Prairie Provident

PPR S. Pointed Mountain (D-1) L-68 Abandonment Program Well ID: 1207

Rev: 0 Date: 30-Apr-2021

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Table of Contents

1 Well Data ................................................................................................................... 2

2 Detailed Well History ................................................................................................ 5

3 Abandonment Program – Recommended Procedure .............................................. 22 3.1 Wellbore Abandonment .................................................................................... 22 3.2 Surface Abandonment ...................................................................................... 25 3.3 Daily Reports .................................................................................................... 27 3.4 Services ............................................................................................................. 29

4 APPENDIX A – Downhole Schematic Post Abandonment ................................... 30

5 APPENDIX B – Well Control Equipment Requirement ........................................ 31

6 APPENDIX C – Geological Interpretation ............................................................. 33

7 APPENDIX D – Abandonment Schedule ............................................................... 41

8 APPENDIX E – 2021 Site Inspection ..................................................................... 42

9 APPENDIX F – Daily Drilling Reports .................................................................. 50

10 APPENDIX G – Daily Re-entry and Re-completion Reports ................................ 51

11 APPENDIX H – Cement Bond Log and Interpretation .......................................... 52



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1 WELL DATA

Operator: Prairie Provident Resources Canada Ltd. 1110, 640 – 5th Avenue SW Calgary, Alberta T2P 3G4 24 Hour Emergency #: 1-866-405-4854 Coordinates: 60°17'42.83"N

123°57'55.91"W Elevations: KB: 737.0 m KB – THF: 4.7 m GL: 723.0 m PBTD: 3971.0 mKB MD TD: 4200.0 mKB MD / 4139.86 mTVD Maximum deviation: ~31.25° at 3714 mMD

See attached directional surveys Conductor Casing: 508.0 mm, 139.89 kg/m, S00-95 LT&C landed at 165.0 mKB.

(Cemented with 55 tonnes Oilwell Neat G cement, 100% returns) – 660 mm open-hole

Surface Casing: 339.7 mm, 107.15 kg/m, S00-95 LT&C landed at 1424.0 mKB

(Cemented with 3 blends: 42.7 tonnes Class G + 2% gel (0:1:2); 64.8 tonnes Class G + 8% gel (0:1:8); and 13.2 tonnes Class G neat (0:1:0), full returns) – 445 mm open-hole

Intermediate Casing: 244.5 mm, 64.7 kg/m, S00-95 LT&C landed at 3297.0 mKB

(External casing packer at 1367.82 mKB. Cemented with 122.3 m³ class G + 8% gel (33.3 tonnes 0:1:0 G, 103.3 tonnes 9:1:8), hole bridged off after 89.5 m³ displaced, ECP was set with 32.8 m³ cement left in casing) – 311 mm open-hole

Liner: 177.8 mm, 38.69 kg/m, S00-95 LT&C from 3234.88 to 4130.0 mKB

(Cemented with 24 m³ class G cement + 30% Silica flour, received 2.3 m³ cement returns to surface) – 216 mm open-hole

Frac string (permanent): 114.3 mm, 22.47 kg/m, P-110 casing from 3217.2 to 3899.71 mKB with

permanent liner top packer set at 3217.2 mKB. Ball actuated frac sleeves with ARES two stage hydraulic set packers, and permanent packer on



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bottom of string (see details on wellbore diagram) – 10K WR plug set at 3339 mKB

Tie-back string: 139.7 mm, 34.23 kg/m, P-110, LT&C casing joints, latched into

permanent liner packer at 3217.2 mKB to surface. Whipstock: Whipstock plug set at 4083.6 mKB inside 177.8 mm liner, window cut

in liner at 4078.89 mKB and drilled to 4200 m. Perforations: See perforations table below Wellhead: 279.4 mm x 139.7 mm 69 MPa flowing style bonnet Base of Groundwater Protection: 614.0 mKB (600 m below ground level) OBJECTIVE: Abandon well as per OROGO regulations, repair SCVF and cut and cap. Table 1 – Tubular Data

Production Casing

Tie-back string Frac String Workstring

Size OD [mm] 244.5 139.7 114.3 Size ID [mm] 222.38 118.62 99.57 Weight [kg/m] 64.74 34.23 20.09 Grade S-95 P-110 P-110 Drift [mm] 218.42 115.44 96.39 Capacity [m³/m] 0.038840 0.011051 0.0078 Annular Capacity [m³/m]

0.023511 (139.7 mm inside

string)

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Collapse [MPa] 38.6 100 73.6 Burst [MPa] 51.8 94 85.6 Tension [1000 daN] - 286 197



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Table 2 – Perforations, open-hole details

Perf Date Formation Top Shot Bottom Shot Status Gun Data 5-Sep-11 Exshaw 3351.00 3356.00 Suspended 17 SPM, 25 gr, 60° 5-Sep-11 Exshaw 3365.00 3370.00 Suspended 17 SPM, 25 gr, 60° 4-Sep-11 Upper Muskwa 3784.00 3789.00 Suspended 17 SPM, 25 gr, 60° 4-Sep-11 Upper Muskwa 3805.00 3810.00 Suspended 17 SPM, 25 gr, 60° 4-Sep-11 Lower Muskwa 3935.00 3940.00 Suspended 17 SPM, 25 gr, 60° 4-Sep-11 Lower Muskwa 3948.00 3953.00 Suspended 17 SPM, 25 gr, 60°

12-Oct-82 Nahanni 4079.80 4200.00 Abandoned Whip-stock, 153 mm open-hole

13-Sep-82 Nahanni 4130.00 4200.00 Abandoned 216 mm Open-hole



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2 DETAILED WELL HISTORY Amoco Canada Petroleum Company Ltd. began its operations on Amoco S. Pointed Mountain (D-1) L-68 in January 1982. Upon completion of surveying, and access road and location construction, the well was spudded on March 3, 1982. Drilling and completion operations concluded with the abandonment of the well and subsequent release of the rig Hi-Tower #4 on November 4, 1982.

The original drilling summary scans are attached, and detailed below:

Date Summary of Drilling Operations

1982-02-06

Construction of lease and road begins.

1982-03-09 Rig move to lease.

1982-03-25 Spudded well at 0930 hours. Drilled 445 mm pilot hole. Drilling rig: Hi-Tower #4.

1982-03-31 Finished drilling 445 mm pilot hole to 189 m. Opened hole to 660 mm.

1982-04-09 660 mm hole opened to 165 m. Ran 508 mm casing to 165 m. Cemented with 55 tonnes Oilwell Neat G cement. 100% returns.

1982-04-12 Rigged up diverter, tested to 3500 kPa for 15 minutes. Drilled out cement and began drilling 445 mm hole.

1982-04-21 Encountered drilling break at 577 m. Fresh water kick from formation. Controlled with 1184 kg/m³ mud, drilling resumed with 1200 kg/m³ mud.

1982-05-14 Converted mud system to fresh formation water. Depth 1065 m.

1982-05-20 Sour gas bubbling to surface, convert mud system back to gel-benex mud, density 1200 kg/m³. Depth 1227 mKB.

1982-06-07 Depth 1424 m. Ran 340 mm, 107 kg/m casing. Cemented with 42.7 tonnes Class “G” + 2% gel, 64.8 tonnes Class “G” + 8 % gel, and 13.2 tonnes Class “G” tail in. Full returns.

1982-06-13 Nippled up BOP’s. Tested to 31,000 kPa for 15 minutes. Drilled out cement for 311 mm hole. Performed leak off test, surface pressure 12,400 kPa with 1150 kg/m³ mud at 1434 m. Frac gradient of 19.9 kPa/m. Resumed drilling 311 mm hole.

1982-06-15 Encountering slight deviation problems at 1519 m. Inclination of 5.25°. Added stabilizers to BHA and reduced WOB to combat angle building.

1982-07-05 Depth 2373 m. Encountering severe gas cutting in mud. Combatted by increasing mud weight to 1150 kg/m³ diverting mud through poorboy degasser and drilling with a 1.5 m flare.



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1982-07-11 Gas kick at 2679 m with 1125 kg/m³ mud, 7.5 m³ / 45 min pit gain. SICP 3800 kPa, SIDP 100 kPa. Circulated out dick with 1140 kg/m³ mud.

1982-07-24 Deviation off scale on recording device, great than 8° inclination. RIH with strong dropping BHA.

1982-07-29 Reached casing point of 3297 mKB. Hole suffering from severely sloughing shales. Tried to condition hole for logging.

1982-08-08 Logging program waived by government due to hole programs. Ran 245 mm, 64.7 kg/m, S0095 casing to 3297 m, with a Lynes External Casing Packer at 1367.82 m. Cemented with 122.3 m³ neat G + 8% gel, hole bridged off after 89.5 m³ displaced. ECP is set and 32.8 m³ cement left in casing.

1982-08-10 Cement top at 2434 m, drilled out cement to 3285 m. Ran gyro-survey and cased hole logs.

1982-08-14 Drilled out shoe and drilled 216 mm hole.

1982-09-05 Drilled to T.D. of 4200 m, ran multishot survey. Logged.

1982-09-13 Ran 177.8 mm liner, hung at 3234.88 m and land at 4130 mKB. Cemented with 24 m³ Class “G” cement plus 30% Silica flour. Received 2.3 m³ cement returns at surface.

1982-09-16 While drilling out cement, could not get by 4103 mKB. Parted liner suspected. Attempted milling through.

1982-10-01 Whipstocking tool set at 4083.6 m. Window cut in liner at 4078.89 m.

1982-10-12 Reached T.D. of 4200 m with 153 mm bit.

Date Summary of Initial Completion & Abandonment Operations

1982-10-15 Set packer at 4070 m, RIH with 88.9 mm C.S. Hydril tubing. While pressure testing annulus to 34,000 kPa, tubing collapsed.

1982-10-16 Fishing operations initiated.

1982-10-29 Fish fully retrieved. Ran Halliburton RTTS tool to perform DST. No fluid inflow recorded on DST.

1982-10-30 Set new packer at 4165 m. RIH with new 88.9 mm C.S. Hydril tubing string. Set 1 m³ 28% HCl across Nahanni in attempt to initiate feed rate. Surface pressure of 49,630 kPa applied at surface, negligible feed rate.

1982-11-01 Latched Baker DR plug into packer. Ran cement plug #1: 4005 to 40065 m with 1.5 m³ Oilwell Neat G cement. Ran cement plug #2: 3207 to 3267 m with 1.6 m³ Oilwell Neat G cement. Plug # 2 tagged at 3206 m.



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1982-11-04 Rig released at 1982-11-04 at 0800 hours. All equipment to be left on location until winter when ice bridge is built. Sump will be treated and cleaned up during the winter months as well.

1982-11 (date unknown)

Cut and capped casings at surface with welded plate at 400 L Neat G cement.

Note: at the time in 1982, this well was abandoned in accordance with regulations. The original Nahanni open-hole completion remains abandoned as per the original abandonment requirements to this day.



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Figure 1 - Wellbore schematic after initial drill, completion and abandonment operations

The well was re-entered in 2011 to perforate, fracture and evaluate the Upper and Lower Muskwa and Exshaw formations. A 114.3 mm ball-drop frac string was run into the liner, with a permanent packer set in the 244.5 mm casing at 3217 mKB. A 139.7 mm tie-back string was installed. The well was left



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suspended with 114.3 mm retrievable bridge plug set at 3339.0 mKB and the configuration remains the same today. A summary of the re-entry operations is as follows, with detailed reports attached as backup: Date Summary of Re-entry Operations 2011-08-24 Drive to lease, safety meeting regarding hot-tap, conduct hot-tap, bleed off pressure, monitor

well and wait on daylight. Costs inputted include waiting on weather and standby costs for services while gaining access to lease. All new people on location oriented at entryway, workers on standby were oriented at camp.

2011-08-25 Wait on daylight, no flow or pressure at well when arrived on site. Test for LEL's, cut conductor, cut 508mm csg, cut cap. Cement observed, discuss plan with Calgary, install csg bowl and NU BOP's. Leveled area for water tank. Pressure test blind rams, spot rig and rig up same.

2011-08-26 Continued to pressure test 10 K BOP stack components. Crew Change. Held pre-job and safety meeting. Orientated all new personnel and issued safe work permits to new contractors. Completed pressure testing of all components to 1 & 45 MPa on 10K BOP stack. Installed cross-over spool and 50.8 mm single gate rams. Finished rigging up remaining rig equipment. Hauled in and unloaded a total of 431 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Started building lined water tank and connecting walls. Rigged up snubbing unit above BOP stack. Drill pilot hole in cement plug, no pressure present. Rig down snubbing unit.

2011-08-27 Move in and spotted picker unit. Removed single gate pipe rams and cross-over spool. Crew change. Held pre-job and safety meeting. Made up 215.9 mm Tri-cone Bit and 88.9 mm Drill collar. Rigged up power swivel and pack-off head. Established reverse circulation. Drilled out excess cement at surface left from pilot hole previously drilled. Encountered good torque approximately 1.5 m below casing bowl. Circulated clean and rigged out power swivel and pack-off head. Rigged out rig and moved rig and associated equipment away from well center. Tore down and removed 10K BOP stack. Installed 139.7 mm gate valve and secured well. Moved in track hoe and excavated around wellhead. Wait on people and parts to cut casing bowl.

2011-08-28 Continued to wait on people and parts to arrive. Crew change. Held pre-job and safety meeting. Removed 139.7 mm gate valve and tubing head. Had track hoe finish excavating around wellhead. Welder, wellhead technician, and machined couplings arrived. Cut 339.7 mm surface casing 25 cm below previous welded coupling, removed casing bowl. Install 244.5mm casing extension and weld same. Install 339mm casing collars and casing and install casing bowl to approx. ground level. Jack 244.5mm casing and set slips with 45daN tension. Cut 244.5mm casing, install seal assembly and lift tubing spool into place. Hand tighten studs and wait on construction.

2011-08-29 Continued to wait on construction. Crew change, held pre-job and safety meeting. Back filled hole around wellhead using track hoe and cat. Tightened tubing head onto casing bowl, pressure tested primary and secondary seals to 22 MPa, good test. Installed 70 MPa BOP stack using picker. Spotted rig matting and associated rig equipment. Spotted service rig and rigged up. Rigged up floor and pipe handling equipment. Functioned and pressure tested all components on 70 MPa BOP stack to 1 MPa & 35 MPa, 10 minutes each test. PU bit, 88.9mm collars, install pack-off, drill out cement at surface, trip, remove packoff, torque all



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connections, RIH. Level rig. RIH, obstruction at ~584m. Install power swivel and work through obstruction.

2011-08-30 Continued to drill out cement obstruction tagged at 584 m. Crew change, held pre-job and safety meeting. Picked up another 2 joints and continued to drill down through cement stringers. Ran another 2 joints down without rotating, casing appears cleaned out. Rigged out power swivel and pack-off head. Continued to pick up, tally, drift, and RIH with 88.9 mm, 13.84 kg/m, L-80, tubing. Tag cement at approx. 3204m. LD 1 joint, perform p-test on 9.5/8" csg to 21MPa for 10min. Bleed off, trapped pressure in tubing string. Install CIRC swedge, pressure up, open valve. Reverse CIRC btms up. Run out of suction due to thick fluid left in hole. Wait on vac skid and fluid.

2011-08-31 Continued to wait on fluid and vacuum truck. Crew change. Held pre-job and safety meeting with all personnel on site. Ordered vacuum truck from Ft Nelson (vacuum skid broke down). Note: Towed up 2 water trucks from barge landing last night and 1 water truck this morning. Encountered good rain last night, today sunny and road slowly drying. Hauled in and unloaded 70 m3 of 7% KCL water. Sent 5 water trucks (body jobs) in afternoon down to the barge landing and loaded 90 m3 of fresh water from Ft Liard river. Pump water into 400bbl. Break CIRC, pump returns into 400bbl. Drill cmt plug, pack-off failure. Replace pack-off rubber, drill ahead, CIRC btms up, pack-off failure again. Swap Weatherford pack-off for rig pack-off. Drill cmt plug, power swivel stalling frequently.

2011-09-01 Continued forward circulating, started drilling down. Crew change, held pre-job and safety meeting. Orientated new personnel and issued safe work permit to Troyer vacuum service. Changed back to reverse circulating and circulated bottoms up. Added 8 m3 of clean KCL water to circulating system to help dilute viscous mud in hole. Drilled out approximately 18 m of hard cement down to a total depth of 3240 mKB. Did not tag liner top, estimated liner top within 2 m. Fluid in circulating system more viscous, having trouble pumping. Finished circulating bottoms up and decided to pull out and drill out remaining cement with 158.8 mm bit. Rigged out power swivel and pack-off head, prepared to pull pipe. POOH, pipe not draining. Install mud can and suck with vac truck. Pipe began draining around 2000m, release vac truck, pump 1m3 at 152m to clear pipe (not draining again). Change bit and RIH.

2011-09-02 Continued to run in out of derrick with 88.9 mm tubing. Crew change, held pre-job and safety meeting. Continued running in with 158.8 mm Bit and 88.9 mm Drill collars on 88.9 mm tubing. Ran in out of derrick a total of 154 joints. Landed tubing bottom 9.5 m above previous drilled depth @ 3240 mKB. Picked up 1 joint and rigged up power swivel and RS stripping head. Hauled in 80 m3 of fresh water from the Ft Liard river and spotted tank trucks. Sucked out of tank trucks and reverse circulated to displace mud out of wellbore. Observed golden sand like barite in returns. Started drilling, ran down and cleaned out approximately 7 meters of fill to cement top @ 3240 mKB. Drill from 3240m to 3260m. RIH 2 jts w/o pumping, rig down power swivel and RS head, RIH with 88.9mm tubing.

2011-09-03 Continued to pick up, tally, drift, and run in off pipe racks with 88.9 mm tubing. Crew change, held pre-job and safety meeting with all personnel on site. Ran in a total of 414 joints and tagged plug back @ 3971 mKB. Rigged up power swivel and RS head. Established reverse circulation, could not rotate tubing string, power swivel to small (85 tonne) not enough torque to turn string around bend at this depth. Observed thick mud and good signs of gas in returns. Circulating system more viscous again, lost prime on pump. Continued to circulate gas bubble



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out using clean KCL water, mud returns less viscous. Rigged out power swivel and RS-head. Pulled out a total of 77 joints, tubing pulling wet, used mud can and vacuum truck. Worked joint # 337 through liner top @ 3235 mKB. Pressure tested the casing to 21 MPa for15 minutes, good test. Continue to POOH, LD BHA, MU logging tools, install lubricator, RIH and log well.

2011-09-04 Continued to bond log well. Crew change, held pre-job and safety meeting with all personnel on site. Conducted GR-CCL-VDL-CBL-Radio log inside 177.8 mm casing from PB at 3961 mKB to top of liner @ 3236 mKB, correlated to an emailed copy of open hole log dated March 25/1982. Cement bond looked good over all zones of interest. Cement bond was questionable over liner top, conducted 7 MPa pressure pass from 3500 m to liner top and improved bond slightly, estimated cement top above liner top behind the 244.5 mm casing. Conducted GR-CCL-VDL-CBL-Radio log inside the 244.5 mm casing from 2950 m to 2000 m. Cement bond looked very poor, conducted 7 MPa pressure pass with no improvement, could not determine cement top. Pulled out and laid down logging tools. RIH and perf 6 intervals as per time log. All charges fired in runs #1-5. Perforated with 127 mm ERHSC, 17 spm, 25 gr salt/pepper, 60° phasing: 3948 – 3953 mKB 3935 – 3940 mKB 3805 – 3810 mKB 3784 – 3789 mKB 3365 – 3370 mKB 3351 – 3356 mKB

2011-09-05 Pulled out and recovered last gun, all shots fired. Rigged out and released wireline unit. Made up and ran in as follows; 155.6 mm Tri-cone Bit, 177.8 mm casing scraper, x-over, 88.9 mm pup joint, 79 joints of 88.9 mm, 13.84 kg/m, L-80, tubing, x-over, 244.5 mm casing scraper, x-over, 88.9 mm pup joint, and 340 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Worked scraper over all perforated intervals. Tagged hard PB same as before @ 3971 mKB (rig tally). Circulated down and cleaned out approximately 0.5 m of fill, PB was solid. Continued to circulate and displaced well over to 3% KCL water. LD RS head, POOH, LD casing scrapers.

2011-09-06 Continued to pull out with 88.9 mm tubing, racked a total of 328 joints into derrick. Crew change, held pre-job and safety meeting with all personnel on site. Rigged up casing tongs and 114.3 mm handling equipment. Made up, tallied, drifted and ran in with 57 joints of 114.3 mm casing liner and packer assembly. Ran in with weatherford setting tool on 340 joints of 88.9 mm tubing. Set packers, pull test packers, p-test packer top to 21MPa for 15 min. Back-off from packer and POOH laying down 88.9mm tubing.

2011-09-07 Continued to pull out with 88.9 mm tubing, racked a total of 328 joints into derrick. Crew change, held pre-job and safety meeting with all personnel on site. Rigged up casing tongs and 114.3 mm handling equipment. Made up, tallied, drifted and ran in with 57 joints of 114.3 mm casing liner and packer assembly. Ran in with weatherford setting tool on 340 joints of 88.9 mm tubing. Set packers, pull test packers, p-test packer top to 21MPa for 15 min. Back-off from packer and POOH laying down 88.9mm tubing.

2011-09-08 Continued to wait on rig repair to cracked gusset on A-leg frame.

2011-09-09 Repair gusset, test weld with magnetic particles, test is good. Shutdown by NEB.



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2011-09-10 Continued to wait on NEB approval to move forward. Conducted CAODC level III inspection on derrick components and documented. NEB approval was granted to continue operations. Held pre-job and safety meeting with all personnel on site. Stood derrick and rigged up rig. Rigged up floor and pipe handling equipment. Made up and ran in with 176.9 mm Ultrapak Latch Seal assembly on 139mm 34.23kg/m P110 LT&C casing. RIH to joint 229, stab into upper packer, mark 20 and 25kdaN compression, back out of packer.

2011-09-11 Continued to wait on NEB approval to move forward. Conducted CAODC level III inspection on derrick components and documented. NEB approval was granted to continue operations. Held pre-job and safety meeting with all personnel on site. Stood derrick and rigged up rig. Rigged up floor and pipe handling equipment. Made up and ran in with 176.9 mm Ultrapak Latch Seal assembly on 139mm 34.23kg/m P110 LT&C casing. RIH to joint 229, stab into upper packer, mark 20 and 25kdaN compression, back out of packer.

2011-09-12 Started up, held pre-job and safety meeting. Rigged out and loaded remaining equipment, cleaned rig tank. Removed 70 MPa BOPS and installed upper 139.7 mm x 70 MPa wellhead. Secured well. Spotted evaporation tank and propane skids. Released water haulers. Total water hauled from Ft Liard river and stored in double lined C-ring tank on location was 6,010 m3. Hauled all rig equipment down to barge landing and prepared to move across river in morning. SDFN.

2011-09-13 Started up, held pre-job and safety meeting. Loaded rig equipment onto barge and moved across river. Loaded rig onto wheeler and moved back to base in Grande Prairie. Hauled rental equipment back to Grande Prairie. Released service rig. Transferred fluid on location to evaporation tank. Wait on frac equipment. Note: Ordered High rate pressure truck and surface gauges to conduct breakdown and feed rate test.

2011-09-14 Wait on availability of Cal-Frac pumping equipment. Assisted NEB on camp and location site inspection.

2011-09-15 Wait on pressure truck to arrive, had tug boat barge across river and unload. Held pre-job and safety meeting. Rigged up pressure truck, installed adapter flange to flow-tee on 70 MPa wellhead. Installed surface recorders. Applied annular pressure. Pumped off tubing end plug and achieved breakdown on Lower Muskwa intervals @ 65.5 MPa. Initial feed rate was 40 lit/min @ 70 MPa, final feed rate was 80 lit/min @ 65.5 MPa. Secured well with surface recorders monitoring pressure every 30 seconds. Rigged out and released pressure truck. Continued to wait on availability for Cal-Frac pumping equipment.

2011-09-16 Continued to wait on Cal-Frac pumping equipment. Surface recorders still monitoring leak off pressure from previous injection test. SITP: 32,280 kPa.

2011-09-17 Continued to wait on availability of Cal-Frac pumping equipment. Surface recorders still monitoring leak off pressure from previous injection test to Lower Muskwa intervals. SITP: 26,200 kPa.

2011-09-18 Continued to wait on availability of Cal-Frac pumping equipment. Scheduled to arrive on Friday Sept 23. Hauled in and spotted sand cans on location, prepared to haul in frac sand next day. Surface recorders still monitoring leak off pressure. SITP was 24,254 kPa.



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2011-09-19 Barged 9 transports across river and moved up to location. Unloaded 260 tonnes of sand into sand cans on location. Prepared to move sand transports across river and release units in the morning. Continued to wait on remaining Cal-Frac pumping equipment.

2011-09-20 Hauled in and rigged up transfer pumps and tank manifold to supply water from C-ring tank. Continued to wait on CalFrac pumping equipment.

2011-09-21 Hauled in and rigged up 36.5 m flare stack. Installed ammonia scrubbers to shipping tanks. Continued to wait on availability of Cal-Frac pumping equipment.

2011-09-22 MIRU wellhead isolation tool. Rigged up wind monitoring tower. Continued to wait on Cal-Frac pumping equipment. First wave of equipment to arrive at barge in the morning.

2011-09-23 Barged 15 frac units across river and moved up lease road to camp site. Chained up all equipment and had tow cats assist equipment up access road. Orientated all new personnel.

2011-09-24 Move in remaining CWS units, spot same and rig up to frac. Wait on daylight.

2011-09-25 Rig up to frac. Start transfer pumps from water tank, return line fell from tank edge striking 1 person. See incident report for further details. Review transfer equipment, add additional return line and secure same. Test transfer equipment. Prep to p-test CWS and p-test same. Pump frac treatment as per time long summary. Shut IES isolation equipment, bleed off CWS and rig-down flow lines. Shut-down for daylight.

2011-09-26 Started up, held pre-job and safety meeting with all personnel on site. Staged out wellhead isolation tool. Dropped 84 mm ball onto gate valve. Installed wellhead isolation tool, opened well and dropped ball, staged in isolation tool. Rigged up pumping lines. Pressure tested surface equipment and lines to 83 MPa. Spearheaded 3 m3 of 15% HCL acid + additives. Seated ball and shifted frac sleeve port @ 70 MPa, spotted acid into formation and allowed to soak for 5 minutes. Fracture treated the upper Muskwa intervals down 139.7 mm casing at an average rate of 9 m3/min. Observed breakdown ( feed rate ) at 70 MPa with an average treating pressure of 69 MPa. Pumped a total of 1,763 m3 fresh water. Down hole sand concentration went from 30 kg/m3 to 220 kg/m3 with sweeps between stages. Total sand pumped was 10 tonne 50/140 mesh, 80 tonne 40/70 mesh and 20 tonne 40/70 prime plus mesh. Total sand into formation was 110 tonne, over flushed by 15 m3. ISIP was 54.7 MPa, 5 min SIP was 52.6 MPa, 15 min SIP was 51.5 MPa. Rigged off pumping lines and secured well for night. SDFN.

