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206-025
Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 907383247 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-21 0 12 2M-19 50-103-20158-00 907335394 Kuparuk River Multi Finger Caliper Field & Processed 19-Aug-21 0 13 2M-19 50-103-20158-00 907335394 Kuparuk River Plug Setting Record Field- Final 20-Aug-21 0 14 2M-27 50-103-20175-00 907335397 Kuparuk River Plug Setting Record Field- Final 18-Aug-21 0 15 2M-33 50-103-2024-00 907316545 Kuparuk River Packer Setting Record Field- Final 8-Aug-21 0 16 2N-333 50-103-20525-00 907331967 Kuparuk River Radial Bond Record Field- Final 17-Aug-21 0 17 2N-333 50-103-20525-00 907383501 Kuparuk River String Shot Record Field- Final 13-Sep-21 0 18 2T-207 50-103-20287-00 907326322 Kuparuk River Packer Setting Record Field- Final 15-Aug-21 0 19 2V-04 50-029-21041-00 907398078 Kuparuk River Correlation Record Field- Final 20-Sep-21 0 110 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 1-Sep-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϮϬϲϬϮϱϬ Ͳ^Ğƚ͗ϯϱϳϬϱBy Abby Bell at 10:25 am, Sep 23, 2021 Originated: Delivered to:22-Sep-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 907383247 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-21 0 12 2M-19 50-103-20158-00 907335394 Kuparuk River Multi Finger Caliper Field & Processed 19-Aug-21 0 13 2M-19 50-103-20158-00 907335394 Kuparuk River Plug Setting Record Field- Final 20-Aug-21 0 14 2M-27 50-103-20175-00 907335397 Kuparuk River Plug Setting Record Field- Final 18-Aug-21 0 15 2M-33 50-103-2024-00 907316545 Kuparuk River Packer Setting Record Field- Final 8-Aug-21 0 16 2N-333 50-103-20525-00 907331967 Kuparuk River Radial Bond Record Field- Final 17-Aug-21 0 17 2N-333 50-103-20525-00 907383501 Kuparuk River String Shot Record Field- Final 13-Sep-21 0 18 2T-207 50-103-20287-00 907326322 Kuparuk River Packer Setting Record Field- Final 15-Aug-21 0 19 2V-04 50-029-21041-00 907398078 Kuparuk River Correlation Record Field- Final 20-Sep-21 0 110 2V-11 50-029-21311-00 907365411 Kuparuk River Leak Detect Log Field- Final 1-Sep-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:09/23/2021Wd͗ϮϬϲϬϮϱϬ Ͳ^Ğƚ͗ϯϱϳϬϰBy Abby Bell at 10:25 am, Sep 23, 2021 Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϮϬϲϬϮϱϬ Ͳ^Ğƚ͗ϯϱϰϴϰBy Abby Bell at 2:10 pm, Aug 03, 2021 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2060250 E-Set: 34733 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2H-11 50-029-20052-00 906834022 Kuparuk River Leak Detect Log with ACX Processed 2-Dec-20 0 1 2 2H-11 50-029-20052-00 906834022 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-20 0 1 3 2N-333 50-103-20525-00 906859420 Tarn Participating Area Plug Setting Record Field- Final 11-Dec-20 0 1 4 2N-333 50-103-20525-00 906869831 Tarn Participating Area Leak Detect Log Field- Final 17-Dec-20 0 1 5 2W-13 50-029-21252-00 906808475 Kuparuk River Leak Detect Log Field- Final 13-Nov-20 0 1 6 2W-13 50-029-21252-00 906808475 Kuparuk River Packer Setting Record Field- Final 14-Nov-20 0 1 7 2W-13 50-029-21252-00 906813971 Kuparuk River Multi Finger Caliper Field & Processed 11-Nov-20 0 1 8 2Z-08 50-029-20924-00 906803595 Kuparuk River Plug Setting Record Field- Final 8-Nov-20 0 1 9 3H-01 50-103-20084-00 906826894 Kuparuk River String Shot Record Field- Final 19-Nov-20 0 1 10 3H-26 50-103-20208-00 906832308 Kuparuk River Leak Detect Log Field- Final 24-Nov-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 2060250 E-Set: 34550 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2H-11 50-029-20052-00 906834022 Kuparuk River Leak Detect Log with ACX Processed 2-Dec-20 0 1 2 2H-11 50-029-20052-00 906834022 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-20 0 1 3 2N-333 50-103-20525-00 906859420 Tarn Participating Area Plug Setting Record Field- Final 11-Dec-20 0 1 4 2N-333 50-103-20525-00 906869831 Tarn Participating Area Leak Detect Log Field- Final 17-Dec-20 0 1 5 2W-13 50-029-21252-00 906808475 Kuparuk River Leak Detect Log Field- Final 13-Nov-20 0 1 6 2W-13 50-029-21252-00 906808475 Kuparuk River Packer Setting Record Field- Final 14-Nov-20 0 1 7 2W-13 50-029-21252-00 906813971 Kuparuk River Multi Finger Caliper Field & Processed 11-Nov-20 0 1 8 2Z-08 50-029-20924-00 906803595 Kuparuk River Plug Setting Record Field- Final 8-Nov-20 0 1 9 3H-01 50-103-20084-00 906826894 Kuparuk River String Shot Record Field- Final 19-Nov-20 0 1 10 3H-26 50-103-20208-00 906832308 Kuparuk River Leak Detect Log Field- Final 24-Nov-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 2060250 E-Set: 34549 STATE OF ALASKA AliKA OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown r Performed: Suspend E Perforate E Other Stimulate E Alter Casing r Change Approved Program 1- Plug Plug for Redrill r Perforate New Pool r Repair Well F Re-enter Susp Well r Other: Stactk,Packer 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r206-025 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20525-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 375074 KRU 2N-333 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 10921 feet Plugs(measured) 10305 true vertical 5265 feet Junk(measured) None Effective Depth measured 10760 feet Packer(measured) 10081 true vertical 5143 feet (true vertical) 4744 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 112 112 SURFACE 3417 9 5/8 3452 2391 PRODUCTION 10876 7 10908 5255 RECEIVED scow JAN 2 6 !Z JUL_ 22 2016 Perforation depth: Measured depth: 10759-10774 True Vertical Depth: 5140-5151 AOGCC Tubing(size,grade,MD,and ND) 4.5, L-80, 10249 MD,4822 TVD Packers&SSSV(type,MD,and ND) PACKER -BAKER S-3 PRODUCTION PACKER @ 10081 MD and 4744 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in • 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service F', Stratigraphic r' Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR IT WINJ IT WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-278 Contact Danny Kane @.265-6048 Email Danny.Kaneaconocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date A/ 2k-3vL-? � vi"L d r`A Form 10-404 Revised 5/2015 / /2- / 1( RBDMS VV JUL 2 2 2016 Submit Original Only r1,,, 1 • • ,it,',,,,,,, Operations Summary (with Timelog Depths) (,,,,,,::7:::,.:,,,,,,L,140,.',,,zz'ijoi,„4, ,,,,,.4 2N-333 Corso illips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code` Time P-T-X Operation MKS) End Depth MKS) 6/19/2016 6/19/2016 5.00 MIRU MOVE RURD P Pull electrical lines between 0.0 0.0 03:00 08:00 interconnects. Break all mud,water, steam,and air lines at all interconnects. Pre sub for skidding as pre skid checklist. RD beaver slide and lay down the skate to the pipe shed. Peak trucks arrived at 07:00 hours. 6/19/2016 6/19/2016 1.50 MIRU MOVE MOB P Set power,pump,pipe shed,and pits 0.0 0.0 08:00 09:30 on suspension and stage for transport. 6/19/2016 6/19/2016 0.50 MIRU MOVE MOB P Remove rock washer complex. 0.0 0.0 09:30 10:00 6/19/2016 6/19/2016 2.50 MIRU MOVE MOB P Move the power,pump,and pit 0.0 0.0 10:00 12:30 modules from 1L pad to CPF-2. SimOps: Install tow tongue onto the sub,skid the floor,and raise the stomper feet. 6/19/2016 6/19/2016 3.00 MIRU MOVE MOB P Pull the pipe shed away from the sub. 0.0 0.0 12:30 15:30 Stage the pipe shed and sub for transport. 6/19/2016 6/19/2016 0.50 MIRU MOVE MOB P Move the sub from 1L to 1F pad. 0.0 0.0 15:30 16:00 6/19/2016 6/19/2016 3.50 MIRU MOVE WAIT P Wait for authorization to move the sub 0.0 0.0 16:00 19:30 from 1F pad to CPF-2 6/19/2016 6/19/2016 1.00 MIRU MOVE MOB P Move the sub from 1F pad to the spine 0.0 0.0 19:30 20:30 road. 6/19/2016 6/20/2016 3.50 MIRU MOVE WAIT P Just before the rig mats over the pipe 0.0 0.0 20:30 00:00 line crossing near the spine road the drillers and off drillers side tires sunk into the road. Jacked up the tires and place 3"x 12"boards and plywood under the tires. 6/20/2016 6/20/2016 2.50 MIRU MOVE WAIT P Continue to place 3"x 12"boards and 0.0 0.0 00:00 02:30 plywood under the tires. 6/20/2016 6/20/2016 2.50 MIRU MOVE MOB P Pull the sub out and move onto the, 0.0 0.0 02:30 05:00 spine road and to CPF-2. 6/20/2016 6/20/2016 6.75 MIRU MOVE WAIT P PU mats on the road behind the rig, 0.0 0.0 05:00 11:45 shuffle them in front of the rig,and lay out the mats from CPF-2 to 2N pad. 6/20/2016 6/20/2016 1.25 MIRU MOVE MOB P Move the sub,pits,power,pump,and 0.0 0.0 11:45 13:00 pipe shed from CPF-2 to 2M pad. 6/20/2016 6/20/2016 1.00 MIRU MOVE MOB P Stage the sub on 2B. Move the pits, 0.0 0.0 13:00 14:00 power,pump,and pipe shed from 2M to 2B pad. Identified additional soft spot in the spine road while moving the four modules. 6/20/2016 6/21/2016 10.00 MIRU MOVE WAIT P Layout plywood and additional mats 0.0 0.0 14:00 00:00 from 2B pad to 2N pad. 6/21/2016 6/22/2016 24.00 MIRU MOVE WAIT P Continue to layout plywood and 0.0 0.0 00:00 00:00 additional mats from 2B pad to 2M pad,laying out rig mats and plywood on the road and culvert crossings while picking up plywood on the 1L access road and transporting to 2M pad. Page 1/7 Report Printed: 7/12/2016 Operations Summary (with Timelog Depths) 2N-333 ConocoP'hit!ips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (8KB) End Depth(ft(B) 6/22/2016 6/22/2016 2.50 MIRU MOVE WAIT P Continue to layout plywood and 0.0 0.0 00:00 02:30 additional mats from 2B pad to 2M pad,laying out rig mats and plywood on the road and culvert crossings while picking up plywood on the 1 L, access road and transporting to 2M pad. 6/22/2016 6/22/2016 1.50 MIRU MOVE MOB P Move Sub base from 2B pad to 2M 0.0 02:30 04:00 Pad and stage up with existing equipment. 6/22/2016 6/22/2016 8.00 MIRU MOVE MOB P Stage plywood and additional mats 04:00 12:00 from 2M pad to 2L pad,in preparation for laying out rig mats and plywood on the road and culvert crossings while picking up plywood on the 2B Pad and transporting to areas between 2M pad and 2L Pad. Sim-ops:working on PM's while waiting for plywood to be staged. Change out Hyd/Lube filters on Top drive and draw works. Paint around sub base and remove shipping tape from outside modules with the use of the man lift. General housekeeping around rig,inspect sub moving system,cylinder bolts and hydraulic lines. 6/22/2016 6/23/2016 12.00 MIRU MOVE WAIT P Layout plywood and additional mats 12:00 00:00 from 2M pad to 2L pad,laying out rig mats and plywood on the road and culvert crossings while picking up plywood on the 2B Pad and transporting to areas between 2M pad and 2N Pad. 6/23/2016 6/23/2016 10.00 MIRU MOVE WAIT P Continue Laying mats Plywood and 00:00 10:00 rolling road from 2M Pad to 2N pad, P/U and shuffle plywood around rig, Prep well and lay mats for rig on 2N pad. 6/23/2016 6/23/2016 2.50 MIRU MOVE MOB P PJSM,Move pit,Motor room,Pump 10:00 12:30 and Pipe shed modules from 2M pad to 2N pad. 6/23/2016 6/23/2016 1.00 MIRU MOVE MOB P Release peak trucks from modules, 12:30 13:30 stage rig mats for spotting sub lay erculite around cellar, 6/23/2016 6/23/2016 4.50 MIRU MOVE MOB P Continue prep road f/2M to 2N Lay 13:30 18:00 plywood and rig mats,Simops Move shop and rock washer f/1L to 2M Pad. 6/23/2016 6/24/2016 6.00 MIRU MOVE MOB P Continue Laying plywood and rig mats 18:00 00:00 in soft spots found from power modules.Shuffle and transport plywood from behind rig and lay on road. Page 2/7 Report Printed: 7/12/2016 p ��a • • Operations Summary (with Timelog Depths) ni 2N-333 ConocoPhitiips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our`{hr) Phase Op Code Activity Code Time P-T-X Operation {ftKE) End Depth MKS)f 6/24/2016 6/24/2016 4.50 MIRU MOVE WAIT P Continue to lay matting boards and 00:00 04:30 plywood for sub base were needed. PU and shuffle all materials from 2B Pad to 2M ahead of Sub Base to 2N Pad. Sim Ops-Move shop and rock washer to 2L Pad. Offload and release trucks. 6/24/2016 6/24/2016 4.00 MIRU MOVE MOB P Move Sub base from 2M Pad 1.75 04:30 08:30 miles and road base failed. Set down sub and shore up under tires with plywood on both sides of the road. 6/24/2016 6/24/2016 2.00 MIRU MOVE WAIT P Lay out additional plywood from 1.75 08:30 10:30 miles to the 2 mile turn out. 6/24/2016 6/24/2016 0.50 MIRU MOVE MOB P Move sub to mile and pull off to the 10:30 11:00 side for equipment transport to pass. 6/24/2016 6/24/2016 12.50 MIRU MOVE WAIT P Continue to lay matting boards and 11:00 23:30 plywood for sub base were needed towards 2N Pad,while PU and shuffle all materials from 2M ahead to 2S access. 6/24/2016 6/25/2016 0.50 MIRU MOVE MOB P Move sub to 2S Pad Access and pull 23:30 00:00 off to the side for equipment transport to pass. 6/25/2016 6/25/2016 12.00 MIRU MOVE WAIT P Continue to lay matting boards and 00:00 12:00 plywood for sub base were needed towards 2N Pad,while PU and shuffle all materials from 2S ahead to 2L Pad access. 