j) core Page 1/2 Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM Report Printed: 22/01/2014 www.peloton.com Daily Completion and Workover UWI 102/10-01-011-27W1/00 Surface Location 12-06-11-26 Field Name VIRDEN License # 9680 State/Province Manitoba Well Configuration Type Horizontal Original KB Elevation (m) 473.20 KB-Tubing Head Distance (m) Spud Date 10/12/2013 20:00 Rig Release Date 15/12/2013 12:00 PBTD (All) (mKB) Total Depth All (TVD) (mKB) Report # 1.0, Report Date: 16/12/2013 Primary Job Type Initial Completion Secondary Job Type WHITEWATER COMPLETION Objective Contractor Canyon Technical Services Rig Number 138105 Contractor Essential Coil Rig Number 2146 Contractor Eagle Well Servicing Rig Number 56 AFE Number C13-VIR-07 Total AFE + Supp Amount (Cost) 590,000.00 Daily Field Est Total (Cost) 18,498.94 Cum Field Est To Date (Cost) 18,498.94 Operations 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 BHA Operations Next Report Period Fracturing Daily Readings Weather Cloudy. Winds 26 kmh W Temperature (°C) -3 Road Condition Tubing Pressure (kPa) Casing Pressure (kPa) 0 Rig 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 18:00 23:30 5.50 401 Rig Up/Rig Out: Stimulation 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 23:45 00:00 0.25 401 Rig Up/Rig Out: Stimulation Make up NCS Instafrac tool as follows: Total length 6.78 meters Shear sub 79.0 mm OD, 0.305 meter length Centralizer 98.0 mm OD, 0.915 meter length Ball seat 1.375 " 78.0 mm OD, 0.11 meter length Centralizer 98.0 mm OD, 0.915 meter length Jet body 98.0 mm OD, 0.236 meter length Instafrac tool 78.0 mm OD, 1.58 meter length Packer 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
122
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j)core
Page 1/2
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
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
18:00 23:30 5.50 401 Rig Up/Rig Out: Stimulation
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
23:45 00:00 0.25 401 Rig Up/Rig Out: Stimulation
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)
15/12/2013 12:00PBTD (All) (mKB) Total Depth All (TVD) (mKB)
Report # 1.0, Report Date: 16/12/2013
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
j)core
Page 1/4
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 # 2.0, Report Date: 17/12/2013
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)
64,354.58Cum Field Est To Date (Cost)
82,853.52Operations Summary
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
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
03:30 06:30 3.00 401 Rig Up/Rig Out: Stimulation
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.
08:30 09:15 0.75 403 Pressure Test: Stimulation
Prime up and pressure test frac equipment to 55 mpa. All good. Test annulas iron to 40 mpa. All good.
j)core
Page 2/4
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 # 2.0, Report Date: 17/12/2013
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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
Stage # 03 Brazzer Jet @ 1346.5 mkB 11:24 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 13.8 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 - 10.0 mpa, ISIP - 9.1 mpa. Total Clean Fluid Injected 32.3 m3. Fluid Injected Moving Tools 0.4 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
Stage # 05 Brazzer Jet @ 1277.0 mkB 13:43 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 16.0 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 - 9.7 mpa, ISIP - 9.5 mpa. Total Clean Fluid Injected 32.9 m3. Fluid Injected Moving Tools 0.7 m3
Stage # 06 Brazzer Jet @ 1247.5 mkB 14:52 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 17.8 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 - 9.7 mpa, ISIP - 9.4 mpa. Total Clean Fluid Injected 32.8 m3. Fluid Injected Moving Tools 0.8 m3
j)core
Page 3/4
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 # 2.0, Report Date: 17/12/2013
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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 # 08 Brazzer Jet @ 1171.5 mkB 17:08 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 19.4 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 - 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 - 11.7 mpa, ISIP - 9.4 mpa. Total Clean Fluid Injected 30.7 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 # 11 Brazzer Jet @ 1067.0 mkB 20:27 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 22.2 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 - 10.1 mpa, ISIP - 8.9 mpa. Total Clean Fluid Injected 32.3 m3. Fluid Injected Moving Tools 0.7 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
22:30 00:00 1.50 404 Fracture: Stimulation Stage # 13 Brazzer Jet @ 993.50 mkB 22:40 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 14.2 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 - 9.9 mpa, ISIP - 9.1 mpa. Total Clean Fluid Injected 31.4 m3. Fluid Injected Moving Tools 0.7 m3
Stage # 14 Brazzer Jet @ 962.0 mkB 23:45 --Note: Info on 18 / 12 / 2013
j)core
Page 4/4
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 # 2.0, Report Date: 17/12/2013
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
Time Type Top (mKB) Btm (mKB) Cased?