2011-09-27 Started up, held pre-job and safety meeting with all personnel on site. Staged out wellhead isolation tool. Dropped 88.9 mm ball onto gate valve. Installed wellhead isolation tool, opened well and dropped ball, staged in isolation tool. Rigged up pumping lines. Pressure tested surface equipment and lines to 83 MPa. Spearheaded 4 m3 of 15% HCL acid + additives. Seated ball and shifted frac sleeve port @ 75 MPa, had difficulty shifting sleeve, spotted acid into formation and allowed to soak for 5 minutes. Fracture treated the upper Exshaw intervals down 139.7 mm casing at an average rate of 3.6 m3/min. Observed no breakdown, very tight, started to feed at 65 MPa with a lower rate initially. Average treating pressure was 72 MPa. Pumped a total of 871 m3 fresh water. Down hole sand concentration was between 30 kg/m3 to 70 kg/m3 with sweep stages. Total sand pumped was 10 tonne 50/140 mesh and 17 tonne 40/70 mesh. Total sand into formation was approximately 26 tonne. Sanded off with approximately 1 tonne inside pipe, total flush volume was 9.5 m3. ISIP was 75 MPa, 5 min



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SIP was 55.8 MPa. Rigged off pumping lines, rigged out wellhead isolation tool. SITP: 48,170 kPa; SICP: 10,220 kPa. Opened well up and flowed back to P-tank through 7.9 mm bean choke. Made straight fluid, no sign of any gas, returns slightly foamy, average recovery rate was 40 m3/hr. Water salinity was 14,000 ppm, temperature was 124 deg C, no sign of any sand. After 8 hours of continuous flowing the tubing pressure was down to 28,870 kPa, total fluid recovered was 324 m3. See testers field notes for all details. Continued to flow well back on clean up.

2011-09-28 Continued to flow back well on clean up. Held pre-job and safety meeting. Rigged out Cal-frac pumping equipment. Moved mostly all of Cal-Frac equipment off location. Chained up equipment and had tow tractors assist equipment down access road back to camp. Continued to flow well back to P-tank up 139.7 mm casing. Observed first signs of burnable gas after 15 hours of flowing and approximately 20% load fluid recovered. Gradually increased choke size until flowing wide open through gutline. Average fluid recovery rate gradually decreased to 15.5 m3/hr. After 32 hours of continuous flowing the tubing pressure gradually declined to 830 kPa. Well appeared to be slowly loading up. Estimated gas rate between 2,000 - 3,000 m3/d, no sign of any H2S, tested approximately 15% CO2. No sign of any more sand in returns. Total load fluid recovered was 1,031 m3 water, load fluid left to recover was approximately 2,837 m3. Final water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well back on clean up.

2011-09-29 Continued to flow well back to P-tank up 139.7 mm casing. Moved remaining frac equipment off location, emptied sand cans and prepared to move. Flowed back wide open through 50.8 mm gutline. Pressure and rates gradually declined. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 7.5 m3/hr, no sign of any sand. After 56 hours flowing tubing pressure ( 139.7 mm csg ) declined to 800 kPa, estimated gas rate around 2,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 39 deg C. Total load fluid recovered to date was 1,327 m3 water, load fluid left to recover was approximately 2,541 m3. Water salinity was 28,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well until dead.

2011-09-30 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 6.5 m3/hr, no sign of any sand. After 80 hours flowing tubing pressure (139.7 mm csg) appeared stable between 650 to 700 kPa, estimated gas rate between 2,000 to 3,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Total load fluid recovered to date was 1,488 m3 water, load fluid left to recover was approximately 2,380 m3. Water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

2011-10-01 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Shut in well for 1 hour 3 times and monitored build up pressure. SITP increased to 9,700 kPa twice and 8,940 kPa on the third time. Pressure bled off immediately each time well was opened, very little gas head, all fluid pressure. Average fluid recovery rate decreased to 3.5 m3/hr, no sign of any sand. After 104 hours flowing tubing pressure (139.7 mm csg) would flux between 570 to 650 kPa, estimated gas rate at 2,000 m3/d or less. Unable to get accurate gas rate because meter too big to measure small rates, smaller meter to arrive and install today. No sign of any H2S, tested 15% CO2, flow temperature at 30 deg C. Total load fluid recovered to date was 1,575 m3 water, load fluid left to recover was approximately 2,293 m3.



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Water salinity was 40,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

2011-10-02 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Average fluid recovery rate was 3.5 m3/hr, flowing tubing pressure (139.7 mm csg) was 650 kPa. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Shut in well for 4 hours. Removed ball catcher from wellhead and retrieved 88.9 mm ball stuck inside catcher. Rigged up flowline back to wellhead, installed smaller meter before outlet to flare stack. SITP was 11,250 kPa. Flowed back to P-tank wide open through 50.8 mm gutline. Pressure bled off immediately, observed small gas head followed by straight fluid. Pressure decreased to 100 kPa, no sign of any more gas, average fluid recovery rate increased to 6.4 m3/hr last 4 hours. Shut in well and monitored pressure build up overnight. Flowed well for a total of 106 hours. Total load fluid recovered to date was 1,611 m3 water, load water left to recover was approximately 2,257 m3. Water salinity was 39,000 ppm, PH was 7. SIWP after 13 hrs was 13,800 kPa. See testers field notes for all details. Continued to monitor build up pressure.

2011-10-03 Continued to monitor build up pressure. After 26 hours SIWP was 15,470 kPa. Rigged out and released 36.5 m flare stack. Rigged up 12.2 m flare stack. Collected 2 gas samples. Opened well up and flowed back to P-tank through 50.8 mm gutline. Pressure bled down immediately to 800 kPa, observed very small gas head then started making straight fluid. Flowing pressure would flux between 300 to 600 kPa, average fluid recovery rate was approximately 6.4 m3/hr. No sign of any gas. Total fluid recovered last 11 hours was 69.9 m3. Total fluid recovered to date was 1,680.6 m3 water, load water left to recover was approximately 2,187.4 m3. Water salinity was 36,000 ppm, flow temperature was 18 deg C. See testers field notes for all details. Continued to flow well back on clean up.

2011-10-04 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, average fluid recovery rate last 6 hours was 3.8 m3/hr, no sign of any sand. After 35 hours of continuous flowing, the tubing pressure (139.7 mm csg) appeared stable around 410 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 18 deg C. Total load fluid recovered to date was 1,798 m3 water, load fluid left to recover was approximately 2,070 m3. Water salinity was 48,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

2011-10-05 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, very little gas again, average fluid recovery rate was 3.5 m3/hr, no sign of any sand. After 59 hours of continuous flowing, the tubing pressure ( 139.7 mm csg ) would flux between 100 to 300 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2. The well stopped making gas last 8 hours, used propane to ship fluid. Flow temperature at 18 deg C. Total load fluid recovered to date was 1,882.6 m3 water, load fluid left to recover was approximately 1,985.4 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.



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2011-10-06 Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Presently no sign of any gas (comes & goes). Average fluid recovery rate decreased to 2.7 m3/hr, no sign of any sand. After 70.5 hours flowing tubing pressure was around 450 kPa. Last estimated gas rate was below 1,000 m3/d, no sign of any H2S, tested 15% CO2. Final flow temperature was at 20 deg C. Total load fluid recovered to date was 1,914 m3 water, load fluid left to recover was approximately 1,954 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Shut in well and rigged up electric wireline unit. Installed lubricator with grease injector head. Ran in with 70 mm gauge ring and tagged possible frac ball at 2350 m, chased ball down to bottom and tagged frac sleeve port @ 3811 m. Pulled out with gauge ring and rigged off lubricator. Continued to monitor build up pressures. SIWP after 11.5 hours was 10,100 kPa. Opened well up and flowed back to P-tank through 50.8 mm gutline. Pressure bled down rapidly and started making straight fluid, very little signs of gas. Recovered 7.7 m3 load water in first hour. Continued to flow well and prepared for spinner log.

2011-10-07 Continued to flow up 139.7 mm casing back to P-tank wide open through 50.8 mm gutline. Flowing straight fluid around 200 kPa, very little signs of gas, average fluid recovery rate last 3 hrs was 5 m3/hr. Held pre-job and safety meeting. Rigged up wireline lubricator with grease injector head. Continued flowing well and ran in with production-spinner log. Ran down through both frac sleeve ports to a total depth of 3850 mKB, no sign of missing shifting sleeve ball. Correlated on depth to Encore Radial Cement Bond Log dated Sept 4/2011. Conducted 3 up and 3 down passes at 30, 20, and 10 m/min from 3850 m to 3250 m. Started to see more gas at surface while logging, measured gas rate at 0.4 m3/d. Made 10 minute station stops at 3835, 3775, 3380, and 3340 mKB. Collected 2 gas samples prior to shutting in well. Total load water recovered was 1,953 m3. See testers report for details. Made 3 shut in passes at 30, 60, and 90 minute intervals at 20 m/min from 3850 m to 3250 m. Pulled out with logging tools. Rigged out grease injector and lubricator with BOPS. Rigged out wireline unit and moved equipment back to camp. Prepared to barge across river in the morning. Moved in and rigged up High rate pressure truck, held prejob and safety meeting. Started to inject load water back into wellbore. Initial pumping rate was 0.5 m3/min @ 30 MPa. Final pumping rate was 0.5 m3/min @ 48 MPa. Stopped pumping to cool down unit and tighten leak on flange.

2011-10-08 Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 48 MPa. Injection pressure remained stable last 20 hours. Total pumping time was 33 hours including cool down and maintenance breaks. Estimated total volume pumped was 620 m3. Continued to dispose load water down wellbore.

2011-10-09 Pressure truck shut down due to diesel pollution control for exhaust, urea pod was empty. Wait on hot shot from Ft Nelson with more urea. Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 49 MPa. Injection pressure remained fairly stable. Total pumping time was 48 hours including cool down and maintenance breaks. Estimated total volume pumped was 900 m3. Continued to dispose load water down wellbore.

2011-10-10 Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 49 MPa. Injection pressure remained stable last 33 hours. Total pumping time was 72 hours including cool down and maintenance breaks. Estimated total volume pumped was 1400 m3. Continued to dispose load water down wellbore.



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2011-10-11 Continued to suck out of C-ring tank and pump load water down wellbore. Sucked out C-ring tank mostly dry for a total of 1,420 m3 disposed down wellbore. Rigged out pressure truck and moved over to suck out of tank farm. Started to pump from tank farm when pressure truck broke down due to clutch failure, could not continue. Rigged out pressure truck and lines. Towed pressure truck down to barge landing for morning. Secured well. Note: Backup pressure truck still not available, on waiting list with several contractors. Attempt to line up tank trucks to transfer remaining fluid, approximate load water left on location is 530 m3. SDFN.

2011-10-12 Barged picker and tractor trailers across river to assist in tear down of C-ring tank. Access road very wet and muddy, very slippery at barge landing. Tow tractors had to assist all equipment up to camp, took all day to get equipment that far, road condition bad. Has been wet fog and light rain/snow last several days. Wait on availability of high rate 10K pressure truck, initial truck possibly has clutch repaired tomorrow.

2011-10-13 Towed picker and trucks up to location from camp. Dismantled and loaded C-ring tank along with liner for disposal. Towed equipment back to camp. Access road very wet and muddy, used both tow tractors on each end of units to assist in and off location, very slippery conditions.

2011-10-14 Towed bed truck trailers down to barge landing with heavy loads (c-ring walls & liner debris). Access road in poor condition at sections, tow tractor and bed truck both stuck, wait on cat to assist equipment free. Had to repair chains on one tow tractor. Loaded trucks onto barge, Tiggo picker still at camp waiting for tow. Towed wireline unit and picker from barge landing up to camp. Wireline unit broke down, tore fan belt off, have no power to computer end. Replace fan belt and check fuses in morning and attempt to fix electrical problem. Note: Access road from camp to location site starting to dry and improve. Note: Ordered 2 commanders with 24 hr crews for Monday Oct 17 to start demobilization of camp. Will also use another commander previously here for Apache.

2011-10-15 Worked on wireline truck. Replaced fan belt and repaired electrical problem. Moved Boreal electric wireline unit from camp to location site. Access road was frozen early morning, equipment moved in chained up with no problems. Held pre-job and safety meeting. Rigged up wireline unit with picker. Installed lubricator with grease injector head, pressure tested lubricator. SIWP: 26,000 kPa. Ran in with 94 mm gauge ring to just above the Exshaw intervals. Ran in with Tryton 10K WR plug, correlated to Boreal Production-Spinner Log dated October 7/2011. Set Retrievable Bridge Plug inside the 114.3 mm Liner 12 m above the Exshaw intervals @ 3339 mKB. Pulled out and recovered setting tools. Rigged out and released wireline unit. Bled well pressure off back to P-tank, pressure bled off quickly and recovered minimum fluid, well was dead, plug was holding. Ran hose down tubing and had vacuum truck suck down fluid level. Pour 160 liters of weighted corrosion inhibitor down tubing for approximately 0.5% inhibited volume. Shut in and secured well. Rigged out remaining test equipment. Rigged out all remaining rental equipment. Prepared to move equipment in the morning. SDFN.

2011-10-16 Had tow tractors assist wireline equipment and testers down to barge landing. Loaded barges and transported equipment across river and released. Hauled evaporation tank and wellsite shack down to barge landing. Hauled all remaining equipment including P-tank off location and down to camp site. Left 12 rental tanks with approximately 530 m3 load water on



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location. Cleaned up location site and secured well. Note: Sent 4 gas samples to AGAT in Ft St John for routine analysis.

2011-10-17 Barged 2 commander units across river. Started to dismantle camp. Emptied water tanks and sucked out sewer tank. Tore down water lines and sewer lines. Pulled all pumps from water wells. Released camp staff and moved all other necessary personnel over to base camp on other side of river. Started hauling camp and equipment down to barge landing. Total of 3 commander units hauling 24 hr/d.

2011-10-18 Continue to load and haul camp and equipment down to barge landing using commanders to travel access road. Had 1 bed truck working camp site and another bed truck loading barges. Encountered rain again, access road soft and muddy, tow tractors had to assist commanders through bad section. Had cats continue to work section of road. The smaller commander unit broke down, could not repair drive shaft, continued hauling with remaining commanders. Approximately 60% of camp and equipment hauled down to barge landing with approximately 40% across river.

2011-10-19 Continued to load and haul camp and equipment down to barge landing using commanders. Had cat and grader smooth out location site and access road down to camp site. Remaining cats worked bad section on access road to barge landing to help keep equipment moving. Road getting better. Continued barging equipment and shacks across river. Had bed trucks haul camp shacks to Acho camps yard near Ft Liard. Hauled and set up camps wellsite unit at main base camp in Ft Liard. Hauled P-tank and pipe skid to Ft St John. Hauled 10K rental pipe and manifold to Grande Prairie. Approximately 90% of camp and equipment hauled down to barge landing with approximately 70% across river. Continued with camp clean up and road repair.

2011-10-20 Continued to haul final loads down to barge landing. Cleaned up camp site. Loaded barges and transported all remaining camp and equipment across river. Transported bed trucks and commanders across river. Hauled and returned all camp shacks back to Acho yard near Ft Liard. Load and release commanders in the morning. Note: Left construction equipment on other side of river to clean up access road.

2011-10-21 Had cats and grader work access road and smooth all ruts out. Moved all construction equipment down to barge landing and prepared to transport across river in the morning. Started loading and hauling out all rental equipment.

2011-10-22 Cleaned up barge landing site and restored to original condition. Loaded all construction equipment and barged across river. Loaded and returned all rental equipment back to origins in Edmonton, Red Deer, Grande Prairie, Ft St John, and Ft Nelson. Access road left in fair condition with no bad ruts. Well secured. Left 12 rental tanks with approximately 530 m3 water equally balanced between all tanks on location to freeze over winter. Job completed. Note: Beaver Enterprises will tear up and load liner material into Kris Muller's end dumps and haul to Secure in Grande Prairie for disposal.



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Figure 2 - Well diagram after 2011 re-entry



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Figure 3 - Detailed frac string schematic



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Figure 4 - Spinner log notes – Boreal Eline Oct 7, 2011



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3 ABANDONMENT PROGRAM – RECOMMENDED PROCEDURE Refer to Vertex Professional Service standard procedure, “Fire and Explosion Prevention” regarding Directive 33.

3.1 WELLBORE ABANDONMENT Note: Copy of Operations Authorization, Well approval and operating manuals and other procedures to execute the work activity should be available all the time in the location

• All depths in the program are measured depths.

• “Oil and Gas Occupational Health and Safety Regulations”, “Oil and Gas Drilling and Production Regulations” and “Oil and Gas Operations Act” Copies should be followed and available on site all the time.

• Personnel and equipment certificates should always be available during operations.

2. Notify the PPR field office and OROGO at least 24 hours before commencing well site operations. Ensure the following documentation is completed prior to commencing wellsite operations:

• PPR Wellsite Hazard Assessment Plot Plan; scout the location for construction requirements, hazard identification, and wellhead specification.

• PPR Notice of Supervision form.

• PPR Well Site / Facility Handover Form with the PPR production staff.

• PPR ‘Ground Disturbance’ requirements.

• PPR Flaring / Venting / Incinerating Resident Notification Form; deliver to all the applicable residents and document the date and time of delivery in daily report - confirm with the Calgary office that the resident notification has been conducted.

i. Note: Refer to the key contacts in the program for names and numbers.

3. No flaring is anticipated on this wellbore.

4. Perform a surface casing vent flow and gas migration test. Ensure the PPR Surface Casing Vent Flow/Gas Migration Data Sheet is completed and sent in with the final report.

5. Rig in free standing Class III rig and associated equipment in accordance with which OROGO, PPR Exploration and OH&S specifications. Complete CAODC service rig inspection and rectify any deficiencies before continuing. Function test crown saver and all diesel engine kills.

• Note: Ensure the Unit and associated equipment can handle 73.0 mm / 60.3 mm tapered work string, and 3200 m of 139.7 mm tie-back string



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6. Rig in the following safety services as required:

Service Condition

ETV Travel time from wellsite to health care facility > 40 min

Medic Number of workers on location > 19

Air Trailer H2S > 0 ppm

Safety Supervisor H2S > 1.0%

Fire Protection Heating or high pressure pumping of flammable fluids

Shower unit Potential of body exposure to injurious materials

7. Sweep area for ‘LELs’. Check wellhead for H2S and shut-in pressures.

8. Hold a safety and procedural meeting; conduct a pre-job hazard assessment with all onsite personnel and document in the daily report.

• Note: Ensure the Directive 033 - Explosive Mixture and Ignition Potential Identification Sheet is filled out, discussed, and posted in the doghouse.

9. Stump test the BOP equipment, manifold, and lines. Ensure the well is dead; kill well by circulating well over to fresh water. Remove wellhead, install the BOPs and pressure test the ring groove connection. Perform all pressure and function tests.

• Note: Low pressure test: 1400 kPa. High pressure test: 21 000 kPa (Or Max. capability of wellhead)

• Note: water will be used as a kill fluid since Hydrostatic Pressure of water @ deepest existing open perforation is higher than the determined BHP @ that depth.

10. Run in hole with Tryton “WR” retrieving tool on 60.3 mm / 73.0 mm tapered tubing string. Latch on to plug and open equalizing valve. Unset “WR” plug at 3339 mKB and let elements relax for 10 minutes. Pull and stand tapered tubing string. Lay down “WR” plug.

11. Conduct injectivity test in to the Exshaw, Upper and Lower Muskwa perforations with at least 2.0 m3 of fresh water. Design a cementing program based on the injectivity test results. Record the ISIP and monitor SCVF during injection.

12. Run recommended Weatherford 5-Blade Mill to tag ball seat in frac sleeve at 3372.33 mKB. Rig in power swivel and mill through ball sleeve. Continue to mill through second frac sleeve at 3812.23 mKB. Circulate clean, pull and lay down milling equipment.

13. Rig up wireline unit with pressure tested lubricator, run gauge ring to approximately 3900 mKB and retrieve.

14. Run and set cement retainer above lower frac sleeve at ~3775 mKB.



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15. Run cement stinger on tapered work string, sting into cement retainer (cementing program pending injection test results).

• Move in C&A unit, bulker and vacuum truck. Conduct slow rate cement squeeze through the cement retainer in to the Muskwa perforations.

i. The cement volume squeezed must be at least equal to the casing volume from the bottom of the retainer to the bottom perforations plus 0.5 m3.

ii. The final squeeze pressure must be a minimum of 7 MPa above the current reservoir pressure of the Muskwa.

16. Sting out of retainer and circulate a 30 m cement cap on the retainer. Pull and stand tapered tubing string.

17. Conduct secondary injectivity test into Exshaw perforations while monitoring SCVF. Document ISIP.

18. Rig up wireline unit, run and set second cement retainer above upper frac sleeve at ~3340 mKB. Pressure test to 7000 kPa for 10 minutes.

19. Run cement stinger on tapered work string, sting into cement retainer (cementing program pending injection test results).

• Move in C&A unit, bulker and vacuum truck. Conduct slow rate cement squeeze through the cement retainer in to the Exshaw perforations.


ii. The final squeeze pressure must be a minimum of 7 MPa above the current reservoir pressure of the Exshaw.

20. Sting out of retainer and circulate a 30 m cement cap on the retainer. Pull and stand tapered tubing string.

21. Change tubing handling equipment and pipe rams to 139.7 mm. Attempt to unlatch from Ultrapack Liner top packer.

• Contingency: if unable to unlatch, chemical cut 139.7 mm tie-back string above seal assembly

22. Once released from permanent liner hanger, top up with fresh water and pressure test entire wellbore to 7000 kPa for 10 minutes, pending results a bridge plug may need to be set before running logs.

23. Pull and lay down 139.7 mm tie-back string.

24. If required: run and set 244.5 mm bridge plug as close as practicable to liner hanger packer at 3217 mKB. Pressure test 244.5 mm casing to 7000 kPa for 10 minutes.



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25. Allow wellbore to stabilize before logging. Rig in wireline unit, run noise-temperature logs as per wireline proposal from bridge plug to surface. Send logs for interpretation.

26. Pending results of initial cement squeezes and review and interpretation of logs, additional cement squeezes will be conducted to repair SCVF at depths to be determined.

27. Contingency:

• Perforate the identified SCVF source(s) with a 127 mm x 1 m ERHSC (25 Gram GH, 20 SPM, 60 Deg)

• Conduct injectivity test in to the remedial perforations with at least 2.0 m3 of fresh water. Design a cementing program based on the injectivity test results. Record the Initial Shut in Pressure.

• Run in with a 244.5 mm cement retainer on hydraulic setting tool on 73.0 mm tubing and set the cement retainer within 5 m of remedial perforations (sweep the setting area with the MCCL prior to setting to ensure there are no nearby collars). Pressure test cement retainer to 7 MPa for 10 minutes.

• Move in C&A unit, bulker and vacuum truck. Conduct slow rate cement squeeze through the cement retainer in to the remedial perforations.


ii. The final squeeze pressure must be a minimum of 7 MPa above the current reservoir pressure

• Sting out of the retainer and balance a 30 m cement cap on the retainer

• Pull and lay down tubing.

28. Pending results of cement squeezes on SCVF, rig out service rig.

3.2 SURFACE ABANDONMENT 1. Conduct surface casing vent flow test to confirm the wellbore can be cut and capped. Fill

out and sign the Surface Casing Vent Flow data sheet. Also ensure there is no pressure on the wellbore. If no evidence of gas migration or surface casing vent flow exits, proceed with cut and cap operation.

2. Excavate a ditch / hole around the wellhead down to a depth of 2.5 m.

3. Ensure no wellhead pressure has built up by opening the casing or tubing valve. Perform a LEL atmospheric measurement in the excavation to ensure cutting operations are safe. Secure the wellhead with overhead rigging. Cut two windows into the production casing – DO NOT EXCEED 1/3 CASING CIRCUMFERENCE WITH EITHER WINDOW. Cut off both casings so that the production casing is recessed lower than the surface casing



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and that both casing strings are at least 2.0 meters below ground level when capped. Ensure all workers are fully prepared for well head and casing movement during this operation and are protected accordingly.

4. TACK Weld a metallurgic ally compatible steel plate across the production casing, using non continuous fillet welds to allow the production string to vent. Weld a separate steel plate in a similar fashion onto the surface casing. Weld the first two numbers of the location onto the top of the surface casing plate for future identification (i.e. – LSD-SECTION).

• NOTE: All steel plates must be compatible with the production casing to avoid corrosion.

5. Fill in the excavation above the casings. Remove all debris and move off location. Install post and sign at casing stub location with the following information:

• NOTE: No fluid or solids waste is anticipated during the operations.

6. Inform the field foreman that the job is complete.

7. Rig out and release all equipment. Note: All waste should be handled in accordance with PPR NWT Waste Management Plan document.

8. Prepare a sketch of the lease, including surplus equipment, contaminated area, etc. and forward to Calgary.



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3.3 DAILY REPORTS Daily activity report for the preceding 24 hours is to be in typed form and emailed to Vertex Professional Services weekdays prior to 7:30 A.M. MST time. VPS’s Calgary email is [email protected]. On weekends email field copy of report daily to contacts listed below.

After hours, weekdays or holiday, call the advised appointed contact at:

Jonah Urton [email protected]

Vertex Professional Services (587) 580-8514 (cell)

David Duncan [email protected]

Prairie Provident (403) 292-8188 (office)

(403) 660-1821 (cell)

Brad Likuski [email protected]


(403) 512-8305 (cell)

Rob Lemermeyer [email protected]


(403) 554-2202 (cell)

NOTES: All operations carried out on behalf of Prairie Provident shall be conducted in a safe manner, in compliance with the occupational health and safety act, Office of the Regulator of Oil and Gas Operations regulations, and any other relevant act, regulation, or law.

Prairie Provident’s operations must protect and maintain the quality and integrity of the environment in compliance with all environmental acts and regulations.

All tickets to be stamped and labeled with the AFE number or cost center number, coded and signed by the Completion Field Supervisor.

All contracted services must have an on-going safety program in place, which is being implemented and monitored.

A copy of this program shall be on location at all times.

Ensure that CAODC safety inspections are completed on a weekly basis and emailed to VPS’s Calgary office.

Ensure safety meetings are held on a weekly basis with each crew. Minutes of these meetings are to be forwarded to VPS’s Calgary office with the morning report and noted in the tour book.

mailto:[email protected]







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Ensure that daily BOP function tests are conducted and noted in the tour book.

Ensure that every seven (7) days a BOP drill is conducted and noted in the tour book.

Ensure that all personnel on site are aware of Prairie Provident’s EH&S policy

Ensure pre-job safety meetings are held and documented.

Ensure all personal protective equipment is in place and kept in good usable condition.