6/25/2016 6/26/2016 12.00 MIRU MOVE WAIT P Continue to lay matting boards and 12:00 00:00 plywood for sub base were needed towards 2N Pad,while PU and shuffle all materials from 2S ahead to 2L Pad access. Ordered out 300 6"Mats from arctic mats after gaining approval, Utilized peak and CH2MHill for support in loading and trucking mats from Dead Horse to 2L Pad. Sim- Ops:Move shop and rock washer from 2L Pad to 2N Pad @ 12:00 hrs to 13:00 hrs. 6/26/2016 6/26/2016 16.50 MIRU MOVE WAIT P Continue laying plywood and Matting 00:00 16:30 boards,receive remaining mats from dead horse.Lay on the road,Have roads and pads take crown out of road to keep mats from breaking. Relay mats after crown removal. 6/26/2016 6/26/2016 2.00 MIRU MOVE MOB P Move sub from 2S intersection to 2L 16:30 18:30 Access. 6/26/2016 6/27/2016 5.50 MIRU MOVE WAIT P Begin picking up and moving road 18:30 00:00 coverage from 2S access and spotting it on road between 2L Access and 2N Pad. 6/27/2016 6/27/2016 12.00 MIRU MOVE WAIT P Continue to pick up and move road 00:00 12:00 coverage from 2S access and spotting it on road between 2L Access and 2N Pad.Simops grade crown off road for rig mats. Page 3/7 Report Printed: 7/12/2016 • • ,„,..(::,,,,,,,,, ,,,,,:;:,•,,,,:::,-...„,t,, Operations Summary (with Timelog Depths) r,:;, y V 2N-333 Con acoPhitiips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKD), 6/27/2016 6/28/2016 12.00 MIRU MOVE WAIT P Continue pulling mats and plywood 12:00 00:00 from the 2S to 2L side of rig,Start laying mats on the 2N road 6/28/2016 6/28/2016 12.00 MIRU MOVE WAIT P Continue Laying plywood and rolling 00:00 12:00 road, Lay rig mats on road way over soft spots between 2L and 2N (simops welding prodjects on pits interconnects) 6/28/2016 6/28/2016 4.00 MIRU MOVE WAIT P Finish Laying Plywood and rolling road 12:00 16:00 from 2L to 2N 6/28/2016 6/28/2016 1.75 MIRU MOVE MOB P Move Sub from 2L to 2N 16:00 17:45 6/28/2016 6/28/2016 0.75 MIRU MOVE MOB P Spot Sub over well 17:45 18:30 6/28/2016 6/28/2016 1.00 MIRU MOVE MOB P Lower stompers on sub,remove king 18:30 19:30 pin hitch on sub 6/28/2016 6/28/2016 0.75 MIRU MOVE MOB P Skid rig floor into drilling position. 19:30 20:15 6/28/2016 6/28/2016 2.75 MIRU MOVE MOB P Spot modules in palce,pits pump 20:15 23:00 room power pack and pipe shed,spot rock washer. 6/28/2016 6/29/2016 1.00 MIRU MOVE RURD P Hook up interconnects between all 23:00 00:00 modules 6/29/2016 6/29/2016 4.00 MIRU MOVE RURD P Hook up interconnects,spot cuttings 0.0 0.0 00:00 04:00 tanks,handy berm around cellar and cuttings tank,raise skate rail to rig floor install drive cables,function test, Install beaver slide Rig accepted @ 0400 hrs 6/29/2016 6/29/2016 2.00 MIRU WELCTL RURD P Spot flow back tank,R/U hardline and 0.0 0.0 04:00 06:00 choke skid,Onload 580 bbls of 10ppg brine 6/29/2016 6/29/2016 2.00 MIRU WELCTL MPSP P P/U lubricator and M/U to tree test 0.0 0.0 06:00 08:00 lubricator to 250/1000 psi Pull 4"H plug BPV as per FMC R/D Lubricator. 6/29/2016 6/29/2016 1.50 MIRU WELCTL RURD P Move flow back tank and hard line for 0.0 0.0 08:00 09:30 well kill. 6/29/2016 6/29/2016 0.50 MIRU WELCTL SEQP P Flood lines with water pressure test 0.0 0.0 09:30 10:00 surface equipment to 250/2500 psi check for leaks all test good. 6/29/2016 6/29/2016 1.00 MIRU WELCTL OTHR P Bleed 700 psi off tubing shut in swap 0.0 0.0 10:00 11:00 over to annulus bleed off 700 psi line up to circulate well. 6/29/2016 6/29/2016 1.00 MIRU WELCTL KLWL P Stage pumps to 3 bpm pumping down 0.0 0.0 11:00 12:00 tubing taking returns up IA to tiger tank ' 6/29/2016 6/29/2016 1.50 MIRU WELCTL KLWL P Continue Circulating 10 ppg KWF 0.0 0.0 12:00 13:30 down tubing taking returns up IA to tiger tank at 3 bpm 120 psi Total stks pumped 3874 6/29/2016 6/29/2016 0.75 MIRU WELCTL RURD P R/U to take returns to pits 0.0 0.0 13:30 14:15 6/29/2016 6/29/2016 1.00 MIRU WELCTL KLWL P Circ10 ppg KWF 3 bpm 150 psi 0.0 0.0 14:15 15:15 monitor for losses none observed 6/29/2016 6/29/2016 0.50 MIRU WELCTL OWFF P Observe well for flow Open to 0.0 0.0 15:15 15:45 atmosphere well static 6/29/2016 6/29/2016 1.00 MIRU WELCTL RURD P Blow down and R/D Hardlines 0.0 0.0 15:45 16:45 Page 4/7 Report Printed: 7/12/2016 0 • ' ry" � ���_ Operations Summary (with Timelog Depths) '. 2N-333 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 6/29/2016 6/29/2016 0.75 MIRU WHDBOP MPSP P Set BPV and test in direction of flow to 0.0 0.0 16:45 17:30 1000 psi f/10 min good test 6/29/2016 6/29/2016 3.00 MIRU WHDBOP NUND P Nipple down tree and adaptor flange 0.0 0.0 17:30 20:30 instal blanking plug 9 turns 6/29/2016 6/30/2016 3.50 MIRU WHDBOP NUND P Nipple up BOP Stack and adaptor 0.0 0.0 20:30 00:00 flange,Dutch riser and flow nipple. 6/30/2016 6/30/2016 2.00 MIRU WHDBOP NUND P Continue to Nipple up BOPE,Hook up 00:00 02:00 choke and Kill lines Torque to spec. 6/30/2016 6/30/2016 1.50 MIRU WHDBOP RURD P R/U to Test BOPE Fill lines with 02:00 03:30 water,purge air. 6/30/2016 6/30/2016 6.50 MIRU WHDBOP BOPE P Test BOPE w/4.5"Test jt to 250 low 03:30 10:00 3000 high 5 min tests Test all Choke valves 1-14,Manual choke and Kill; HCR CHoke and Kill,TIW and Dart, Auto and Man IBOP,Upper Lower and Blind Rams Preform koomey draw down test and test gas alarms Test annular to 250 low 2500 high,State Inspector Lou Grimaldi Waived Witness of test. 6/30/2016 6/30/2016 1.00 MIRU WHDBOP RURD P R/D test Eqiuipment Blow Down Lines 10:00 11:00 6/30/2016 6/30/2016 1.00 MIRU WHDBOP MPSP P Pull TWC M/U landing Jt to hanger 11:00 12:00 and top drive BOLDS 6/30/2016 6/30/2016 0.50 COMPZN RPCOMP PULL P Pull Tubing hanger off seat Pipe 10,229.0 10,199.0 12:00 12:30 vbroke over @ 152K Pull to rig floor. 6/30/2016 6/30/2016 1.25 COMPZN RPCOMP CIRC P Circulate bottoms up 3 bpm 65 psi 10,199.0 10,199.0 12:30 13:45 1944 stks pumped 6/30/2016 7/1/2016 10.25 COMPZN RPCOMP PULL P POOH L/D 4.5"L-80 Tubing 10,199.0 2,268.0 13:45 00:00 completion,f/10199't/2268'63k PUW Strap and Tally all pipe before it leaves shed.Holle took Correct fill. 7/1/2016 7/1/2016 3.50 COMPZN RPCOMP PULL P Continue POOH w/4.5"completion 2,268.0 0.0 00:00 03:30 tubing L/D in shed f/2268'to surface 7/1/2016 7/1/2016 0.50 COMPZN RPCOMP RURD P R/D Tubing equipment 0.0 0.0 03:30 04:00 7/1/2016 7/1/2016 0.50 COMPZN WELLPR BOPE P R/U to test BOP w/4"Test jt 0.0 0.0 04:00 04:30 7/1/2016 7/1/2016 1.50 COMPZN WELLPR BOPE P Test Upper Lower and Annular w/4" 0.0 0.0 04:30 06:00 test Jt 250/3000psi 2500 high test on anular 7/1/2016 7/1/2016 0.50 COMPZN WELLPR BOPE P R/D and B/D test equipment Instal 0.0 0.0 06:00 06:30 wear ring. 7/1/2016 7/1/2016 0.25 COMPZN WELLPR BHAH P M/U Test Packer BHA RIH 0.0 22.0 06:30 06:45 7/1/2016 7/1/2016 0.75 COMPZN WELLPR PULD P RIH w/test packer on 4"DP f/shed f/ 22.0 514.0 06:45 07:30 22'to 514' 7/1/2016 7/1/2016 0.50 COMPZN WELLPR PRTS P Test Casing IA to 2500 psi f/10 min 514.0 514.0 07:30 08:00 Good Test 7/1/2016 7/1/2016 6.00 COMPZN WELLPR PULD P Continue RIH w/test packer on 4"DP 514.0 5,041.0 08:00 14:00 singling out of shed f/514'to 5041' 7/1/2016 7/1/2016 0.75 COMPZN WELLPR PRTS P Test Casing IA to 2500 psi f/10 min 5,041.0 5,041.0 14:00 14:45 Goog Test 7/1/2016 7/1/2016 2.25 COMPZN WELLPR PULD P Continue RIH w/test packer on 4"DP 5,041.0 6,997.0 14:45 17:00 f/5041'to 6997' 7/1/2016 7/1/2016 1.00 COMPZN WELLPR SFTY P Safety Stand Up Meeting with Rig 6,997.0 6,997.0 17:00 18:00 Team Page 5/7 Report Printed: 7/12/2016 0 • Operations Summary (with Timelog Depths) vi-- 1"I: ''.' 2N-333 EV ,3 J ConocoPh itli Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time e End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth(ftKE) 7/1/2016 7/1/2016 3.75 COMPZN WELLPR PULD P Continue RIH w/Test packer on 4"DP 6,997.0 10,155.0 18:00 21:45 f/6997't/10155' 7/1/2016 7/1/2016 0.75 COMPZN WELLPR PRTS P Test Casing IA t/2500 psi f/10 min 10,155.0 10,155.0 21:45 22:30 Good test 7/1/2016 7/2/2016 1.50 COMPZN WELLPR CIRC P Circulate bottoms up @ 3 bpm 230 psi 10,155.0 10,155.0 22:30 00:00 B/D top Drive Monitor well Static Simops Load Shed w/4.5"Tubing , 7/2/2016 7/2/2016 10.50 COMPZN ''WELLPR PULD P Pooh L/D 4"DP f/10155'to surface 10,155.0 0.0 00:00 10:30 L/D Baker test Packer 7/2/2016 7/2/2016 1.00 COMPZN WELLPR SFTY P Safety Stand Down with Rig Team 0.0 0.0 10:30 11:30 discussion on resent incidents. 7/2/2016 7/2/2016 2.00 COMPZN WELLPR OTHR P Load Shed with remaining tubing drift 0.0 0.0 11:30 13:30 strap and tally remaining 4.5"Tubing 7/2/2016 7/2/2016 0.50 COMPZN RPCOMP RURD P R/U and Pull Wear ring and R/D 0.0 0.0 13:30 14:00 7/2/2016 7/2/2016 0.25 COMPZN RPCOMP OTHR P P/U DB Nipple run in mouse hole, 0.0 0.0 14:00 14:15 install ball and rod fill with water check for leaks no leaks remove ball and rod L/D DB nipple. 7/2/2016 7/2/2016 0.50 COMPZN RPCOMP RURD P R/U GBR Power tongs and tubing 0.0 0.0 14:15 14:45 running equipment 7/2/2016 7/3/2016 9.25 COMPZN RPCOMP PUTB P RIH w/4.5"Completion as per Detail t/ 0.0 5,397.0 14:45 00:00 5397'Monitor well on trip tank,PUW- 83k SOW-73k 7/3/2016 7/3/2016 7.00 COMPZN RPCOMP PUTB P Continue RIH w/4.5'Completion String 5,397.0 10,140.0 00:00 07:00 f/5397'to 10140' 7/3/2016 7/3/2016 2.50 COMPZN RPCOMP PUTB T Found tubing to have torque rings 10,140.0 9,940.0 07:00 09:30 installed POOH I/D tubing w/torque rings f/10140'to 9940'7 jts 7/3/2016 7/3/2016 0.75 COMPZN RPCOMP PUTB T Rih w 4.5"Completion f/9940'to 9,940.0 10,218.0 09:30 10:15 10218' 7/3/2016 7/3/2016 0.75 COMPZN RPCOMP HOSO P RIH w/completion string w/pumps 10,218.0 10,240.0 10:15 11:00 cycleing @ 1 bpm 40 psi locate PBR confirm seals engage,Shut pumps off locate nogo @ 10257'Pull out to top of PRB 7/3/2016 7/3/2016 1.00 COMPZN RPCOMP CIRC P Pump 10 bbls 10ppg CI brine folowed 10,240.0 10,240.0 11:00 12:00 by 152 bbls 10ppg brine @ 3 bpm 200 psi 7/3/2016 7/3/2016 1.00 COMPZN RPCOMP PACK P Drop ball and rod wait 45 min allow to 10,240.0 10,240.0 12:00 13:00 land on seat. 7/3/2016 7/3/2016 1.00 COMPZN RPCOMP PACK P Space out of packer setting depth 10,240.0 10,255.0 13:00 14:00 ensure ball is on seat bring pumps up to speed psi up to 4500psi hold f/15 min set packer and bleed off psi to 2000 psi Shear out of PBR confirm nogo tag 10255' 7/3/2016 7/3/2016 1.50 COMPZN RPCOMP HOSO P L/D 3jts make up space out pups p/u 10,255.0 10,190.0 14:00 15:30 jt 341 M/U hanger and landing jt,M/U Circ equipment. 7/3/2016 7/3/2016 1.00 COMPZN RPCOMP CRIH P Pump 160 bbls of 10 ppg CI brine 10,190.0 10,190.0 15:30 16:30 chase with 152 bbls 10 ppg brine to spot 7/3/2016 7/3/2016 0.50 COMPZN RPCOMP RURD P Drain stack blow down hole fill 10,190.0 10,190.0 16:30 17:00 7/3/2016 7/3/2016 0.25 COMPZN RPCOMP THGR P Land tubing on hanger RILDS 10,190.0 10,247.0 17:00 17:15 Page 6/7 Report Printed: 7/12/2016 • Operations Summary (with Timelog Depths) 2N-333 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 7/3/2016 7/3/2016 1.75 COMPZN RPCOMP PRTS P Pressure test tubing to 3000 psi f/15 10,247.0 10,247.0 17:15 19:00 min bleed tubing to 2000 psi shut in pressure up on IA to 2500 psi f/30' min Bleed tubing off and shear SOV Sheared @ 2600 psi Pump down IA ©2 bpm shut down and pump down tubing at 2 bpm good returns both ways. 7/3/2016 7/3/2016 0.75 COMPZN RPCOMP OWFF P Observe well for flow f/30 min,well 0.0 0.0 19:00 19:45 static,Simops R/D hardlines in cellar and blow down 7/3/2016 7/3/2016 0.75 COMPZN WHDBOP MPSP P Set BPV as per FMC test in direction 0.0 0.0 19:45 20:30 of flow t/1000 psi f/10 min 7/3/2016 7/3/2016 1.75 COMPZN WHDBOP NUND P N/D Stack and riser,choke and kill 0.0 0.0 20:30 22:15 lines DSA and Adaptor spool. 7/3/2016 7/4/2016 1.75 COMPZN WHDBOP NUND P N/U Prodution tree as per FMC Prep 0.0 0.0 22:15 00:00 hanger and N/U bonnet 7/4/2016 7/4/2016 1.50 COMPZN WHDBOP NUND P Continue Nippling up tree and adaptor 0.0 0.0 00:00 01:30 flange,Turn Swab valve as per DSO. 7/4/2016 7/4/2016 1.00 COMPZN WHDBOP PRTS P Pressure test Void to 250/5000 psi as 0.0 0.0 01:30 02:30 per FMC,Test tree to 250/5000 psi w/ diesel 7/4/2016 7/4/2016 0.75 COMPZN WHDBOP MPSP P Pull TWC Simops R/U to freeze 0.0 0.0 02:30 03:15 protect well 7/4/2016 7/4/2016 1.50 COMPZN WHDBOP FRZP P Freeze protect well w/80 bbls diesel 0.0 0.0 03:15 04:45 pumping down IA Taking returns out Tubing,PT Lines t/2500 7/4/2016 7/4/2016 1.75 COMPZN WHDBOP FRZP P Allow well to U-Tube unit)static • 0.0 0.0 04:45 06:30 Simops R/D Interconnects clean pits. R/D Lines 7/4/2016 7/4/2016 0.50 COMPZN WHDBOP MPSP P Set BPV as per FMC Tubing 0 psi IA 0 0.0 0.0 06:30 07:00 psi OA 300 psi 7/4/2016 7/4/2016 1.00 DEMOB MOVE RURD P Secure wellhead clean cellar 0.0 0.0 07:00 08:00 7/4/2016 7/4/2016 1.00 DEMOB MOVE RURD P Finish Cleaning pits Rig released @ 0.0 0.0 08:00 09:00 0900 hrs R/D skate LID beaver slide Page 7/7 Report Printed: 7/12/2016 KUP D 2N-333 ConocoPhillips i €f 'z Well Attribut Max Angle D TD Alaska inc.. ••• Wellbore API/UWI Field Name Wellbore Status nol CI MD(ftKB) Act Btm(ftKB) G•xeocO5tillips'i 501032052500 TARN PARTICIPATING AREA PROD 72.88 7,566.77 10,921.