

REED

NM DP NM FLEX DC

269.3

32m3

00:15

5

2

MOTOR 7/8-4.8STAG 2

50

1093.6m

156

1

20D

DP(4.5 IN)

4.00

Humalite

CN

1

35.23m3

1NO

114

114

46s/l

8.93m

12

33.69m3

73

1110

21.21

1112.97m

SHORT NM FLEXDC

8

1263.8m

0.75

CLINT NEWBY

2013/12/10 20:00

00:15

45

1110

CLOSED 3 SEC

0

CN

1213.61m73

0.00m

8

0.25

HSE ALERT 2007-002 METHANOL POISONING

x

0.75

83

1760

1441m

83

1

MB

154

1441

50s/l

1

56

6.75

45

9.5

HORIZ

1

sacks


0.25

0

03:15

1

2.25

7.93m

CC

56

UP TO 19 KM/H

CN

sk513m-b2c

KYLE WILKINSON

1265

20:15

153

ds

08:15

50

25

687.31m

1

04:00

91.5

109

12kdaN

1

ds

88.7

HWDP(4.5 IN)

0

16.50

114

HANDLE DIRECTIONAL TOOLS\ LAY DOWN BHA

00:15

NM FLEX DC

REED

1146.2m

9.5

109

12-06-011-26W1

847

0.00m

10:00

154

GAP SUB

1067kPa

1

2.50

234

269.8

20:30

0.00m

4.30


45

X/O FLOAT SUB

CIRCULATE/WORKING STRING/CONNECTION TIME

1.83m

153

sacks

2.75m

1.83m

2

0.25

7.93m

1

24:00

1

160

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



46.00kdaN

08:00

268.8

0.75

9.75

9680

0.25

269.3

06:45

102/10-01-011-27W1/00

269.9

1316.2m

12.00

00:00

17:45

2013

90.2

1.00

270.8

0.25

1368.5m

272.21211.4m

271.1

2.25

1329.3m


8.00

0.50

0.25

1185.1m1172m

0.25 4.00

1198.3m

1342.5m

12 14

46.00kdaN

24.00

6.75

DRIFTING CASING

2 of 6

0.25

13:45


d13-vir-04

TRIPPING

1355.5m

272.7

CLINT NEWBY

2013/12/10 20:00

Dave Shubert

05:15

14:30

06:00

1.50

271.5

0.25

1396m

0.25

205


0.75

1382.2m

MB

07:45

0.75

90.5

88.9

HORIZ

0.25

2.25

KYLE WILKINSON


90.7

89.6

3.25

DANA GOERTZEN

90.4

Pason

90.4

16.50

2013/12/15 12:00

20:00

08:00

16:15

12-06-011-26W1

59.00kdaN

90.4

1067kPa

15:00

88.7

1067kPa

234

270.9

1067kPa

90.5

DANA GOERTZEN

270.6

15:30

270.5

0Y52205_20131214_1A

17:15

20:00

24:00

90.5

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



46.00kdaN

08:00

9.75

0.75

9680

0.25

270.2

102/10-01-011-27W1/00

1409.8m

12.00

00:00

2013

1.00 0.252.25

1423.4m


8.00

0.25

0.50

0.25 4.00

1426m

12 14

46.00kdaN

24.00

6.75

DRIFTING CASING

3 of 6

0.25

18:45


TRIPPING

d13-vir-04

CLINT NEWBY

2013/12/10 20:00

Dave Shubert

19:15

1.50 0.250.25

205


0.75

MB

0.75

90.9

HORIZ

0.25

2.25

KYLE WILKINSON


3.25

DANA GOERTZEN

91.1

Pason

16.50

2013/12/15 12:00

20:00

08:00

12-06-011-26W1

59.00kdaN

1067kPa

19:30

1067kPa

234

1067kPa

DANA GOERTZEN

270271.2

0Y52205_20131214_1A

20:00

24:00

91

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

10

2013/12/15 12:00

10cm3

4 of 6

9680 12-06-011-26W1

36.58m3

1110kg/m3

HORIZ

11cm3

102/10-01-011-27W1/00

1149.51m 1182.89m

02:00

1112.97m

SHAKER

1110kg/m3

1

43s/l

POLYMER

1111kg/m3


234d13-vir-04

2013

46s/l

SHAKER

CLINT NEWBY

10cm3

33.69m3

DLS

2013/12/10 20:00

Dave Shubert


46s/l

06:00

35.24m3


10

Pason 0Y52205_20131214_1A

x

04:00

SHAKER

12

9.5

14

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

9.5

9cm3