Ensure that all personnel are wearing/using personal protective equipment as required.

Ensure that hazards are identified and marked where required:

• Sump fences or markers should be in place

• Check and locate pipelines, power lines, and telephone lines before digging or trenching

Ensure that all spills are reported and cleaned up or recovered; this includes spilled drilling fluid, oil, produced water, diesel fuel or other chemicals.

Ensure that all wastes are disposed of in an approved manner, whether they are liquid or solid wastes.

Review MSDS sheets with crewmembers when handling hazardous chemicals.

Ensure that first aid equipment and supplies are in the designated location and readily available for use.

Record the fire extinguisher’s number and location and ensure that they have recent inspection tags on them.

Ensure that all confined areas around the rig are thoroughly checked out with both a toxic gas detector and explosive meter, before workers enter the confined spaces.

Ensure that the air quality is monitored on locations where H2S may be present.

Supervisor and the rig manager should be familiar with Prairie Provident’s emergency response plan. When working in an area where Prairie Provident does not have an established field operation, the supervisor and rig manager will be responsible for the initial implementation of the ERP.

Ensure that security around the wellsite is adequately maintained, to prevent unauthorized entry, and prevent the theft and damage of materials and supplies.

ALL OPERATIONS WILL CONFORM TO ALL CURRENT OROGO, OH&S AND PRAIRIE PROVIDENT RESOURCES CANADA LTD. REQUIREMENTS.



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3.4 SERVICES Table 3 – Service Contacts

Service Name Number Wellsite Supervisor TBD

PPR Foreman TBD

Rentals TBD

Cementers

TBD

Testers TBD

Wireline TBD

Slickline TBD

Fluid Heating TBD

Water Source TBD

Fluid Hauling TBD

Fluid Tanks TBD

Wellhead / Frac-head TBD

Service Rig TBD

Safety (medic) Production Tubing

TBD TBD

Hydraulic Catwalk TBD



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4 APPENDIX A – DOWNHOLE SCHEMATIC POST ABANDONMENT



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5 APPENDIX B – WELL CONTROL EQUIPMENT REQUIREMENT Well Control Equipment Requirements

- A well servicing 35 MPa blowout preventer (BOP) stack will be used for well control (see schematic below

o The BOP stack will consist of Work spool Pipe rams (sized tubing installed in the 2K-02 wellbore – 139.7 mm tie-back

string and 73 mm workstring) Blind rams Annular Preventer Remote Controls

- The BOP stack was chosen for two reasons: o The working pressure of the stack is well above the expected bottomhole pressure o The addition of the Annular Preventer allows for an additional level of backup for the

pipe rams when tripping tubing, pumping kill fluid, etc. - An appropriately size 35 MPa pump will be mobilized to the location with the service rig for

well kill operations - Enough kill fluid for 2 times the hole volume will be mobilized to location for well kill

operations.



- 32 -



- 33 -

6 APPENDIX C – GEOLOGICAL INTERPRETATION



- 34 -



- 35 -

Figure 5 - Geological Interpretation of Logs



- 36 -



- 37 -



- 38 -



- 39 -



- 40 -

Figure 6 - Geological Review of Cuttings



- 41 -

7 APPENDIX D – ABANDONMENT SCHEDULE

Days Description of Operations

1 – 3 Equipment mobilization

4 – 5 Rig up, run workstring to retrieve WR plug. Pull and lay down WR plug.

6 – 7 Run milling equipment, rig in power swivel. Mill out ball seats in frac ports.

8 Set cement retainer # 1

9 – 10 Cement squeeze Muskwa

11 Set cement retainer # 2

12 – 13 Cement squeeze Exshaw

14 – 15 Pull tie-back string

16 Set bridge plug, top up casing and allow well to settle

17 Run noise-temperature logs to identify SCVF source(s)

18 Perforate identified sources, set cement retainer #3

19 Cement squeeze remedial interval

20 Monitor SCVF

21 If SCVF has been repaired – cut and cap

22 – 24 Equipment demobilization



- 42 -

8 APPENDIX E – 2021 SITE INSPECTION

- This page was intentionally left blank -

Version: February 9, 2017

Page 1 of 3 Please print double-sided.

WELL INSPECTION REPORT

INSTRUCTIONS:

1. Complete both pages.

2. Send one electronic copy of this form and supporting technical documentation by email to [email protected].

3. Send one signed hard copy of this form and supporting technical documentation by courier to:

Chief Conservation Officer Office of the Regulator of Oil and Gas Operations 4th floor Northwest Tower 5201 50th Avenue

Yellowknife NT X1A 3S9

WELL INFORMATION

Well Name: CFOL FT Liard L-68-60-20-123-45 2k-02

Coordinates: (verify onsite) Lat: 60 ° 11 ‘ 34 .7 “ Long: 123 ° 31 ‘ 9.3 “

Datum: NAD83

Well Operator: Prairie Provident Resources Status: Suspended

Current Inspection Date: 24-Apr-2021 WID: 1207

Previous Inspection Date: 07-Dec-2020 Completed in H2S zone? No; % of H2S:

EVALUATION Site

Accessible for inspection and monitoring? Yes; Lease in good condition to land helicopter.

Equipment or debris on site? Yes; Wellhead, 42 swamp mats, 8 joints of casing, box of wellhead equipment..

Additional clean up required? No; Lease visually looks in good condition.

Any environmental or safety concerns? (see Note 1) No; All appeared good.

Number of photos attached? (required) (wellhead, valves, signage and site area, other)

Wellhead

Wellhead accessible for inspection and monitoring? Yes; By helicopter in summer time.

Brush cleared 10m around wellhead? Yes; No brush on location.

Visible well marker in place? Yes; Hanging on wellhead and on matting at lease entrance.

Wellhead chained and locked? Yes; With combination lock.

Pumpjack secure? No; No pumpjack on location.

Wellhead valves operate freely? Yes; Wellhead valves were greased.

Surface casing vent open? Yes; SCV left open to the vent flow nanny.

Pressure test well head seal assembly? No;

Pressure rating of all components: 69 MPa

Wellhead schematic attached? (required) Yes; Attached with wellfile.




SCVF / Gas Migration

Evidence of SCVF? Note 1 Yes;

SCVF test conducted?

Yes; the SCV 8 m3 catch tank contains 1.5 m3 of fluid with a 1 m3 gain from the 07-Dec-2020 inspection to current. Observed 30 bubbles / minute and rigged in with the vent flow nanny for data.

Signs of gas migration outside surface casing? Note 1 No;

Gas migration test conducted? No;

Well

Does well contain tubing? Yes; As per current schematic.

Does well contain pump and rods? No; Flowing style wellhead.

Is there a packer/plug above the perfs? Yes; 10K WR plug at 3339 mKB.

Are tapped bull plugs in place? Yes; Tapped plug on tubing and casing inlets.

Shut in production casing pressure: 8315 kPa Note 2 Shut in intermediate casing pressure: 0 kPa Note 2

Shut in production tubing pressure: 23,250 kPa Note 2

Include any other readings taken:

(Use separate page(s) if needed)

Note 1: As per Section 75 of the Oil and Gas Drilling and Production Regulations, it is the responsibility of the operator to notify OROGO of any pollution incident as soon as possible.

Note 2: Indicate any change in pressure since last inspection.

COMMENTS:

Checked the 8 m3 tank and confirmed there was new fluid produced from the SCV. There was 1.5 m3 total fluid in the 8 m3 tote (~1 m3 fluid gain from December to now). Performed a 10 minute bubble test on the SCV and observed 30 bubbles / minute. With a calibrated digital dead weight observed a SITP of 23,250 kPa and a SICP of 8315 kPa. Rigged in with the vent flow nanny equipment onto the SCV. Phoned Roke and confirmed the data was transmitting correctly. On 24-Apr-2021 traveled to the above location and observed 1.5 m3 of fluid in the 8 m3 catch tank tied into the SCV (1 m3 fluid gain from the past 07-Dec-2021 inspection to current). Installed the vent flow nanny onto the SCV.

“I certify on the basis of personal knowledge of operations undertaken at the above named well that the above information is accurate.”

Name Brak Likuski Phone (780) 268-3500 Ext

Title VP Operations E-Mail [email protected]

Operator Prairie Provident Resources Canada Ltd. Inspected by Charles Patriquin



Signature Date

Responsible Officer of Company

OROGO use only

The details of this document have been examined and verified by:

Job Designation ______________________________

Well Identifier

___________ Signature

_______________________________ Approval Authority

Unique Well Identifier

30_/ ____ ___-___ ___-___ /__ (eg.300 / A01 60-00 120-00 / 0)

Date

______________________________



- 43 -

Figure 7 - L-68 lease from helicopter – 2021-04-24



- 44 -

Figure 8 - L-68 lease - 2021-04-24



- 45 -

Figure 9 - L-68 wellhead - 2021-04-29



- 46 -

Figure 10 - L-68 SCVF catch tank - 2021-04-29



- 47 -

Figure 11 - L-68 SCVF catch tank volume - 2021-04-29



- 48 -

Figure 12 - L-68 SCVF catch tank inside - 2021-04-29



- 49 -

Figure 13 - L-68 SCVF flow meter installation 2021-04-29



- 50 -

9 APPENDIX F – DAILY DRILLING REPORTS




- 51 -

10 APPENDIX G – DAILY RE-ENTRY AND RE-COMPLETION REPORTS


/3

Well Name: CFOL FT LIARD L-68-60-20-123-45

Report Printed: 11/9/2011www.peloton.com

Daily Report

Well HeaderAPI/UWI

N1207Field Name

POINTED MOUNTAINBusiness Unit Orig KB Elev (m…

737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)

4,200.0State/Province

NTCounty FOC WI (%) NRI (%) Foreman

Contact Name Title Role

Plug Back Total Depths

Date Depth (mKB) Type Method

AFE SummaryAFE Number

1183031AFE + Supp Amount (Cost)

9,358,000.00Field Est (Cost)

13,630,582.00AFE-Field Estimate (Cost)

-4,272,582.00

Daily Operations

Date From: 8/24/2011 - Date To: 8/25/2011Operations at Report Time

Waiting on daylight, monitor wellTubing Pressure (kPa) Casing Pressure (kPa)

Operations Summary

Drive to lease, safety meeting regarding hot-tap, conduct hot-tap , bleed off pressure, monitor well and wait on daylight. Costs inputted include waiting on weather and standby costs for services while gaining access to lease. All new people on location oriented at entryway, workers on standby were oriented at camp.Proposed Activity 24hrs

Cut off casing, install casing bowl, weld on casing exstensions, jack casing and install slips, NU BOP's and rig-upDaily Status

2. CompletionAFE Number

1183031Total AFE Amount (Cost)

9,358,000Supp Amt (Cost) Daily Field Est Total (Cost)

637,608Cumulative Cost (Cost)

637,608Objective

TestTarget Formation

Job Contact

Rory NewtonPosition

Daily Costs

Cost Des Code 1 Code 3 Vendor Note Field Est (Cost)

TRUCKING 07 COMPLETION Bert Baxter Transport Work at barge landing unloading barged loads - Aug 24

3,920.00

TRUCKING 07 COMPLETION Bert Baxter Transport Bed truck and haul 2 x wet sleepers to location - Aug 23

10,150.00

TRUCKING 07 COMPLETION Bert Baxter Transport Unload rig loads at barge landing - Aug 22

3,920.00

TRUCKING 07 COMPLETION Bert Baxter Transport Unload rig loads at barge landing - Aug 21

3,920.00

TRUCKING 07 COMPLETION Bert Baxter Transport Haul 400bbl and enviro-tanks w bedtruck - Aug 20

8,600.00

TRUCKING 07 COMPLETION Bert Baxter Transport Load and unload equipment at FSJ to Fort Nelson - Aug 14

14,500.00

TRUCKING 07 COMPLETION Bert Baxter Transport Haul rental equipment from Fort Nelson to location

19,600.00

TRUCKING 07 COMPLETION Cooper Barging Service Barging rig loads - Aug 19 12,150.00





TRUCKING 07 COMPLETION GT's Oilfield Hauling Multiple tickets - condensed to 1 ticket. Work Aug 20 - 24th

38,304.00

TRUCKING 07 COMPLETION GT's Oilfield Hauling Rig move charges from GP to location 45,000.00

SAFETY SERVICES AND EQUIPMENT

07 COMPLETION Newcart Safety Services Ltd Safety services - mob to location - Aug 12 4,440.00


07 COMPLETION Newcart Safety Services Ltd Safety services - Aug 13 to Aug 23 10,300.00


07 COMPLETION Newcart Safety Services Ltd Ongoing safety services - $1500/day for D/N shift, $200 for trucks, $200/light plant

2,430.00


07 COMPLETION Robert James Medic Group $2200/ ETV with 2 x medics, 1 x paramedic

2,200.00

TRUCKING 07 COMPLETION Formula Powell LP Catch-up costs for bed-truck use from Aug 19-24th

34,272.00

Report # 1, Report Date: 8/24/2011

Job Type: Re-Entry

/3



Daily Report

Daily Costs


EQUIPMENT RENTALS 07 COMPLETION Weatherford Rental equipment for drill out of surface plug (collars, power swivel, handling equip)

9,000.00

PRODUCTION TESTING 07 COMPLETION Spike Production Services Mob to location (1/2 trip) - Aug 17 5,940.00

PRODUCTION TESTING 07 COMPLETION Spike Production Services Mob to location (1/2 trip) - Aug 18 5,650.00

PRODUCTION TESTING 07 COMPLETION Spike Production Services Production testing services - Aug 19 3,400.00






TRUCKING 07 COMPLETION Colt Energy Services Trucking of testing pipe skid to Fort Liard barge landing

6,930.00

TRUCKING 07 COMPLETION Sawyer Oilfield Hauling Haul and unload P-tank from Red Deer to Ft Liard barge landing

11,310.00

EQUIPMENT RENTALS 07 COMPLETION McClelland Oilfield Rentals 5 day min on McClelland rental BOP stack

43,450.00

SERVICE RIG 07 COMPLETION CWC Well Services Load rig for rig move - Aug 18 12,140.00

SERVICE RIG 07 COMPLETION CWC Well Services Travel from GP to Fort Liard - Aug 19 21,935.00

SERVICE RIG 07 COMPLETION CWC Well Services Load equip on barge, unload at barge landing - Aug 20

9,955.00

SERVICE RIG 07 COMPLETION CWC Well Services Load equip on barge, unload at barge landing - Aug 21

9,955.00

SERVICE RIG 07 COMPLETION CWC Well Services Sort and spot equip, handling equip w Weatherford rep

9,955.00

SERVICE RIG 07 COMPLETION CWC Well Services Wait on move at base camp 9,955.00

SERVICE RIG 07 COMPLETION CWC Well Services Move rig to location, move into camp 17,455.00

SUPERVISION & CONSULTANTS

07 COMPLETION Barlon Engineering Group Rory Newton - Wellsite Supervision - project start to Aug 24

35,000.00


07 COMPLETION Lone Pine Resources Travel charges and consummables for M. Ross from Calgary to location

1,000.00

SNUBBING / CTU / HOT OILER 07 COMPLETION CWC Snubbing Snubbing charges - standby - Aug 19 to Aug 24

41,610.00

CAMP AND CATERING 07 COMPLETION Acho Camps and Catering Estimated camp charges - Aug 24 6,000.00

TRUCKING 07 COMPLETION Radar Road Transport Estimated tow-cat services up to date - 8 x $2000/day

16,515.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter services to date

15,527.00

TRUCKING 07 COMPLETION Hope's Ventures Estimated charges for jet-boat services 9,000.00

TRUCKING 07 COMPLETION RyTy Developments Nodwell charges from Aug 22 to Aug 24 46,000.00

TRUCKING 07 COMPLETION Koda Transport Ltd Hauled out 4 rental tanks form G.P to barge landing

18,470.00

Time Log

From To HRS. (hr) Sum HRS (hr) CODE SUB CODE Description OP

07:00 07:30 0.50 0.50 C MO Travel to location

07:30 08:00 0.50 1.00 C JSA Safety meeting with casing jackers, testers, on-site reps, safety, medics, wellhead, and welders

08:00 10:00 2.00 3.00 C WH Tap into side of 339mm casing, pressure present. Test gas for H2S, no H2S present. Tap into top of well, pressure present as well, again, no H2S.

10:00 18:15 8.25 11.25 C FT Bleed off trapped pressure through hot-taps. Pressure and flow decreased over time with small shows until 15:00h. Monitor well every 30min. Pressure and flow decreasing. Shut-in well for 5min at 18:00h, check pressure and flow. Both pressure and flow are minimal. Monitor overnight.

18:15 06:00 11.75 23.00 CT FT Monitor flow out of well overnight. Wait on daylight.

PerforationsDate

9/5/2011Top Depth (mKB)

3,351.00Bottom Depth (mKB)

3,356.00Zone # of Perfs

Comment

25 gram charges, salt and pepper


Job Type: Re-Entry

/3



Daily Report

PerforationsDate




Comment

25 gram charges, salt and pepperDate




Comment





Comment





Comment





Comment



Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations

Date From: 8/25/2011 - Date To: 8/26/2011Operations at Report Time Tubing Pressure (kPa) Casing Pressure (kPa)

Operations Summary

Wait on daylight, no flow or pressure at well when arrived on site. Test for LEL's, cut conductor, cut 508mm csg, cut cap. Cement observed, discuss plan with Calgary, install csg bowl and NU BOP's. Leveled area for water tank. Pressure test blind rams, spot rig and rig up same.Proposed Activity 24hrs

Continue to rig up, pressure test BOP's. Drill pilot hole through cement inside 339mm csg to ensure no pressure at surface.Daily Status





829,721Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Daily cost of bed truck and picker truck used for BOPs and unload equipment at site

14,784.00


07 COMPLETION Newcart Safety Services Ltd Ongoing safety services - $1500/day for D/N shift, $200 for trucks, $400/light plants, + misc

2,550.00



2,200.00

TRUCKING 07 COMPLETION Formula Powell LP Charges for bed-truck use 4,500.00


0.00

PRODUCTION TESTING 07 COMPLETION Spike Production Services Production testing services 3,600.00

EQUIPMENT RENTALS 07 COMPLETION McClelland Oilfield Rentals 5 day min on McClelland rental BOP stack

0.00

SERVICE RIG 07 COMPLETION CWC Well Services Daily rig charges 17,825.00


07 COMPLETION Barlon Engineering Group Rory Newton - Wellsite Supervision 1,600.00

SNUBBING / CTU / HOT OILER 07 COMPLETION CWC Snubbing Estimated charges for snubbing crew and equipment

7,100.00

CAMP AND CATERING 07 COMPLETION Acho Camps and Catering Estimated daily camp charges 6,000.00

TRUCKING 07 COMPLETION Radar Road Transport Estimated tow-cat services, $2000/day 2,000.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter services 7,030.00


LABOUR 07 COMPLETION Long Bow Pipe and Tap Demob welder charges - Aug 25 2,740.00

LABOUR 07 COMPLETION Long Bow Pipe and Tap Standby welding charges - Aug 19-23 11,650.00

LABOUR 07 COMPLETION Long Bow Pipe and Tap Welding charges for hot-tap - Aug 24 4,975.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Ardy Rigging Ltd Casing jack services to date - Aug 20 to 25th. Truck left on location for future work.

49,100.00

SERVICE RIG 07 COMPLETION Allrite Anchors Install rig and grounding anchors, 5 in total - Aug 25

4,705.00

WELLHEAD EQUIPMENT 07 COMPLETION StreamFlo Industries Dayrate from Aug 19 to 26th. Install StreamFlo csg bowl, tubing spool, backpressure valve.

18,945.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Mykyte Transportation Trucking charges for Weatherford equipment from Nisku and GP to site

9,009.00

TRUCKING 07 COMPLETION RyTy Developments Operating rate for Nodwell - 12 hrs 20,300.00

Time Log


06:00 07:00 1.00 1.00 CT FT Wait on daylight, continue to monitor well for pressure and flow. Travel to location.

07:00 07:30 0.50 1.50 C JSA Arrive on location, held safety meeting to discuss planned operations. Orientate new personnel on location including CWC Well Service hands.

07:30 09:30 2.00 3.50 C WH Cut conductor and remove same. Cut 508mm casing and remove same. Cut cap off 339mm casing, cement at surface, no signs of 244mm casing. Stop work, discuss plan forward with Calgary.

09:30 09:45 0.25 3.75 C JSA Stop work. Discuss go-forward plan with workers on site.

09:45 16:00 6.25 10.00 C WH Prep 339mm casing for extension. Lift 339mm casing extension into place and weld on same. Cut 339mm casing for clamp-on wellhead bowl. Prep cut for bowl and install same. Test between seals for 3 and 15min at 4000psi. Both tests passed. Install tubing spool, tighten all studs, install hanger and back pressure valve. Install master valve above tubing spool. Leveled area for water tank while working on wellhead. Released welder, casing jacks, wellhead truck.

16:00 20:00 4.00 14.00 CT WO Wait on picker truck to NU BOP's (did not make 1st barge)

20:00 22:00 2.00 16.00 C MO Unload 2 x 400bbl tanks and man-lift with bed truck. Use loader to move wellhead crates away from well center.

22:00 01:00 3.00 19.00 C BO Picker arrive on location, unload double gates and annular. Remove back pressure valve and install 3.5" bull plug in tubing hanger. Lift double gate onto tubing spool. Lift annular onto double gate. Tighten BOP studs.

01:00 03:30 2.50 21.50 C MO Unload pipe racks, rig stairs, rig matting, 2 x light plants, rig catwalk with picker truck.Spot rig matting. Install accumulator hoses to BOP.

03:30 04:00 0.50 22.00 C BO Pressure test blind rams, low of 1000kPa, high of 45000kPa for 10min each.

04:00 06:00 2.00 24.00 C RU Spot rig and rig up same. Raise mast and continue to rig up.

PerforationsDate




Comment





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Comment



Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to pressure test 10 K BOP stack components. Crew Change. Held pre-job and safety meeting. Orientated all new personnel and issued safe work permits to new contractors. Completed pressure testing of all components to 1 & 45 MPa on 10K BOP stack. Installed cross-over spool and 50.8 mm single gate rams. Finished rigging up remaining rig equipment. Hauled in and unloaded a total of 431 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Started building lined water tank and connecting walls. Rigged up snubbing unit above BOP stack. Drill pilot hole in cement plug, no pressure present. Rig down snubbing unit.Proposed Activity 24hrs

ND single gate and XO spool. PU packoff, DC and mill tooth bit and drill out cmt plug. ND BOP's and prep to cut csg and land 9.5/8" csg in csg bowl.Daily Status





934,676Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Charges for picker tospot catwalk and unload 3.5" tubing onto pipe racks

3,920.00



2,510.00



2,200.00



0.00


EQUIPMENT RENTALS 07 COMPLETION McClelland Oilfield Rentals Rental BOP stack charges - $43450 during 5 day min, $5675/day after

0.00




SNUBBING / CTU / HOT OILER 07 COMPLETION CWC Snubbing Estimated charges for snubbing crew and equipment

14,620.00





EQUIPMENT RENTALS 07 COMPLETION Earth Communications Travel and setup rig site internet 2,650.00

EQUIPMENT RENTALS 07 COMPLETION Ketek Group Ltd Install rig site sewer system 900.00

INSPECTIONS 07 COMPLETION Peregrine Pressure Testing Pressure test BOP's 8,110.00

EQUIPMENT RENTALS 07 COMPLETION McClelland Oilfield Rentals Travel to and setup rental 10k BOP stack 11,760.00

TRUCKING 07 COMPLETION RyTy Developments Standby for Nodwell and release night crew ($2900)

7,500.00

EQUIPMENT RENTALS 07 COMPLETION Alberta Gold Energy & Rentals 2 x shacks, 2 x enviro bins, 6 x 400bbl tanks, 4 x ins 400bbl = $1065/day

4,300.00


Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 07:00 1.00 1.00 C BO Continued to pressure test 10K BOP stack components.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting. Orientated all new personnel and issued safe work permits to new contractors.

07:30 09:30 2.00 3.50 C BO Continued pressure testing BOP components. Pressure tested 88.9 mm rams to 1 MPa and 45 MPa, 10 minutes each, good test. Pressure tested annular bag to 1 MPa and 21 MPa, 10 minutes each, good test. Recorded and documented all pressure tests. Pulled and removed pup joint and 279.4 mm tubing hanger with bull plug on bottom. Installed cross-over spool ontop of annular bag, installed 50.8 mm single gate rams.

09:30 15:00 5.50 9.00 C RU Finished rigging up remaining rig equipment. Spotted pipe racks. Hauled in and unloaded onto pipe racks a total of 431 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Unloaded 6 - 88.9 mm Drill collars and 7 - 50.8 mm collars. Started rigging up lined water tank and connecting walls. Spotted subbing unit and rigged up snubbing stack above BOPS.

15:00 17:00 2.00 11.00 C PT Picked up and ran in 50.8 mm drill collar with safety valve. Closed single gate pipe rams and held drill collar with snubbing slips. Pressure tested 50.8 mm rams to 1 & 35 MPa, 10 minutes, each test, held sold. Pressure tested snubbing stack to 21 MPa, good test. Pulled out and laid down drill collar.

17:00 17:30 0.50 11.50 C JSA Held pre-job and safety meeting with all personnel on site. Discussed procedures for drilling out surface cement plug and potential hazards.

17:30 20:30 3.00 14.50 C PU Made up 57.1 mm Bladed Junk Mill and 42.8 mm Weatherford CTD Motor assembly onto 50.8 mm Drill collar. Picked up and connected circulating head and anti-rotational device. Tagged cement top and established circulation.

20:30 01:00 4.50 19.00 C DC Drill surface cement plug with Weatherford tools. Last 2 joints ran in hole without circulation. No pressure observed.

01:00 01:15 0.25 19.25 C CC CIRC hole and prepare to laydown tools.

01:15 02:00 0.75 20.00 C LD Laydown Weatherford tools. Motor and motor head bent. Mill worn on outside.

02:00 04:30 2.50 22.50 C RU Rig down snubbing unit.

04:30 06:00 1.50 24.00 C BO Nipple down single gate and crossover spool. Wait on picker.

PerforationsDate




Comment





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Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Move in and spotted picker unit. Removed single gate pipe rams and cross-over spool. Crew change. Held pre-job and safety meeting. Made up 215.9 mm Tri-cone Bit and 88.9 mm Drill collar. Rigged up power swivel and pack-off head. Established reverse circulation. Drilled out excess cement at surface left from pilot hole previously drilled. Encountered good torque approximately 1.5 m below casing bowl. Circulated clean and rigged out power swivel and pack-off head. Rigged out rig and moved rig and associated equipment away from well center. Tore down and removed 10K BOP stack. Installed 139.7 mm gate valve and secured well. Moved in track hoe and excavated around wellhead. Wait on people and parts to cut casing bowl.Proposed Activity 24hrs

Wait on people and parts. Cut off casing bowl, expose 9.5/8" casing, weld on casing bowl, jack 9.5/8" casing and land inside csg bowl.Daily Status





1,151,671Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Bed truck and picker charges for Aug 27th.