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-333,7/13/20162:5152 PM SSSV:NIPPLE 45 11/23/2015 Last WO: 41.21 3/18/2006 . Vertical schematc.(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,747.0 4/19/2015 Rev Reason:WORKOVER lehallf 7/13/2016 HANGER;31.7 �)�'(( Casing Strings �tii ••4t _a. Casmg Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.250 34.6 112.0 112.0 62.50 H-40 WELDED Casing Description OD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 34.6 3,451.7 2,390.7 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread )1 f� PRODUCTION 7"x4.5"@ 7 6.276 37.9 0,905 3 5,254.7 26.00 L-80 BTC-MOD & fJ 10254' a I3o o Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...Wt(Ibl/t) Grade Top Connection 4-1/2"Completion 4 1/2 3.958 31.7 10,248.6 4,822.2 12.60 L-80 IBTM RWO 2016 J%. CONDUCTOR;34.6-112.0+-4 s .�s\Completion Details • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 31.7 31.7 0.00 HANGER Tubing Hanger,FMC,TC-1A-EMS,11"x 4-1/2"IBT top x 3.958 bottom,4"H BPVG 10,053.3 4,732.2 66.03 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 3.958 5.85') 10,054.5 4,732.7 65.99 SEAL ASSY Seal Assembly,190-47(total seal assembly length= 3.880 SURFACE;34.6-3,451 7� 16.72') 10,059.9 4,734.9 65.80 PBR Baker 190-47 PBR 4.750 10,081.1 4,743.7 65.05 PACKER Baker 4 1/2"x 7"Baker S-3 Production Packer(85-47 x 3.875 38) .11 10,212.6 4,804.1 60.34 NIPPLE Camco 3.75 DB Nipple SN:4341-3 3.750 GAS LIFT;3,756.5 10,230.6 4,813.1 59.79 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 3.870 m. 3') al 10,231.6 4,813.6 59.75 SEAL ASSY Seal Assembly,190-47 3.870 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;6,630.2 Top(ftKB) (ftKB) Cl Des Com Run Date ID(in) 10,206.6 4,801.1 60.53 Ball&Rod Ball&Rod 7/3/2016 0.000 I il 10,212.6 4,804.1 60.35 RHC Plug RHC Plug Body 7/3/2016 1.000 Body 10,302.0 4,850.2 57.68 CATCHER 3.71 CATCHER(OAL-37") 5/30/2016 0.000 GAS LIFT;8,967.4 10,305.0 4,851.8 57.61 i PLUG 3.65"SPECIAL CLEARANCE RBP @ 10305'RKB 3/23/2016 0.000 ili :t Perforations&Slots Shot Den lop(ND) etm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn GAS LIFT;10,002.1 = 10.759.0 10,774.0 5,140.3 5,151.4 S-3,2N-333 4/6/2006 6.0 IPERF 2 7/8"HSD,2906 PJ HMX,60 deg phase Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) LOCATOR;10,053.3 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,759.0 10,774.0 5,140.3 5,151.4 FRAC 5/21/2006 placed 253098 lbs of 16/20 prop in the formation w/ SEAL ASSY;10,054.5 - 128 ppa @ the perfs PBR;10,059.9 Mandrel Inserts St XO Threads;10,079.1 all PACKER;70,081.1 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn XO Threads;10,085.1 1 3,756.5 2,497.6 Camco KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 7/3/2016 a 2 6,830.2 3,593.5 Camco KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 7/3/2016 3 8,967.4 4,347.1 Camco KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 7/3/2016 4 10,002.2 4,712.1 Camco KBG-2 1 GAS LIFT SOV BEK 0.000 0.0 7/3/2016 SOV Ball&Rad;10,206.6 kill Sehdea RHC Plug Body;10,212.6.. (I'w . Notes:General&Safety NIPPLE;70,212.6 ( End Date Annotation 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;10 230.6 Mit liri SEAL ASS)/10,231.6 gat INK• CATCHER;10,302.0 lili, PLUG;10,305.0 �rt IPERF;10,759.0.10,774.0 FRAC;10,759.0 I Casing 3,10,234.0-10,908.0 PRODUCTION Tot 5 10254',31.9-10,908.3 • 2_0(o2,b RECEIVED -�t2--� 2. JUN 0 2�1� WELL LOG TRANSMITTAL#903264531 AOGOC To: Alaska Oil and Gas Conservation Comm. May 26, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 K BENDER RE: Leak Detect Log: 2N-333 Run Date: 4/22/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-333 Digital Data in LAS format,Digital Log Image file 1 CD Rom 50-103-20525-00 Leak Detect Log (Field Print) 1 color log 50-103-20525-00 ow JAN 0 6 2317, sc PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' Lcc„.0 -,� / _� ,� v OF 7Alaska Oil and Gas • *,� �y ;��A THE STATE �,,s�� OfA LAsKA. Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �� Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Travis Smith Wells Engineer , ` CANt* ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-333 Permit to Drill Number: 206-025 Sundry Number: 316-278 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /1°41444,—. Cath P. Foerster Chair DATED this 2- ay of May, 2016. RBDMS LL MAY 1 5 2016 RECEIVED • STATE OF ALASKA • MAY 16 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION Ra -51Zg/!46 APPLICATION FOR SUNDRY APPROVALS AOGC(' 20 AAC 25.280 1.Type of Request: Abandon — Plug Perforations I Fracture Stimulate� Repair Well lv - Operations Shutdown (- Suspend _. Perforate I Other Stimulate I...... Pull Tubing �_ Change Approved Program F Plug for Redrill ',— Perforate New Pool 1— Re-enter Susp Well --- Alter Casing 1- Other: Stack Packer 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. s Exploratory Development (v - 206-025 ` 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ( Service 50-103-20525-00 • 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2N-333 Will planned perforations require a spacing exception? Yes No 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL375074 ' Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,921' • 5,265' 10760 5143 < ;r/i <. n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 112' 112' Surface 3,417' 9 5/8 3,452' 2,391' Intermediate Production 10,876' 7" 10,908' 5,255' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10759-10774 5140-5151 4.500" L-80 10,247' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary I] Wellbore schematic Ei 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic ...... Development (v Service 1 14.Estimated Date for 5/30/2016 15.Well Status after proposed work: Commencing Operations: OIL f�.... . WINJ r WDSPL n Suspended r 16.Verbal Approval: Date: GAS WAG E GSTOR I SPLUG [— Commission Representative: GINJ E Op Shutdown i....... Abandoned I- 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Travis Smith @ 265-6450 Email Travis.T.Smith@conocophillips.com Printed Name ..vis ith Title Wells Engineer fA9 57/ Signature Phone 265-6450 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O 6\�— 2-1 Plug Integrity ❑ BOP Test Ly Mechanical Integrity Test ❑ Location Clearance ❑ Other: BaP /- 71-. /6 3 Ul'v p 5, 117j1vr✓OGi ,�p rtr�7rvlJt��7 r7 � v �SO� ��5� Post Initial Injection MIT Req'd? Yes E No Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: it — 40 T RBDMS LL MAY 2 5 2016 APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: 5-2_4.r Fi�•� Form 10-403 R iseed 1 /2015 113 vd li •o i is valid for 12 m th from the date of approval Attachments in Duplicate • lk: ECEIVED ';A..AY 16 Zit k ConocoPhillips Alaska , OCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 12,2016 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips hereby applies for an Application for Sundry Approval to workover the Tarn Producer 2N- 333 (PTD#206-025). Well 2N-333 is a Tarn producer well. While shut-in for unrelated issues in January 2016, a high IA pressure was observed in well 2N-333. Subsequent diagnostics showed multiple leaks in the well: a leak detect log on March 23, 2016 observed a leak in the sliding sleeve at 10,166' and a TMD-3D waterflow (pulse neutron)log found a leak in the 7"casing at 10,165'. The scope or the rig workover is to pull the existing 4-1/4" tubing and run a new 4-1/4" tubing string to surface with a stacked-packer above the 7"casing leak. If you have any questions or require any further information,please contact me at 265-6450 or Travis.T.Smith@conocophillips.com. Sincerely, e /1.j----/* 0 r // Travis Smith Wells Engineer ConocoPhillips Drilling&Wells • • 2N-333 Rig Workover Run Stacked-Packer and ReplaceTubing (PTD# 206-025) Current Status: The well is currently shut in with a leak in the 4-'/2"tubing and 7"casing. Scope of Work: Pull the existing 4-'/2"tubing,run a 5-1/2"stacked packer assembly,and run new 4-'/2"tubing. General Well info: MPSP: 2108 psig(using 0.1 psi/ft gas gradient from reservoir to surface) ✓r Reservoir pressure/TVD: Tarn—2,62102_5,134' TVD (9.8 ppg EMW measured 2/8/2016 Wellhead type/pressure rating: WKM Gen V wellhead,5M Doyon 142 BOP Configuration: Annular/VBR Pipe Ram /Blind Rams/Mud Cross/VBR Pipe Ram MIT results: Combo TxIA MIT—Failed 3/23/2016 Well Type: Producer Estimated Start Date: May 30,2016 Production Engineer: David Lagerlef/Stephanie Pilch Workover Engineer: Travis Smith(265-6450/Travis.T.Smith@ conocophillips.corn) Pre-Rig Work: 1. RU Slickline: Pull DV for circulation point. Set BPV. RWO Procedure: 1. MIRU. Pull BPV.No-flow test. Circulate workover fluid as needed. 2. Install TWC. PT TWC from above. ND tree. NU BOPE. PT BOPE to 3,000 psig. Remove TWC. No-flow test. 3. BOLDS for tubing hanger. Pull tubing free from seal bore at 10,229'. No-flow test. POOH laying down 4-'/2" tubing. 4. Trip in hole with new 4-'/2"tubing and stacked packer/PBR. With packer spaced out above leak in 7"casing, circulate corrosion inhibitor to 4-1/2"x 7"annulus, stab seals into seal bore receptacle and set packer. 5. Shear out of PBR. PU out of seal bore. Engage the seal bore and space out. Circulate corrosion inhibitor. Land the tubing hanger.RILDS. ¢-- 6. PST the tubing. PT the IA. Pressure up to shear the SOV and pump the freeze protect. Allow tubing and IA to equalize. 7. Set BPV. PT BPV from below through open SOV. ND BOPE. NU tree. PT tree and packoffs. RDMO. Post-Rig Work: 1. Pull BPV. RU slickline to replace the SOV with DV. Reset well houses and flow lines. Turn over to Operations. 0 - - 4 i - • • • k 2N -333 ConocoPhillips k Producer 9 112' MD: 16" 62.5#, H-40 y AS-Planned 4 I 4 9 4 o4 1 t i 4 4 44 4-1/2" 12.6#, L-80 IBT-Mod 9 9 9 •3,452' MD: 9-5/8"40#, L-80 BTC— k 1 MJ f— Camco 4-1/2" KBG-2 Mandrels (ALL) li 4 f Oh4 ; 9 4 4 110 k 1 1 ` f— Camco CMU Sliding Sleeve w/ 1 3.812" D-Nipple t` Baker 4-1/2" x 7" Packer w/ A s PBR and Seal Assembly 1 10,165' (Estimated): 7" Casing Leak `V 10,235' MD: 7" 26#, L-80 BTC-Mod im M -4111-- Camco 3.75" D-Nipple Iii f- 10,235': Baker 190-47 Seal Bore Extension i ' 1 i i i i 10,759'–10,774': Bermuda Perforations - f i i i 10,908' MD: 4-1/2" 12.#, L-80 IBT-Mod ' 1 Date: May 12,2016 Drawn By: Travis Smith KUP D 2N333 ConocoPhilhaps - a Well Attribu Max Angle- D TD Alaska,Inc. '”Iii Wellbore API/UWI Field Name Wellbore Status incl(') MD(ftKB) Act Btm(ftKB) os 501032052500 TARN PARTICIPATING AREA PROD 72.88 7,566.77 10,921.0 ... Comment H2S(ppm) Date Annotation End Date KB-Gni(ft) -Rig Release Date 2N-333,5/160016633.14 AM SSSV:NIPPLE 45 11/23/2015 Last WO: 41.21 3/18/2006 Vertical.schematic.(actual). Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 10,747.0 4/19/2015 Rev Reason:GLV C/O pproven 4/21/2016 HANGER;31.7 e - -1 Casing Strings Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 - 34.6 112.0 112.0 62.50 1-1-40 WELDFD Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 34.6 3,451.7 2,390.7 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7"x4 5" 7 6.276 31.9 10,908.3 5,254.7 26.00 L-80 BTC-MOD I� 10254' @ ' '' "`Tubing Strings _A_,•,_CONDUCTOR;34.6-112.0 _ � :../yam Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft..1561 Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 31.7 10,247.5 4,821.6 12.60 L-80 (BTM Completion Details NIPPLE;496.8 II Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 1"1 Item Des Com (in) 31.7 31.7 0.00 HANGER 'FMC GEN V 5M TUBING HANGER 4.500 496.8 496.4 5.76 NIPPLE 'CAMCO DS LANDING NIPPLE w/3.875"NO GO 3.875 10,166.3 4,781.7 61.88 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/3.812"DS NO GO 3.812 PROFILE 10,185.1 4,790.7 61.20 NIPPLE CAMCO D NIPPLE NO GO 3.750 • 10,229 4 4,812.5 59.82 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY w/5.21"OD 3.870 LOCATOR suRrncL,34 34s1.�� Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD( Top Incl Top(ftKB) MKS) (') Des Com Run Date ID(in) 10,305.0 4,851.8 57.61 PLUG 3.65"SPECIAL CLEARANCE RBP @ 10305'RKB 3/23/2016 0.000 GAS LIFT;3,751.3 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ It Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 10,759.0 10,774.0 5,140.3 5,151.4 S-3,2N-333 4/6/2006 6.0 IPERF 27/8"HSD,2906 PJ HMX,60 deg phase GAS LIFT;6,981.4II Stimulations&Treatments Min Top Max Btm 111 Depth Depth Top(TVD) Btm(ND) 1 11 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,759.0' 10774.0- 5,140.3- 5,151.4 FRAC 5/21/2006 placed 253098 lbs of 16/20 prop in the formation w/ 126 ppa @ the perfs Mandrel Inserts GAS LIFT.6 762 6 at i Nn Top(ND) Valve Latch PortTRO Run Top(RKB) (ftKB) Make Model OD(in) Sem Type Type (in)) (psi) Run Date Corn 1 3,751.3 2,495.7 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 5/25/2006 10:00 2 6,981.4 3,645.5 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/17/2006 4:00 3 8,762.8 4,274.5 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000' 0.0 4/19/2016 GAS LIFT;10,1146 • 4 10,114.8 4,758.2 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 5/17/2006 1.00 Notes:General&Safety End Date Annotation 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 • SLEEVE-O;10,1663 NIPPLE,10,185.1 I SEAL ASSY,10,229.4 ..