Perforations
Time Zone Top (mKB) Btm (mKB) Current Status
Stimulations & TreatmentsTime
07:00Zone
Whitewater, Original HoleType
Hydraulic FracDelivery Mode
Coil TubingStim/Treat Company
Canyon Technical Services
Stg # Stage Type Top (mKB) Btm (mKB) Vol Clean Pump (m³)
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
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
j)core
Page 1/3
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 # 3.0, Report Date: 18/12/2013
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)
293,836.88Cum Field Est To Date (Cost)
376,690.40Operations Summary
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.
00:00 03:00 3.00 404 Fracture: Stimulation Stage # 14 Brazzer Jet @ 962.0 mkB 23:45 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 15.4 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 - 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 - 10.6 mpa, ISIP - 8.9 mpa. Total Clean Fluid Injected 31.1 m3. Fluid Injected Moving Tools 0.7 m3
Stage # 15 Brazzer Jet @ 927.0 mkB 00:51 -- Bullheading 400 kg Cut Sand @ 100 kg/m3 con. Set packer and achieve a formation Break of 14.8 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 - 10.4 mpa, ISIP - 9.1 mpa. Total Clean Fluid Injected 31.5 m3. Fluid Injected Moving Tools 0.8 m3
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.
j)core
Page 2/3
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 # 3.0, Report Date: 18/12/2013
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
05:30 13:30 8.00 401 Rig Up/Rig Out: Stimulation
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.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
Time Type Top (mKB) Btm (mKB) Cased?
Perforations
Time Zone Top (mKB) Btm (mKB) Current Status
08:00 Whitewater, Original Hole 857.00 857.10 Open - Flowing
08:00 Whitewater, Original Hole 894.00 894.10 Open - Flowing
08:00 Whitewater, Original Hole 927.00 927.10 Open - Flowing
08:00 Whitewater, Original Hole 962.00 962.10 Open - Flowing
08:00 Whitewater, Original Hole 993.50 993.60 Open - Flowing
08:00 Whitewater, Original Hole 1,032.00 1,032.10 Open - Flowing
08:00 Whitewater, Original Hole 1,067.00 1,067.10 Open - Flowing
08:00 Whitewater, Original Hole 1,107.00 1,107.10 Open - Flowing
08:00 Whitewater, Original Hole 1,137.00 1,137.10 Open - Flowing
08:00 Whitewater, Original Hole 1,171.50 1,171.60 Open - Flowing
08:00 Whitewater, Original Hole 1,207.00 1,207.10 Open - Flowing
08:00 Whitewater, Original Hole 1,247.50 1,247.60 Open - Flowing
08:00 Whitewater, Original Hole 1,277.00 1,277.10 Open - Flowing
08:00 Whitewater, Original Hole 1,312.00 1,312.10 Open - Flowing
08:00 Whitewater, Original Hole 1,346.50 1,346.60 Open - Flowing
08:00 Whitewater, Original Hole 1,382.00 1,382.10 Open - Flowing
08:00 Whitewater, Original Hole 1,417.00 1,417.10 Open - Flowing
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)
j)core
Page 3/3
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 # 3.0, Report Date: 18/12/2013
Cement
Start Time Des Type String Cement Comp
j)core
Page 1/2
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 # 4.0, Report Date: 19/12/2013
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)
10,450.00Cum Field Est To Date (Cost)
387,140.40Operations Summary
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
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
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
j)core
Page 2/2
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 # 4.0, Report Date: 19/12/2013
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
j)core
Page 1/2
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 # 5.0, Report Date: 20/12/2013
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)
6,650.00Cum Field Est To Date (Cost)
393,790.40Operations Summary
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
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
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
j)core
Page 2/2
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 # 5.0, Report Date: 20/12/2013
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
j)core
Page 1/2
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 # 6.0, Report Date: 21/12/2013
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)
9,150.00Cum Field Est To Date (Cost)
402,940.40Operations Summary
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
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.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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)
j)core
Page 2/2
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 # 6.0, Report Date: 21/12/2013
Cement
Start Time Des Type String Cement Comp
j)core
Page 1/1
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 # 7.0, Report Date: 22/12/2013
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)
13,470.00Cum Field Est To Date (Cost)
416,410.40Operations Summary
Cleaning flow back tankOperations at Report Time
Wating for service rigOperations Next Report Period
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
j)core
Page 1/2
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 # 8.0, Report Date: 04/01/2014
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)
8,250.00Cum Field Est To Date (Cost)
424,660.40Operations Summary
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
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
****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
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.