7,055.00



2,510.00



2,200.00



0.00



0.00




SNUBBING / CTU / HOT OILER 07 COMPLETION CWC Snubbing Charges for snubbing crew and equipment

16,035.00





TRUCKING 07 COMPLETION RyTy Developments Standby for Nodwell 3,000.00


1,065.00

TRUCKING 07 COMPLETION Tiggo Transport Ltd Estimated cost for trucking & setting up Posiden double lined water tank

75,500.00

OTHER COSTS 07 COMPLETION Weatherford Thru Tubing Mud motor & mill. Estimated cost included for bent & damaged motor

67,200.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Earth C ommunications Had technician come out and set up phone service & internet

1,900.00


Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 07:00 1.00 1.00 C BO Moved in and spotted picker truck. Removed single gate rams and cross-over spool from above BOP stack.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting with all personnel on site.

07:30 10:00 2.50 4.00 C DC Made up 215.9 mm Tri-cone Bit and 88.9 mm Drill Collar. Rigged up power swivel and pack-off head. Established reverse circulation and started to drill out excess cement at surface left from smaller pilot hole previously drilled. Encountered good torque approximately 1.5 meters below casing bowl, suspect top of production casing was tagged. Circulated clean and rigged out power swivel and pack-off head.

10:00 13:00 3.00 7.00 C RU Laid derrick over and rigged out rig. Moved rig and matting away from wellhead. Moved remaining associated rig equipment away from wellhead area using picker.

13:00 16:00 3.00 10.00 C BO Using picker to assist, tore down and removed 10K BOP stack away from wellhead. Installed 139.7 mm gate valve above tubing head and secured well. Wait on track hoe to arrive.

16:00 18:00 2.00 12.00 C OT Excavate area around wellhead.

18:00 06:00 12.00 24.00 CT WO Wait on people and parts to cut off casing bowl and land 9.5/8" casing inside csg bowl.

PerforationsDate




Comment





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Comment





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Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on people and parts to arrive. Crew change. Held pre-job and safety meeting. Removed 139.7 mm gate valve and tubing head. Had track hoe finish excavating around wellhead. Welder, wellhead technician, and machined couplings arrived. Cut 339.7 mm surface casing 25 cm below previous welded coupling, removed casing bowl. Install 244.5mm casing extension and weld same. Install 339mm casing collars and casing and install casing bowl to approx ground level. Jack 244.5mm casing and set slips with 45daN tension. Cut 244.5mm casing, install seal assembly and lift tubing spool into place. Hand tighten studs and wait on construction.Proposed Activity 24hrs

Backfill hole dug for casign extensions. Nipple up BOP's and p-test broken connections. Spot rig over well center and rig-up to drill out.Daily Status





1,261,074Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Picker charges daily 12 hr rate at $ 3,500. 3,500.00



2,605.00



2,200.00



0.00



0.00










1,065.00

LABOUR 07 COMPLETION Long Bow Pipe and Tap Welding charges to cut csg, re-install bowl, cut 244.5mm casing

7,750.00

TRUCKING 07 COMPLETION Cooper Barging Service Barging charges - Aug 24 9,028.00






Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 07:00 1.00 1.00 CT WO Continued to wait on people and parts.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting

07:30 09:30 2.00 3.50 C OT Removed 139.7 mm gate valve and tubing head. Finished excavating around wellhead. Dug down approximately 4 m below ground level.

09:30 13:00 3.50 7.00 CT WO Continued waiting on people and parts. Welder, wellhead technician, and machined couplings with casing jacks arrived on location.

13:00 16:00 3.00 10.00 C WH Cut 339.7 mm surface casing 25 cm below previous welded coupling, removed casing stub and bowl. Cut off and removed conducter pipe, cleaned out cement, cut off and removed section of 508 mm casing. Cut off 2 m of surface casing and exposed 244.5 mm production casing. Note: Production casing was not previously capped. Cleaned up production casing stub and welded on machined coupling with 69.9 kg/m, L-80, extension casing.

16:00 18:45 2.75 12.75 CT CS Work on casing collars. Machined couplings too small to fit over casing (3mm). Grind inside of couplings.

18:45 19:00 0.25 13.00 C JSA Crew change and handover meeting

19:00 19:30 0.50 13.50 CT CS Work on casing collars. Machined couplings too small to fit over casing (3mm). Grind inside of couplings.

19:30 22:00 2.50 16.00 C CS Install 339mm casing and cut same. Prep for 2nd collar to install 339mm casing bowl. Lift casing bowl into place.

22:00 23:30 1.50 17.50 C WH Lift casing jacks into place, pull tension into 244.5mm to level 339mm casing bowl.

23:30 01:45 2.25 19.75 C CS Weld top and bottom of 2nd casing collar on 339mm casing.

01:45 03:30 1.75 21.50 C WH Jack 244.5mm casing, set slips with 45daN tension. Rig down casing jacks and prep to cut 244.5mm casing. Cut 244.5mm casing 6" above top of casing bowl flange. Prep top of 244.5mm casing for tubing spool. Lift tubing spool into place. Hand tighten studs.

03:30 06:00 2.50 24.00 CT WO Wait on construction to backfill hole around wellhead and surface casing.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on construction. Crew change, held pre-job and safety meeting. Back filled hole around wellhead using track hoe and cat. Tightened tubing head onto casing bowl, pressure tested primary and secondary seals to 22 MPa, good test. Installed 70 MPa BOP stack using picker. Spotted rig matting and associated rig equipment. Spotted service rig and rigged up. Rigged up floor and pipe handling equipment. Functioned and pressure tested all components on 70 MPa BOP stack to 1 MPa & 35 MPa, 10 minutes each test. PU bit, 88.9mm collars, install pack-off, drill out cement at surface, trip, remove packoff, torque all connections, RIH. Level rig. RIH, obstruction at ~584m. Install power swivel and work through obstruction.Proposed Activity 24hrs

Continue to RIH to plug at 3206mDaily Status





1,546,334Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Picker charges daily 12 hr rate at $ 3,500. 2 day charge to release & travel home.

7,000.00



2,580.00



2,200.00



1,600.00



5,675.00








TRUCKING 07 COMPLETION RyTy Developments Refuel camp and unload mats 12,600.00


1,065.00

EQUIPMENT RENTALS 07 COMPLETION Poseidon Concepts Supervision cost setting up Lined Atlantis water tank & daily rental cost of $4,500.00

20,000.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Ardy Rigging Standby charges for csg jacks/hot shot parts/ machineing charges/jacking charges

30,440.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


WELLHEAD EQUIPMENT 07 COMPLETION Stream Flo Wellhead technician installed seals and slips. Pressure tested seals. Travel home.

7,875.00

TUBING 07 COMPLETION Pac Rim 88.9 mm, 13.84 kg/m, L-80, tubing string 150,000.00

EQUIPMENT RENTALS 07 COMPLETION Weatherford One-time charges for pack-off element and core, cables, ring gaskets

2,300.00

Time Log


06:00 07:00 1.00 1.00 CT WO Continued to wait on construction.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting with all personnel on site. Orientated new personnel.

07:30 09:00 1.50 3.00 CT WO Continued to wait on construction equipment.

09:00 11:30 2.50 5.50 C WH Track hoe and cat arrived on location and back filled hole around wellhead. Tightened tubing head connection to casing bowl. Pressure tested primary and secondary seals to 22 MPa, good test.

11:30 13:00 1.50 7.00 C BO Using picker installed 70 MPa BOP stack onto tubing head. Rigged up accumulator and lines.

13:00 16:00 3.00 10.00 C RU Spotted CWC rig # 256 and associated equipment according to NEB, ERCB, and OH&S regulations. Rigged up rig and equipment, installed guyline anchors, conducted a rig inspection. Rig was declared ready to commence operations. Rigged up floor and pipe handling equipment. Landed tubing hanger with bull plug below.

16:00 18:30 2.50 12.50 C BO Functioned and pressure tested all ram components on BOPS to 1 & 35 MPa, 10 minutes, each test. Functioned and pressure tested annular bag to 1 & 21 MPa, 10 minutes each test. Note: Previously tested all BOP components to 1 & 45 MPa and documented pressure tests. After 3 functions remaining accumulator pre-charge pressure was 10,500 kPa. System re-charged to 19,600 kPa after 3 minutes 27 seconds.

18:30 19:00 0.50 13.00 C DC Made up 215.9 mm Tri-cone Bit and 88.9 mm Drill collar. Rigged up power swivel and pack-off head. Drill cement plug. RIH with 88.9mm drill collars. POOH, remove pack-off, torque all collar connections, RIH.

19:00 19:15 0.25 13.25 C JSA Crew change and handover meeting.

19:15 01:00 5.75 19.00 C DC Made up 215.9 mm Tri-cone Bit and 88.9 mm Drill collar. Rigged up power swivel and pack-off head. Drill cement plug. RIH with 88.9mm drill collars. POOH, remove pack-off, torque all collar connections, RIH.

01:00 01:30 0.50 19.50 C RS Re-level rig over well centre. Tubing catching on bottom of v-door.

01:30 05:45 4.25 23.75 C PU Strap 88.9mm tubing and RIH with same to 584m. Obstruction at 584m. Unable to work past obstruction. PU power swivel.

05:45 06:00 0.25 24.00 C DC Work through obstruction with power swivel. CIRC btms up. Cement noted in connections as well as fiberous material (possibly burlap).

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to drill out cement obstruction tagged at 584 m. Crew change, held pre-job and safety meeting. Picked up another 2 joints and continued to drill down through cement stringers. Ran another 2 joints down without rotating, casing appears cleaned out. Rigged out power swivel and pack-off head. Continued to pick up, tally, drift, and RIH with 88.9 mm, 13.84 kg/m, L-80, tubing. Tag cement at approx 3204m. LD 1 joint, perform p-test on 9.5/8" csg to 21MPa for 10min. Bleed off, trapped pressure in tubing string. Install CIRC swedge, pressure up, open valve. Reverse CIRC btms up. Run out of suction due to thick fluid left in hole. Wait on vac skid and fluid.Proposed Activity 24hrs

Suck out mud tanks, CIRC out remaining clay based mud fro the well. Drill cement plug up to liner top, POOH for bit change.Daily Status





1,624,356Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,580.00



2,200.00



1,600.00



5,675.00








TRUCKING 07 COMPLETION RyTy Developments Haul waterwell rig to barge, load wireline unit and bring to camp

16,600.00


1,065.00


4,500.00

Time Log


06:00 07:00 1.00 1.00 C DC Continued to drill out cement obstruction tagged at 584 m.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting. Discussed procedures for picking up pipe and potential hazards involved.


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 11:30 4.00 5.50 C DC Picked up 2 joints of tubing and continued to drill down through cement stringers. Ran in another 2 joints without rotating, casing appeared cleaned out from anymore obstruction. Rigged out power swivel and pack-off head.

11:30 19:00 7.50 13.00 C PU Continued to pick up, tally, drift, and RIH with 88.9 mm, 13.84 kg/m, L-80, tubing. Held BOP drill, well was secured in 63 seconds.


19:15 22:00 2.75 16.00 C PU RIH with 88.9mm tubing, tag cement plug. Ran a total of 334 jts, tagged plug top at 3204m.

22:00 22:15 0.25 16.25 C JSA Held BOP drill with night crew, well secure in 50s.

22:15 22:30 0.25 16.50 C PT Pressure test 244mm casing to 21MPa for 10min.

22:30 23:00 0.50 17.00 CT CC Pressure trapped in tubing string following pressure test. Close kelly cock, install CIRC hose, pressure up to 21MPa, open kelly cock, CIRC re-established.

23:00 01:00 2.00 19.00 C CC Reverse CIRC bottoms up. Returns started as inhibited water, changing to clay-based drilling mud, and viscosity increased as bottoms up was noted at surface. Mud too thick to pump, loss of suction at the pump. Pump pressure changed from 15000kPa @ 0.5m3/min to 10000kPa @ 0.5m3/min once thick mud noted at surface.

01:00 06:00 5.00 24.00 CT CC Wait on daylight. Unable to pump due to thick mud in tanks. Vac skid located at camp, no fresh water on site.

PerforationsDate




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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on fluid and vacuum truck. Crew change. Held pre-job and safety meeting with all personnel on site. Ordered vacuum truck from Ft Nelson ( vacuum skid broke down ). Note: Towed up 2 water trucks from barge landing last night and 1 water truck this morning. Encountered good rain last night, today sunny and road slowly drying. Hauled in and unloaded 70 m3 of 7% KCL water. Sent 5 water trucks ( body jobs ) in afternoon down to the barge landing and loaded 90 m3 of fresh water from Ft Liard river. Pump water into 400bbl. Break CIRC, pump returns into 400bbl. Drill cmt plug, pack-off failure. Replace pack-off rubber, drill ahead, CIRC btms up, pack-off failure again. Swap Weatherford pack-off for rig pack-off. Drill cmt plug, power swivel stalling frequently.Proposed Activity 24hrs

Drill cement plug to liner top. Clean mud tanks, POOH for 6.1/4" bit.Daily Status





1,726,433Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,580.00



2,200.00



1,600.00



5,675.00










1,065.00


4,500.00

TRUCKING 07 COMPLETION Tru-North Trucking 2 x water haulers - Aug 27 6,310.00



TRUCKING 07 COMPLETION Tru-North Trucking Standby water haulers - Rained out - Aug 30

3,320.00

TRUCKING 07 COMPLETION Alberta Gold Energy & Rentals Hotshot mudcan to Cooper Barging 1,800.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Transport Released Formula bedtruck & moved in Bert Baxter bedtruck

3,160.00

Time Log


06:00 07:00 1.00 1.00 CT WO Continued to wait on fluid and vacuum truck. Note: Encountered steady rain last night. Towed 2 tank trucks and wireline truck up from barge landing last night. Left 1 tank truck at barge landing ovenight.


07:30 18:00 10.50 12.00 CT WO Ordered vacuum truck from Ft Nelson ( vacuum skid unit broke down ). Towed last tank truck up from barge landing and disconnected pups. Using body jobs hauled in and unloaded 70 m3 of 7% KCL water into rental tanks on location. Weather conditions improved, road starting to dry. Sent 5 tank trucks ( body jobs ) down to the barge landing and loaded 90 m3 of fresh water from the Ft Liard river. Hauled fluid back up to location to mix with KCL water.

18:00 20:00 2.00 14.00 CT WO Wait on water trucks to travel to lease and unload in 400bbl tank

20:00 20:15 0.25 14.25 C JSA Safety meeting prior to unloading water trucks and pumping water downhole to re-establish CIRC.

20:15 22:15 2.00 16.25 C CC Unload fresh water from river into 400bbl tank. Pump from 2 trucks downhole and re-establish CIRC. Monitor returns at mud tank (trough) and flow into 400bbl tank to isolate from working volume. Isolated returns in 400bbl = 27m3

22:15 23:30 1.25 17.50 C PU Install pack-off and power swivel, held safety meeting prior to resuming drilling operations.

23:30 00:15 0.75 18.25 C DC Drill cement, reverse CIRC.

00:15 01:30 1.25 19.50 CT RR Pack-off seal failure. Shut-down drilling operations and replace packoff. Top up pack-off fluid reservoir.

01:30 02:30 1.00 20.50 CT CC Resume CIRC (reverse), pressure too high to resume drilling. CIRC btms up, monitor returns, flow thick mud into 400bbl. Pump pressure dropped from 9000kPa to 5000kPa, and increased again to 7000kPa.

02:30 03:15 0.75 21.25 C DC Pump pressure too high to reverse CIRC, switch to fwd CIRC to drill cement plugs to minimize pressure on pack-off.

03:15 04:30 1.25 22.50 C CC Reverse CIRC with annular closed. Decide to stick with forward CIRC while drilling cement plug due to viscous mud in hole, high pump pressures, and limited pack-offs. Forward CIRC to clear string and move cement cuttings above bit.

04:30 06:00 1.50 24.00 CT RR While CIRC string clean, pack-off leaked. Replace Weatherford pack-off with rig pack-off.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued forward circulating, started drilling down. Crew change, held pre-job and safety meeting. Orientated new personnel and issued safe work permit to Troyer vacuum service. Changed back to reverse circulating and circulated bottoms up. Added 8 m3 of clean KCL water to circulating system to help dilute viscous mud in hole. Drilled out approximately 18 m of hard cement down to a total depth of 3240 mKB. Did not tag liner top, estimated liner top within 2 m. Fluid in circulating system more viscous, having trouble pumping. Finished circulating bottoms up and decided to pull out and drill out remaining cement with 158.8 mm bit. Rigged out power swivel and pack-off head, prepared to pull pipe. POOH, pipe not draining. Install mudcan and suck with vac truck. Pipe began draining around 2000m, release vac truck, pump 1m3 at 152m to clear pipe (not draining again). Change bit and RIH.Proposed Activity 24hrs

Continue RIH to bottom, drill out liner top and continue to RIH to PBTD.Daily Status





1,823,278Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,580.00



2,200.00

TRUCKING 07 COMPLETION Bert Baxter Charges for bed-truck use 3,600.00


1,600.00



5,675.00










1,065.00


4,500.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Earth Communications Communications for camp and lease site, end of month rental charges

6,340.00

TRUCKING 07 COMPLETION Peben Oilfield services Catch up cost for trucking in 88.9 mm tubing string

6,705.00

TRUCKING 07 COMPLETION Peben Oilfield Services Catch up cost for trucking in 88.9 mm tubing string

6,845.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Peben Oilfield Services Catch up cost for trucking in 88.9 mm tubing string

6,705.00

EQUIPMENT RENTALS 07 COMPLETION Auburn Rentals Rental on wet sleepers added to camp site @ $550/day

2,750.00

Time Log


06:00 07:00 1.00 1.00 C DC Continued forward circulating and started drilling out cement again.

07:00 07:30 0.50 1.50 C JSA Crew change. Held pre-job and safety meeting. Orientated new personnel and issued safe work permit to Troyer vacuum service.

07:30 18:00 10.50 12.00 C DC Continued drilling down from 3222 mKB. Established reverse circulation again and circulated bottoms up. Added 8 m3 of clean KCL water to circulating system to help dilute viscous mud in hole. Changed out pack-off rubber again after drilling down 1 joint. Pumping rate was 0.4 m3/min @ 7 MPa, had between 60 - 80 RPM. Average weight on bit was between 1,000 - 3,000 daN, power swivel would stall out with too much weight on bit. Drilled out approximately 18 m of hard cement down to a total depth of 3240 mKB, did not tag liner top. Fluid in circulating system more viscous, having trouble pumping. Finished circulating bottoms up and decided to pull out, should be drilled down within 2 m to liner top. Drill out remaining cement with the 158.8 mm bit. Rigged out power swivel and pack-off head and prepared to pull pipe. Note: Had vacuum truck clean out thick mud from rigtank.

18:00 04:00 10.00 22.00 C TR POOH for 6.1/4" bit to drill through 7" liner. Pipe not draining, install mudcan and suck with vac truck. Released vac truck at 1am. Pipe started to drain at 2000m up until 152m, pump fluid to clear pipe of thick mud.

04:00 06:00 2.00 24.00 C TR Change bit and RIH. Bit was plugged on one nozzle with fabric (similar to burlap sack) and cones unable to rotate due to chunk of (unknown) metal lodged in between cones. No visible damage to bit.

PerforationsDate




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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to run in out of derrick with 88.9 mm tubing. Crew change, held pre-job and safety meeting. Continued running in with 158.8 mm Bit and 88.9 mm Drill collars on 88.9 mm tubing. Ran in out of derrick a total of 154 joints. Landed tubing bottom 9.5 m above previous drilled depth @ 3240 mKB. Picked up 1 joint and rigged up power swivel and RS stripping head. Hauled in 80 m3 of fresh water from the Ft Liard river and spotted tank trucks. Sucked out of tank trucks and reverse circulated to displace mud out of wellbore. Observed golden sand like barite in returns. Started drilling, ran down and cleaned out approximately 7 meters of fill to cement top @ 3240 mKB. Drill from 3240m to 3260m. RIH 2 jts w/o pumping, rig down power swivel and RS head, RIH with 88.9mm tubing.Proposed Activity 24hrs

Finish RIH to bottom, tag bottom, CIRC btms up, pressure test casing to 21MPa. POOH for logging.Daily Status





1,970,724Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,650.00



2,200.00



1,600.00



5,675.00










1,065.00


4,500.00


550.00

TRUCKING 07 COMPLETION Troyer Vac truck services - Aug 31 4,240.00

TRUCKING 07 COMPLETION Troyer Vac truck services - Sept 1 4,505.00

TRUCKING 07 COMPLETION Silverstar Oilfield Transportation Haul 114.3mm tubing from GP to location and return to GP

10,600.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION NOV Tuboscope Haul 139mm casing to location - 5 trucks - Nisku to location

60,146.00

Time Log


06:00 07:00 1.00 1.00 C TR Continued to run in hole out of derrick with 88.9 mm tubing.

07:00 07:30 0.50 1.50 C JSA Crew change, held pre-job and safety meeting with all personnel on site. Discussed safe work procedures for drilling and potential hazards involved.

07:30 13:00 5.50 7.00 CT TR Continued to run in with 158.8 mm Bit and six 88.9 mm Drill collars on 88.9 mm tubing. Ran in a total of 154 joints out of derrick, total tubing in hole was 335 joints. Landed tubing bottom approximately 9.5 m above previous drilled depth of 3240 mKB. Picked up 1 joint and rigged up power swivel and RS-stripping head. Ready to start drilling after displacing out drill mud from wellbore.

13:00 17:00 4.00 11.00 C CC Hauled in approximately 80 m3 of fresh water from the Ft Liard river and spotted tank trucks. Had vacuum truck clean out rigtank. Sucked out of tank trucks and established reverse circulation, displaced out mud from wellbore. Mud came back in 3 stages, diverted and saved clean water to complete full circulation. Observed golden sand like barite in returns.

17:00 18:00 1.00 12.00 C DC Started drilling, pumping rate was 0.45 m3/min @ 4 MPa. Ran down and cleaned out approximately 7 meters of fill down to cement top @ 3240 mKB.

18:00 18:45 0.75 12.75 C DC Tag liner at approx 3243m. Having trouble drilling ahead, seem to be hanging up on top of liner. Metal specs and eventually slivers noted in returns. Occasional stalling of power swivel.


19:00 00:00 5.00 18.00 C DC Tag liner at approx 3243m. Having trouble drilling ahead, seem to be hanging up on top of liner. Metal specs and eventually slivers noted in returns. Occasional stalling of power swivel.

00:00 01:30 1.50 19.50 C DC Off cement top, drill down remaining portion of joint #337. CIRC btms up to confirm cement in returns.

01:30 03:15 1.75 21.25 C DC MU joint #338, had to drill 1st part of connection. CIRC 15min, MU jt #339, RIH, had to wash down, CIRC 15min to keep cuttings moving up hole. MU joint # 340 and 341, no pumping required.

03:15 04:15 1.00 22.25 C CC CIRC btms up to confirm no gas present and fluid type/consistency below cement plug. Thin WBM returns below plug.

04:15 05:00 0.75 23.00 C RU Rig down power swivel and RS head.

05:00 06:00 1.00 24.00 C PU RIH with 88.9mm tubing to approx 3555m.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to pick up, tally, drift, and run in off pipe racks with 88.9 mm tubing. Crew change, held pre-job and safety meeting with all personnel on site. Ran in a total of 414 joints and tagged plug back @ 3971 mKB. Rigged up power swivel and RS head. Established reverse circulation, could not rotate tubing string, power swivel to small ( 85 tonne ) not enough torque to turn string around bend at this depth. Observed thick mud and good signs of gas in returns. Circulating system more viscous again, lost prime on pump. Continued to circulate gas bubble out using clean KCLwater, mud returns less viscous. Rigged out power swivel and RS-head. Pulled out a total of 77 joints, tubing pulling wet, used mud can and vacuum truck. Worked joint # 337 through liner top @ 3235 mKB. Pressure tested the casing to 21 MPa for15 minutes, good test. Continue to POOH, LD BHA, MU logging tools, install lubricator, RIH and log well.Proposed Activity 24hrs

Finish logging run #1, determine depth correlation, RIH with perf guns and perf well. POOH for scraper run.Daily Status





2,028,474Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,780.00



2,200.00



1,600.00



5,675.00










1,065.00


4,500.00


550.00

Time Log


06:00 07:00 1.00 1.00 C PU Continued to pick up, tally, drift, and run in hole with 88.9 mm tubing off pipe racks.

07:00 07:30 0.50 1.50 C JSA Crew change, held pre-job and safety meeting with all personnel on site.


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 11:00 3.50 5.00 C PU Ran in a total of 414 joints. Tagged PB with 1.5 meters in on joint #414 @ 3971 mKB. Rigged up power swivel and RS-stripping head. Note: Birch Oilfield vacuum trucks arrived, orientated new personnel and issued safe work permit.

11:00 14:30 3.50 8.50 C DC Established reverse circulation and attempted to drill down PB. Could not rotate tubing string, power swivel to small ( 85 tonne ) to drill around bend at this depth, could only increase the torque to 2,200 ft lbs. Observed thick mud and good gas in returns ( not sour ). Continued to circulate gas pocket out. Circulating system became more viscous again, lost prime on pump. Tied onto 400 bl tank and continued to circulate using clean KCL water. No more signs of gas, mud returns less viscous. Stopped pumping and monitored well for 10 minutes, well was dead. Rigged out power swivel and RS-head, prepared to pull pipe.

14:30 17:00 2.50 11.00 C TR Pull out of hole, tubing pulling wet, used mud can and vacuum truck. Laid down 2 joints and stood 74 joints into derrick. Pulled next stand and worked joint # 337 through liner top @ 3235 mKB. Pulled through with no problems, ran back down with slight tag then entered liner top with no problems. Racked back 2 more joints. Conducted BOP drill and secured well in 57 seconds.

17:00 17:30 0.50 11.50 C PT Pumped 3 m3 of KCL water down tubing and established circulation briefly. Shut in well and pressure tested the casing to 21 MPa, 15 minutes, good test.

17:30 19:00 1.50 13.00 C TR Continued to pull out and stand 88.9 mm tubing.


19:15 00:15 5.00 18.25 C TR POOH with tubing. BOP drill, well secure in 51s. Continue to POOH, LD BHA, MU Encore logging tools on ground, install lubricator.

00:15 00:30 0.25 18.50 C JSA Safety meeting prior to PU logging tools.