�'� AC .. PLUG;10,3050 V4 FRAC;10,774.0 9 I II IPERF;10,758.0-10,774.0 Casing 3,10,234.0-10,808.0 PRODUCTION 7'x4.5 10254';31.9-10,808.3 RECEIVED 2.0G-02-s MAY 0 6 2016 • • 2-1 k AOGCC WELL LOG TRANSMITTAL#903082132 To: Alaska Oil and Gas Conservation Comm. May 3, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5 /2014 M K.BENDER SCANNED RE: Multi Finger Caliper: 2N-333 Run Date: 3/15/2016 The technical data listed below is being submitted herewith. Please address anyproblems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-333 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20525-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20525-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: `E;0t_a STATE OF A RECEVED AL OIL AND GAS CONSERVATION ON COMMSION REPORT OF SUNDRY WELL OPERATIONS OCT 0 1 2015 1.Operations Abandon RugPerforationsPull Tubing r w n r- (® r Fracture Stimulate � �,��~^;;E� Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change 'pr`uve gram r Rug for Redrill rPerforate New Pool rRepair Well Re-enter Susp Well r° Other:Conductor ext ( � 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r" 206-025 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska`99510 Stratigraphic r Service 50-103-20525-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0375074 KRU 2N-333 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 10921 feet Plugs(measured) None true vertical 5265 feet Junk(measured) None Effective Depth measured 10760 feet Packer(measured) 10229 true vertical 5141 feet (true vertical) 4813 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 112 112 1640 630 SURFACE 3417 12 3452 2391 5740 3090 PRODUCTION 10876 10.3 10908 5255 7240 5410 Perforation depth: Measured depth: 107959-10774 True Vertical Depth: 5138-5150 S(app cc$$EP .:1\N 1 $) /),i 1 h Tubing(size,grade,MD,and TVD) 4.5, L-80, 10229 MD,4813 TVD Packers&SSSV(type,MD,and TVD) PACKER=BAKER GBH-22 SEAL ASSEMBLY @ 10229 MD and 4813 TVD SSSV=CAMCO DS LANDING NIPPLE @ 497 MD and 496 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure ' Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-153 Contact MJ Loveland/Martin Walters Email N1878na conocophillips.com Printed Name Martin W tens Title Well Integrity Project Supervisor Signature /7741*..4GLV ,A Phone:659-7043 Date 9/27/15 `0! Z-,,//0� V T 1.- A A ( �r- RBDMSJ C, Ul;I 0 1 2015 Form 10-404 Revised 5/2015 Submit Original Only • • • 2N-333 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/24/15 Fit and welded 10 3/4"X 16" .375 conductor extension on top of existing conductor. 09/25/15 Pump 5.1 gals of sealant into conductor. • 2N-333 • DESCRIPTION OF WORK COMPLETED SUMMARY r S RECEIVED ConocoPhillips ocr 2 Alaska 20P5 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 September 28, 2015 S14 wiY11za oqo - oas- Commissioner Cathy Foerster ^ 1 Alaska Oil& Gas Commissionat\) .-. '333 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, / 70./L, 1,c)(4)-4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 • OF Tit, yw\*\\I//7, 4, THE STATE Alaska Oil and Gas ofALASKA Conservation Commission _: 333 West Seventh Avenue OF w ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASj' Fax: 907 276 7542 www.aogcc.alaska.gov Martin Walters Well Integrit; :a, inc. c )7 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-333 Sundry Number: 315-153 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair 4- DATED this Z7 day of March, 2015 Encl. RECEIVED STATE OF ALASKA • ALA— A OIL AND GAS CONSERVATION COMM. .ON MAR 1 9 2015 • APPLICATION FOR SUNDRY APPROVALS OTs 312-7[15 20 AAC 25.280 �. AOGCC 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell CS Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing E Other:Cond Extension P. ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development IV. 206-025 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20525-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exceptions Yes r No P 14.9.0 2N-333 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL375074 • Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10921 . 5265 • 10?(od 511-B t 1 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 112' 112' 1640 630 SURFACE 3417 9 625 3452' 2391' 5750 3090 PRODUCTION 10876 7 10908' 5255' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10759- 10774 • 5138-5150 4.5 L-80 10229 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER GBH-22 SEAL ASSEMBLY MD= 10229 TVD=4813 • SSSV-CAMCO DS LANDING NIPPLE MD=497 TVD=496 . 12.Attachments: Description Summary of Proposal F7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development IV •• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2015 Oil r . Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cob.com Printed Name Martin Wal rs Title: Well Integrity Project Signature %1/4 - 11:.• :./?:(41 Phone:659-7043 Date: 3/16/2015 /71/47-e-77 / Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 31 S-153 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes 0 No LTJ Subsequent Form Required C i-j-- APPROVED BY Approved by: I •.r_ye• ap•lication is vaclIIr ss lPMnt s frpm tVcriMPUNroval. Date: 3 -2.7-15- Form 10-403(Revi ed 10/2012) Submit Submit Form and Attachm in Duplicate YTS 312 /15-- ORIGINAL �l W/i — RBDM$ ' APR - 3 2015 RECEIVED MAR 1 9 2015 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 16, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-333, PTD 206-025 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, . ( Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 2N-333 (PTD 206-025) SUNDRY NOTICE 10-403 APPROVAL REQUEST March 16, 2015 This application for Sundry approval for Kuparuk well 2N-333 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 8". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • Drys, KUP • 2N-333 ConocoP fillips . .vweas Well Attributes Max Angle 4 M TD • Alaska,Inc. Wellbore API/UWI Field Name Well Status !noir) MD(ftKB) Act Btm(ftKB) 501032052500 TARN PARTICIPATING AREA PROD 72.88 7,566,76 10,921.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Rebase Date .. Well cor,6a:-2N333,6/102013957:51 AM -SSSV:NIPPLE 90 12/11/2012 Last WO: 41.21 3/18/2006 Schwabe-Actual Annotation Depth(ftKB) [End Date !Annotation Last Mod...End Date Last Tag:RKB 10,760.0 i 6/1/2013 Rev Reason:TAG,H2S osborl 6/10/2013 -' Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...'Set Depth(TVD)...String Wt...String...String Top Thrd HANGER.32111111 - CONDUCTOR 16 15.250 34.6 112.0 112.0 62.50 H-40 WELDED _ ` Casing Description String 0... String ID...Top(ORB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd SURFACE 95/8 8.835 34.6 3,451.7 2,391.2 40.00 L-80 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Sat Depth(TVD)...String WE..String...String Top Thrd PRODUCTION 7 6.276 31.9 10,908.3 5,254.7 26.00 L-80 BTC-MOD 7"04.5"@ 10254' Tubing Strings Tubing Descnptlon String 0... String ID...Tap(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. Str ng Top Thrtl TUBING 41/2 1 3.958 I 31.7 10,247.5 4,821.8 I 12.60 L-80 IBTM Completion- CONDUCTOR, Top Depth I 35112 (TVD) Top Ines Nomi... Top(RKB) (RKB) U it..Description Comment ID(in) NIPPLE,497 31.7 31.7 u0.01 HANGER FMC GEN V 5M TUBING HANGER 4.500 496.8 496.3 5.48 NIPPLE CAMCO DS LANDING NIPPLE w/3.875"NO GO 3.875 10,166.3 4,781.8 61.88 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/3.812"DS NO GO PROFILE 3.812 10,185.1 4,792.0 60.57 NIPPLE CAMCO D NIPPLE NO GO 3.750 10,229.4 4,812.9 59.47 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY w/5.21"OD LOCATOR 3.870 Perforations&Slots Shot I Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (RKB) (RKB) Zone Date (511... Type Comment SURFACE. ah, 10,759.0 10,774.0 5,138.3 5,150.0 S-3,2N-333 4/6/2006 6.0 IPERF 2 7/8"HSD,2906 PJ HMX,60 deg 35-3,452 Phase rirErMr r Bottom IMF Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (RKB) (RKB) (RKB) Typa Date Comment GAS LIFT, 10,759.0 10,774.0 5,138.3 5,150.0 FRAC 5/21/2006 placed 253098 lbs of 16/20 prop in the formation w/ 3.751 12#ppa @ the perfs I Notes:General& End Date Annotation 11/23/22010 NOTE:View Schematic w/Alaska Schematic9.0 II- GAS GAS LIFT, 6,981 III II I GAS LIFT, 8.763 I t GAS LIFT, 10,115op Ir 1 111 II SLEEVE-O. 10.168 I. NIPPLE.10.165 1! I SEAL ASS0,2Y, 129 Mandrel lils Top Depth Top T - (TVD) Incl Port OD Valve Latch Sire TRO Run N...Top(RKB) (RKB) r) Make Model (in) Sery Type Type (In) (psi) Run Date Cont.. 1 3,751.3 2,495.8 68.00 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 5/25/2006 IPERF, 2 6,981.4 3,645.5 69.30 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 3/17/2006 FRAC.10,1o.7747s9-\ ' I FRAc, 3 8,762.8 4,274.4 68.71 CAMCO KBG-2 1 GAS LIFT OV BK-5 0.313 0.0 5/26/2006 4 10,114.8 4,758.3 63.82 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 5/17/2006 Casing 3, 10,234- ' ., PRODUCTION 7'k4.5'fa 10254', 32-10.906 - TD,10.921 Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Wednesday, March 25, 2015 9:58 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2N-333: Suntry Application ab6 - ° 2w6- The The last tag was at 10,760 MD (5141 TVD) so that would be the effective depth. Martin From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, March 19, 2015 10:46 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 2N-333: Suntry Application Good morning Martin, What is the current effective depth, both MD and TVD, for KRU 2N-333. This was missing from Form 10-403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, March 19, 2015 10:46 AM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 2N-333: Suntry Application °6 C31?-5 Good morning Martin, ca What is the current effective depth, both MD and TVD, for KRU 2N-333. This was missing from Form 10-403, Box 11. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - Q ~,~ Well History File Identifier Organizing (done> ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: Diskettes, No. ~, ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ U /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: /s/ Scanning Preparation ,~ x 30 = d + 1~ =TOTAL PAGES BY: r. Maria Date: ~ ~ ~ 8 (Count does not include cover sheet) /sl ~ ~i Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES _ BY: Maria Date: ~'~ /1(~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~ 1 NO viiiuiuuiiiiuii Res~,~~~, iuuiiiiiiimu BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III IIII III 10/6/2005 Well History File Cover Page.doc . ~` ~ y~~. 'x!' ~~~. ~ r ~ M" ~; • t ~ ~., ~ ~~ t. X -... s.'1~ ~w: lf - 4 t ' >.^; ~ }' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc r tg DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060250 Well Name/No. KUPARUK RIV U TARN 2N-333 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20525-00-00 MD 10921 TVD 5265 Completion Date 3/18/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI ON Types Electric or Other Logs Run: GR/RES, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc ' ' Directional Survey 34 10921 Open 4!17!2006 , QED C 14108 Induction/Resistivity 3492 10838 Open 8/30/2006 Lis Veri, GR, NPHI, FET, ~ ~ RHOB, ROP w/graphics , ,, 4~Rpt 14124 Report: Final Well R 0 0 Open 9/5/2006 Final Well Report w/ Graphics Mudlogging Equip, Well Details, Geo Data, Pres/Form Strength Data, Drilling Data, ~ Morning Reports, Well Logs rL ~ 14124 Mud Log 2 Col 129 10921 Case 9/5/2006 MD Formation Log 12-Mar- V 2006 og 14124 Mud Log 2 Col 129 5264 Case 9/5/2006 ND Formation Log 12- Mar-2006 1L~ _ 14124 See Notes 2 Col 129 10921 Case 9/5/2006 MD Drilling Dynamics 12- !