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
j)core
Page 1/3
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 # 12.0, Report Date: 08/01/2014
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)
25,935.81Cum Field Est To Date (Cost)
486,541.21Operations Summary
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.
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
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
j)core
Page 2/3
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 # 12.0, Report Date: 08/01/2014
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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
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.
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
j)core
Page 3/3
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 # 12.0, Report Date: 08/01/2014
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
j)core
Page 1/2
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 # 13.0, Report Date: 09/01/2014
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)
88,686.06Cum Field Est To Date (Cost)
575,227.27Operations Summary
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.
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
10:30 12:00 1.50 101 Install or Change Wellhead
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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Page 2/2
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 # 13.0, Report Date: 09/01/2014
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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
15:00 16:00 1.00 101 Install or Change Wellhead
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.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
13:00Tubing Description
Tubing - ProductionSet Depth (mKB)
755.63String Max Nominal OD (mm)
73.0Weight/Length (kg/m)
9.673String Grade
J-55
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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Page 1/2
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 # 14.0, Report Date: 10/01/2014
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)
20,319.42Cum Field Est To Date (Cost)
595,546.69Operations Summary
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
Daily ReadingsWeather
Sunny.Temperature (°C)
-8Road Condition Tubing Pressure (kPa)
10,000Casing Pressure (kPa)
10,000Rig Time (hr)
3.50
Daily Contacts
Job Contact Title Mobile
Mike Smith Completions Sup 403-801-0828
Scott Kingdon Wellsite Supervisor 306-457-8250
Karl Menzies Wellsite Supervisor 306-278-8576
Myles Simonar Production Engineer 403-804-3630
Sandy Angus Eng Tech 403-826-1244
Darrell Wild Completions 204-851-5595
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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
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Page 2/2
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 # 14.0, Report Date: 10/01/2014
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
j)core
Page 1/2
Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM
Report Printed: 21/02/2014www.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: 29/01/2014
Primary Job Type
Pump RepairSecondary Job Type
Objective
Contractor
C.D OilwellRig Number
4AFE Number
O14-VIR-07Total AFE + Supp Amount (Cost)
17,289.00Daily Field Est Total (Cost)
6,370.00Cum Field Est To Date (Cost)
6,370.00Operations Summary
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
Daily ReadingsWeather
Windy, 50 km hrTemperature (°C)
-14Road Condition Tubing Pressure (kPa)
0Casing Pressure (kPa)
0Rig Time (hr)
4.00
Daily Contacts
Job Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630
Sandy Angus Eng Tech 403-826-1244
Glen Cantelo Wellsite Supervisor 204-748-7767
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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.
16:15 16:30 0.25 607 Secure Well & Shut Down for Night
Secured wellhead, SDON.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
Water 8.00 0.00
Safety Checks
Time Des Type Com
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
j)core
Page 2/2
Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM
Report Printed: 21/02/2014www.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: 29/01/2014
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
j)core
Page 1/2
Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM
Report Printed: 21/02/2014www.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 # 2.0, Report Date: 30/01/2014
Primary Job Type
Pump RepairSecondary Job Type
Objective
Contractor
C.D OilwellRig Number
4AFE Number
O14-VIR-07Total AFE + Supp Amount (Cost)
17,289.00Daily Field Est Total (Cost)
10,655.30Cum Field Est To Date (Cost)
17,025.30Operations Summary
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
Daily ReadingsWeather
Windy, 60 km hrTemperature (°C)
-24Road Condition Tubing Pressure (kPa)
0Casing Pressure (kPa)
0Rig Time (hr)
4.50
Daily Contacts
Job Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630
Sandy Angus Eng Tech 403-826-1244
Glen Cantelo Wellsite Supervisor 204-748-7767
Time Log
Start Time End Time Dur (hr) Code 1 Code 2 Com
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.