00:30 06:00 5.50 24.00 C LO Log well as per program with GR/CCL/Radial Bond log from PBTD to 3235m inside 177.8mm liner and from 2950m to 2000m inside 244.5mm production casing.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to bond log well. Crew change, held pre-job and safety meeting with all personnel on site. Conducted GR-CCL-VDL-CBL-Radio log inside 177.8 mm casing from PB at 3961 mKB to top of liner @ 3236 mKB, correlated to an emailed copy of open hole log dated March 25/1982. Cement bond looked good over all zones of interest. Cement bond was questionable over liner top, conducted 7 MPa pressure pass from 3500 m to liner top and improved bond slightly, estimated cement top above liner top behind the 244.5 mm casing. Conducted GR-CCL-VDL-CBL-Radio log inside the 244.5 mm casing from 2950 m to 2000 m. Cement bond looked very poor, conducted 7 MPa pressure pass with no improvement, could not determine cement top. Pulled out and laid down logging tools. RIH and perf 6 intervals as per time log. All charges fired in runs #1-5.Proposed Activity 24hrs

Finish POOH with charge #6, rig down loggers, PU 88.9mm and scraper BHA, RIH, and CIRC btms up. Work liner top, POOH for Weatherford packer systemDaily Status





2,125,481Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,625.00



2,200.00



1,600.00



5,675.00










1,065.00


4,500.00


550.00

TRUCKING 07 COMPLETION Cooper Barging Service Barging charges Aug 26 9,468.00

TRUCKING 07 COMPLETION Cooper Barging Service Barging charges Aug 29 10,188.00

TRUCKING 07 COMPLETION Cooper Barging service Barging charges Aug 30 9,028.00

TRUCKING 07 COMPLETION Cooper Barging Service Barging charges Sept 2 9,028.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Cooper Barging Service 3 days dock charges for tow cat 1,800.00

Time Log


06:00 07:00 1.00 1.00 C LO Continued to bond log well.


07:30 14:00 6.50 8.00 C LO Conducted GR-CCL-VDL-CBL-Radio log inside the 177.8 mm casing from PB @ 3961 mKB to top of liner hanger packer @ 3236 mKB, correlated to an emailed copy of open hole log dated March 25/1982. Cement bond looked good over all zones of interest. Cement bond was questionable over liner top, conducted 7 MPa pressure pass from 3500 m to to just above liner top, cement bond improved slightly, estimated cement top above liner top at the bottom of the 244.5 mm casing. Conducted GR-CCL-VDL-CBL-Radio log inside the 244.5 mm casing from 2950 m to 2000 m. Cement bond looked very poor, appeared to be no cement, conducted 7 MPa pressure pass with no improvement, could not determine a cement top. Pulled out and laid down logging tools.

14:00 14:30 0.50 8.50 C JSA Held pre-job and safety meeting with all personnel on site. Discussed safe operating procedures for arming guns and potential hazards involved.

14:30 19:00 4.50 13.00 C PP Using full lubricator and BOPS ran in with 127 mm ERHSC & CCL, correlated to above CBL log. At 15:48 hrs positioned CCL @ 3947.2 mKB ( CCL - T.S. = 0.8m, CCL - B.S. = 5.8m ) and perforated the Muskwa interval from 3948 - 3953 mKB with 17 spm, 25 gr salt/pepper, 60 deg, 86 shots total. Observed no real well responce at surface after perforating ( slight vacuum ), hole was full of fluid. Pulled out and recoverd gun, all shots fired. Note: Pulled 2300 lbs overline weight to get through liner top. Made up second identical gun and ran in and correlated same as the first. At 18:55 hrs positioned CCL @ 3934.2 mKB and perforated the Muskwa interval from 3935 - 3940 mKB. Observed small vacuum at surface after perforating.

19:00 19:15 0.25 13.25 C JSA Crew change and handover meeting - ensure no radio or cell phone use during perf'ing.

19:15 20:00 0.75 14.00 C PP POOH after shot #2.

20:00 20:30 0.50 14.50 C PP LD shot #2, PU same configuration for shot #3.

20:30 22:30 2.00 16.50 C PP RIH with charge #3, correlate to CCL logs, perf interval 3805-3810m, shot fired at 21:30h. POOH with shot #3.


23:00 01:00 2.00 19.00 C PP RIH with charge # 4 correlate to CCL logs, perf interval 3784-3789m, shot fired at 23:52h. POOH with shot #4.

01:00 01:45 0.75 19.75 CT PP Rope socket threads damaged. Rebuild unit prior to PU run #5.

01:45 02:15 0.50 20.25 CT PP LD charge #4, PU charge #5.

02:15 04:15 2.00 22.25 C PP RIH with charge # 5 correlate to CCL logs, perf interval 3365-3370m, shot fired at 03:20h. POOH with shot # 5.


04:45 06:00 1.25 24.00 C PP RIH with charge # 6 correlate to CCL logs, perf interval 3351-3356m, shot fired at 05:23h. POOH with shot # 6.

PerforationsDate




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Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Pulled out and recovered last gun, all shots fired. Rigged out and released wireline unit. Made up and ran in as follows; 155.6 mm Tri-cone Bit, 177.8 mm casing scraper, x-over, 88.9 mm pup joint, 79 joints of 88.9 mm, 13.84 kg/m, L-80, tubing, x-over, 244.5 mm casing scraper, x-over, 88.9 mm pup joint, and 340 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Worked scraper over all perforated intervals. Tagged hard PB same as before @ 3971 mKB ( rig tally ). Circulated down and cleaned out approximately 0.5 m of fill, PB was solid. Continued to circulate and displaced well over to 3% KCL water. LD RS head, POOH, LD casing scrapers.Proposed Activity 24hrs

PU 114.3mm completion string with packers and RIH with same with 88.9mm tubing. POOH with 88.9mm tubing and LD same.Daily Status





2,331,770Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,950.00



2,200.00



1,600.00



5,675.00










1,065.00


4,500.00


550.00

E-LINE SERVICES 07 COMPLETION Encore Dataline Inc Bond log and perforate. 129,000.00

LEASE COSTS 07 COMPLETION Beaver Enterprisees Ltd Construction cost to maintain access road and lease condition

11,565.00


Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 07:00 1.00 1.00 C PP Pulled out and recovered last gun ran, all shots fired. Rigged out and released wireline unit.

07:00 07:30 0.50 1.50 C JSA Held pre-job and safety meeting with all personnel on site. Orientated new personnel and issued safe work permits to new contractors.

07:30 15:00 7.50 9.00 C TR Made up and RIH tandem scraper assembly as follows; 155.6 mm Tri-cone Bit, 177.8 mm Casing scraper, x-over, 88.9 mm Pup joint, 79 joints of 88.9 mm, 13.84 kg/m, L-80, tubing, x-over, 244.5 mm Casing scraper, x-over, 88.9 mm Pup joint, and 340 joints of 88.9 mm, 13.84 kg/m, L-80, tubing. Tagged PB at same depth as before @ 3971 mKB according to tally ( wireline depth @ 3962 mKB ). Note: Worked 177.8 mm scraper over all perforated intervals.

15:00 19:00 4.00 13.00 C CC Rigged up RS-head and established reverse circulation. Cleaned out approximately 0.5 meters of fill and tagged hard PBTD @ 3971.5 mKB. Continued to circulate and displace well over to clean 3% KCL water.


19:15 21:00 1.75 15.00 C CC Continue to displace hole to KCl water, pumped out of rig tank once 400bbls were empty. Total displacement = 1 hole volume (143m3)

21:00 22:00 1.00 16.00 C RU Rig down RS head, install slips.

22:00 06:00 8.00 24.00 C LD LD 90 joints of 88.9mm tubing. Rack back remaining for running 114.3mm completion. LD casing scrapers.

PerforationsDate




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Job Type: Re-Entry

/3



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to pull out with 88.9 mm tubing, racked a total of 328 joints into derrick. Crew change, held pre-job and safety meeting with all personnel on site. Rigged up casing tongs and 114.3 mm handling equipment. Made up, tallied, drifted and ran in with 57 joints of 114.3 mm casing liner and packer assembly. Ran in with weatherford setting tool on 340 joints of 88.9 mm tubing. Set packers, pull test packers, p-test packer top to 21MPa for 15 min. Back-off from packer and POOH laying down 88.9mm tubing.Proposed Activity 24hrs

Finish laying down 88.9mm tubing. Move rig from wellcenter, re-level under rig. Spot rig and rig-up to run 139mm tubing.Daily Status





2,601,569Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00


07 COMPLETION Robert James Medic Group $2200/ ETV with 2 x medics, 1 x paramedic ( total cost for 16 days invoiced 35,200 )

2,200.00



1,600.00



5,675.00










1,065.00


4,500.00


550.00

EQUIPMENT RENTALS 07 COMPLETION Miko Casing Services Casing tongs to run in liner/packer assembly

7,854.00

TRUCKING 07 COMPLETION Miko Casing Services Second tong hand traveled up and delivered inhibiter pails, stayed to run nights

1,500.00


Job Type: Re-Entry

/3



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Granite Construction Inc Hot shot bit from Grande Prairie 1,890.00

COMPLETION FLUIDS 07 COMPLETION TWH Oilfield Services Catch up cost for KCL brine 10,890.00

PROD/LINER CASING & ATTACHMENTS

07 COMPLETION Global Steel Ltd Estimated cost for 114.3 mm, 22.47 kg/m, P-110, casing ( 707 m )

41,200.00

TRUCKING 07 COMPLETION Troyer Catch up cost for vacuum truck on mud can sept 2 & 3, hauled load back to disposal

5,300.00

RIG MOVES 07 COMPLETION GT'S Oilfield Hauling Catch up cost for rig move on Aug 19 46,000.00

TRUCKING 07 COMPLETION GT'S Oilfield Hauling Catch up cost for hauling broke down picker back to base in GP

15,085.00

TRUCKING 07 COMPLETION GT'S Oilfield Hauling Catch up cost for hauling in rental equipment & 10K BOPS on Aug 19

36,670.00

OTHER COSTS 07 COMPLETION CCS Disposal cost for mud 2,800.00

LEASE COSTS 07 COMPLETION Beaver Enterprises Ltd Construction cost to maintain access road condition

9,650.00

TRUCKING 07 COMPLETION Tru-North Trucking Haul fluid from river to Lined c-ring tank Aug 31

4,980.00

TRUCKING 07 COMPLETION Tru-North trucking Haul fluid from river to lined tank on location Sept 1

4,980.00

TRUCKING 07 COMPLETION Tru-North trucking Haul fluid from river to location Sept 2 4,980.00




Time Log


06:00 07:00 1.00 1.00 C TR Continued to pull out with 88.9 mm tubing string as previously ran. Racked a total of 328 joints into derrick.

07:00 07:30 0.50 1.50 C JSA Held pre-job and safety meeting with all personnel on site. Discussed safe operating procedures for picking up casing and potential hazards involved.

07:30 13:30 6.00 7.50 C PU Rigged up casing tongs and 114.3 mm handling equipment. Note: Pipe rams did not need to be changed, rubbers seal around 88.9 mm to 127 mm. Picked up, tallied, drifted and ran in with 114.3 mm liner/packer assembly as follows;

125 mm x 0.25 m, Pump out shoe ( 28.7 MPa shear )3 joints of 114.3 mm x 34.25 m, 22.47 kg/m, P-110, casing114.3 mm x 2.76 m, Pup joint149 mm x 3.4 m, Weatherford Ultrapak HU hydraulic set Permanent Packer4 joints of 114.3 mm x 46.19 m, 22.47 kg/m, P-110, casing139.7 mm x 1.23 m, Weatherford Frac Sleeve Port ( 84 mm ball seat )35 joints of 114.3 mm x 403.64 m, 22.47 kg/m, P-110, casing147.3 mm x 3.6 m, Ares hydraulic set Open hole packer114.3 mm x 11.55 m, 22.47 kg/m, P-110, casing joint114.3 mm x 1.86 m, Pup joint147.3 mm x 3.6 m, Ares hydraulic set Open hole packer114.3 mm x 11.35 m, 22.47 kg/m, P-110, casing joint114.3 mm x 3.07 m, Pup joint139.7 mm x 1.23 m, Weatherford Frac Sleeve Port ( 89.2 mm ball seat )5 joints of 114.3 mm x 57.23 m, 22.47 kg/m, P-110, casing147.3 mm x 3.6 m, Ares hydraulic set Open Hole Packer8 joints of 114.3 mm x 91.85 m, 22.47 kg/m, P-110, casing219 mm x 1.4 m, Ultrapack Liner top Packer

Made up setting tool to bottom of 88.9 mm tubing and connected to liner packer. Ran in hole and changed over handling equiment to 88.9 mm.Rigged out casing tongs.

13:30 19:00 5.50 13.00 C TR Continued to run in hole with 88.9 mm, 13.84 kg/m, L-80, tubing.


19:15 20:45 1.50 14.75 C TR Continue to RIH with 88.9mm tubing to land completion string. PU 12 singles for proper spacing. Nothing noted on weight indicator when packers passed through 177.8mm liner. Space out tubing, 1.8m stick-up on joint #340. Total run length 3900m.

20:45 21:30 0.75 15.50 C CC Drop 1.3/8" aluminum ball to shoe. Allow 30mins to freefall, CIRC for 15min until pressure noted at surface.


Job Type: Re-Entry

/3



Daily Report

Time Log


21:30 22:30 1.00 16.50 C PT Pressure up inside tubing to 10MPa, observe packer shear on PP guage, slack off weight to 40kadN, pull test to 60kdaN, measure 2.9m stretch. Pressure up to 20MPa, observed shear at 14MPa and 17MPa. Slack off to 42kdaN, pull test to 60kdaN, observed 2.8m stretch, slack off to 45kdaN.

22:30 22:45 0.25 16.75 C PT Pressure test backside (packer) to 21MPa for 15min, p-test good, bleed off pressure. Opened up inside tubing to observe flow due to pressure test and check for leaks.

22:45 23:00 0.25 17.00 C TR Slack off weight to 40kdaN, rotate 15 turns with rig tongs to the right (800ft-lbs). Pipe turned 1 turn backwards after releasing torque. Close kelly cock, pull up, released from liner, hookload 35kdaN. Open kelly cock, vacuum inside tubing.

23:00 06:00 7.00 24.00 C TR POOH and lay-down 88.9mm tubing.

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Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to pull out and lay down 88.9 mm, 13.84 kg/m, L-80 tubing. Crew change, held pre-job and safety meeting. Laid down 71 joints for a total of 340 joints pulled as previously ran. Laid derrick over and rigged out rig, pulled rig ahead and moved matting. Had cat build up pad and fill hole around wellhead. Spotted matting and backed rig up to wellhead. Stood derrick and started to scope out top section when gusset cracked on A-leg frame connected to turn buckle. Rig now on down time untill repaired. Welder and Inspector scheduled for Sept 8th.Proposed Activity 24hrs

Repair gusset on turnbuckle and inspect same. PU 139mm tubing and run same.Daily Status





2,663,046Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00





TRUCKING 07 COMPLETION Radar Road Transport Estimated tow-cat services, $2470/day/Now on 24 hr ops est @ $4,440/day

3,950.00




1,065.00


4,500.00


550.00


8,155.00

Time Log


06:00 07:00 1.00 1.00 C LD Continued to pull and lay down 88.9 mm, 13.84 kg/m, L-80, tubing.


Job Type: Re-Entry

/2



Daily Report

Time Log


07:00 07:30 0.50 1.50 C JSA Crew change, held pre-job and safety meeting with all personnel on site.

07:30 10:00 2.50 4.00 C LD Pulled out and laid down 71 joints, total tubing laid down was 340 joints as previously ran. Secured well. Rigged out pipe handling equipment and working floor.

10:00 15:00 5.00 9.00 C RU Laid derrick over and rigged out rig, moved rig ahead and parked out of way. Pulled matting away from wellhead. Had cat build up pad and fill in hole around wellhead. Spotted matting and backed rig up to wellhead again. Stood derrick and started to scope out top section when gusset cracked on A-leg frame connected to turn buckle. Rig now on down time untill repaired.

15:00 06:00 15.00 24.00 CT RR Waiting on welder and inspector to arrive and repair damaged gusset connected to A-leg frame.

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Job Type: Re-Entry

/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on rig repair to cracked gusset on A-leg frame.Proposed Activity 24hrs

Inspect welding work, RU to run 139mm casing and run same.Daily Status





2,725,731Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00

SERVICE RIG 07 COMPLETION CWC Well Services Daily rig charges 0.00





4,690.00




1,065.00


4,500.00


550.00


8,155.00

EQUIPMENT RENTALS 07 COMPLETION Keytek Group Inc Monthly rental for 2 light towers/sewage tank/rig matting

14,700.00


Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 06:00 24.00 24.00 CT RR Continued to wait on repairs to cracked gusset on A-leg frame. Rig still on down time. Gusset welded back in place, waiting on inspection. Investigation ongoing.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Repair gusset, test weld with magnetic particles, test is good. Shutdown by NEB.Proposed Activity 24hrs

Wait on NEB.Daily Status





2,860,855Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00

SERVICE RIG 07 COMPLETION CWC Well Services Daily rig charges 0.00





3,395.00




1,065.00


4,500.00


550.00


4,910.00

OTHER COSTS 07 COMPLETION Secure Energy Services Disposal cost for mud recovered from wellbore

91,679.00

Time Log


06:00 20:00 14.00 14.00 CT RR Repair gusset, magnetic particle test weld, test is good.


Job Type: Re-Entry

/2



Daily Report

Time Log


20:00 06:00 10.00 24.00 CT REG Shutdown by NEB following gusset repair.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on NEB approval to move forward. Conducted CAODC level III inspection on derrick components and documented. NEB approval was granted to continue operations. Held pre-job and safety meeting with all personnel on site. Stood derrick and rigged up rig. Rigged up floor and pipe handling equipment. Made up and ran in with 176.9 mm Ultrapak Latch Seal assembly on 139mm 34.23kg/m P110 LT&C casing. RIH to joint 229, stab into upper packer, mark 20 and 25kdaN compression, back out of packer.Proposed Activity 24hrs

LD joint # 229 and 228, PU pups, MU csg joint and dognut. RIH, CIRC inhibited water, stab into packer, land dognut, p-test and rig down service rig.Daily Status




3,121,910Cumulative Cost (Cost)

5,982,765Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00

SERVICE RIG 07 COMPLETION CWC Well Services Daily rig charges - full dayrate inputted, unsure of DT.

17,500.00





4,690.00




1,065.00


4,500.00


550.00


5,620.00

LEASE COSTS 07 COMPLETION Construction cost carried over from building access road

3,000,000.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Tidy Trucking Ltd Haul fluid from river to location. Ticket # 129776 to # 129785

32,340.00

TRUCKING 07 COMPLETION Tidy Trucking Ltd Haul fluid from river to location. Ticket # 114268 to # 114275

26,620.00

Time Log


06:00 11:30 5.50 5.50 CT REG Continued to wait on NEB approval to move forward. Conducted CAODC level III inspection on all derrick components and documented. NEB approval was granted to continue operations.

11:30 12:00 0.50 6.00 C JSA Held pre-job and safety meeting with all personnel on site. Discussed safe operating procedures for rigging up and running casing and any potential hazards involved.

12:00 15:30 3.50 9.50 C RU Stood derrick and rigged up rig, installed guyline anchors. Rigged up floor and pipe handling equipment. Note: Previously changed out pipe rams, pressure tested 139.7 mm pipe rams to 1 & 35 MPa, 10 minutes each test.

15:30 19:00 3.50 13.00 C PU Tallied, drifted, picked up and ran in with 139.7 mm frac string. Torqued all connections to 6,000 ft lbs. Ran in as follows; 176.9 mm x 0.76 m Ultrapak Latch Seal assembly on 50 joints of 139.7 mm, 34.23 kg/m, P-110, casing.


19:15 06:00 10.75 24.00 C PU Continue to RIH with 139.7mm, 34.23kg/m P110 LT&C frac string. MU joint 229, stab into upper packer assembly, chalk mark 20kdaN and 25kdaN compression on pipe, back out of packer.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Rotated out and disengaged from Permanent Liner Top Packer previously set @ 3217.2 mKB. Crew change, held pre-job and safety meeting. Spaced out and buried 2 pup joints. Installed 279.4 mm x 139.7 mm tubing hanger. Circulated inhibited water down annular. Stung into liner top and landed hanger in 23,000 daN compression. Pressure tested annular and seal bore assembly to 21 MPa, 15 min, held solid. Secured well. Rigged out rig and associated equipment. Note: Picker to arrive in morning to remove 70 MPa BOPS and install upper wellhead.Proposed Activity 24hrs

Clean out rigtank. Remove BOPS and install upper wellhead using picker. Move remaining rig equipment down to landing. Load rig and equipment onto barge. Finish hauling in frac water and release tank trucks.Daily Status





6,614,845Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00


17,800.00





4,690.00




1,065.00


4,500.00


550.00


6,175.00

PROD/LINER CASING & ATTACHMENTS

07 COMPLETION Summit Tubulars Corp. 139.7 mm, 34.23 kg/m, P-110, Casing. Total of 237 joints, 3,274 m.

306,900.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


PACKERS 07 COMPLETION Weatherford Frac sleeves and liner packer assembly 141,000.00

EQUIPMENT RENTALS 07 COMPLETION Miko Casing Services Ltd Casing tongs w/2 men/3 days standby 19,000.00

COMPLETION FLUIDS 07 COMPLETION Baker Hughes Petrolite Weighted corrosion inhibitor, 800 liters 5,825.00

OTHER COSTS 07 COMPLETION Cooper Barging Service Ltd Barging charges. Tickets 09438 to 09441 & 10123, 10117, 10109, 10149, 10150

90,750.00

OTHER COSTS 07 COMPLETION Cooper Barging Service Ltd Tow cat and barge landing maintenance 4,800.00

Time Log


06:00 07:00 1.00 1.00 C PU Rotated out of Permanent Liner Top Packer previously set @ 3217.2 mKB. Spaced out and buried 2 pup joints. Installed 279.4 mm x 139.7 mm tubing hanger. Rigged up pumping lines.

07:00 07:30 0.50 1.50 C JSA Crew change, held pre-job and safety meeting with all personnel on site. Discussed safe operating procedures for circulating and rigging out and potential hazards involved.

07:30 09:00 1.50 3.00 C CC Pumped 800 liters of weighted Baker CRW9935 corrosion inhibitor down annular followed by 5 m3 of fresh water. Inhibited back side to 1%.

09:00 09:30 0.50 3.50 C PU Lowered bottom latch seal assembly and stung into liner top, pulled tension and confirmed engaged. Landed tubing hanger in 23,000 daN compression. Note: Bottom of pump out ball seat landed @ 3899.25 mKB, top of 114.3 mm packer @ 3862 mKB, top of frac port sleeve @ 3811.2 mKB, center element on first open hole packer @ 3406.8 mKB, center element on second open hole packer @ 3389.8 mKB, top of frac port sleeve @ 3371.3 mKB, center element on third open hole packer @ 3313.3 mKB, top of 244.5 mm liner top packer @ 3217.2 mKB.

09:30 10:00 0.50 4.00 C PT Pressure tested seal bore assembly and annular to 21 MPa, 10 minutes, held solid. Bled off pressure and secured well.

10:00 19:00 9.00 13.00 C RU Rigged out pipe handling equipment and working floor. Rigged out rig and associated equipment. Transferred fluid from rigtank. Moved service rig down to barge landing.

19:00 19:30 0.50 13.50 C JSA Crew change, held pre-job and safety meeting with all personnel on site. Discussed safe operating procedures for rigging out.

19:30 21:30 2.00 15.50 C RU Finished rigging out remaining equipment. Prepared equipment to move in the morning. Released night crew. Well secured. SDFN.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Started up, held pre-job and safety meeting. Rigged out and loaded remaining equipment, cleaned rigtank. Removed 70 MPa BOPS and installed upper 139.7 mm x 70 MPa wellhead. Secured well. Spotted evaporation tank and propane skids. Released water haulers. Total water hauled from Ft Liard river and stored in double lined C-ring tank on location was 6,010 m3. Hauled all rig equipment down to barge landing and prepared to move across river in morning. SDFN.Proposed Activity 24hrs

Load service rig on wheeler and haul back to base. Load remaining rig equipment onto barge then haul back to base. Released service rig and crew. Prepare access road and location site for frac equipment.Daily Status





6,942,680Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00


19,300.00





2,850.00




1,065.00


4,500.00


550.00


6,085.00

TRUCKING 07 COMPLETION Tru- North Trucking Delivered town water from Ft Nelson to camp. Ticket # 19205, 19206, 19207

13,540.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Tru-North Trucking Catch up cost for hauling water. Ticket #'s 18922, 18924, 18925, 18792-18794, 18953

45,585.00

TRUCKING 07 COMPLETION Tidy Trucking Ltd Hauling water. Ticket # 129751-129756, 129726-129734, 128122-128125, 129786

74,700.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for hauling water. Ticket #'s 22462, 22463, 22464, 34147, 34148

68,530.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for hauling mud to disposal Sept 3 & 5/ Ticket # 22445, 22437

60,225.00

TRUCKING 07 COMPLETION Cooper Barging Service Ltd Hauled out 2 propane skids from Ft Nelson

1,880.00

Time Log


07:30 08:00 0.50 0.50 C JSA Started up, held pre-job and safety meeting with all personnel on site. Orientated new personnel and issued safe work permit to GT Oilfield hauling.

08:00 11:00 3.00 3.50 C RU SIWP: staticHad vacuum truck clean out rigtank and prepared to move. Finished rigging out remaining equipment and hauled loads down to barge landing. Cleaned up location site.

11:00 14:00 3.00 6.50 CT WO Waited on picker and trucks to arrive from barging across river.

14:00 17:30 3.50 10.00 C WH Picker arrived on location. Stripped over and removed 70 MPa BOPS, broke apart and loaded in 2 pieces. Removed pup joint with safety valve. Installed 279.4 mm x 139.7 mm x 70 MPa upper flowing style wellhead. Secured well.

17:30 19:30 2.00 12.00 C RU Loaded rig matting, pipe racks and catwalk. Loaded all rental equipment. Hauled all equipment off location and parked at camp, ready to load barge in the morning.

Note: Total fresh water hauled into location for fracture treatment was 6,010 m3. Hauled from Ft Liard river into double lined tank in 8 days. Released all tank trucks and barged across river.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Started up, held pre-job and safety meeting. Loaded rig equipment onto barge and moved across river. Loaded rig onto wheeler and moved back to base in Grande Prairie. Hauled rental equipment back to Grande Prairie. Released service rig. Transferred fluid on location to evaporation tank. Wait on frac equipment.

Note: Ordered High rate pressure truck and surface gauges to conduct breakdown and feed rate test.Proposed Activity 24hrs

Wait on fracture treatment. Prepared for breakdown and feed rate test.Daily Status





7,007,348Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00



1,600.00



5,675.00

SERVICE RIG 07 COMPLETION CWC Well Services Rig charges - full 24 hr dayrate inputted for move back to base. (double charged?)

20,593.00




TRUCKING 07 COMPLETION Radar Road Transport Estimated tow-cat services, $2800/day for standby on 2 tractors

2,850.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter service 1,500.00



1,065.00


4,500.00


550.00


6,085.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 08:00 0.50 0.50 C JSA Started up, held pre-job and safety meeting with all personnel. Discussed safe operating procedures for loading equipment and potential hazards involved.