/ Mar-2006 ~g 14124 See Notes 2 Col 129 5264 Case 9/5/2006 TVD Drilling Dynamics 12- Mar-2006 og 14124 See Notes 2 Col 129 10921 Case 9/5/2006 MD Combo Log 12-Mar- 2006 ~g 14124 See Notes 2 Col 129 5264 Case 9/5!2006 TVD Combo Log 12-Mar- 2006 ~0 14124 See Notes 2 Col 129 10921 Case 9/5!2006 MD Gas Ratio 12-Mar-2006 og 14124 See Notes 2 Col 129 5264 Case 9/5/2006 TVD Gas Ratio 12-Mar- 2006 L Induction/Resistivity 25 Col 112 10921 Open 4/10/2008 MD ROP, DGR, EWR, CTN, ALD, ACAL 7-Mar- 2006 • DATA SUBMITTAL COMPLIANCE REPORT si2oi2oos Permit to Drill 2060250 Well Name/No. KUPARUK RIV U TARN 2N-333 Operator CONOCOPHILLIPS ALASKA INC MD 10921 TVD 5265 Completion Date 3/18/2006 Induction/Resistivity r/1=D C 16101 "Induction/Resistivity C 14124 Report: Final Well R Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORN~ON Well Cored? Y N Chips Received? l~Ttd~ Analysis ~'f'P~ Received? Comments: Compliance Reviewed By: - _______. __ __. __ _____ API No. 50-103-20525-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N --- - p 25 Col 112 5264 O en 4/10!2008 MD ROP, DGR, EWR, CTN, ALD, ACAL 7-Mar- 2006 0 0 Open 4/10/2008 Graphics EWR, EMF and CGM 0 0 Open 9/5/2006 Final Well Report w/ Graphics Mudlogging Equip, Well Details, Geo Data, Pres/Form Strength Data, Drilling Data, Morning Reports, Well Logs Sample Set Sent Received Number Comments Daily History Received? Y N Formation Tops / N Date: WELL LOG TRANSMITTAL To: State of Alaska Apri12, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-333 AK-MW-423615 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-333 2" x 5" MD TC Logs: 1 Color Log 50-103-20525-00 2" x 5" TVD TC Logs: 1 Color Log 50-103-20525-00 Digital Log Images 1 CD Rom 50-103-20525-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd:-= -° Anchorage, Alaska• 99518 Date: it Signed: ~(olD( ~ M ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~,CEtVED 5 E P 1 2 2007 ~I~ai~a ail ~ bas Cons. Commission ~nClifl(a~B ao6" 33 a~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, _ '-----, J Arend ConocoPhillips Well Integrity Field Supervisor • M ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/9!2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2N-327 207-069 12" n/a 12" n/a 3.5 9/8/2007 2N-329 198-067 24" n/a 24" n/a 6 9/8/2007 2N-331 198-117 26" n/a 26" n/a 2 9/8/2007 2N-332 200-079 8" n/a 8" n/a 2 9/8/2007 2N-333 206-025 29" n/a 29" n/a 8.5 9/8/2007 2N-349 200-139 3" n/a 3" n/a 1 9/8/2007 2N-350 201-175 11" n/a 11" n/a 4.5 9/8/2007 2P-438 201-082 4' 10" n/a 4' 10" n/a 2 9/8/2007 ConocaPh~llip~ Sf:.P (i `~ "1006 TRANSMITTAL CONF/DENT/AL DATA Alaska Oil ~ Gas Gons. Commission Anchorage FROM: Sandra D. Lemke, AT01486 TO: Librarian ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7"' Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2N-333 Permit: 206-025 DATE: 9/5/2006 Kuparuk River. Unit 2N-333 501032052500 `~~- (1-I I ~~~ a Epoch -Final well report /Mud Logging Data; 3/15/2006; includes color prints in both MD and TVD for Formation Log; I Drilling Dynamics; Gas Rati, Combo Log ICDROM contains Final well report; morning reports; LAS data; DML Data; lithology remarks; and .pdf format color log image files Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for iyour records. ~To all data recipients: All data is confidential until State of Alaska designated AOGCC release date CC: Andy Andre ; CPA1 Geologist r _. Recei t: ____--------...-_-. p Date: ~~~~L(%~ ~~ 4l . ~ ..~~- GIS-Technical Data Management ~ ConocoPhillips ~ Anchorage, Alaska ~ Ph: 907.Z6S.6947 Sandra. D. LemkeC~Conocophillips. com • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2N-333, August 21, 2006 AK-MW-4236152 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20525-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 -~ ~~ ~`_' ~ i 9 Date: ,~„-, Signed: I ~ ' a ~~,_v~~5 ~ J~la~ ~ ~~ ~ ~ ~ ~ u, ~ - a ~ r FRANK H. MURKOWSKI, GOVERNOR ~ 9~9 ~~ ~~~~ ~~~~++ ~ cail[>•-7~ O~ ~ ~ °~ 333 W. 7`" AVENUE. SUITE 100 COI~TSERQA`l`IO1~T C011'II1iISSIOI~T g'r ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 27, 2006 Mr. Terry S. Lucht Manager, Drilling & Wells ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: 2N-333 Well Control Incident Dear Mr. Lucht: The Commission acknowledges receiving your letter dated June 29, 2006 in response to the Commission's letter dated June 16, 2006 regarding possible regulatory violations while drilling Kuparuk River Unit ("KRU") Well 2N-333. We also acknowledge receipt of an email message to ConocoPhillips' ("CP") field personnel from Mr. Randy Thomas dated July 7, 2006 regarding compliance with Commission regulations. Based on the Commission's experience with CP regarding well operations, it is probable that either Commission Inspectors or engineers were contacted during the events at 2N- 333. It is however unfortunate that neither CP nor the Commission has a record of these communications. While we recognize the intent of CP to comply fully with Commission regulations, the rapid flux of personnel makes it imperative that all involved with rig op- erations be aware of the regulatory requirements. Mr. Thomas' message to your field personnel strongly reiterated CP's expectations regarding compliance. Meeting the ex- pectations of your letter and Mr. Thomas' message should greatly reduce if not eliminate similar events in the future. Thank you for your and Mr. Thomas' cooperation in this matter. The Commission con- sid rs this m er closed. John r aniel T. Se ount, Jr. Commissioner ~-a~15 ~,vuij~uau~c i~~uc~ • Subject: Compliance Issues From: "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com> Date: Fri, 07 Ju12006 1:44:49 -0800 To: Down. 141 Company '~1an ~^n l > 4 ci conocophillips.com~ Doyen 1 ~ Compan_y~ Man <~D1 ~C11~1(ciconocophi]lips.com= , Doyon 19 Company Man <doyonl(a?conocophillips.com%, Nordic (:ompan}~ .titan ~n14 ~~~~z!conocophillips.com>, NSK Fld Drlg Supv <n13 ~~~conocophillips.conl>, CPA Drl~~-W"ells Slay Spec ~n1 128icr)conocophillips.com-=~ CC: "Al~~ord, Chip" <Chip.Al~~oz~d a;~conocophillips.com>. "Mazzolini, Paul" <Paul.l~Iazzolinir~l:~conocophillips.eom>, "E~gemeyer, Jerome C." ?Jerome.C.Eg~re~meyer(cz'conocophillips.com>, "Stahl, ~'Vlike A" <ti~Iike.A.Stahl(a;cono~ophillips.com>, "Lucht, Terry S." <Terry.S.LUCht a?conocophillips.com>, Thomas l~Saunder ~~tom maunder(a:;ad~nin.state.ak.us> It is critical that we fully understand the policies, procedures, and regulations that dictate how we manage operations. It is equally as critical to ensure that the hands on the rig also fully understand the expectations set out by these policies, procedures, and regulations. We need to recognize the high turnover of hands that is currently happening on the rigs in Alaska, along with an influx of less experienced hands. Please take the time to evaluate not only your personal knowledge of these documents, but also the knowledge of the personnel on the rig who are executing the work. ConocoPhillips will accept nothing less than 100% compliance with these guiding documents. Attached is a link to the AOGCC website for a copy of their regulations. Also attached is a link to the D&W Policy document. Feel free to call me with any questions. Randy L. Thomas Kuparuk Drilling Team Lead 907-265-6830 office 907-244-5205 cell 907-222-6088 home Randy. L.Thomas@conocophillips.com http://www.aogcc.alaska.gov/Regulations/art199.htm http~//biz ak ppco com/weIIsIFSBrowse.aspx?subfioider=Po4icies%20and%20Guidelines 1 of 1 7/18/2006 2:49 PM ConocoPhillips r~ ~~ Terry S. Lucht Manager Drilling & Wells 700 G Street Anchorage, AK 99501 Phone: 907 263 4585 Terry s IuchtC~conocophillips.com June 29, 2006 Mr. John K. Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Notice of Possible Violation, 2N-333 Well Control Incident ~~ Dear Commissioner Norman, +~1 ~ ~~~~ da~i<a iii a~ ~an~. ~ ,'ssio achorage The following is in response to your letter dated June 16, 2006 regarding the Notice of Possible Violation concerning the well control incident on Well 2N-333. The first issue is related to notifying the Commission of the need to use the BOP to control the well on March 9, 2006. While the regulations do not require written notification, our normal procedure is to follow verbal notifications with an email. We also can find no record of an email or written notice to the Commission. The Drilling Supervisor (Jerry Haberthur) recalls talking to the North Slope inspector several times that week regarding the well control operations and subsequent need to extend the BOP test to get the well stabilized and cased. The Drilling Engineer (Mike Winfree Jr.) and the Drilling Team Lead (Randy Thomas) both recall discussing the incident and the need to notify the Commission. Mike Winfree remembers conversations with Tom Maunder that week regarding the incident. Unfortunately, I can not provide any documentation of these discussions. 1 will reinforce to my staff the need to provide a written record of such conversations, either by letter or email. The second issue is related to the requirement to "function pressure test" any BOPE components used to prevent the flow of fluids from a well prior to the next wellbore entry. The BOPE component used in this incident was the annular preventer. Once this well was killed and stable, the decision was made to run casing and not drill any additional footage. The regular BOPE test was due on the day that we were ready to run casing. The Commission was contacted to extend the test to allow time to run the casing to TD. The annular was functioned prior to beginning the trip out of the hole. The expensive BHA involving MWD/LWD and directional drilling tools was laid down. and a clean out assembly was made up. This was run to the shoe of the surface casing. A kick drill was done at that point which required function testing the annular. The assembly was then run to bottom to condition the hole. Casing was run and cemented after pulling out of the hole. The end result is that the annular was function tested twice prior to entering the open hole section again. However, it was not function pressure tested. I suspect that getting approval for the delay of the BOPE test diverted attention from the need to pressure test that one component prior to re-entering the well rather than a function test only. Chairman John K. Norman AOGCC June 29, 2006 Page Two It is clearly our policy and commitment to be in full compliance with all regulations. I think our history operating in the state of Alaska over the last several decades has proven our intent. Unfortunately, in this case it appears that we were not in full compliance with the pressure testing requirement and have no documentation of the verbal conversations with the Commission regarding this incident. These deficiencies will be highlighted in our team meetings as a means to reinforce the need to fully understand and comply with all regulations and policies. If you have any questions or require any further information, please contact me at 263 4585. Sincerely, .~ j~9~~/ Terry S. Lucht Manager Drilling & Wells TSL: db _ __. - FRANK H. MURKOWSKI, GOVERNOR ~5J~1 OIL ~D ~~ 333 W. T" AVENUE, SUITE 100 1~T~+ CO„-7ERQAiiOls COr~iI-7SIO~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 16, 2006 Certified Mail Return Receipt Requested Article Number 7005 1160 0001 5754 0055 Mr. Terry Lucht Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Notice of Possible Violation Dear Mr. Lucht: The Alaska Oil and Gas Conservation Commission ("Commission") hereby notifies ConocoPhillips Alaska, Inc. ("CPAI") that the Commission considers CPAI may have violated provisions of 20 AAC 25.035(e)(10)(C) and 20 AAC 25.035(e)(11) while con- ducting drilling operations on Kuparuk River Unit (" KRU") we112N-333 (206-025}. The completion report (Form 10-407) for the well was recently submitted and a review of the report indicates that, while conducting drilling operations, it was necessary to use the BOPS to prevent the flow of fluids from well 2N-333 at about 17:30 on March 9, 2006. The Commission has no record of being notified by CPAI of the use of the BOPE to pre- vent flow as required by 20 AAC 25.035(e)(11). Further, the operations summary does not indicate that the BOPE components used to prevent the flow of fluids from the well were function pressure-tested prior to the next wellbore entry as required by 20 AAC 25.035(e)(10)(C). You are requested to review your records regarding this event and submit the results of such review to the Commission not later than 4:30 pm, June 30, 2006. The Commission reserves the right to pursue an Enforcement Action according to 20 AAC 25.535. If you have questions regardin is matter, please contact Tom Maunder, PE at 793-1250. Si K.. )1 f -- - --- Subject: Re: 2N-333 and CD4-208 From: James Regg <jim_regg@ad~nin.state.ak.us> Date: Wed, 31 May 2006 13:21:22 -0800 Ta: Thomas 1Vlaunder'<tam maunder@admin.state.ak.us> that wlll get their attention; letter should go certified mail and you should be ID'd as contact point for any questions I spoke with Chuck yesterday (he was on the Slope 3/8-15); he recalled some notice about use of BOPS involving a Doyon rig but did not recall details; definitely did not recall notice about event as significant as the one you showed me in 2N-333 daily rpts. Jim Thomas Maunder wrote: Jim, Here is a first stab at the letter regarding no report of use of the BOP. I am still reviewing the completion reports. At least for 2N-333 I cannot find any emails regarding their fun. The way they went about "things" up until they needed to shut in are interesting. It appears they tried to "outrun" their flow and handle it on the fly without shutting in. What this resulted in was oil contaminated mud so bad that it wouldn't hold the bar and they had to totally replace the system. It may be appropriate for me to scan the ops summary and have the inspectors take `a look. I was going to send them an email asking if they had any records for these wells. .