Report Fluids Summary
Fluid To well (m³) From well (m³) To lease (m³) From lease (m³)
Water 1.20 0.00
Safety Checks
Time Des Type Com
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
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Page 2/2
Well Name: COREX VIRDEN HZNTL 10-01-11-27WPM
Report Printed: 21/02/2014www.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 # 2.0, Report Date: 30/01/2014
Tubing PulledPull Time Tubing Description Set Depth (mKB) String Max Nominal OD (mm) Weight/Length (kg/m) String Grade
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
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)
Report # 1.0, Report Date: 7/29/2014
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)
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)
Report # 1.0, Report Date: 7/29/2014
PerforationsTime 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)
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
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
Operat one Next Report Penod
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
Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)650 0 4.00
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
SITP / SICP Pressure
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.
Report Fluids SummaryFluid
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
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)
Report # 1.0, Report Date: 11/12/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)4,285.00
Cum Field Est To Date (Cost)4,285.00
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
Road Condition Tubing Pressure (kPa)650
Casing Pressure (kPa)0
Rig Time (hr)4.00
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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.
18:00 18:15 0.25 607 Secure Well & Shut Down for Night
Secured well, SDON.
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
Water 15.00 0.00
Safety ChecksTime Des Type Com
LogsTime Type Top (mKB) Btm (mKB) Cased?
PerforationsTime 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
102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680State/Pro nce
ManitobaINeh Conrguraton Type
HonzontalOnenal KB Elevat on (m) KB-T 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 22,317.20 26,602.20Operat one Summary
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
Operat one Next Report Penod
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
Temperat re('C) RoadCondton-12
Production Engineer
Eng Tech
INellsite Supervisor
Tide
403-804-3630
403-826-1244
204-748-7767
Moor(a
Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 2'me (hr)0 0 12.00
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
SITP / SICP Pressure
Tnpping Rods
BOPS-Install / Remove
Tnpping Tubing
Tnpping Tubing
Circulate / Reverse Well
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
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)
Report # 2.0, Report Date: 11/13/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)22,317.20
Cum Field Est To Date (Cost)26,602.20
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
Temperature (°C)-12
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)12.00
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
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
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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)
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 20,350.00 46,952.20Operat one Summary
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
Operat one Next Report Penod
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
Temperat re('C) RoadCondton-16
Production Engineer
Eng Tech
)Net)site Supervisor
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 12.00
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
SITP / SICP Pressure
Tnpping Tubing
Circulate / Reverse Well
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.
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)
Report # 3.0, Report Date: 11/14/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)20,350.00
Cum Field Est To Date (Cost)46,952.20
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
Temperature (°C)-16
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)12.00
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
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
102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680StatelPro nce
ManitobaIsed 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 11,856.00 58,808.20Operat one Summary
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
Operat one Next Report Penod
Move in Millenium and assoaated equipment for N2 sand frac
Daily ReadingsINeather
Cool, windy
Daily Contacts
Myles Simonar
SandyAngus
Glen Cantata
Time Log
Job C(sttect
Temperat re('C) RoadCondton-17
Production Engineer
Eng Tech
INellsite Supervisor
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 6.00
Sert Time End Time Dur (hr) Cods 1 Cods 2 Com
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
SITP / SICP Pressure
Tnpping Tubing
Tnpping Tubing
BOPS-Install / Remove
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
Report Fluids SummaryFluid
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
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)
Report # 4.0, Report Date: 11/15/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)11,856.00
Cum Field Est To Date (Cost)58,808.20
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
Temperature (°C)-17
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)6.00
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
Water 11.50 0.00 15.00 0.00
Safety ChecksTime Des Type Com
LogsTime Type Top (mKB) Btm (mKB) Cased?
PerforationsTime Zone Top (mKB) Btm (mKB) Current Status
102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680State/Pro nce
ManitobaINed 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 56,760.36 115,568.56Operat one Summary
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
Operat one Next Report Penod
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
Daily ReadingsINeather
Cloudy, windy
Daily Contacts
Myles Simonar
SandyAngus
Glen Cantelo
Time Log
Job C(sttect
Temperat re('C) RoadCondton
9
Production Engineer
Eng Tech
INellsite Supervisor
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.
Report Fluids SummaryFluid
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
LogsTime Type Top (mkel Btm (mKB) Cesed7
PerforationsTime Torte Top (mKB) Btm (mKB) Current SteWs
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)
Report # 5.0, Report Date: 11/19/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)56,760.36
Cum Field Est To Date (Cost)115,568.56
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
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)8.50
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
12:45 13:45 1.00 401 Rig Up/Rig Out: Stimulation
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.