08:00 16:00 8.00 8.50 C MO Loaded rig onto wheeler and hauled back to base in Grande Prairie. Loaded remaining rig equipment and rental equipment onto barge and traveled across river. Unloaded and hauled all equipment back to base in Grande Prairie. Service rig was released. Transferred fluid on location into evaporation tank. Wait on availability of Cal-Frac pumping equipment. Prepared to conduct breakdown and feed rate test, ordered equipment for Thursday Sept 15/2011.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Wait on availability of Cal-Frac pumping equipment. Assisted NEB on camp and location site inspection.Proposed Activity 24hrs

MIRU Pressure truck. Install surface recorders. Pump off ball seat end plug. Establish breakdown and small injection test to lower Muskwa intervals.Daily Status





7,067,943Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00

TRUCKING 07 COMPLETION Bert Baxter Charges for bed-truck use ( ticket # 15235 was for the last 6 consecutive days )

3,500.00


1,600.00



5,675.00

SERVICE RIG 07 COMPLETION CWC Well Services Charged another 12 hrs for rig move back to base. ( too many rig hrs for move back )

10,580.00





2,850.00




1,065.00


4,500.00


550.00


6,085.00

TRUCKING 07 COMPLETION Tidy Trucking Ltd Catch up cost for hauling dirty water back to disposal after releasing trucks

5,940.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 17:30 10.00 10.00 CT WO Wait on availability of Cal-Frac pumping equipment. Assisted NEB on camp and location site inspection.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Wait on pressure truck to arrive, had tug boat barge across river and unload. Held pre-job and safety meeting. Rigged up pressure truck, installed adapter flange to flow-tee on 70 MPa wellhead. Installed surface recorders. Applied annular pressure. Pumped off tubing end plug and achieved breakdown on Lower Muskwa intervals @ 65.5 MPa. Initial feed rate was 40 lit/min @ 70 MPa, final feed rate was 80 lit/min @ 65.5 MPa. Secured well with surface recorders monitoring pressure every 30 seconds. Rigged out and released pressure truck. Continued to wait on availability for Cal-Frac pumping equipment.Proposed Activity 24hrs

Wait on availability for Cal-Frac pumping equipment.Daily Status





7,426,183Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00


07 COMPLETION Robert James Medic Group $2200/ ETV with 2 x medics, 1 x paramedic ( down to ETV w/1 medic/first aid station )

950.00







2,850.00




1,065.00


4,500.00


550.00


6,085.00

OTHER COSTS 07 COMPLETION Peregrine Pressure Testing Pressure truck conducted breakdown and injectivity test.

5,420.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Colt Energy Purchased 100 m3 evaporation tank 215,670.00

OTHER COSTS 07 COMPLETION Cooper Barging Service Ltd Catch up cost for barging services. Ticket #'s 10157 - 10160

40,400.00

OTHER COSTS 07 COMPLETION Cooper Barging Service Ltd Tow cat and barge landing maintenance 4,200.00

OTHER COSTS 07 COMPLETION AFD Petroleum Ltd Estimated cost for cartage and fuel to supply for fracture treatments

57,000.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 12:30 5.00 5.00 C OT Waited for pressure truck to arrive. Tug boat barged unit across river and unloaded. Traveled up lease road to location site.

12:30 13:00 0.50 5.50 C JSA Held pre-job and safety meeting with all personnel on site. Orientated new personnel and issued safe work permit.

13:00 18:00 5.00 10.50 C OT Loaded 5 m3 of fresh water onto pressure truck. Spotted and rigged up pressure truck. Installed adapter flange to side of flow-tee on 70 MPa wellhead. Installed surface recorders ontop of flow-tee. Applied 7 MPa annular pressure and monitored with gauge. Connected pumping line to adapter flange and pressure tested the wellhead to 70 MPa, good test. Opened wellhead and started pumping at a rate of 60 lit/min. Observed pump out tubing end plug released at 38.5 MPa. Continued pumping at same rate and achieved breakdown to Lower Muskwa intervals @ 65.5 MPa. Started to feed tight formation, injection pressure gradually increased. Decreased rate to 40 lit/min @ 70 MPa, squeezed 0.4 m3 away at this rate. Stopped pumping and waited 10 minutes. Pressure bled down to 63 MPa. Initiated pumping again at 25 lit/min, started to feed at 70 MPa. Observed second breakdown. Increased to maximum rate of 80 lit/min @ 65.5 MPa. Squeezed another 1.2 m3 away at this rate. Total fluid pumped was 4.5 m3. Used 1.7 m3 to establish first breakdown and squeezed remaining 2.8 m3 away into formation. Secured well with surface recorders still monitoring tubing pressure. Bled annular pressure down to 1,000 kPa, no sign of any communication. Rigged out and released pressure truck. SITP after 4 hours was 44,340 kPa.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on Cal-Frac pumping equipment.Surface recorders still monitoring leak off pressure from previous injection test. SITP: 32,280 kPa.Proposed Activity 24hrs

Wait on availability of Cal-Frac pumping equipment.Daily Status





7,500,532Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,660.00



950.00







2,850.00




1,065.00


4,500.00


550.00


6,085.00

TRUCKING 07 COMPLETION Sawyer Oilfield Hauling Hauled out evaportion tank from Spike's yard in Red Deer on Sept 12

9,195.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for hauling water/mud to disposal when tank trucks were released

7,920.00

OTHER COSTS 07 COMPLETION CCS Midstream Services Disposal cost 21,624.00

Time Log


07:30 17:30 10.00 10.00 CT WO Continued to wait on availability of Cal-Frac pumping equipment. Note: Had Newcart safety maintain 24 hr security. Surface recorders still monitoring bleed off pressure from previous injection test. SITP: 32,280 kPa and still declining. Total frac water on location is 6,010 m3, temperature was 13.3 deg C.


Job Type: Re-Entry

/2



Daily Report

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on availability of Cal-Frac pumping equipment. Surface recorders still monitoring leak off pressure from previous injection test to Lower Muskwa intervals. SITP: 26,200 kPa.Proposed Activity 24hrs

Wait on Cal-Frac pumping equipment. Barge across river and haul in sand cans. Spot sand cans on location and prepare to haul sand in over next few days.Daily Status





7,533,047Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



950.00







2,850.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter service ( signed 7 catch up tickets )

1,500.00



1,065.00


4,500.00


550.00


3,050.00

Time Log


07:30 17:30 10.00 10.00 CT WO Continued to wait on availability of Cal-Frac pumping equipment. Surface recorders still monitoring bleed off pressure from previous injection test to the Lower Muskwa intervals. SITP: 26,200 kPa.

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Daily Report

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to wait on availability of Cal-Frac pumping equipment. Scheduled to arrive on Friday Sept 23. Hauled in and spotted sand cans on location, prepared to haul in frac sand next day. Surface recorders still monitoring leak off pressure. SITP was 24,254 kPa.Proposed Activity 24hrs

Start hauling in sand concentrations and unloading into sand cans on location. Continue to wait on Cal-Frac pumping equipment, scheduled to arrive Friday Sept 23/2011.Daily Status





7,568,402Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



950.00







5,060.00


1,500.00



1,065.00


4,500.00


550.00


3,680.00

Time Log


07:30 17:00 9.50 9.50 CT WO Continued to wait on availability of Cal-Frac pumping equipment. Barged sand cans across river. Chained up equipment and had tow cats assist sand cans up access road ( wet & muddy ).

17:00 17:30 0.50 10.00 C JSA Held pre-job and safety meeting. Orientated new personnel and issued safe work permit.

17:30 18:30 1.00 11.00 CT WO Moved in and spotted sand cans. Prepared to haul in sand next day. Surface recorders still monitoring leak off pressure from previous injection test. SITP after 72 hours was 24,254 kPa. Continued to wait on Cal-Frac pumping equipment.


Job Type: Re-Entry

/2



Daily Report

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Barged 9 transports across river and moved up to location. Unloaded 260 tonnes of sand into sand cans on location. Prepared to move sand transports across river and release units in the morning. Continued to wait on remaining Cal-Frac pumping equipment.Proposed Activity 24hrs

Continue to wait on Cal-Frac pumping equipment. Move in and rig up tank manifold & transfer pumps.Daily Status





7,741,528Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



950.00







4,690.00


1,500.00



1,065.00


4,500.00


550.00


3,775.00

RIG MOVES 07 COMPLETION GT's Oilfield Hauling Catch up cost for wheeling rig & hauling equipment back to Grande Prairie/Nisku

114,478.00

TRUCKING 07 COMPLETION PeBen Oilfield Services Hauled used yellow band 88.9 mm tubing to Nisku for possible re-sale

6,460.00

TRUCKING 07 COMPLETION PeBen Oilfield Services Hauled used yellow band 88.9 mm tubing to Nisku for re-sale

6,960.00

TRUCKING 07 COMPLETION PeBen Oilfield Services Hauled used yellow band 88.9 mm tubing to Nisku for possible re-sale

7,110.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 18:30 11.00 11.00 CT WO Barged 9 sand transports across river and traveled up lease road to location site. Orientated new personnel and held pre-job and safety meeting. Unloaded 260 tonnes of sand into sand cans previously spotted on location. Prepared to move transports across river in the morning. Continued to wait on remaining Cal-Frac pumping equipment. First loads scheduled to arrive Friday Sept 23/2011.

Note: Surface recorders still monitoring leak off pressure from previous injection test. SITP: 23,080 kPa.

PerforationsDate




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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Hauled in and rigged up transfer pumps and tank manifold to supply water from C-ring tank. Continued to wait on CalFrac pumping equipment.Proposed Activity 24hrs

Continue to wait on availability of Cal-Frac pumping equipment. MIRU 120 foot flare stack. Pumping equipment still scheduled to arrive on Friday Sept 23/2011Daily Status





7,788,471Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



950.00

TRUCKING 07 COMPLETION Bert Baxter Charges for bed-truck use ( ticket 15236 was for charges last 6 days )

3,500.00






2,850.00


1,500.00



1,065.00


4,500.00


550.00


5,985.00

TRUCKING 07 COMPLETION Bert Baxter Transport Ltd Trucking charges for hauling out transfer pumps & tank manifold

5,390.00

LABOUR 07 COMPLETION Keytek Industries Labour and travel charges to rig up transfer pumps and manifold for frac treatment

3,065.00

Time Log


07:30 11:30 4.00 4.00 CT WO Continued to wait on availability of Cal-Frac pumping equipment.

11:30 12:00 0.50 4.50 C JSA Held pre-job and safety meeting. Orientated new personnel and issued safe work permit.


Job Type: Re-Entry

/2



Daily Report

Time Log


12:00 16:00 4.00 8.50 C OT Hauled in and rigged up transfer pumps and tank manifold to supply water from C-ring tank for frac equipment.

16:00 17:30 1.50 10.00 CT WO Continued to wait on Cal-Frac pumping equipment. Removed surface recorders and secured well. Final leak off pressure was 22,115 kPa. Returned gauges back to Bonnetts in Ft Nelson to download data.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Hauled in and rigged up 36.5 m flare stack. Installed ammonia scrubbers to shipping tanks. Continued to wait on availability of Cal-Frac pumping equipment.Proposed Activity 24hrs

Continue to wait on Cal-Frac pumping equipment. MIRU wellhead isolation tool. Install wind monitoring tower.Daily Status





7,851,321Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



950.00







2,850.00


1,500.00



1,065.00


4,500.00


550.00


4,635.00

EQUIPMENT RENTALS 07 COMPLETION Am-Gas Estimated cost for travel, rig up, and ammonia scrubbers w/product. Daily rental $170

7,260.00

EQUIPMENT RENTALS 07 COMPLETION Alberta Flare Daily rental cost for 120 foot flare stack 350.00

EQUIPMENT RENTALS 07 COMPLETION 10K Rentals Estimated Daily cost for 10K flowline & manfolid with ESD

1,600.00

TRUCKING 07 COMPLETION Bert Baxter Transport Picker hauled out and helped set up 120 foot flare stack

10,290.00

OTHER COSTS 07 COMPLETION Allright Anchors Installed guyline anchors to support flare stack

3,750.00

TRUCKING 07 COMPLETION Beaver Enterprises Ltd Haul D-8 cat back to Ft Nelson 3,400.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 12:30 5.00 5.00 CT WO Continued to wait on availability of Cal-Frac pumping equipment. Barged flare stack with test equipment and ammonia scrubbers across river and transported up to location.

12:30 13:00 0.50 5.50 C JSA Held pre-job and safety meeting. Orientated new personnel and issued safe work permit. Discussed safe operating procedures for lifting tall stack and possible hazards involved.

13:00 17:30 4.50 10.00 C OT Unloaded and spotted 70 MPa flowline and manifold. Rigged up ammonia scrubber to shipping tanks. Made up sections and stood 36.5 m flare stack using picker, installed guyline anchors. Continued to wait on Cal-Frac pumping equipment. SDFN.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

MIRU wellhead isolation tool. Rigged up wind monitoring tower. Continued to wait on Cal-Frac pumping equipment. First wave of equipment to arrive at barge in the morning.Proposed Activity 24hrs

Barge first half of frac equipment across river and move up and spot on location. Remaining frac equipment to arrive next day.Daily Status





7,903,116Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,200.00







2,850.00




1,065.00


4,500.00


550.00


5,430.00

EQUIPMENT RENTALS 07 COMPLETION Am-Gas Daily rental $170 170.00



1,600.00

EQUIPMENT RENTALS 07 COMPLETION IES Travel up and rig in wellhead isolation tool.

11,430.00

Time Log


07:30 13:30 6.00 6.00 CT WO Continued to wait on availability of Cal-Frac pumping equipment. Barge wellhead isolation tool and wind tower across river.


Job Type: Re-Entry

/2



Daily Report

Time Log


13:30 14:00 0.50 6.50 C JSA Held pre-job and safety meeting with all personnel on site. Orientated new personnel and issued safe work permits.

14:00 19:00 5.00 11.50 C OT SITP: 21,000 kPaBled off well pressure back to P-tank. Installled 105 MPa wellhead isolation tool ontop of 139.7 mm x 70 MPa wellhead. Stung through wellhead and seated cups inside casing frac string. Rigged up wind monitoring tower. Continued to wait on Cal-Frac pumping equipment, first wave of equipment scheduled to arrive at barge landing in the morning.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Barged 15 frac units across river and moved up lease road to camp site. Chained up all equipment and had tow cats assist equipment up access road. Orientated all new personnel.Proposed Activity 24hrs

Barge remaining frac equipment across river. Spot and rig up all frac equipment on location.Daily Status





8,029,426Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00


07 COMPLETION Robert James Medic Group $2200/ ETV with 1 medic, 1 x paramedic, safety trailer

2,000.00







5,800.00




1,065.00


4,500.00


550.00


7,150.00


170.00



1,600.00


3,450.00

EQUIPMENT RENTALS 07 COMPLETION Weatherford 5 day min rental charges for ball catcher $440/day after min charges

3,600.00

MATERIALS & SUPPLIES 07 COMPLETION Liard fuel centre Ltd Catch up cost for diesel & gas 68,595.00

EQUIPMENT RENTALS 07 COMPLETION HSE Integrated Rigged up and installed MET tower 5,830.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 20:30 13.00 13.00 C MO Moved frac equipment from Ft Nelson to Coopers barge landing in Ft Liard. Held pre-job and safety meeting. Barged 15 units across river and moved up access road to camp site. Chained up all equipment and had tow tractors assist equipment up lease road. Orientated all new frac personnel. Note: Remaining 8 frac units to arrive at coopers barge landing in the morning.

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Move in remaining CWS units, spot same and rig up to frac. Wait on daylight.Proposed Activity 24hrs

Fracture treat the Muskwa & Exshaw intervals.Daily Status





8,078,601Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00



2,000.00







3,580.00




1,065.00


4,500.00


550.00


6,660.00


170.00



1,600.00


3,450.00


3,600.00

Time Log


07:30 20:30 13.00 13.00 C RU Move in remaining CWS units, spot all trucks and rig up to frac. Wait on daylight.


Job Type: Re-Entry

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Daily Report

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/2



Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Rig up to frac. Start transfer pumps from water tank, return line fell from tank edge striking 1 person. See incident report for further details. Review transfer equipment, add additional return line and secure same. Test transfer equipment. Prep to p-test CWS and p-test same. Pump frac treatment as per time long summary. Shut IES isolation equipment, bleed off CWS and rig-down flow lines. Shut-down for daylight.Proposed Activity 24hrs

Prep for frac and frac same.Daily Status





9,071,227Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,835.00



2,000.00







5,060.00




1,065.00


4,500.00


550.00


4,730.00


170.00



1,600.00


7,021.00


0.00

STIMULATION 07 COMPLETION Cal-Frac Well Service Travel day, standby day with rig up. Fracture treated lower Muskwa intervals

943,695.00


Job Type: Re-Entry

/2



Daily Report

Time Log


07:30 08:30 1.00 1.00 C MO MOB to site with all crew. Fill up pressure truck w 2m3 water.

08:30 09:00 0.50 1.50 C JSA Safety meeting with all crews on location. Review upcoming jobs, touch on high pressure, remote location, weather conditions.

09:00 09:15 0.25 1.75 C PT Rig up to pressure test, start transfer pumps from water tank, 3" return line fell from tank edge when return fluid pumped back to water tank. 1 person struck with aluminum tube. IP taken to medic for evaluation, shut-down equipment and investigate.

09:15 11:00 1.75 3.50 C JSA Treat IP, investigate work area, add additional return line and tie-down return lines. Conduct another pre-job meeting, test transfer pumps and return lines, test good. Report and pictures to follow.

11:00 14:00 3.00 6.50 CT FR Troubleshoot flow meters and CWS frac equipment. Fill lines and p-test to 83MPa, leak on transducer, shut-down, bleed off and check transducer.

14:00 14:15 0.25 6.75 C PT P-test CWS again, test good.

14:15 18:30 4.25 11.00 C FR Pump 3m3 acid @ 14.2MPa, followed by 152m3 PAD, 294m3 w 10T 50/140 sand blend, 207m3 w 20T 40/70 sand blend, 240m3 w 15T 40/70 Prime Plus blend. Total sweeps pumped throughout job 239m3. Flushed at end of job w 60m3. Total volume pumped 1195m3. Feedrate was 70MPa, average treating pressure was 70.5MPa, max treating pressure 75.2MPa, min treating 66.6MPa. Annulus pressure started at 4MPa during pressure tests and brought up to 18MPa during frac treatment. Min treatment rate, 3.65m3/min, avg of 8.5m3/min, max of 9.35m3/min.

18:30 18:45 0.25 11.25 C FR Other job data: total power used, 9988kW. Calc frac gradient, 25.6kPa/m, Acid ISIP 59.7MPa, final treatment ISIP 62MPa, 1min SIP 56.7MPa, 5min SIP 51.7MPa, 10min SIP 51MPa, 15min SIP 49.3MPa.

18:45 20:00 1.25 12.50 C RU Shut-in on IES isolation, bleed off pressure on CWS equipment, rig down CWS flow lines. Bleed down pressure on annulus to 10MPa. Wait on daylight.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Started up, held pre-job and safety meeting with all personnel on site. Staged out wellhead isolation tool. Dropped 84 mm ball onto gate valve. Installed wellhead isolation tool, opened well and dropped ball, staged in isolation tool. Rigged up pumping lines. Pressure tested surface equipment and lines to 83 MPa. Spearheaded 3 m3 of 15% HCL acid + additives. Seated ball and shifted frac sleeve port @ 70 MPa, spotted acid into formation and allowed to soak for 5 minutes. Fracture treated the upper Muskwa intervals down 139.7 mm casing at an average rate of 9 m3/min. Observed breakdown ( feed rate ) at 70 MPa with an average treating pressure of 69 MPa. Pumped a total of 1,763 m3 fresh water. Down hole sand concentration went from 30 kg/m3 to 220 kg/m3 with sweeps between stages. Total sand pumped was 10 tonne 50/140 mesh, 80 tonne 40/70 mesh and 20 tonne 40/70 prime plus mesh. Total sand into formation was 110 tonne, overflushed by 15 m3. ISIP was 54.7 MPa, 5 min SIP was 52.6 MPa, 15 min SIP was 51.5 MPa. Rigged off pumping lines and secured well for night. SDFN.Proposed Activity 24hrs

Fracture treat the upper Exshaw intervals.Daily Status





9,774,671Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,835.00



2,000.00







6,540.00




1,065.00


4,500.00


550.00


4,945.00


170.00



1,600.00

EQUIPMENT RENTALS 07 COMPLETION IES Wellhead isolation tool 7,471.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



0.00

STIMULATION 07 COMPLETION Cal-Frac Well Service Fracture treated upper Muskwa intervals. 616,853.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for standby and vacuum truck use. Ticket #'s 38643 to 38647

35,515.00

Time Log


07:30 08:00 0.50 0.50 C JSA Started up. Held pre-job and safety meeting with all personnel on site. ETV with paramedic and shower unit on location.

08:00 10:00 2.00 2.50 C RU SITP: 43,100 kPa; SICP: 18,500 kPa.Staged out wellhead isolation tool. Placed 84 mm shifting ball onto gate valve. Installed wellhead isolation tool, opened well and allowed ball to drop, staged in isolation tool and seated cups. Rigged up pumping lines.

10:00 10:30 0.50 3.00 C PT Pressure tested surface equipment and lines to 83 MPa.

10:30 18:30 8.00 11.00 C FR Pumped water down well at 1 m3/min and seated ball in frac sleeve port @ 3812.4 mKB. Shifted sleeve at 70 MPa and opened port, started to feed into formation. Spearheaded 3 m3 of 15% HCL acid + additives and placed half the acid into formation, allowed acid to soak for 5 minutes. ISIP was 56.1 MPa. Started pumping pad and gradually increasing rate. Lost good prime to blender from transfer pumps. Suspected suction line inside C-ring tank partially plugged off. Pumped through and purged suction line clean. Continued with stimulation and fracture treated the upper Muskwa intervals ( 3784 - 3789, 3805 - 3810 ) down 139.7 mm casing at an average pumping rate of 9 m3/min, average treating pressure was 69 MPa. Pumped 125 m3 for pad, 1,313 m3 used for proppant, and 267 m3 on sweeps. Total fluid pumped was 1,763 m3 fresh water. Down hole sand concentration went from 30 kg/m3 to 220 kg/m3. Total sand pumped was 10 tonne 50/140 mesh, 80 tonne 40/70 mesh, and 20 tonne 40/70 prime plus mesh. Total sand into formation was 110 tonne, overflushed by 15 m3. ISIP was 54.7 MPa, 5 min SIP was 52.6 MPa, 15 min SIP was 51.5 MPa. Held 18 MPa annulus pressure during treatment. Note: Blender broke down at end of treatment, had replacement blender barged across river ready to move onto location in the morning. Rigged off pumping lines and secured well for night. Bled annulus pressure down to 8 MPa. SDFN.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Started up, held pre-job and safety meeting with all personnel on site. Staged out wellhead isolation tool. Dropped 88.9 mm ball onto gate valve. Installed wellhead isolation tool, opened well and dropped ball, staged in isolation tool. Rigged up pumping lines. Pressure tested surface equipment and lines to 83 MPa. Spearheaded 4 m3 of 15% HCL acid + additives. Seated ball and shifted frac sleeve port @ 75 MPa, had difficulty shifting sleeve, spotted acid into formation and allowed to soak for 5 minutes. Fracture treated the upper Exshaw intervals down 139.7 mm casing at an average rate of 3.6 m3/min. Observed no breakdown, very tight, started to feed at 65 MPa with a lower rate initially. Average treating pressure was 72 MPa. Pumped a total of 871 m3 fresh water. Down hole sand concentration was between 30 kg/m3 to 70 kg/m3 with sweep stages. Total sand pumped was 10 tonne 50/140 mesh and 17 tonne 40/70 mesh. Total sand into formation was approximately 26 tonne. Sanded off with approximately 1 tonne inside pipe, total flush volume was 9.5 m3. ISIP was 75 MPa, 5 min SIP was 55.8 MPa. Rigged off pumping lines, rigged out wellhead isolation tool. SITP: 48,170 kPa; SICP: 10,220 kPa. Opened well up and flowed back to P-tank through 7.9 mm bean choke. Made straight fluid, no sign of any gas, returns slightly foamy, average recovery rate was 40 m3/hr. Water salinity was 14,000 ppm, temperature was 124 deg C, no sign of any sand. After 8 hours of continuous flowing the tubing pressure was down to 28,870 kPa, total fluid recovered was 324 m3. See testers field notes for all details. Continued to flow well back on clean up.Proposed Activity 24hrs

Flow back and evaluate well on clean up. Move frac equipment down to barge landing and prepare to move across riverDaily Status





10,239,168Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,835.00



2,000.00







5,060.00




1,065.00


4,500.00


550.00


6,195.00


170.00



Job Type: Re-Entry

/3



Daily Report

Daily Costs



1,600.00

EQUIPMENT RENTALS 07 COMPLETION IES Wellhead isolation tool 7,206.00


0.00


PACKERS 07 COMPLETION Weatherford Tool hand came out to drop balls and verify frac ports shifting

8,656.00

TRUCKING 07 COMPLETION Aggressive Energy Hauled acid out and waited on location 3 days to assist with spearhead

26,550.00


07 COMPLETION HSE Integrated Shower unit on location for acid spearheads

11,400.00

OTHER COSTS 07 COMPLETION Peregrine Pressure Testing Catch up cost for pressure truck to hold annulus pressure during stimulation

20,790.00

Time Log


07:30 08:00 0.50 0.50 C JSA Started up. Held pre-job and safety meeting with all personnel on site. ETV with paramedic and shower unit on location.

08:00 12:00 4.00 4.50 C RU SITP: 44,300 kPa; SICP: 26,180 kPa.Staged out wellhead isolation tool. Placed 88.9 mm shifting ball onto gate valve. Installed wellhead isolation tool, opened well and allowed ball to drop, staged in isolation tool and seated cups. Rigged up pumping lines. Moved in and spotted replacement blender, had cat tow into position. Rigged up blender, purged suction line on transfer pumps. Fix technical problem with blender.

12:00 12:30 0.50 5.00 C PT Pressure tested surface equipment and lines to 83 MPa.

12:30 19:00 6.50 11.50 C FR Pumped water down well at 0.7 m3/min and seated ball in frac sleeve port @ 3372.5 mKB. Shifted sleeve at 75 MPa and opened port with some difficulty, started to feed into formation at low rate @ 65 MPa. Spearheaded 4 m3 of 15% HCL acid + additives and placed acid into formation, allowed acid to soak for 5 minutes. ISIP was 44.3 MPa. Started pumping pad and gradually increasing rate, formation very tight, maximum rate was 3.8 m3/min. Fracture treated the upper Exshaw intervals ( 3351 - 3356, 3365 - 3370 ) down 139.7 mm casing at an average pumping rate of 3.6 m3/min, average treating pressure was 72 MPa. Pumped 110 m3 for pad, 619 m3 was used for proppant, and 129 m3 on sweeps. Total fluid pumped was 871 m3 fresh water. Down hole sand concentration was between 30 kg/m3 to 70 kg/m3. Total sand pumped was 10 tonne 50/140 mesh and 17 tonne 40/70 mesh. Total sand into formation was 26 tonne. Sanded off with approximately 1 tonne inside pipe, flush volume was 9.5 m3. ISIP was 75 MPa, 5 min SIP was 55.8 MPa. Held 18 MPa annulus pressure during treatment, bled annulus pressure down to 5 MPa after treatment.