- Let me know your thoughts. Tom ~~~~ \ ~~ ~ S l ~~~5 E. ~~~ ~ `ofl~~ ~t v ~ ~~ ~ i~ S c~hx,~~! ©v~ wvrs~c a~~ c~ ~'.~'"'i 513, ~~.c~ 1 of 1 5/31/2006 2:01 PM Subject: Re: 2N-333 and C 8 From: James Regg <jim_regg@admin.state.ak.us> Date: Wed, 31 May 2.006 1323:00 -0800 To: Thomas 1Wtaunder <tom_maunder@admin.state.ak.us> agree; significant one to deal with is 2N-333 Thomas Maunder wrote: On this letter, I pulled the file on CD4-208 and there is a message in the file regarding shutting in the well and the determination that it was breathing. The message time is some 30 hours after the event. Vern did note in his message of the need to contact the Commission within 24 hours of shutting in the well. On that basis, I think we can eliminate CD4-208 from the letter. Tom Thomas Maunder wrote, On 5/31/2006 10:57 AM: Jim, Here is a first stab at the letter regarding no report of use of the BOP. I am still reviewing the completion reports. At least for 2N-333 I cannot find any emails regarding their fun. The way they went about "things" up until they needed to shut in are interesting. It appears they tried to "outrun" their flow and handle it on the fly without shutting in. What this resulted in was oil contaminated mud so bad that it wouldn't hold the bar and they had to totally replace the system. It may be appropriate for me to scan the ops summary and have the inspectors take a look. I was going to send them an email asking if they had any records for these wells. Let me know your thoughts. Tom D4- 0 1 of 1 5/31/2006 2:01 PM • ~ Mike Mooney Wells Group Team Leader Drilling & Wells ` ,,,.. P. O. Box 100360 '~° Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~ ~~ Phone: 907-263-4574 June 14, Zoos DECEIVED Commissioner JUN 2 p 2006 State of Alaska Alaska Oil & Gas Cons. Commission Alaska Oil & Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2N-333 (APD # 206-025) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2N-333. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, lV~ ~ NI M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ~,- STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED JUN 2 0 2006 REPORT OF SUNDRY WELL OPERATIO it & Gas Cons. Comnissiol7 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other At1Ct1~Qe Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development ^~ Exploratory ^ 206-025 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20525-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 34' 2N-333 8. Property Designation: 10. Field/Pool(s): ADL 375074; ALK 4293 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 10921' ~ feet true vertical 5265' feet Plugs (measured) Effective Depth measured 10760' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 112' 112' SURFACE 3417' 9-5/8" 3451' 2390' PRODUCTION 10200' 7" 10234' 4815' LINER 674' 4-1/2" 10908' 5254' Perforation depth: Measured depth: 10759'-10774' [a, ~ SUN ~ ~ 200 true vertical depth: 5140'-5152' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10248' MD. Packers & SSSV (type & measured depth) no packer ~'J~`^~ ~~~rS~^~o,'~c ~o~l~~?~n11 t Camco 'DS' nipple @ 497' O~a 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10759'-10774' MD ' Treatment descriptions including volumes used and final pressure : 253098# of 16/20 proppant in formation 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 938 2962 1022 -- 285 Subsequent to operation 3257 4548 - 4431 -- 349 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development O Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N1a if C.o. Exempt: contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature Phone Date ~~~~~Uto Pre ared b haron Allsu -Drake 263-4612 Form 10-404 Revised 04/2004 O R 1 G 1 N A L ~~G:s3 ~ G ~"o` Sub n n l0 y ~~ ~ • 2N-333 Well Events Summary • DATE Summary 05/21/06 Initial Frac completed through flush, placed 253098 Ibs of 16/20 prop in the formation w/ ~ 12# ppa @ the perfs. Frac was completed per design using 50# XL Gel. A Bracket Frac was pumped just prior to the Frac stage.Approximately 50 psi of net pressure gain was seen. Maximum WHTP was 6600 psi during the breakdown. App: 1300# of prop was left in the wellbore above the perfs. Freeze protected tubing to 5000' with diesel. 05/22/06 CLEANED OUT FILL TO PBTD AT 10844' (EST. 75' OF RATHOLE) USING SEAWATER J313 & 1-1/2# DUO-VIS USING 1.75 JETSWIRL NOZZLE. WELL LEFT SHUT IN AND FREEZE PROTECTED W/ DIESEL TO 3000'+. 05/23/06 TAGGED FILL @ 10760' RKB, EST. 1' RATHOLE. DRIFTED TBG W/ 3.80" G/R TO CMU @ 10166' RKB. ATTEMPTED PULL DV @ 10115' RKB, UNABLE TO WORK 4.5" KOT PAST 9741' SLM. PUMPED 90 BBL DSL. ATTEMPTED PULL DV @ 8763' RKB, NO SUCCESS. TOOL SEIZED WITH FRAC SAND. 05/24/06 PULLED DVs @ 3732' & 8763' RKB. IN PROGRESS. 05/25/06 SET DV @ 3751' RKB, SET OV @ 8763' RKB. ATTEMPTED CHECK SET OV @ 8763', NO SUCCESS. IN PROGRESS. 05/26/06 CHECK SET OV @ 8763' RKB, SHEARED PINS INDICATING OV SET. '~ ~\ Gcat't~tc~Phillips Al ar, Irtc. 2N-333 API: 501032052500 TUBING (0-10248, OD:4.500, ID:3.958) SURFACE (0-3451, OD:9.625, wt:ao.oo> PRODUCTION (0-10234, OD:7.000, wt:zs.oo> Gas Lift MandrelNalve 3 (8763-8764, SLEEVE ;10166-10167, OD:5.300) NIP ;10185-10186, OD:5.570) SEAL ;10229-10230, OD:4.750) • KRU aV-333 SSSV Type: NIPPLE Annular Fluid: Reference Lo :34.4' RKB Last Ta :10760 Last T Date: 5/23/2006 ~ Casing String -ALL STRINGS_ _ _ Descri lion Size SURFACE 9.625 Well T e: PROD Orig 3/18/2006 :om letion: Last W/O: f Lo Date: TD: 10921 ftK6 sole Angle: 73 deg aQ7567 L-80 I BTC PRODUCTION 7.000 0 10234 4815 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 112 112 62.50 WELD LINER 4.500 10234 10908 5254 12.60 L-80 IBTM Tubing String -TUBING _ --- . Size i Top bottom i ND ~ Wt Grade ~ Thread 4.500 ~ 0 10248 _ 4822 12.60 L-8_~ IBTM Perforations Summary --------------- Interval ND Zone Status Ft SPF Date T e Comment 10759 - 10774 5140 - 5152 15 6 4/6/2006 IPERF 2 7/8" HSD, 2906 PJ HMX, 60 deg phase Stimulations 8 Treatments Interval __ Date __ T e Comment 10759 - 10774 5/21/2006 FRAC Initial Frac completed through flush, placed 253098 Ibs of 16/20 prop in the formation w/ 12# ppa @ the perfs. Frac was completed per design using 50# XL Gel. A Bracket Frac was pumped just prior to the Frac stage.Approximately 50 psi of net pressure gain was seen. Maximum WHTP was 6600 psi during the breakdown. App: 1300 Ibs of prop was left in the wellbore above the perfs. Freeze protected tubing to 5000' with diesel. __ Gas Lift Mandre lsNalves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3751 2496 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 5/25/2006 2 6981 3646 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 3/17/2006 3 8763 4274 CAMCO KBG-2 OV 1.0 BK-5 0.313 0 5/26/2006 4 10115 4759 CAMCO KBG-2 --- - - DMY 1.0 _ BK-5 0.000 0 5/17/2006 Other plugs, eguip., etc.) - COMPLETION JEWELRY _ De th ND T e Descri lion ID 32 32 HANGER FMC 5M GEN V HANGER 4.500 497 497 NIP CAMCO'DS' LANDING NIPPLE w/3.875" NO GO 3.875 10166 4782 SLEEVE BAKER CMU SLIDING SLEEVE w/3.812" DS NO GO PROFILE 3.812 10185 4791 NIP CAMCO'DB' NIPPLE NO GO PROFILE 3.750 10229 4813 SEAL 4.5" BAKER GBH-22 SEAL ASSEMBLY w/5.21" OD LOCATOR 3.870 10247 4822 WLEG BAKER WIRELINE GUIDE 3.870 Angle @ TS: deg @ Angle @ TD: 39 deg @ 10921 LINER ;10234-10908, OD:4.500, Wt:12.60) Perf ;10759-10774) • ConocoPhillips April 28, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ,° .,~ Subject: Well Completion Report for 2N-333 (APD 206-025) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2N-333. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ~ `~ `3, ~~~~'' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L ~~~ ~-:i, r ,~~, 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March 18, 2006 12. Permit to Drill Number: 206-025 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 25, 2006 ~ 13. API Number: 50-103-20525-00 ' 4a. Location of Well (Governmental Section): Surface: 103' FNL, 938' FEL, Sec. 3, T9N, R7E, UM 7. Date TD Reached: March 9, 2006 ~ 14. Well Name and Number: 2N-333 ' At Top Productive Horizon: 968' FNL, 1157' FWL, Sec. 4, T9N, R7E, UM 8. KB Elevation (ft): 34' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1014' FNL, 4384' FEL, Sec. 4, T9N, R7E, UM 9. Plug Back Depth (MD + TVD): 10844' MD / 5205' TVD Tarn Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460655 y- 5911906 ' Zone- 4 10. Total Depth (MD + TVD): ' 10921' MD / 5265' TVD' 16. Property Designation: ADL 375074 TPI: x- 452188 y- 5911090 Zone- 4 Total Depth: x- 451927 - 5911046 - Zone- 4 11. Depth where SSSV set: Landing nipple @ 497' 17. Land Use Permit: ALK 4293 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: n/a 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 34' 112' 34' 112' 24" 9 cu yds High Early 9-5/8" 40# L-80 34' 3452' 34' 2390' 12.25" 442 sx Class G, 199 sx LiteCrete 7" x 26# L-80 34' 10234' 34' 4815' 8.5" 307 sx Class G 4.5" 12.6# L-80 10234' 10908' 4815' 5254' 8.5" see above 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 10247' 14232' 10759'-10774' MD 5140'-5152' TVD 6 spf ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 19, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 4/22/2006 Hours Tested 12.5 hours Production for Test Period --> OIL-BBL 135 GAS-MCF 34 WATER-BBL 173 CHOKE SIZE 12% GAS-OIL RATIO 465 Flow Tubing press. 724 psi Casing Pressure 774 Calculated 24-Hour Rate -> OIL-BBL 223 GAS-MCF 104 WATER-BBL 331 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". txffi°.., .- ~ i....~d NONE - ~~ S ~F~, ~A~ 3 0 2006 3 ~~~ I -- -__ ' Form 10-407 Revised 12/2003 CONTINUED ON REVERSE i~~~ ~~/y~~ OR1GiN~L 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2N-333 T3.1 10483' T3 10539' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed NaRand Thomas Title: Greater Kuoaruk Area Drillino Team Leader Y~Z~~~O ~ ~ Signature one ~~ ~--6 ~ j U Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Operations Summary Report Page 1 of 12 Legal Well Name: 2N-333 Common Well Name: 2N-333 Spud Date: 2/25/2006 Event Name: ROT -DRILLING Start: 2/24/2006 End: 3/18/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Group: Rig Name: Doyon 14 Rig Number: Date 2/24/2006 2/25/2006 2/26/2006 2/27/2006 From - To Hours Code ' Phase Description of Operations Code 03:00 - 04:00 ! 1.00 MOVE RURD II I MOVE Prepare rig floor to skid to move position -Blow down same 04:00 - 05:00 1.00 MOVE SKID I MOVE Skid rig floor from drlg position to move position 05:00 - 06:00 ~; 1.00 MOVE I MOVE MOVE Move rig off well 2L-309 06:00 - 10:00 ~ 4.00 MOVE MOVE MOVE Move rig from 2L Pad to 2N Pad 10:00 - 11:00 i 1.00 MOVE POSN MOVE Spot rig on well 2N-333 -Shim rig 11:00 - 12:00 1.00 MOVE SKID RIGUP Skid rig floor from move position to drlg position 12:00 - 14:00 1 2.00 MOVE RURD RIGUP Rig up floor -Steam -Water -Air -Mud lines 14:00 - 17:00 '~, 3.00 WELCT NUND RIGUP Accept rig 14:00 hrs -Nipple up Divertor system -Riser -Flow line - 17:00 - 18:00 it 18:00 - 19:30 19:30 - 20:00 j 20:00 - 23:30 I. 23:30 - 00:00 ! 00:00 - 01:00 01:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 07:30 07:30 - 10:00 10:00 - 12:00 '. 12:00 - 13:00 '', 13:00 - 00:00 00:00 - 06:00 1.00 1.50 0.50 3.50 0.50 1.00 1.00 1.00 1.50 0.50 Center up same DRILL OTHR RIGUP Load pipe shed with 5" DP -Strap same DRILL RIRD RIGUP Spot rock washer -Berm same DRILL RIRD RIGUP Change up DP handling from 4" to 5" DRILL ~ PULD RIGUP Pick up 5" dp 1 X 1 -Stand back in derrick 30 stands RIGMNT RSRV RIGUP PJSM -Cut drlg line RIGMNT RSRV RIGUP Cut drlg line -Top drive service -rig service DRILL OTHR ~ RIGUP Function test divertor -Perform accumulator test -All gas alarms -PVT -Flow meter properly functioned -John Crisp with AOGCC waived '~ witness of test -Derrick inspection DRILL PULD RIGUP PU 5" HWDP 1 X 1 -Jars -Stand back in derrick DRILL PULD SURFAC Make up BHA - PU Motor -Make up bit - MWD - XO -One stand HWDP - RU Sperry Sun gyro sheave /equipment DRILL i SFTY SURFAC Pre spud meeting with crews -Prime pumps -Fill riser with mud - ~ Check for leaks -Air boot on riser -leaking 1.50'; RIGMNT RGRP i SURFAC Change out air boot on riser 1.00; DRILL 'i DRLG SURFAC Drill ice from 34' to 112' -Drill formation from 112' to 218' 2.501 DRILL I TRIP SURFAC POH - PU Flex DC's - MWD 2.00! DRILL I DRLG SURFAC Drill from 218' to 251' - WOB 10 to 15 -RPM 60 - TO on 1-off 1 -GPM ~~ 375 - PP on 1000 -off 960 - PU 65 - SO 65 -ROT 65 -Drag chain off 1.00' RIGMNT I RGRP SURFAC sprocket Place drag chain back on sproket in conveyor system 11.00! DRILL ,' DRLG SURFAC Directional Drill from 251' to 1074' - WOB 5 to 20 -RPM 60 - TO on 4 - ~ off1-GPM423-PPon1320-off 1150-PU95-SO 90-ROT 95 6.00 i' DRILL DRLG ~~, SURFAC Directional Drill from 1074' to 1586' - WOB 6 -RPM 60 - TO on 4 -off 1 I -GPM 423 - PP on 1240 -off 1180 - PU 102 - SO 96 -ROT 100 -Gas li ~ s~tirig ~ 1154'.