2013/12/15 12:00

SHAKER

9cm3

1361.53m

5 of 6

9680

9cm3

12-06-011-26W1

SHAKER

35.07m3

45s/l

1110kg/m3

HORIZ

9cm3

102/10-01-011-27W1/00

1250.93m 1285.91m

08:00

SHAKER

1213.61m

43s/l

1110kg/m3

2

1110kg/m3

SHAKER

POLYMER

18:00

1120kg/m3


234

10

34.86m3

d13-vir-04

42s/l

2013

44s/l

SHAKER

CLINT NEWBY

9cm3

36.02m3

DLS

2013/12/10 20:00

45s/l

Dave Shubert

16:00


1110kg/m3

44s/l

12:00

34.73m3

9cm3

35.23m3


109

Pason

1319.87m

35.45m3

0Y52205_20131214_1A

10:00

x

1397.52m

10

SHAKER

1110kg/m3

12

9

14

14:00

MB

Time

Density

Funnel Viscosity

Fluid Loss

Fluid pH

Location of Sample

Depth

PVT

Test 1


Value

Test 2

Type (ex: Sand%)

Value

Test 3

Type (ex: Hard Ca)

Value

Test 4

Type (ex: Sulfides)

Value

MUD SAMPLE REMARKS


Pason



Operator

Operator’s AFE


Well Type Re-Entry

Spud Date Time


Contractor Rig No



V. 1.1

CLINT NEWBY

10

32m3

2013/12/15 12:00

DLS

2013/12/10 20:00

Dave Shubert


6 of 6

9680 12-06-011-26W1

HORIZ

9cm3

102/10-01-011-27W1/00


20:30

1441m

205

50s/l

3

1110kg/m3

Pason

POLYMER

0Y52205_20131214_1A

x


234

SHAKER

d13-vir-04

122013 14

MB

CODE 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

TOTALRigUp



RepairRig

Cut Off Drilg Line

Dev Survey

Wireline Logs

Run Csg& Cement

Wait On Cement

Nipple Up BOP

TestBOP

Drillstem Test

PlugBack


WorkSafety

MeetingTear

DownWaiting

OnRig

Watch Other

HO

UR

S Tour 1Tour 2

Tour 3Total




WE

AT

HE

R Time Temp

Current Conditions


Road Condition


Well Type Re-Entry

Spud Date Time



Contractor Rig No



Operator

Operator’s AFE



Remarks:







NameHours Run

Intake Density

Over Flow Density

Under Flow Density



V. 1.3

Remarks:



Remarks:




TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


T0 ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom


TO ODC

MDC Reason Pulled



Drill Pipe Stands

Drill Pipe Singles

Kelly DownTotal


BITSBit Number

Size

IADC Code

Manufacturer

Type

Serial No

Jets

Depth Out (m)

Depth In (m)

Total Drilled (m)

Hrs Run Today




@ @

@ @

@ @


Other

TimeDensity

Funnel Viscosity

Fluid Loss

pH

Location of Sample

Depth

PVT


Remarks:


Torque at Bottom

Fill on Bottom



NameHours Run

Intake Density

Over Flow Density

Under Flow Density





NameHours Run

Intake Density

Over Flow Density

Under Flow Density



RIG SERVICE

08:00

83

0.25

9680

0

11:00

5.50

12C

06:15

08:00

1

03:45

56

150

2.00

12:00

1

12.00

0.25m

320

12.00

00:00

06:45

0.25

00:45

23B

NM DP NM FLEX DC

1

0

114

0

12A

12C

CN

320

followed by 58 jts of 139.7mm , 23.067kg/m LT&C csg . Marker jt @ 1241.69m

BIT

73


21

2600.00

RIG UP TO RUN CASING

12 15

NM FLEX DC

25.00kdaN

12:00

24.00

RUNNING CASING

1 of 1

CN

73

75

CN

0.25

9.18m

FAIR

DP(4.5 IN)

d13-vir-04

ds

20:00

CEMENTING . Cement casing with 18t 0f Titanium 1400 followed by 20t of T.A.C

83

CN

Dave Shubert

plug held . Plug down @ 09:00 hr

7

320

31kdaN

CN205

HWDP(4.5 IN)