19:00 22:00 3.00 14.50 C RU Rigged off pumping lines. Staged out and rigged out wellhead isolation tool. Installed flanged wellhead cap. Moved IES service truck back to camp. Note: Cal-Frac to rig out pumping equipment in the morning. Rigged up equalizing lines to shipping tanks along with transfer pump previously dismantled to use for supply system during stimulation. Prepared to open and flow back well on clean up.

22:00 06:00 8.00 22.50 C FB SITP: 48,170 kPa; SICP: 10,220 kPa.Opened up and pressure tested flow back line with ball catcher using well pressure. Flowed back to P-tank through 7.9 mm bean choke. Making straight fluid, no sign of any gas, average fluid recovery rate was approximately 40 m3/hr. Returns were slightly foamy, temperature was 124 deg C, no sign of any sand. After 8 hours of continuous flowing the tubing pressure ( 139.7 mm ) was down to 28,870 kPa. Total fluid recovered was approximately 324 m3, water salinity was 14,000 ppm. See testers field notes for all details. Continued to flow well back on clean up.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow back well on clean up. Held pre-job and safety meeting. Rigged out Cal-frac pumping equipment. Moved mostly all of Cal-Frac equipment off location. Chained up equipment and had tow tractors assist equipment down access road back to camp. Continued to flow well back to P-tank up 139.7 mm casing. Observed first signs of burnable gas after 15 hours of flowing and approximately 20% load fluid recovered. Gradually increased choke size untill flowing wide open through gutline. Average fluid recovery rate gradually decreased to 15.5 m3/hr. After 32 hours of continuous flowing the tubing pressure gradually declined to 830 kPa. Well appeared to be slowly loading up. Estimated gas rate between 2,000 - 3,000 m3/d, no sign of any H2S, tested approximately 15% CO2. No sign of any more sand in returns. Total load fluid recovered was 1,031 m3 water, load fluid left to recover was approximately 2,837 m3. Final water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well back on clean up.Proposed Activity 24hrs

Continue to flow back well on clean up. Move remaining frac equipment off location. Dump excess sand and move sand cans off location. Attempt to get all frac equipment down to barge landing using chains and tow tractors.Daily Status





10,392,623Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,060.00



2,000.00







7,280.00




1,065.00


4,500.00


550.00


3,500.00


170.00



1,600.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


EQUIPMENT RENTALS 07 COMPLETION IES Wellhead isolation tool. Travel home & 2 standby days. Ticket #'s 30540 to 30542

14,665.00


440.00


Time Log


06:00 07:30 1.50 1.50 C FB Continued to flow well back to P-tank up 139.7 mm casing. Increased choke size from 7.9 mm to 9.5 mm. Observed changed bean choke was washed out, had good sand returns previously. Fluid recovery rate was approximately 44 m3/hr. Flowing pressure very gradually decreasing.

07:30 08:00 0.50 2.00 C JSA Held pre-job and safety meeting with all personnel on site ETV with medic on location. Discussed safe operating procedures for rigging out and moving equipment in muddy, slippery, conditions and potential hazards involved.

08:00 11:00 3.00 5.00 C RU Rigged out Cal-Frac pumping equipment, had vacuum truck suck out and drain lines and equipment. Prepared to move equipment off location during night time after road drys up some. Had equipment chained up and used tow tractors to assist equipment on access road, very muddy and slippery conditions.

11:00 06:00 19.00 24.00 C FB Continued to flow well back to P-tank up 139.7 mm casing. Observed first signs of gas after 15 hours of flowing and approximately 20% load fluid recoverd. Gradually increased choke size untill flowing wide open through gutline. Average fluid recovery rate gradually decreased to 15.5 m3/hr, no sign of any more sand. Flowing tubing pressure ( casing ) gradually declined to 830 kPa. Well appeared to be slowly loading up. Estimated gas rate between 2,000 to 3,000 m3/d, no sign of any H2S, tested approximately 15% CO2. After 32 hrs of continuous flowing recovered a total of 1,031 m3 load water, remaining load water left to recover was approximately 2,837 m3. Final water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Moved remaining frac equipment off location, emptied sand cans and prepared to move. Flowed back wide open through 50.8 mm gutline. Pressure and rates gradually declined. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 7.5 m3/hr, no sign of any sand. After 56 hours flowing tubing pressure ( 139.7 mm csg ) declined to 800 kPa, estimated gas rate around 2,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 39 deg C. Total load fluid recovered to date was 1,327 m3 water, load fluid left to recover was approximately 2,541 m3. Water salinity was 28,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well untill dead.Proposed Activity 24hrs

Continue to flow & evaluate well. Start to barge Cal-Frac equipment across river. Prepare to possibly run smaller tubing into wellbore.Daily Status





10,700,238Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,700.00



1,000.00







4,690.00




1,065.00


4,500.00


550.00


5,790.00


170.00



1,600.00


440.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


STIMULATION 07 COMPLETION Cal-Frac Well Service Fracture treated upper Muskwa intervals. ( Job finished, standby charges )

245,425.00


07 COMPLETION HSE Integrated Charges for Rover to monitor atmosphere and record data

20,285.00

Time Log


06:00 06:00 24.00 24.00 C FB Continued to flow well back to P-tank up 139.7 mm casing. Moved remaining frac equipment off location, emptied sand cans and prepared to move. Flowed back wide open through 50.8 mm gutline. Pressure and rates gradually declined. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 7.5 m3/hr, no sign of any sand. After 56 hours flowing tubing pressure ( 139.7 mm csg ) declined to 800 kPa, estimated gas rate around 2,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 39 deg C. Total load fluid recovered to date was 1,327 m3 water, load fluid left to recover was approximately 2,541 m3. Water salinity was 28,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well untill dead.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 6.5 m3/hr, no sign of any sand. After 80 hours flowing tubing pressure ( 139.7 mm csg ) appeared stable between 650 to 700 kPa, estimated gas rate between 2,000 to 3,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Total load fluid recovered to date was 1,488 m3 water, load fluid left to recover was approximately 2,380 m3. Water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.Proposed Activity 24hrs

Continue to flow and evaluate well. Attempt to get Cal-Frac pumping equipment down to barge landing. Road conditions very wet, muddy, and soft.Daily Status





10,853,558Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00


07 COMPLETION Robert James Medic Group ETV with 1 medic/safety trailer 1,000.00







5,800.00




1,065.00


4,500.00


550.00


7,470.00


170.00



1,600.00


440.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



95,225.00

EQUIPMENT RENTALS 07 COMPLETION McClelland Oilfield Rentals Final service & inspection charges on rental BOPS & Equipment

6,610.00

OTHER COSTS 07 COMPLETION Peregrine Pressure Testing Standby charges for being stuck another day and travel charges back to base

4,290.00

EQUIPMENT RENTALS 07 COMPLETION Dans Oilfield Rentals Rental charges for cross-over flanges & wrenches ( 5 day min/add days @ $250 )

2,600.00

Time Log


06:00 06:00 24.00 24.00 C FB Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Average fluid recovery rate decreased to 6.5 m3/hr, no sign of any sand. After 80 hours flowing tubing pressure ( 139.7 mm csg ) appeared stable between 650 to 700 kPa, estimated gas rate between 2,000 to 3,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Total load fluid recovered to date was 1,488 m3 water, load fluid left to recover was approximately 2,380 m3. Water salinity was 30,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Shut in well for 1 hour 3 times and monitored build up pressure. SITP increased to 9,700 kPa twice and 8,940 kPa on the third time. Pressure bled off immediately each time well was opened, very little gas head, all fluid pressure. Average fluid recovery rate decreased to 3.5 m3/hr, no sign of any sand. After 104 hours flowing tubing pressure ( 139.7 mm csg ) would flux between 570 to 650 kPa, estimated gas rate at 2,000 m3/d or less. Unable to get accurate gas rate because meter to big to measure small rates, smaller meter to arrive and install today. No sign of any H2S, tested 15% CO2, flow temperature at 30 deg C. Total load fluid recovered to date was 1,575 m3 water, load fluid left to recover was approximately 2,293 m3. Water salinity was 40,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.Proposed Activity 24hrs

Continue to flow and evaluate well. Move remaining frac equipment down to barge landing using tow tractors. Barge equipment across river.Daily Status





10,991,713Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00









3,950.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters 11 tickets # 220238, 220241, 220242, 220244, 220248 - 220252, 224252, 224255

1,500.00



1,065.00


4,500.00


550.00


6,755.00


170.00



1,600.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



440.00


96,125.00


0.00

Time Log


06:00 06:00 24.00 24.00 C FB Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Shut in well for 1 hour 3 times and monitored build up pressure. SITP increased to 9,700 kPa twice and 8,940 kPa on the third time. Pressure bled off immediately each time well was opened, very little gas head, all fluid pressure. Average fluid recovery rate decreased to 3.5 m3/hr, no sign of any sand. After 104 hours flowing tubing pressure ( 139.7 mm csg ) would flux between 570 to 650 kPa, estimated gas rate at 2,000 m3/d or less. Unable to get accurate gas rate because meter to big to measure small rates, smaller meter to arrive and install today. No sign of any H2S, tested 15% CO2, flow temperature at 30 deg C. Total load fluid recovered to date was 1,575 m3 water, load fluid left to recover was approximately 2,293 m3. Water salinity was 40,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

Note: Continued to tow frac equipment down to barge landing.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Average fluid recovery rate was 3.5 m3/hr, flowing tubing pressure ( 139.7 mm csg ) was 650 kPa. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Shut in well for 4 hours. Removed ball catcher from wellhead and retrieved 88.9 mm ball stuck inside catcher. Rigged up flowline back to wellhead, installed smaller meter before outlet to flare stack. SITP was 11,250 kPa. Flowed back to P-tank wide open through 50.8 mm gutline. Pressure bled off immediately, observed small gas head followed by straight fluid. Pressure decreased to 100 kPa, no sign of any more gas, average fluid recovery rate increased to 6.4 m3/hr last 4 hours. Shut in well and monitored pressure build up overnight. Flowed well for a total of 106 hours. Total load fluid recovered to date was 1,611 m3 water, load water left to recover was approximately 2,257 m3. Water salinity was 39,000 ppm, PH was 7. SIWP after 13 hrs was 13,800 kPa. See testers field notes for all details. Continued to monitor build up pressure.

Proposed Activity 24hrs

Monitor pressure build up. Rig out and release 36.5 m flare stack and rig up 12.2 m flare stack. Open well after 24 hr shut in and continue with flow test.Daily Status





11,458,983Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,600.00


07 COMPLETION Robert James Medic Group ETV with 1 medic/safety trailer ( ticket #'s 55, 56, 57 )

1,100.00







5,060.00




1,065.00


4,500.00


550.00


7,345.00


170.00



1,600.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



440.00

STIMULATION 07 COMPLETION Cal-Frac Well Service 1 day standby and demobilization charges

383,000.00


0.00

OTHER COSTS 07 COMPLETION HSE Integrated Rental and demobilization of wind tower 12,640.00

EQUIPMENT RENTALS 07 COMPLETION Big Al's Plumbing & Heating Catch up rental cost on diesel tanks/Genie/Loader. Ticket #'s 4743 & 4773 to 4776

27,800.00

Time Log


00:00 00:00 24.00 24.00 C FB Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Average fluid recovery rate was 3.5 m3/hr, flowing tubing pressure ( 139.7 mm csg ) was 650 kPa. No sign of any H2S, tested 15% CO2, flow temperature at 32 deg C. Shut in well for 4 hours. Removed ball catcher from wellhead and retrieved 88.9 mm ball stuck inside catcher. Rigged up flowline back to wellhead, installed smaller meter before outlet to flare stack. SITP was 11,250 kPa. Flowed back to P-tank wide open through 50.8 mm gutline. Pressure bled off immediately, observed small gas head followed by straight fluid. Pressure decreased to 100 kPa, no sign of any more gas, average fluid recovery rate increased to 6.4 m3/hr last 4 hours. Shut in well and monitored pressure build up overnight. Flowed well for a total of 106 hours. Total load fluid recovered to date was 1,611 m3 water, load water left to recover was approximately 2,257 m3. Water salinity was 39,000 ppm, PH was 7. SIWP after 13 hrs was 13,800 kPa. See testers field notes for all details. Continued to monitor build up pressure.

Note: Towed all frac equipment down to river and loaded onto barges. All equipment but 4 units across river. Transport remaining frac units across river in the morning.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to monitor build up pressure. After 26 hours SIWP was 15,470 kPa. Rigged out and released 36.5 m flare stack. Rigged up 12.2 m flare stack. Collected 2 gas samples. Opened well up and flowed back to P-tank through 50.8 mm gutline. Pressure bled down immediately to 800 kPa, observed very small gas head then started making straight fluid. Flowing pressure would flux between 300 to 600 kPa, average fluid recovery rate was approximately 6.4 m3/hr. No sign of any gas. Total fluid recovered last 11 hours was 69.9 m3. Total fluid recovered to date was 1,680.6 m3 water, load water left to recover was approximately 2,187.4 m3. Water salinity was 36,000 ppm, flow temperature was 18 deg C. See testers field notes for all details. Continued to flow well back on clean up.Proposed Activity 24hrs

Flow and evaluate well.Daily Status





11,563,833Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,080.00



TRUCKING 07 COMPLETION Bert Baxter Charges for bed-truck use ( ticket # 15238 & 15240 for Sept 22 - Oct 3 )

3,500.00






5,060.00




1,065.00


4,500.00


550.00


7,665.00


170.00



1,600.00


440.00


Job Type: Re-Entry

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Daily Report

Daily Costs



120.00

EQUIPMENT RENTALS 07 COMPLETION Earth Communications Catch up rental cost for communications 10,470.00

OTHER COSTS 07 COMPLETION Superior Propane Charges for propane used to operate evaporation tank and shipping dead fluid

22,000.00

TRUCKING 07 COMPLETION Bert Baxter Transport Catch up charges for hauling 6 tanks from Grande Prairie to Ft Liard & load on barge

27,530.00

Time Log


06:00 06:00 24.00 24.00 C FT Continued to monitor build up pressure. After 26 hours SIWP was 15,470 kPa. Rigged out and released 36.5 m flare stack. Rigged up 12.2 m flare stack. Collected 2 gas samples. Opened well up and flowed back to P-tank through 50.8 mm gutline. Pressure bled down immediately to 800 kPa, observed very small gas head then started making straight fluid. Flowing pressure would flux between 300 to 600 kPa, average fluid recovery rate was approximately 6.4 m3/hr. No sign of any gas. Total fluid recovered last 11 hours was 69.9 m3. Total fluid recovered to date was 1,680.6 m3 water, load water left to recover was approximately 2,187.4 m3. Water salinity was 36,000 ppm, flow temperature was 18 deg C. See testers field notes for all details. Continued to flow well back on clean up.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, average fluid recovery rate last 6 hours was 3.8 m3/hr, no sign of any sand. After 35 hours of continuous flowing, the tubing pressure ( 139.7 mm csg ) appeared stable around 410 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 18 deg C. Total load fluid recovered to date was 1,798 m3 water, load fluid left to recover was approximately 2,070 m3. Water salinity was 48,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.Proposed Activity 24hrs

Continue to flow and evaluate well.Daily Status





11,602,988Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,900.00









2,850.00




1,065.00


4,500.00


550.00


4,360.00


170.00



1,600.00


440.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



120.00

Time Log


06:00 06:00 24.00 24.00 C FT Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, average fluid recovery rate last 6 hours was 3.8 m3/hr, no sign of any sand. After 35 hours of continuous flowing, the tubing pressure ( 139.7 mm csg ) appeared stable around 410 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2, flow temperature at 18 deg C. Total load fluid recovered to date was 1,798 m3 water, load fluid left to recover was approximately 2,070 m3. Water salinity was 48,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

PerforationsDate




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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, very little gas again, average fluid recovery rate was 3.5 m3/hr, no sign of any sand. After 59 hours of continuous flowing, the tubing pressure ( 139.7 mm csg ) would flux between 100 to 300 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2. The well stopped making gas last 8 hours, used propane to ship fluid. Flow temperature at 18 deg C. Total load fluid recovered to date was 1,882.6 m3 water, load fluid left to recover was approximately 1,985.4 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.Proposed Activity 24hrs

Continue to flow and evaluate well. MIRU wireline unit and conduct spinner production log.Daily Status





11,671,803Objective


Job Contact

Rory NewtonPosition

Daily Costs




2,800.00









2,850.00




1,065.00


4,500.00


550.00


9,870.00


170.00


1,600.00


440.00


120.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs


TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for vacuum truck 9 days Sept 27 to Oct 5

24,600.00

Time Log


06:00 06:00 24.00 24.00 C FT Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well was still pushing fluid, very little gas again, average fluid recovery rate was 3.5 m3/hr, no sign of any sand. After 59 hours of continuous flowing, the tubing pressure ( 139.7 mm csg ) would flux between 100 to 300 kPa, estimated gas rate just below 1,000 m3/d. No sign of any H2S, tested 15% CO2. The well stopped making gas last 8 hours, used propane to ship fluid. Flow temperature at 18 deg C. Total load fluid recovered to date was 1,882.6 m3 water, load fluid left to recover was approximately 1,985.4 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Continued flowing well on clean up.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Presently no sign of any gas ( comes & goes ). Average fluid recovery rate decreased to 2.7 m3/hr, no sign of any sand. After 70.5 hours flowing tubing pressure was around 450 kPa. Last estimated gas rate was below 1,000 m3/d, no sign of any H2S, tested 15% CO2. Final flow temperature was at 20 deg C. Total load fluid recovered to date was 1,914 m3 water, load fluid left to recover was approximately 1,954 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Shut in well and rigged up electric wireline unit. Installed lubricator with grease injector head. Ran in with 70 mm gauge ring and tagged possible frac ball at 2350 m, chased ball down to bottom and tagged frac sleeve port @ 3811 m. Pulled out with gauge ring and rigged off lubricator. Continued to monitor build up pressures. SIWP after 11.5 hours was 10,100 kPa. Opened well up and flowed back to P-tank through 50.8 mm gutline. Pressure bled down rapidly and started making straight fluid, very little signs of gas. Recovered 7.7 m3 load water in first hour. Continued to flow well and prepared for spinner log.Proposed Activity 24hrs

Continue to flow well. Conduct spinner production log. Monitor build up pressures. Start injecting water and dispose into wellbore.Daily Status





11,743,188Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,300.00



TRUCKING 07 COMPLETION Bert Baxter Charges for bed-truck use Oct 4 to Oct 6 3,500.00






2,470.00




1,065.00


4,500.00


550.00


11,200.00


170.00


1,600.00


Job Type: Re-Entry

/2



Daily Report

Daily Costs



440.00


120.00

E-LINE SERVICES 07 COMPLETION Boreal Well Services Travel and rig up electric wireline unit c/w grease injector. RIH w/gauge ring

21,400.00

E-LINE SERVICES 07 COMPLETION First Choice Waterboy Picker unit to assist with wireline work 4,770.00

Time Log


06:00 17:30 11.50 11.50 C FT Continued to flow well back to P-tank up 139.7 mm casing. Flowed back wide open through 50.8 mm gutline. Well appears to be slowly dying off and loading up, but still pushing fluid. Presently no sign of any gas ( comes & goes ). Average fluid recovery rate decreased to 2.7 m3/hr, no sign of any sand. After 70.5 hours flowing tubing pressure was around 450 kPa. Last estimated gas rate was below 1,000 m3/d, no sign of any H2S, tested 15% CO2. Final flow temperature was at 20 deg C. Total load fluid recovered to date was 1,914 m3 water, load fluid left to recover was approximately 1,954 m3. Water salinity was 44,000 ppm, PH was 7. See testers field notes for all details. Shut in well and monitor build up pressures.

17:30 18:00 0.50 12.00 C JSA Orientated new personnel and issued safe work permit to Boreal Wireline. Held pre-job and safety meeting.

18:00 21:00 3.00 15.00 CT LO Moved in and rigged up Boreal electric wireline unit with picker. Note: Chained up equipment and had tow tractors assist equipment up long access road from barge landing. Installed and pressure tested lubricator with grease injector and BOPS. Ran in with 70 mm gauge ring, tagged possible frac ball at 2350 m and hung up occasionally on remaining way down. Pushed shifting ball down and tagged frac port sleeve @ 3811 m. Pulled out and recovered gauge ring. Rigged out lubricator and secured well.

21:00 06:00 9.00 24.00 CT FT Continued to monitor build up pressures. SIWP after 11.5 hours was 10,100 kPa. Opened up well and flowed back to P-tank through 50.8 mm gutline. Started making fluid immediately, pressure dropped off rapidly and was at 170 kPa after 1 hour. No sign of any gas. Recovered 7.7 m3 load water in first hour. Continued flowing well in preperation for spinner log.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to flow up 139.7 mm casing back to P-tank wide open through 50.8 mm gutline. Flowing straight fluid around 200 kPa, very little signs of gas, average fluid recovery rate last 3 hrs was 5 m3/hr. Held pre-job and safety meeting. Rigged up wireline lubricator with grease injector head. Continued flowing well and ran in with production-spinner log. Ran down through both frac sleeve ports to a total depth of 3850 mKB, no sign of missing shifting sleeve ball. Correlated on depth to Encore Radial Cement Bond Log dated Sept 4/2011. Conducted 3 up and 3 down passes at 30, 20, and 10 m/min from 3850 m to 3250 m. Started to see more gas at surface while logging, measured gas rate at 0.4 m3/d. Made 10 minute station stops at 3835, 3775, 3380, and 3340 mKB. Collected 2 gas samples prior to shutting in well. Total load water recovered was 1,953 m3. See testers report for details. Made 3 shut in passes at 30, 60, and 90 minute intervals at 20 m/min from 3850 m to 3250 m. Pulled out with logging tools. Rigged out grease injector and lubricator with BOPS. Rigged out wireline unit and moved equipment back to camp. Prepared to barge across river in the morning. Moved in and rigged up High rate pressure truck, held pre-job and safety meeting. Started to inject load water back into wellbore. Initial pumping rate was 0.5 m3/min @ 30 MPa. Final pumping rate was 0.5 m3/min @ 48 MPa. Stopped pumping to cool down unit and tighten leak on flange.Proposed Activity 24hrs

Continue to pump and dispose of load water down wellbore.Daily Status





11,848,928Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,300.00









3,210.00




1,065.00


4,500.00


550.00


7,990.00


170.00


1,600.00


Job Type: Re-Entry

/3



Daily Report

Daily Costs



120.00

E-LINE SERVICES 07 COMPLETION Boreal Well Services Travel and rig up electric wireline unit c/w grease injector. RIH w/gauge ring

29,400.00

E-LINE SERVICES 07 COMPLETION First Choice Waterboy Picker unit to assist with wireline work. Travel home next day

5,300.00

TRUCKING 07 COMPLETION Cooper Barging Service Catch up trucking cost for hauling matting up to use at barge landing

3,010.00

TRUCKING 07 COMPLETION Tru North Trucking Catch up cost for final water delivery to camp ( Sept 2 & 11 ). Now on well water

7,075.00

OTHER COSTS 07 COMPLETION Newalta Previous cost for tank truck cleaning 240.00

EQUIPMENT RENTALS 07 COMPLETION RyTy Developments Ltd Rental cost for fuel tank/25 days 3,750.00

OTHER COSTS 07 COMPLETION Big Al's Plumbing and heating Insulated and heat traced all water & sewer lines for camp. ( catch up cost )

9,060.00

OTHER COSTS 07 COMPLETION Baker Hughes Purchased weighted inhibitor to dump down well.

2,100.00

Time Log


06:00 09:00 3.00 3.00 C FT Continued to flow up 139.7 mm casing back to P-tank wide open through 50.8 mm gutline. Flowing straight fluid around 200 kPa, very little signs of gas, average fluid recovery rate last 3 hrs was 5 m3/hr.

09:00 09:30 0.50 3.50 C JSA Held pre-job and safety meeting with all personnel on site. MTC with medic on location. Bailey site # 84

09:30 20:00 10.50 14.00 C LO Rigged up wireline lubricator with grease injector head. Continued flowing well and ran in with production-spinner log. Ran down through both frac sleeve ports to a total depth of 3850 mKB, no sign of missing shifting sleeve ball. Correlated on depth to Encore Radial Cement Bond Log dated Sept 4/2011. Conducted 3 up and 3 down passes at 30, 20, and 10 m/min from 3850 m to 3250 m. Started to see more gas at surface while logging, measured gas rate at 0.4 m3/d. Made 10 minute station stops at 3835, 3775, 3380, and 3340 mKB. Collected 2 gas samples prior to shutting in well. Total load water recovered was 1,953 m3, see testers field notes for all details. Made 3 shut in passes at 30, 60, and 90 minute intervals at 20 m/min from 3850 m to 3250 m. Pulled out with logging tools. Rigged out grease injector and lubricator with BOPS. Rigged out wireline unit and moved equipment back to camp. Prepared to barge across river in the morning.

20:00 20:30 0.50 14.50 C JSA Orientated new personnel and issued safe work permit to Daler pressure truck. Held pre-job and safety meeting.

20:30 06:00 9.50 24.00 C CC Moved in and rigged up High rate pressure truck. Pressure tested surface equipment and lines to 35 MPa. Started to inject load water and dispose into wellbore. Initial pumping rate was 0.5 m3/min @ 30 MPa. After 9 hours pumping rate was 0.5 m3/min @ 48 MPa. Estimated 220 m3 load water injected. Stopped pumping to cool down unit and tighten leak on wellhead flange.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 48 MPa. Injection pressure remained stable last 20 hours. Total pumping time was 33 hours including cool down and maintenance breaks. Estimated total volume pumped was 620 m3. Continued to dispose load water down wellbore.Proposed Activity 24hrs






12,130,088Objective


Job Contact

Rory NewtonPosition

Daily Costs




3,300.00









7,280.00




1,065.00


4,500.00


550.00


11,445.00

EQUIPMENT RENTALS 07 COMPLETION Am-Gas Estimated cost for travel to rig out amonia scrubbers and release.