- Max units 600 @ 1185' - 960 @ 1210' - ' ' 1910 units @ 1255' - 1190 units @ 1305' - 400 units @ 1320' -Holding ' 400 units - Flaw ~ #resm 25% av~ to 413'Yo fifgh #rom 1150' to ', 134Q' - irann 1320' to 15~' droptpe@ i~r ~8t3 tv 400 units 06:00 - 08:00 , 2.00''., WAITON ORDR I, SURFAC Circulate -GPM 423 - PP 1180 -Wait on orders due to close approach ' issues -Gas increased to 1900 units 08:00 - 22:00 i 14.00', DRILL DRLG ',SURFAC Directional Drill from 1586 to 2477 - WOB - 22 -RPM 60 - TO on 5 -off 4-GPM423-PPon1480-off 1350-PU105-S090-ROT100- 22:00 - 23:30 ~ 1.501 DRILL CIRC 'SURFAC CBU 3 X -GPM 400 to 525 - PP 1100 to 1830 - On btms up lot of clay ~ balls 23:30 - 00:00 I 0.501, DRILL ',TRIP 'SURFAC Flow check -Pump out @ 423 gpm 00:00 - 01:30 1.50 li DRILL ',TRIP SURFAC Pump out to HWDP -GPM 423 01:30 - 03:00 1.501 DRILL I TRIP ;SURFAC POH with BHA -Change motor setting from 1.83 to 1.5 -Inspect bit 03:00 - 03:30 0.50 ~ DRILL ',TRIP iSURFAC RIH with BHA @ 702' 03:30 - 04:30 1.00 DRILL 'TRIP 'SURFAC RIH from 702' to 2383" 04:30 - 05:30 1.0011 DRILL '~, CIRC ~ SURFAC Wash last stand down to 2477 -Circulate bottoms up -Clay balls / thick mud -Stage up pumps from GPM 200 to 423 - PP 600 to 1160 - I ' RPM 60 - TO 4 05:30 - 17:30 12.001 DRILL ~I DRLG ''SURFAC Directional Drill from 2477 to 3462' - WOB 20 -RPM 80 - TO on 8 -off Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Start: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Rig Name: Doyon 14 Rig Number: Date From - To 'Hours ,, Code 2/27/2006 2.50 ' 17:30 - 19:30 2.00' DRILL I CIRC ~ SURFAC 19:30 - 21:30 I, ' 2.00 ~~ DRILL ' 'TRIP I SURFAC 21:30 - 22:00 ' i 0.50 DRILL I PULD SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 00:00 ', 1.00 DRILL 11 TRIP I SURFAC 2/28/2006 00:00 - 01:00 1.00 DRILL ~ TRIP ~; SURFAC :01:00 - 02:30 ~ 1.50 ~ DRILL CIRC I SURFAC 02:30 - 05:00 I1 ~! 2.5011 DRILL ~~ TRIP 'SURFAC ~~~ ! 05:00 - 05:30 0.50' DRILL ~ TRIP SURFAC 05:30 - 07:00 ~, 1.50 ~ DRILL ~ ~-PULD SURFAC 07:00 - 07:30 0.50 I DRILL ', OTHR ~ SURFAC 07:30 - 08:30 1.00 ~ CASE 'RURD SURFAC 08:30 - 12:00 ' 3.501 CASE ~I RUNC SURFAC 12:00 - 14:30 II 14:30 - 15:00 15:00 - 15:30 15:30 - 16:30 '' 16:30 - 19:00 ' 19:00 - 20:00 3/1!2006 05:30 - 17:30 12.001. DRILL I DRLG :SURFAC i120:00 - 20:30 1~1 ' 20:30 - 21:30 1121:30 - 22:30 ~; '122:30 - 00:00 00:00 - 01:00 '. 01:00 - 03:30 03:30 - 04:30 CASE Sub Phase Code SFTY 'SURFAC 0.50' CASE !RURD ~ SURFAC 0.50' CEMENT PULD SURFAC 1.OOICEMENTCIRC ',SURFAC 2.5011 CEMENT PUMP 'SURFAC 1.00'1, CEMENTDISP I~SURFAC 0.50', CEMENT PULD 1.0011 CASE RURD 1.00'1 RIGMNTI RURD 1.501 CASE NUND 1.00 ~ WAITON OTHR 2.50 'I WAITON OTHR 1.00! CASE 'NUND iiSURFAC (SURFAC SURFAC "SURFAC 'SURFAC SURFAC SURFAC Page 2 of 12 Spud Date: 2/25/2006 End: 3/18/2006 Group: Description of Operations I4 -GPM 528 - PP on 2130 -off -2080 PU -110 SO 90 -ROT 100 - IGas CBU 3.5 X -GPM 550 - PP 2000 -RPM 100 - TO 4 Flow check well -Pump out to HWDP -Lost 200 psi -Found washout 8" from pin on bottom single of stand 18 out of hole - (2830 'where washout occured) -Horizontal washout on tube 'Change out single ' Con't pump out from 1830' to HWDP @ 703' -Max gas pumping out 1610 units ' Blow down top drive -RIH from 703' to 2000' RIH from 2000' to 3462' -Precautionary wash from 3383' to 3462' CBU 3 X -Stage up pump from 250 GPM to 500 GPM - PP 1900 - RPM 100 - TO 5K -Trip gas 451 units -Gas after CBU 3 X 85 units Flow check -Pump out to HWDP from 3462' to BHA @ 703' -Pump out @ 400 gpm -Hole in good condition -Gas 50 units for high and 35 avg on trip out !Stand back HWDP -Jars LD BHA -Flex DC's - MWD -Break Bit - LD motor 'Clear and clean rig floor. PJSM, R/U 9 5/8"casing equipment. I Run Weatherford 9 5/8" cement shoe w/ Baker lock, 2 joint shoe track, 9 5!8" Weatherford float collar w/ Baker lock below and above float ~, collar, using premium thread compond on each connection, continue to ~, run 9 5/8" 40#, L-80 Butrss casing U1350', displacing mud away, circulating every 10 joints, w/45 spm, at 230-280 psi. PJSM, Continue to RIH w/ 9 5/8" 40# L-80 BTC casing f/1350'-t/3451', a total of 82 jts, Landed casing on landing ring @3451'. Casing shoe @ 3451.69', 2 joint shoe track (77.42'), top of float @3371.10' Note: while running casing break circulation every 10 jts., to condition mud, thin mud, PJSM, rig down Franks fill up tool, and blow down TDS. '~ PJSM, R/U Schlumberger cementing equipment, lines, and cementing head, load plugs in head. ;Break circulation w/35 spm, and staging up U 60 spm, w/310 psi final .circulating pressure. PJSM, Pump 5 bbls of water. Pressure test lines U3500 psi, bleed off, ,start pumping 50 bbls CW 100 chemical wash, pump 50 bbls mud j push, w/10.2 ppg, drop bottom plug. Pumped 442 sacks of type ASL Lead cement, 337 bbls slurry, @ 10.7 ppg. Pumped Tail 262 sacks of Deep Crete Class "G", 120 bbls slurry, @ 12.0 ppg. Drop top plug, and start displacement, Schlumberger pumped 30 bbls, switch to rig pumps, and finished displacement, w/ a total of 254 bbls, Bump Plug, and pressured up to 1500 psi, bleed pressure off and check float, OK, no returns. Total Cement to surface 180 bbls., Circulation ~ throughout cement job. ~; Rig down and lay down Schlumberger cementing head. Flush stack, blow down lines. :Clean surface equipment after cement job, and clear rig floor. '1 PJSM, Nipple down diverter, riser, and surface hydrill. 'Remove 4" valves on 16" conductor. On 16" conductor welder cut off 4" threaded nipples on conductor & welded on cover plates over holes. Install 9 5/8" speed head, and casing spool. Test metal to metal seal to Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Start: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Rig Name: Doyon 14 Rig Number: Date From - To '' Hours 3/1 /2006 ', 03:30 - 04:30 ' 1.00 '04:30-06:30 2.0011 ~, 06:30 - 07:30 ~ ~ 1.00 I 07:30 - 11:30 I 4.00 11:30 - 12:00 ', 0.50' 12:00 - 12:30 I 0.50' j 12:30 - 13:00 ! 0.50' ',13:00 - 13:30 0.50' ,13:30 - 21:00 7.50 21:00 - 22:00 j .1.00 22:00 - 23:30 I 1.50 23:30 - 00:00 0.50 3/2/2006 I 00:00 - 01:00 'I 1.00 I 01:00 - 01:30 0.50 01:30 - 02:30 1.00 02:30 - 04:00 1.50 04:00 - 07:00 3.00 07:00 - 08:30 1.50 08:30 - 09:30 1.00 09:30 - 10:30 ~ 1.00 ~I 10:30 - 14:00 I~, 3.50 Code Sub Code CASE NUND WELCTL NUND WELCTL BOPE WELCT BOPE i Phase SURFAC SURFAC SURFAC SURFAC WELCTL BOPE ~ SURFAC WELCTL BOPE ~ SURFAC DRILL ', RIRD 'SURFAC DRILL I RIRD ~I, SURFAC DRILL '(TRIP ( '(SURFAC DRILL PULD (SURFAC DRILL PULD SURFAC DRILL OTHR SURFAC DRILL PULD SURFAC RIGMNT RSRV SURFAC RIGMNT RSRV SURFAC DRILL PULD SURFAC DRILL li PULD SURFAC RIGMNT', RSRV SURFAC DRILL ~ CIRC SURFAC CASE 'MIT ',SURFAC DRILL DRLG ',SURFAC 14:00 - 15:00 ! 1.00 DRILL 15:00 - 16:00 ' 1.00 DRILL ';16:00 - 16:30 i 11, 0.501 DRILL 16:30 - 17:00 1 I 0.501''1 DRILL 17:00 - 00:00 ~ 7.00 i DRILL CIRC SURFAC CIRC 'SURFAC LOT '',SURFAC RIRD I, SURFAC DRLGSURFAC Page 3 of 12 Spud Date: 2/25/2006 End: 3/18/2006 Group: Description of Operations ,1000psi for 10 min. Note: (Called AOGCC John Crisp @ 03:30, to notify of BOP test) ',Nipple up BOPE. R/u to test BOP '!Test BOPE, Test 13 5/8"Annular preventer to 250 psi low/2500 psi high, !f/ 5 min., 2 7/8" X 5" pipe rams to 250 psi low/ 3500 psi high, f/ 5 min., Lower pipe rams 3 1/2" X 6" to 250 psi low/3500 psi high, f/ 5 min., Blind rams, choke line valves, to 250 psi low/3500 psi high, f/ 5 min., 3 ~i 1/8" HCR valves to 250 psi low/3500 psi high f/ 5 min., 3 1/8" kill line valves to 250 psi low/3500 psi high, f! 5 min., and floor safety valves, Upper kelly, Lower kelly, Ball type, Inside BOP to 250 psi low/3500 psi high, f/ 5 min., Accumulator System function test, 3000 psi, pressure ~ after closure 1800 psi, 200 psi attained in 35 sec., full pressure attained in 2 min. 40 sec. All test were witness by AOGCC Rep. John Crisp I Rig down BOP test equipment. Blow down choke and kill lines. !,Install long wear bushing, run in lock down. Note:(Peak truck had small leak on fuel line, duck pond was placed under leak to contain leak, and leak was fixed, and the contaminated snow was pick up by Peak 'trucking, and disposed of, call was made to security and environmental) !Rig up bails, and 5" handling equipment. ,PJSM, Picking up in singles and RIH 5" DP to 3000', connecting TDS to DP and pumping 1 1/2 string volume through DP to wash out clean, ',blow down stand pipe, POOH and stand in derrick, total 54 stds. Mob. Directional tools and BHA to rig floor. j PJSM, P/U and M/U BHA #3 &RIH I~ Upload MWD, R!U Geo skid. Continue to M/u BHA #3 and RIH Rig Service, Lubricate TDS Change out swivel packing on TDS Surface test MWD, 105 spm, @ 750 psi, load radioactive sources, and ~I continue to make up BHA #3, and RIH. Continue to P/u and M/u 5" DP from pipe shed and RIH Slip and cut drilling line, TDS service. I Circulate to condition mud. w/105 spm @1120 spi. Pressure test casing to 3500 psi f/30 min. ,RIH and tagged top of float collar @ 3371', drilled out float and continue Ito drill hard cement to top of cement shoe @ 3449.97, and continue to !drill 20' of new hole to 3482'. Note: On #2 engine the radiator leaked ',1qt. on pad, and lgal in secondary unit, Enivornmental and ACS, and ', security was contacted, spill on pad was clean up and bagged up. 'Circulate bottoms up 1X w/105 spm @1220 psi, while recpricating DP w/ 6,000 Ibs torque, w/60 rpm. Pump 35 bbls Hi-Vis sweep, and pump another 40 bbl Hi-Vis sweep to ,clean hole, continue to circulate and displace well bore with clean 9.6 ~, ppg LSND mud, total 232 bbls. Blow down TDS, R/U for F:LT. test, test good, EMW at 3451.69' MD. j{2390' T1iD}= 16.3PPg•' ~, Rig down lines, blow down kill, choke and cement lines. RIH to bottom, and continue to drill ahead 8.5" hole section at a ~, controlled rate, f/3482'-U3931', Drilling perimeters: 5,000#-10,000# WOB, 130-150 rpm, 2 x 60 spm, 450-500 gpm flow rate, running all j solid control equipment, to control MW, and maintaining a Max. ECD of Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska 9.001 DRILL I DRLG ! INTRM1 Page 4 of 12 Legal Well Name: 2N-333 Common Well Name: 2N-333 Spud Date: 2/25/2006 Event Name: ROT -DRILLING Start: 2/24/2006 End: 3/18/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To I Hours ', Code Code Phase ', Description of Operations 3/2/2006 17:00 - 00:00 7.00 ~~~ DRILL DRLG SURFAC 11.0 I ~I 'Sliding 1.75 hrs ', Rotating 2.94 hrs. ~, :Total Drilling 4.69 hrs. ', I !~ 'Circulating and back reaming 2.31 hrs. ',Average ROP 95.73'/hr I~, ' Slow Pump Rates: ~ I ', #1 30spm-120psi, 40spm-180psi ', ' I #2 30spm-120psi, 40spm-190psi ' ' ' " 3/3/200600:00 - 12:00 12.00 DRILL DRLG INTRM1 -U4780 ~, Continue to drill ahead 8.5 hole section f/3931 , ', ~ ~~ 1 Drilling parameters: 7,000#-10,000# WOB, 2 x 60 spm w/480-524 gpm ', ~ ,flow rate, SPP 1700-1750 psi, 150 rpm, 5,000-6,000 fUlbs torque. Running all solids control equipment to maintain MW of 9.6 ppg, and '~ ' '~ hold ECD to 11.0 '.12:00 - 21:00 PUW-120K, SOW-95K, ROTW-108K SPP on Bottom 1700 psi, Off Bottom 1640 psi Continue to drill ahead 8.5" hole secton f/4780'-U5440', Drilling parameters: 7,000#-10,000# WOB, 480-524 gpm flow rate, SPP 1750-1780 psi, 150 rpm, 5,000-6,000 fUlbs torque. Running all solids control equipment to maintain MW of 9.6 ppg, and hold ECD to 11.0 ECD-11.3 21:00 - 22:00 i 1.00 22:00 - 00:00 II 2.00 Operations Summary Report DRILL CIRC INTRM1 DRILL TRIP I'i INTRMI Circulate bottom up 3X's, w/116 spm, @1790 psi, 4,000 fUlbs torque, 150 rpm, rotate and recipricate string. Flow check, pump out of hole f/5440' on wiper trip U3451', 9 5/8" csg shoe, no over pull, no pack off, no problems, hole in good shape. ', PUW-125K, SOW-102K, ROTW-112K L Pressure on bottom 1800 psi, off bottom 1770 psi, ',Torque on bottom 6,000 fUlbs, off bottom 5,000 fUlbs 3/4/2006 ' 00:00 - 00:30 00:30 - 01:30 01:30 - 12:00 0.501 DRILL 1.00 DRILL 10.50 DRILL DRLG ~ INTRM1 TRIP ' INTRM1 DRLG ' INTRM1 Slow pump rates: #1 30 spm-200 psi, 40 spm-280 psi #2 30 spm-200 psi, 40 spm-300 psi Circulate bottoms up @3450',w/115 spm, 486 gpm, and 1,590 psi SPP, 70 RPM, 4,000 fUlbs torque. RIH at a controlled rate, not to serge well, preventive washed and reamed last stand to bottom f/5344'-U5440', Parameters: 2 x 60 spm, w/500-508 gpm, wl150 rpm, 3800-4200 fUlbs torque, no fill, no problems getting to bottom. Continue to drill ahead 8.5" hole section at a controlled ROP f/5440'-U6189', and controlling ECD's, before each connection backream stand 2 x's to help clean hole. On bottoms up 75 units of gas. Drilling Parameters: 2 x 60 spm, 500-508 gpm flow rate, 150 rpm, 5,000-10,000# WOB, 6,000-7,000 fUlbs torque, 2,000-2,100 SPP. Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Page 5 of 12 Legal Well Name: 2N-333 Common Well Name: 2N-333 Spud Date: 2/25/2006 Event Name: ROT -DRILLING Start: 2/24/2006 End: 3/18/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To ,Hours Code Code Phase '~, Description of Operations 3/4/2006 'i 01:30 - 12:00 '; 10.501 DRILL DRLG ~ INTRM1 Slow Pump Rate: @ 5906' MD, 3270' TVD 12:00 - 00:00 'i 12.00 I I 3/5/2006 100:00 - 07:30 ' 7.50 07:30 - 08:30 I 1.00 08:30 - 11:00 ', 2.50 11:00 - 12:00 ' 1.00 12:00 - 00:00 3/6/2006 ', 00:00 - 04:30 L 04:30 - 05:00 '~ 05:00 - 07:00 07:00 - 07:30 !