0.25

X/O FLOAT SUB

CN

0.50

CN


4kdaN

127

600

1544.00

00:45

1

ds

50


ds

SHORT NM DC

2.50

0

DANA GOERTZEN

Pason

06:30

1

ds

0.59m

1


20:00

11:00

163

4.00

OVERCAST

114

1067kPa

8

164

651.4m

4

1067kPa

23B

200

4.50

2.75

-25.00

9.15m

DANA GOERTZEN

2.50

FLUSH PUMP, BLOW BACK TOP DRIVE, RIG IN CEMENTERS

127

SPLIT BOP STACK, SET CASING SLIPS AT 20 DAN, CUT CASING, LAY OVER BOP STACK

0Y52205_20131215_1A

1

0.25


1441.00m

6600.00

1.00

20:00

4.14m

0.00m

52.00kdaN

102/10-01-011-27W1/00

0.50

SE

RUN CASING . Ran 51 jts of 114.3mm , 17.263kg/m , LT&C csg followed by 1 XO

0

12C

1.00

1.00

00:00

156

2013

RIG OUT CEMENTERS/FLUSH STACK/FILL STACK/CLOSE ANNULAR, HOLD 100 PSI FOR 2

03:45

0

8.00

14B

01:00

08:00

HANDLE DIRECTIONAL TOOLS

56

00:15

W/O DAYLIGHT

0.00m


1.00

MOTOR 7/8-4.8STAG 20D

8.00

0.50

1

NM FLEX DC

1

06:45

4.00

CN

06:30

CN

4.00

8.93m

12

20:00

09:00

73

1.83m

0


0.00m

0.25

56

CLINT NEWBY

CN

2013/12/10 20:00

114

1600 . Displace with 15.8 m3 of water . 7 m3 of cement returns . Bump plug ,

CN

127 4.5

CEMENTING

2.50

83

0

MB

11.25


01:00

HORIZ

ds

0.25


0.25

1.00

9

UP TO 19 KM/H

CN

SAFETY MEETING WITH CEMENTERS

KYLE WILKINSON

24:00

9.5

50

ds

09:00

8.00

SHORT NM FLEXDC

687.31m

1

0

109

ds

5

W/O DAYLIGHT

12

0

00:15

57.54m

06:15

2013/12/15 12:00

08:00

109

12-06-011-26W1

154

GAP SUB

DP(4.5 IN)

CEMENTING

2.00

234

4.30


5

10.5

HOURS RIG RELEASED DEC 15 AT 12:00

109

153

06:00

2.75m

13

160

2.00

0

160 7.93m

1

24:00

INITIAL PRODUCTION REPORT

Two (2) copies of this report are to be completed and submitted to the district office within days

following the fifth after the well has been placed on normal production.


License Number: 9680

Operating Company: COREX RESOURCES LTD

Battery Well Produced To (name & locations): SWB

Completion Interval(s): 857.0 m to 1417.1 m m to m

Open Hole: Perforated: Formation: LODGEPOLE

Completion Oil:

Source of Completion Oil (Co. & location):

Volume Supplied: m3

Date Supplied:* / /

YY MM DD

Date

YY MM DD

Completion Oil

Used

(m3)

Completion Oil

Recovered (m3)

Completion Oil

To Be Recovered

(m3)

Water

Produces (m3)

(Continue on separate sheet if necessary)

Disposition of Recovered Completion Oil: m3 to

(Co. & location)

On-Production Date:* 14/1/19

YY MM DD

* Official on-production date (i.e. date of first new oil production after completion oil recovered).

* Date in which the well produces oil in excess of the volume of completion oil used.

Production Test:

Date

YY MM DD

Hours

Produced

Oil

Produced

m3

Water

Produced

m3

Pumping Flowing Gas-Oil

Ratio

(m3/ m3)

Oil

Density

(kg/ m3)

14 1 19 24 21.7 9.3 x 10 850

14 1 20 24 16.63 7.13 x 10 850

14 1 21 24 14 6 x 10 850

14 1 22 24 11.03 4.73 x 10 850

14 1 23 24 10.85 4.65 x 10 850

Totals

120

74.21

31.81


(Submitted By) (Position) (Telephone)

Remarks:

daily completion and workover -...

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