6,000.00


1,600.00


120.00

OTHER COSTS 07 COMPLETION Cooper Barging Service Ltd Catch up charges for barging frac equipment over and back across after job

222,000.00


Job Type: Re-Entry

/2



Daily Report

Time Log


06:00 06:00 24.00 24.00 C CC Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 48 MPa. Injection pressure remained stable last 20 hours. Total pumping time was 33 hours including cool down and maintenance breaks. Estimated total volume pumped was 620 m3. Continued to dispose load water down wellbore.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Pressure truck shut down due to diesel pollution control for exhaust, urea pod was empty. Wait on hot shot from Ft Nelson with more urea. Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 49 MPa. Injection pressure remained fairly stable. Total pumping time was 48 hours including cool down and maintenance breaks. Estimated total volume pumped was 900 m3. Continued to dispose load water down wellbore.Proposed Activity 24hrs






12,178,808Objective


Job Contact

Rory NewtonPosition

Daily Costs



07 COMPLETION Newcart Safety Services Ltd Released safety hands & equipment. Traveld back to base.

5,040.00









2,850.00




1,065.00


4,500.00


550.00


9,695.00


1,600.00


120.00

Time Log


06:00 15:00 9.00 9.00 CT WO Pressure truck shut down due to diesel pollution control for exhaust, urea pod was empty. Wait on hot shot from Ft Nelson with more urea. Filled reservoir level and computer responded, able to run pressure truck again.


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Daily Report

Time Log


15:00 06:00 15.00 24.00 C CC Continued to suck out of C-ring tank and pump load water down wellbore. Initial rate was 0.25 m3/min for first 3 hours. Had trouble trying to establish higher rate with pressure, wanting to stall out. Circulated back to storage tank and established higher rate then started pumping down well again. Average pumping rate was 0.4 m3/min @ 49 MPa. Injection pressure remained fairly stable. Total pumping time was 48 hours including cool down and maintenance breaks. Estimated total volume pumped was 900 m3. Continued to dispose load water down wellbore.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 49 MPa. Injection pressure remained stable last 33 hours. Total pumping time was 72 hours including cool down and maintenance breaks. Estimated total volume pumped was 1400 m3. Continued to dispose load water down wellbore.Proposed Activity 24hrs






12,224,123Objective


Job Contact

Rory NewtonPosition

Daily Costs










2,850.00




1,300.00


4,500.00


550.00


9,695.00


1,600.00


120.00

Time Log


06:00 06:00 24.00 24.00 C CC Continued to suck out of C-ring tank and pump load water down wellbore at an average pumping rate of 0.4 m3/min @ 49 MPa. Injection pressure remained stable last 33 hours. Total pumping time was 72 hours including cool down and maintenance breaks. Estimated total volume pumped was 1400 m3. Continued to dispose load water down wellbore.


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Daily Report

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to suck out of C-ring tank and pump load water down wellbore. Sucked out C-ring tank mostly dry for a total of 1,420 m3 disposed down wellbore. Rigged out pressure truck and moved over to suck out of tank farm. Started to pump from tank farm when pressure truck broke down due to clutch failure, could not continue. Rigged out pressure truck and lines. Towed pressure truck down to barge landing for morning. Secured well. Note: Backup pressure truck still not available, on waiting list with several contractors. Attempt to line up tank trucks to transfer remaining fluid, approximate load water left on location is 530 m3. SDFN.Proposed Activity 24hrs

Barge across river and move in crew and equipment to dismantle C-ring tank. Wait on availability for high rate 10K pressure truck. Attempt to find enough tank trucks to possibly transfer remaining fluid to disposal.Daily Status





12,367,853Objective


Job Contact

Rory NewtonPosition

Daily Costs










3,765.00




1,300.00


4,500.00


550.00


9,695.00


1,600.00


120.00

OTHER COSTS 07 COMPLETION Big Als Plumbing & heating Charges for disconnecting water/sewer lines & winterizing wet sleepers for move out

1,300.00

OTHER COSTS 07 COMPLETION Daler Pressure Services Travel/work for Pressure truck & support equipment. Pumped 1,420 m3 down wellbore

83,500.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost last 6 days for vacuum truck. Oct 6 to Oct 11

14,100.00


Job Type: Re-Entry

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Daily Report

Time Log


06:00 07:00 1.00 1.00 C CC Continued to suck out of C-ring tank and pump load water down wellbore. Final rate was 0.4 m3/min @ 49 MPa.

07:00 09:00 2.00 3.00 C RU Sucked out C-ring tank mostly dry for an estimated total of 1,420 m3 disposed down wellbore. Rigged out pressure truck and moved over and rigged up to suck out of tank farm.

09:00 16:00 7.00 10.00 CT WO Started to pump from tank farm when pressure truck broke down due to clutch failure, could not repair or continue. Rigged out pressure truck and lines. Towed pressure truck down to barge landing for morning. Secured well. Note: Backup pressure truck still not available, on waiting list with several contractors. Attempt to line up tank trucks to transfer remaining fluid to disposal, approximate load water left on location is 530 m3. SDFN.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Barged picker and tractor trailers across river to assist in tear down of C-ring tank. Access road very wet and muddy, very slippery at barge landing. Tow tractors had to assist all equipment up to camp, took all day to get equipment that far, road condition bad. Has been wet fog and light rain/snow last several days. Wait on availability of high rate 10K pressure truck, initial truck possibly has clutch repaired tomorrow.Proposed Activity 24hrs

Tow picker & trucks up to locaion and have crew dismantle C-ring Liner Tank and haul out. Wait on availability for high rate 10K pressure truck. Initial pressure truck possibly repaired tomorrow.Daily Status





12,414,823Objective


Job Contact

Rory NewtonPosition

Daily Costs










5,800.00




1,300.00


4,500.00


550.00


9,800.00


1,600.00


120.00

Time Log


07:30 17:30 10.00 10.00 C OT Barged picker and tractor trailers across river to assist in tear down of C-ring tank. Access road very wet and muddy, very slippery at barge landing. Tow tractors had to assist all equipment up to camp, took all day to get equipment that far, road condition bad. Has been wet fog and light rain/snow last several days. Wait on availability of high rate 10K pressure truck, initial truck possibly has clutch repaired for tomorrow.


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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Towed picker and trucks up to location from camp. Dismantled and loaded C-ring tank along with liner for disposal. Towed equipment back to camp. Access road very wet and muddy, used both tow tractors on each end of units to assist in and off location, very slippery conditions.Proposed Activity 24hrs

Tow trucks down to barge landing. MIRU electric wireline unit. RIH and set 10K Retrievable Bridge Plug above Exshaw intervals.Daily Status





12,551,143Objective


Job Contact

Rory NewtonPosition

Daily Costs










6,910.00




1,300.00

EQUIPMENT RENTALS 07 COMPLETION Poseidon Concepts Lined Atlantis water tank & daily rental cost of $4,500.00

4,500.00


550.00


7,715.00


1,600.00


120.00

TRUCKING 07 COMPLETION Tiggo Transport Estimated cost for tearing down & hauling out C-ring tank. Hauled liner to disposal

85,325.00

OTHER COSTS 07 COMPLETION Poseidon Concepts Estimated cost for supervision on tear down & removal of Atlantis C-ring tank

5,000.00

Time Log


07:30 11:30 4.00 4.00 C OT Towed picker and tractor trailers from camp to location site. Had tow tractors on both ends of each unit to assist up access road, very muddy and slippery conditions.

11:30 12:00 0.50 4.50 C JSA Held pre-job and safety meeting with all personnel on site. MTC with medic on standby. Orientated new personnel and issued safe work permit to Tiggo Transport Ltd.


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Daily Report

Time Log


12:00 19:30 7.50 12.00 C RU Dismantled and loaded Atlantis double lined C-ring tank. Cut up and loaded liner for disposal.

19:30 23:30 4.00 16.00 C OT Towed picker and tractor trailers back to camp Had tow tractors on both ends of each unit to assist down access road, very muddy and slippery conditions.

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Daily Report

Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Towed bedtruck trailers down to barge landing with heavy loads ( c-ring walls & liner debri ). Access road in poor condition at sections, tow tractor and bedtruck both stuck, wait on cat to assist equipment free. Had to repair chains on one tow tractor. Loaded trucks onto barge, Tiggo picker still at camp waiting for tow. Towed wireline unit and picker from barge landing up to camp. Wireline unit broke down, tore fan belt off, have no power to computer end. Replace fan belt and check fuses in morning and attempt to fix electrical problem. Note: Access road from camp to location site starting to dry and improve.

Note: Ordered 2 commanders with 24 hr crews for Monday Oct 17 to start demobilization of camp. Will also use another commander previously here for Apache. Proposed Activity 24hrs

Attempt to fix electrical problem with wireline unit and move up to location to set bridge plug. Haul rental equipment off location.Daily Status





12,656,042Objective


Job Contact

Rory NewtonPosition

Daily Costs










5,615.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter service. Catch up tickets Oct 1 to Oct 14

1,500.00



1,300.00


550.00


9,770.00


1,600.00


120.00

TRUCKING 07 COMPLETION Coopers Barging Services Ltd catch up cost for barging equipment. Ticket # 10153 - 10156, 09466, 09467

61,144.00


Job Type: Re-Entry

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Daily Report

Time Log


07:30 21:30 14.00 14.00 C OT Towed bedtruck trailers down to barge landing with heavy loads ( c-ring walls & liner debri ). Access road in poor condition at sections, tow tractor and bedtruck both stuck, wait on cat to assist equipment free. Had to repair chains on one tow tractor. Loaded trucks onto barge, Tiggo picker still at camp waiting for tow. Towed wireline unit and picker from barge landing up to camp. Wireline unit broke down, tore fan belt off, have no power to computer end. Replace fan belt and check fuses in morning and attempt to fix electrical problem. Note: Access road from camp to location site starting to dry and improve.

Note: Ordered 2 commanders with 24 hr crews for Monday Oct 17 to start demobilization of camp. Will also use another commander previously here for Apache.

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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Worked on wireline truck. Replaced fan belt and repaired electrical problem. Moved Boreal electric wireline unit from camp to lcation site. Access road was frozen early morning, equipment moved in chained up with no problems. Held pre-job and safety meeting. Rigged up wireline unit with picker. Installed lubricator with grease injector head, pressure tested lubricator. SIWP: 26,000 kPa. Ran in with 94 mm gauge ring to just above the Exshaw intervals. Ran in with Tryton 10K WR plug, correlated to Boreal Production-Spinner Log dated October 7/2011. Set Retrievable Bridge Plug inside the 114.3 mm Liner 12 m above the Exshaw intervals @ 3339 mKB. Pulled out and recovered setting tools. Rigged out and released wireline unit. Bled well pressure off back to P-tank, pressure bled off quickly and recovered minimum fluid, well was dead, plug was holding. Ran hose down tubing and had vacuum truck suck down fluid level. Pour 160 liters of weighted corrosion inhibitor down tubing for approximately 0.5% inhibited volume. Shut in and secured well. Rigged out remaining test equipment. Rigged out all remaining rental equipment. Prepared to move equipment in the morning. SDFN.Proposed Activity 24hrs

Move wireline equipment down to barge landing. Move all equipment off location, clean up location. Release all equipment and prepare to demobilize the camp.Daily Status





12,750,792Objective


Job Contact

Rory NewtonPosition

Daily Costs










3,030.00




1,300.00


550.00


11,150.00


1,600.00


120.00

E-LINE SERVICES 07 COMPLETION Boreal Well Services Ran gauge ring/set WR plug. Charged 3 days Oct 14, 15, & 16. ( stuck & towing )

40,000.00

E-LINE SERVICES 07 COMPLETION First Choice Waterboy Picker assisted wireline unit. Charged 3 days Oct 14, 15, & 16. ( stuck & towing )

11,900.00


Job Type: Re-Entry

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07:30 10:00 2.50 2.50 CT WO SIWP: 26,000 kPa.Started up, waited on repairs to wireline truck. Replaced fan belt and repaired electrical problem. Moved Boreal electric wireline unit from camp to lcation site. Access road was frozen early morning, equipment moved in chained up with no problems.

10:00 10:30 0.50 3.00 C JSA Held pre-job and safety meeting. MTC with medic on standby. Orientated new personnel and issued safe work permit to Boreal wireline.

10:30 17:30 7.00 10.00 C LO Rigged up wireline unit with picker. Installed lubricator with grease injector head, pressure tested lubricator. Ran in with 94 mm gauge ring to 3350 m with no problems. Ran in with Tryton 10K WR plug, correlated to Boreal Production-Spinner Log dated October 7/2011. Set Retrievable Bridge Plug inside the 114.3 mm Liner 12 m above the Exshaw intervals @ 3339 mKB. Pulled out and recovered setting tools. Rigged out lubricator with grease injector head. Rigged out wireline unit and moved equipment back to camp. Prepared to move equipment down to barge landing on the morning frost.

17:30 20:00 2.50 12.50 C RU Bled well pressure off back to P-tank, pressure bled off quickly and recovered minimum fluid, well was dead, plug was holding. Ran suction hose down tubing and had vacuum truck suck down fluid level. Pour 160 liters of weighted corrosion inhibitor down tubing for approximately 0.5% inhibited volume. Shut in and secured well. Started hauling equipment off location. Rigged out remaining test equipment. Rigged out all remaining rental equipment. Prepared to move all remaining equipment off location tomorrow. SDFN.

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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Had tow tractors assist wireline equipment and testers down to barge landing. Loaded barges and transported equipment across river and released. Hauled evaporation tank and wellsite shack down to barge landing. Hauled all remaining equipment including P-tank off location and down to camp site. Left 12 rental tanks with approximately 530 m3 load water on location. Cleaned up location site and secured well.

Note: Sent 4 gas samples to AGAT in Ft St John for routine analysis.Proposed Activity 24hrs

Dismantle and prepare to move camp site. Pull pumps from water wells. Start hauling camp and equipment down to barge landing using 3 commanders running 24 hours a day. Move all personnel over to base camp on other side of river.Daily Status





12,815,517Objective


Job Contact

Rory NewtonPosition

Daily Costs










3,210.00




1,300.00

EQUIPMENT RENTALS 07 COMPLETION Auburn Rentals Rental on wet sleepers. Charges for cleaning and maintenance

5,000.00


11,260.00


1,600.00


120.00

TRUCKING 07 COMPLETION Birch Oilfield Services Catch up cost for vacuum truck last 5 days Oct 12 to Oct 16

14,935.00

Time Log


07:30 07:45 0.25 0.25 C JSA Started up, held pre-job and safety meeting. MTC with medic on standby. Discussed safe operating procedures for moving and towing equipment and possible hazards involved.


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Time Log


07:45 19:30 11.75 12.00 C MO Had tow tractors assist wireline equipment and testers down to barge landing. Loaded barges and transported equipment across river and released. Hauled evaporation tank and wellsite shack down to barge landing. Hauled all remaining equipment including P-tank off location and down to camp site. Left 12 rental tanks with approximately 530 m3 load water on location. Cleaned up location site and secured well. Note: Sent 4 gas samples to AGAT in Ft St John for routine analysis.

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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Barged 2 commander units across river. Started to dismantle camp. Emptied water tanks and sucked out sewer tank. Tore down water lines and sewer lines. Pulled all pumps from water wells. Released camp staff and moved all other necessary personnel over to base camp on other side of river. Started hauling camp and equipment down to barge landing. Total of 3 commander units hauling 24 hr/d.Proposed Activity 24hrs

Continue to load and haul out camp shacks and rental equipment down to barge landing. Start barging equipment across river.Daily Status





12,966,392Objective


Job Contact

Rory NewtonPosition

Daily Costs








CAMP AND CATERING 07 COMPLETION Acho Camps and Catering Estimated daily camp charges and demob charges

25,000.00


6,805.00

MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter service ( catch up tickets for Oct 15 to Oct 17 )

13,000.00



1,300.00


13,900.00


1,600.00


120.00

TRUCKING 07 COMPLETION D & D Well Service Estimated cost for 2 commander units. 24 hr rate approx $19,000 per unit

45,000.00

TRUCKING 07 COMPLETION Coopers Barging Estimated Daily charges for barging out camp and all equipment across river

20,000.00

Time Log


07:00 07:00 24.00 24.00 C MO Barged 2 commander units across river. Started to dismantle camp. Emptied water tanks and sucked out sewer tank. Tore down water lines and sewer lines. Pulled all pumps from water wells. Released camp staff and moved all other necessary personnel over to base camp on other side of river. Started hauling camp and equipment down to barge landing. Total of 3 commander units hauling 24 hr/d.


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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continue to load and haul camp and equipment down to barge landing using commanders to travel access road. Had 1 betruck working camp site and another bedtruck loading barges. Encountered rain again, access road soft and muddy, tow tractors had to assist commanders through bad section. Had cats continue to work section of road. The smaller commander unit broke down, could not repair drive shaft, continued hauling with remaining commanders. Approximately 60% of camp and equipment hauled down to barge landing with approximately 40% across river.Proposed Activity 24hrs

Continue to load and haul out camp shacks and rental equipment down to barge landing and transport across river.Daily Status





13,102,432Objective


Job Contact

Rory NewtonPosition

Daily Costs




TRUCKING 07 COMPLETION Bert Baxter Charges for bedtrucks/tractor trailers/pilot truck to assist in camp demob

20,110.00




5,870.00




1,300.00


12,160.00


40,000.00


35,000.00

EQUIPMENT RENTALS 07 COMPLETION Earth Communications Communication charges. Rig out wellsite & camp site. #109761/005550/005582

7,200.00

TRUCKING 07 COMPLETION Birch Oilfield Services Estimated charges for vacuum truck to suck sewer/water lines & haul to disposal

8,200.00

Time Log


07:00 07:00 24.00 24.00 C MO Continue to load and haul camp and equipment down to barge landing using commanders to travel access road. Had 1 betruck working camp site and another bedtruck loading barges. Encountered rain again, access road soft and muddy, tow tractors had to assist commanders through bad section. Had cats continue to work section of road. The smaller commander unit broke down, could not repair drive shaft, continued hauling with remaining commanders. Approximately 60% of camp and equipment hauled down to barge landing with approximately 40% across river.


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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to load and haul camp and equipment down to barge landing using commanders. Had cat and grader smooth out location site and access road down to camp site. Remaining cats worked bad section on access road to barge landing to help keep equipment moving. Road getting better. Continued barging equipment and shacks across river. Had bedtrucks haul camp shacks to Acho camps yard near Ft Liard. Hauled and set up camps wellsite unit at main base camp in Ft Liard. Hauled P-tank and pipe skid to Ft St John. Hauled 10K rental pipe and manifold to Grande Prairie. Approximately 90% of camp and equipment hauled down to barge landing with approximately 70% across river. Continued with camp clean up and road repair.Proposed Activity 24hrs

Continue to haul out remainng light loads and clean up camp site. Barge all remaining equipment across river. Have cats and grader smooth out and repair access road.Daily Status





13,194,807Objective


Job Contact

Rory NewtonPosition

Daily Costs





20,110.00




5,870.00




1,300.00


6,845.00


30,000.00


20,000.00

LABOUR 07 COMPLETION Earth Communications Travel pick up equip from camp tear down. Install dish in wellsite at main base camp

1,050.00

Time Log


07:00 07:00 24.00 24.00 C MO Continued to load and haul camp and equipment down to barge landing using commanders. Had cat and grader smooth out location site and access road down to camp site. Remaining cats worked bad section on access road to barge landing to help keep equipment moving. Road getting better. Continued barging equipment and shacks across river. Had bedtrucks haul camp shacks to Acho camps yard near Ft Liard. Hauled and set up camps wellsite unit at main base camp in Ft Liard. Hauled P-tank and pipe skid to Ft St John. Hauled 10K rental pipe and manifold to Grande Prairie. Approximately 90% of camp and equipment hauled down to barge landing with approximately 70% across river. Continued with camp clean up and road repair.


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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Continued to haul final loads down to barge landing. Cleaned up camp site. Loaded barges and transported all remaining camp and equipment across river. Transported bedtrucks and commanders across river. Hauled and returned all camp shacks back to Acho yard near Ft Liard. Load and release commanders in the morning. Note: Left construction equipment on other side of river to clean up access road.Proposed Activity 24hrs

Have cats and grader, clean up, repair, and smooth out access road.Daily Status





13,412,687Objective


Job Contact

Rory NewtonPosition

Daily Costs





16,610.00



TRUCKING 07 COMPLETION Radar Road Transport Tow cat services. Released and hauled back to base in Ft Nelson

11,570.00




1,300.00


6,680.00


30,000.00


25,000.00

TRUCKING 07 COMPLETION RyTy Developments Master ticket for commander use (4d) with mob & demob. Tank rental & trucking.

120,020.00

Time Log


07:00 19:00 12.00 12.00 C MO Continued to haul final loads down to barge landing. Cleaned up camp site. Loaded barges and transported all remaining camp and equipment across river. Transported bedtrucks and commanders across river. Hauled and returned all camp shacks back to Acho yard near Ft Liard. Load and release commanders in the morning. Note: Left construction equipment on other side of river to clean up access road.

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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Had cats and grader work access road and smooth all ruts out. Moved all construction equipment down to barge landing and prepared to transport across river in the morning. Started loading and hauling out all rental equipment.Proposed Activity 24hrs

Barge construction equipment across river. Continue to haul out and return remaining rental equipment.Daily Status





13,478,902Objective


Job Contact

Rory NewtonPosition

Daily Costs





8,500.00



MISCELLANEOUS EQUIPMENT 07 COMPLETION Great Slave Helicopters Estimated charges for helicopter service. Oct 18 to Oct 21

800.00



1,300.00


5,615.00


2,300.00

TRUCKING 07 COMPLETION D & D Well Services Final charges/commander units w/mob & demob. Master ticket for Oct 15 to Oct 21

44,000.00

Time Log


08:00 19:00 11.00 11.00 C MO Had cats and grader work access road and smooth all ruts out. Moved all construction equipment down to barge landing and prepared to transport across river in the morning. Started loading and hauling out all rental equipment.

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Well HeaderAPI/UWI

N1207Field Name


737.0Gr Elev (mKB)

723.0KB-Grd (m)

14.00TD (mKB)










-4,272,582.00

Daily Operations


Operations Summary

Cleaned up barge landing site and restored to original condition. Loaded all construction equipment and barged across river. Loaded and returned all rental equipment back to origins in Edmonton, Red Deer, Grande Prairie, Ft St John, and Ft Nelson. Access road left in fair condition with no bad ruts. Well secured. Left 12 rental tanks with approximately 530 m3 water equally balanced between all tanks on location to freeze over winter. Job completed.

Note: Beaver Enterprises will tear up and load liner material into Kris Muller's end dumps and haul to Secure in Grande Prairie for disposal.Proposed Activity 24hrs

Job completed. Well secured.Daily Status





13,630,582Objective


Job Contact

Rory NewtonPosition

Daily Costs


TRUCKING 07 COMPLETION Bert Baxter Master ticket for trucking all equip back to origins. Edm/RD/GP/Ft St John/Ft Nelson

61,145.00





2,650.00

TRUCKING 07 COMPLETION Coopers Barging Final tickets for barging camp & equipment. Oct 16 to Oct 22

8,400.00

TRUCKING 07 COMPLETION Bert Baxter Transport Ltd Master ticket for trucking all equip back to origins. Edm/RD/GP/Ft St John/Ft Nelson

63,955.00

TRUCKING 07 COMPLETION Bert Baxter Transport Ltd Haul fuel tanks to Edmonton/supervision cost

8,630.00

Time Log


08:00 16:00 8.00 8.00 C MO Cleaned up barge landing site and restored to original condition. Loaded all construction equipment and barged across river. Loaded and returned all rental equipment back to origins in Edmonton, Red Deer, Grande Prairie, Ft St John, and Ft Nelson. Access road left in fair condition with no bad ruts. Well secured. Left 12 rental tanks with approximately 530 m3 water equally balanced between all tanks on location to freeze over winter. Job completed.

Note: Beaver Enterprises will tear up and load liner material into Kris Muller's end dumps and haul to Secure in Grande Prairie for disposal.

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- 52 -

11 APPENDIX H – CEMENT BOND LOG AND INTERPRETATION


305, 815-1st Street SW, Phone (403)265-LOGS(5647)

Calgary AB T2P 1N3 Toll Free: 1-877-304-PERF (7373) Fax (403)265-5698

Type of log: Cement Bond Log

Location: L-68-60-20-123-45

Company: Lone Pine Resources

Prepared for: Mr. Dana Roney

______________________________________________________________________________

___

Objective:

- To confirm cement in wellbore for perforating of intended zones to indicate isolation of

these zones with cement and determine the cement integrity throughout the logged

intervals.

Well Configuration:

- Surface Casing 508.0mm x 139.89kg/m from Surface to 165.0mKB

- Surface Casing 339.73mm x 107.15kg/m from Surface to 1424.0mKB

- Production Casing 244.48 x 64.7kg/m From Surface to 3297.0m

- Liner 177.8mm x 38.69kg/m from 3237.8 to 4130.0m

Procedure:

- On September 4th, 2011 Encore performed a Radial Cement Bond log on this well from

3990m to 3850 on the Lower Muskwa @ 0 MPA. We also performed a Radial Cement

Bond Log on the Upper Muskwa @ 0 MPA from 3875m to 3400m and also on the

Exshaw formation from 3400-3225m and then ran a pressure pass on the Exshae

Intermediate section from 3560-to Liner Hanger located at 3237.8m. We then performed

a CBL log in the 9 5/8” Casing from the liner hanger to 2000m.

Summary and Conclusions:

Starting with the lower Muskwa we see great cement bond from both the formation and

the cement to pipe. The Amplitude map which is a representation of the 360 degree view of the

cement shows very good cement with the dark shading and the grey shading. There is no concern

with this portion of the well and the isolation you will see with the perforation intervals at 3948-

305, 815-1st Street SW, Phone (403)265-LOGS(5647)

Calgary AB T2P 1N3 Toll Free: 1-877-304-PERF (7373) Fax (403)265-5698

3953 and 3935-3940m actually shows both intervals being isolated from each other from the

cement in this portion of the well. With this portion of the log there is no concern with cement

integrity from this portion of the well.

The upper Muskwa portion of the well from a CBL standpoint also shows good cement

bond through out this portion of the log from 3875m to 3400m and good isolation for the

perforated intervals located at 3805-3810 & 3784-3789m. This good cement bond continues up

hole to the Exshaw formation perforations located at 3365-3370 & 3351-3356m. There is great

cement showing all through this portion of the well into the 80% Bond index all through the

zones logged until we get to the Liner Hanger and inside the 9 5/8” Casing.

Once inside the 9 5/8” casing the tool is no longer centralized like it was in the 7” casing.

We are unable to run the larger centralizers on the tool for it would not allow us into the 7”

casing then. So once out of the Liner we are running on the low side of the casing and you can

see the effect of the tool spinning on the Amplitude map where the map shows it moving up hole

and spinning as it does. The 9 5/8” casing was cemented with 1545 Kg/m3 cement (light weight).

The VDL does not completely ring free through here and based on the amplitude readings from

the 3‘ and 5‘ reciever it is reading cement. It does not show free pipe through here but is showing

a light weight cement and you can also tell this by the location of the collars, the collars do not

show a chevron effect which is common with no cement bond. The collars do show up but very

lightly indicating a lighter weight cement but having bond there.

Prepared By:

Steve Langan

Sales Manager

Encore Dataline

Prairie Provident

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Transcript of Prairie Provident