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
Frac Fluid 15.10 0.00Water 30.00 14.90
Safety ChecksTime Des Type Com
LogsTime Type Top (mKB) Btm (mKB) Cased?
PerforationsTime Zone Top (mKB) Btm (mKB) Current Status
102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680State/Pro nce
ManitobalNeh 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 19,308.43 134,876.99Operat one Summary
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
Operat one Next Report Penod
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
Temperat re('C) RoadCondton-16
Production Engineer
Eng Tech
INellsite Supervisor
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
SITP / SICP Pressure
BOPS-Install / Remove
Tnpping Tubing
Circulate / Reverse Well
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.
Report Fluids SummaryFluid
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
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)
Report # 6.0, Report Date: 11/20/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)19,308.43
Cum Field Est To Date (Cost)134,876.99
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
Temperature (°C)-16
Road Condition Tubing Pressure (kPa)14,000
Casing Pressure (kPa)0
Rig Time (hr)11.00
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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.
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
RecompletionObiect vs
Secondary Job Type
Contractor
C.D OilwellAFE Number
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)
208,822.00 14,381.50 149,258.49Operat one Summary
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
Operat one Next Report Penod
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
Temperat re('C) RoadCondton-2
Production Engineer
Eng Tech
INellsite Supervisor
Tide
403-804-3630
403-826-1244
204-748-7767
Mobrts
Tub ng Pressure (kPa) Cawng Pressure (kPa) Rg 7'me (hr)0 0 10.50
Sert Time End Time Dur (hr) Cods 1 Cods 2 Com
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
SITP / SICP Pressure
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.
Report Fluids SummaryFluid
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
LogsTime Type Top (mkel Btm (mKB) Cesed7
PerforationsTime Sorts Top (mKB) Btm (mKB) Current SteWs
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
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)
Report # 7.0, Report Date: 11/21/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)14,381.50
Cum Field Est To Date (Cost)149,258.49
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
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)10.50
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
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.
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
102/10-01-011-27W1/00 12-06-11-26 VIRDEN 9680State/Pro nce
Manitobalaed Conrguraton Type
HonzontalOnanal 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 27,580.50 176,838.99Operat one Summary
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
Operat one Next Report Penod
Turned well over to operations.Job complete
Daily Readingslaeather
FoggyDaily Contacts
Myles Simonar
SandyAngus
Glen Cantelo
Job C(attest
Temperat re('C) RoadCondton-18
Production Engineer
Eng Tech
INellsite Supervisor
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
SITP / SICP Pressure
INaiting Time
Tnpping Tubing
Tnpping Tubing
BOPS-Install / Remove
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.
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)
Report # 8.0, Report Date: 11/24/2014
Primary Job TypeRecompletion
Secondary Job Type
Objective
ContractorC.D Oilwell
Rig Number4
AFE NumberW14-VIR-31
Total AFE + Supp Amount (Cost)208,822.00
Daily Field Est Total (Cost)27,580.50
Cum Field Est To Date (Cost)176,838.99
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
Temperature (°C)-18
Road Condition Tubing Pressure (kPa)0
Casing Pressure (kPa)0
Rig Time (hr)9.50
Daily ContactsJob Contact Title Mobile
Myles Simonar Production Engineer 403-804-3630Sandy Angus Eng Tech 403-826-1244Glen Cantelo Wellsite Supervisor 204-748-7767
Time LogStart Time End Time Dur (hr) Code 1 Code 2 Com
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
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.
Report Fluids SummaryFluid To well (m³) From well (m³) To lease (m³) From lease (m³)
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
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 3
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
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 4
GEOLOGICAL MARKERS
GROUND ELEVATION: 468.90 m K. B. ELEVATION: 473.20 m
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 11
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 12
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 13
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 14
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 15
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 16
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 17
Interval Descriptions
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.
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 18
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 19
Interval Descriptions
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 20
Interval Descriptions
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)
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 21
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 22
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 23
STRUCTURE PROFILE
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 24
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).
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 25
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.
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 26
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)
Corex Virden HZNTL 102.10-01-011-27 WPM
RESERVOIR DOGS GEOLOGICAL 27
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.
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
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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)
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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
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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