#1 Pump 30 spm @250 psi, 40 spm @350 psi #2 Pump 30 spm @210 psi, 40 spm @300 psi DRILL DRLG INTRMI Contunue to drill ahead 8.5" hole section f/6189'-U7075', controlled !drilling to maintain ECD below 11.8, backreaming 2 x's before each connection. Drilling Parameters: 2 x 60 spm, 500-508 gpm flow rate, 150 rpm, 5,000-10,000# WOB, 6,500-9,500 fUlbs torque, 2,050-2,100 psi SPP. DRILL DRLG INTRM1 Contunue to drill ahead 8.5" hole section f/6189'-U7075', controlled I ',drilling to maintain ECD below 11.8, backreaming 2 x's before each connection. @7,200' Pumped 40 bbl Hi-Vis sweep to help clean hole, as sweep reach surface there was an increase in cutting observed at shakers. "Drilling Parameters: 2 x 65 spm, 500-550 gpm flow rate, 160 rpm, 7,000-12,000# WOB, 7,500-10,500 ft/Ibs torque, 2,050-2,100 psi SPP. DRILL i CIRC INTRM1 Circulate bottom up 2 x's w/500 gpm, @1970 psi, 150 rpm, while 'recipricating DP. DRILL TRIP ~ INTRM1 !Flow cheat, uw311 static, Pumped out of hole f/7408'-U5340', rotating DP i w/50 rpm, 350 gpm. DRILL TRIP INTRM1 Fbw check, weltstatic, Blow down TDS, and lines, RIH 1/7316', j preventive washed and reamed to bottom 7408'. ;Slow pump rates: @7409' MD, 3802' TVD #1 pump 30 spm, @ 280 psi, 40 spm, @ 400 psi ', #2 pump 30 spm, @ 290 spi, 40 spm, @ 390 psi 12.00', DRILL DRLG INTRM1 !Continue to drill ahead 8.5" hole section f/7408'-U8270', pumping 40 bbl !, sweeps every 500' to help clean hole while drilling. @ 7,920' Pumped i another 40 bbl Hi-Vis sweep, and very little increase in cutting were ~ '~ observed at shakers. 2% Lube 776 and Lubetex added in active system ' ', to reduce torque and drag. ', 'I !, Drilling Parameters: 2 x 70 spm, 592 gpm flow rate, 160 rpm, L 8,000-15,000 WOB, 7,500-10,500 fUlbs torque, w/2,000-2,100 psi SPP. 4.50, DRILL DRLG INTRM1 ~I Continue to directionaly drill ahead 8.5" hole fl8,270'-U8,55T, n a i, ,drop in SPP, drill pressure had been 2,150-2,275 psi, and drop to ~, 1,800-U1,875 psi. Stop drilling and checked off bottom circulating ~ pressure 1,800 psi, took slow pump rates, 30 spm-250 psi, 40 spm-275 ~i ~ psi, this was a drop in pressure of 25-30 psi. Checked all surface I i I I ~ equipment, OK i I Drilling Parameters: 2 x 70 spm, 592 gpm flow rate, 160 rpm, 8,000 #-15,000# WOB, 7,500-10,500 fUlbs torque, w/2,150-2,275 psi SPP. 0.5011 DRILL ii CIRC INTRM1 I Circulate bottoms up, @ 500 gpm, w/150 rpm, and recipricated drill 2.00 DRILL TRIP ' I INTRM1 string. Flow check, well static, PJSM, start to pump out of hole f/8,536' looking , ~ for wash out in drill string 0.50 DRILL ', TRIP INTRM1 Pumped out of the hole 1/7,569' found out3oint,Ud single, and ', II P/u i;< M/u single, blow down TDS, and lines. Printed: 4!21!2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Page 6 of 12 Legal Well Name: 2N-333 Common Well Name: 2N-333 Spud Date: 2/25/2006 Event Name: ROT -DRILLING Start: 2/24/2006 End: 3/18/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To 'Hours Code 'Sub '~ Phase ' Description of Operations : Code DRILL I TRIP !INTRMI ,RIH f/7,569'-U8,536', preventive wash and ream last stand to bottom 3/6/2006 07:30 - 08:00 0.50 ~ ~~, ' 8,557, no problems, no fill. 08:00 - 12:00 4.00'x, DRILL DRLG ', INTRM1 ',Continue to directionaly drill ahead 8.5" hole section f/8,55T-U8,954'. Drilling Parameters: 2 x 70 spm, 592 gpm flow rate, 96% efficiency. 9,000#-15,000# WOB, 9,500-10,800 fUlbs of torque, w/2,250-2,400 psi SPP, 160 RPM. 12:00 - 15:30 3.5011 DRILL ' DRLG INTRM1 I 15:30 - 16:00 ' 0.501 DRILL DRLG I! INTRMI 1,16:00 - 17:00 1.00 DRILL ~~TRIP INTRM1 II 17:00 - 18:00 '', 1.00 DRILL ~~!TRIP ! INTRM1 18:00 - 18:30 0.50 DRILL =TRIP INTRMI 18:30 - 00:00 5.501 DRILL DRLG INTRMI I 3/7/2006 00:00 - 04:30 i I ~Ii 04:30 - 06:30 i 06:30 - 12:00 ', 5.50 12:00 - 13:30 1.50 I 13:30 - 14:30 I, 1.00 ',.14:30 - 16:00 4.50'', DRILL ' DRLG ~ INTRMI I !i 2.00'' DRILL iCIRC ICI INTRM1 DRILL TRIP ', INTRM1 DRILL ',TRIP '':,INTRMI DRILL ',TRIP ',INTRM1 1.50 DRILL TRIP INTRM1 i Slow pump rates: @ 8,910' MD, 4,326' ND, MW 9.6 ppg #1 pump= 30 spm-290 psi, 40 spm-400 psi. #2 pump= 30 spm-305 psi, 40 spm-400 psi. Contanue to directionaly driN ahead 8.5" hole section f/8,954'-U9,243', wher- stand pipe pressure drop ofF, SPP was running around 2,450 psi, and dropped to 2,100 psi. 'Drilling Parameters: 2 x 70 spm, 592 gpm flow rate, 96% efficiency. 9,000#-15,000# WOB, 10,500-12,800 fUlbs of torque, w/2,350-2,500 psi '.SPP, 160 RPM. Trouble shoot surface equipment and found no problem, picked up off 'bottom and recored pressure 1,950-2,000 psi, check slow pump rates ,and found a drop of 30-40 psi. Flow check, PJSN9, PO(?t! ir-,pump out made f/9,243' looking for wash out in driN string: Found wash out ~ 8,467' in tube body. Lay down single, and pick up and make up single. Blow down TDS, and lines. RIH at a controlled rate, not to surge well, 88,467'-U9,191', and preventive washed and ream last stand U9,243', no problems, no fill. Resumed directional drilling 8.5" hole section, f/9,243'-U9,670' Drilling Parameters: 2 x 70 spm, w/ 592 gpm, @ 2,400-2,550 psi, 11,000-13,500 fUlbs of torque, 10,000#-15,000# WOB, 160 rpm Continue to directionaly drill 8.5" hole section f/9,970'-U10,029', maintaining ECD's 10.8-11.2. Drilling Parameters: 130-150 rpm, 2x70 spm, 593 gpm flow rate, 1,10,000#-16,000# WOB, 13,000-16,000 fUlbs torque, 2,400-2,600 spi SPP. 1 Pump 40 bbls Hi-Vis sweep, and Circulated 2 x's bottoms, while ', recpricating drill string, w/ 150 rpm, and 580 gpm flow rate, and 2,500 psi SPP. Flaw check for 1 S min, well static, POOH in pump out mode, w/ 350 -:.gpm flow rate, and 1,500 psi SPP, back reaming w/ 50 rpm, f/ 10,029'-U4,475', no problems, no tight spots, no overpull, no packing loll. ';Continue to pump out to 9 5/8" casing shoe, f/4,475'-U3,451', using 350 ,gpm, and backreaming with 50 rpm, no problems. ', Flow check at shoe, well static,;circulate annular casing volume w/ 50 '1 rpm, and 450 gpm flow rate, 3,000 fUlbs of torque, @ 1,190 psi SPP. Continue to pull out of hole f/3,451'-U800', string pulling wet, standing back HWDP, and flex collars. Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Page 7 of 12 Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Spud Date: 2/25/2006 Event Name: ROT -DRILLING Start: 2/24/2006 End: 3/18/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Group: Rig Name: Doyon 14 Rig Number: Date From - To 'Hours ' Code Sub ~ Phase Description of Operations 3/7/2006 123:30 - 00:00 '' 0.50 --- - Code 16:00 - 16:30 0.50' DRILL ~ITRIP i 16:30 - 20:30 4.00! DRILL I TRIP I, 20:30 - 23:30 I 3.00'.; DRILL 'TRIP 3/8/2006 !.00:00 - 01:30 1.50 01:30 - 03:00 i 1.50 03:00 - 03:30 0.50 03:30 - 06:00 2.50 ~I 06:00 - 09:30 3.50 12.00 Parameter: 2 x 60 spm, 508 gpm flow rate, 120 rpm, 8,000-9,000 fUlbs of torque, and 2,000-2,600 psi SPP. While washing and reaming last stand, hole started packing off, SPP increased up to 2,600 psi, had to pull out of hole (/9,936'-U9,843', in pump out mode, w/ 120 rpm. SPP dropped to 1,800 psi, RIH and continue to preventive washed and reamed f/9,843'-U10,029', without any problem, no fill. Continue to directionaly drill ahead 8.5" hole section, f/10,029'-U10,180', Mi mud enginee adding Lubetex, and Lube 776 pills to help reduse torque, up to 3% in active system. Drilling Parameters: 2 x 60 spm, 508 gpm flow rate, 120 rpm, ',15,000-17,000 fUlbs torque, 2,400-2,650 psi SPP, 2,000#-5,000# WOB INTRM1 ~, PJSM, LWD Engineer pulled sources. INTRMI 'Download MWD, and inspect Geo Pilot, and bit, OK INTRM1 'Pick up and make up BHA#4,Change out Pulsar, and upload MWD, surface test, OK INTRM1 PJSM, Load sources, RIH BHA #4, RR Security FSF2565, Geo-Pilot ':7600, Geo-Fle DM Collar, Smart Blade Stabilizer, MWD-GR/RES/PWD, 'Smart Blade Stabilizer, MWD-HCIM, ', MWD-SLD/CTN, MWD-TM HOC, Non-Mag Float Sub, 3 X Non-Mag Flex Drill Collars, 12X HWDP, Hyd. Drilling Jar, 5X HWDP. INTRM1 ~ Continue to RIH w/HWDP, and M/U Hyd. Jars U2,62T. INTRM1 ', PJSM, Cut and slip drilling line, (59.5'), Kick drill. INTRM1 Lubricate TDS, and lubricate crown, and traveling blocks. INTRM1 Continue to RIH at a controlled rate, being careful not to serge well, and ii filling drill pipe every 5 stands, f/2,62T-U9,936', started preventive washing and reaming last stand to bottom. I NTRM 1 09:30 - 12:00 ', 2.50 j DRILL TRIP ,INTRMI i i '' 12:00 - 00:00 DRILL 'TRIP DRILL TRIP DRILL iTRIP DRILL !.TRIP DRILL TRIP I I DRILL TRIP DRILL DRLG (INTRMI ii 'Deflection=1.66 SPR Pump #1 30 spm-280 psi, 40 spm-370 psi Pump #2 30 spm-270 psi, 40 spm-380 psi Measured depth 10,119' TVD 4,759', MW 9.6 ppg 'Continue to directionaly drill ahead 8.5" hole section f/10,180-U10,68T, Note: At bit dep#h 10,596' TVD 4,998', welt started flowing, and. while drilling doom stand Mi mud engineer-was weithing up mud to try to stabile well. Note: at 10,567' MD, TVD 5,OtfT' took surve}r, w~ started fkawing, MW 9.6 ppg, continue to driN dcwm while increasing mud weight, in 0.2 Ppg incremerits, backgrownd gas 1;900 units, Max get 2dOtl units. 3/9/2006 00:00 - 09:30 09:30 - 15:30 Drilling Parameters: 2 x 70 spm, 593 gpm flow rate, 120 rpm, i I i ~ 18,000-20,000 fUlbs torque, 2,500-2,850 psi SPP, 2,000#-3,000# WOB. 9.501I~ DRILL ~,~ CIRC INTRM1 ~I, Continue to circulate while weighting up active system f/9.9 ppg to 11.0 I ~ ppg, recpricating drill string with 110 rpm, 2 x 70 spm, 600 gpm flow ~ i 'j rate, 2,300-2,600 psi SPP, (Tofat pit<~ain in 9.5 hrs; 50 bbls) 6.00 ~I, DRILL DRLG jl~ INTRMI ~ Continue to directionaly drill f/10,68T-U10,874', w/2 x 70 spm, 600 gpm ~~ ~, flow rate, 2,400-2,650 psi SPP, 17,500-19,750 fUlbs of torque, 120 rpm. Note: Background gas running in the range of 1,700-1,950 units, 4-5% ~I oil cut mud. Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date From - To 'Hours :Code Code Phase 3/9/2006 3/10/2006 15:30 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 00:00 ' 00:00 - 12:00 Page 8 of 12 Spud Date: 2/25/2006 Start: 2/24/2006 End: 3/18/2006 Rig Release: 3/18/2006 Group: Rig Number: Description of Operations Stop drilling, started circulating bottoms up, w/ 570 gpm flow rate, at 2,350 psi SPP, 110 rpm, w/ 14,000 ftllbs torque, and weighting up '; active system to 11.2 ppg throughout. Nobs: (~rotslemis in the ;mud weight constant u~ut scti5re system, oil content rising as we drilled through the reservoir. On well pad a request was`to shuYin all ',injectors around welt. Continue to directionaly drill f/10,874'-t/1Q,921', w/570 gpm flow rate, at 2,350 psi SPP, 110 rpm, w/ 18,275 ft/Ibs of torque, 2,000 WOB. Stopped drilling due to pump decrease f/2,350-t/2,050 psi, and increase in flow out, and .pit volume gain, 4 bbls. j Shut annular preventer, to control well, record pressures, drill pipe ~ I psi, casing 130, after 15 min shut in drill pipe 230 pci, casing 330 psi. Start kill operation, bring #1 pump up to slow pump rate, 210 psi on drill ;pipe, and 240 psi on annular, pumped bottoms up and no gas bubble to .surface, only gas cut oil. Note: during bottoms up and watching returns, mud saturated with oil, after mud check chlorides went from 500 mg/1, to 5,000 mg/I. Continue to try to weight up mud to 11.2 ppg, no ',success, mud coming back diluted. Mud enginee having to dump excess mud and haul off, while trying to weight up active. Well was !.always in control, no spills, no leaks. Total dumped 400 bbls Mixed new mud 160 bbls !Influx est: 240 bbls Deflection-4.2, Art-0, ECD-11.2 KILL it INTRMI Continue to circulate oil saturated mud through choke manifold, while i 'trying to weight up mud with MI Bar. MI mud Engineer testing mud 'contacted WSL, and onsite Conoco/Phillips Rep. and informed that the mud was saturated with 10% oil cut, and could not hold any of the MI ~ ', Bar we were adding to weight up, it was falling out. Max weight 11.4 ppg. The decision was made to dump entire active system and bring in 'clean and new mud, with 12.1 ppg, total 1,100 bbls. While circulating, 'empty active pits 3,4 and 5, and cleaned. 'Take on clean mud off trucks and filled pits 3,4, and 5. ,And waiting on the rest of the mud to come from MI mud plant. Recpricating drill string every 15 min. ~ ',Circulating with 30 spm, 560 psi DP pressure being held to hold back I~ 'influx of oil. 12:00 - 19:00 ' 7.00 WELCTL;! KILL 1.00 _ _ ~ _ _ ---- DRILL CIRC ~~ INTRM1 1.00 DRILL DRLG INTRM1 ~I 0.50 WELCTL KILL I INTRMI 6.001 WELCTL. KILL INTRMI 12.001 WE INTRM1 3/11/200600:00 - 05:00 ', 5.00 WELCTL,, COND I INTRM1 'Continue to circulate through choke, holding back pressure on choke. Offload 550 bbls of fresh mud, 12.1 ppg. PJSM, Shut well in and got 'reading on DP 210 psi, annular 280 psi, filled out kill sheet, and started ',pumping clean 12.1 mud down drill pipe, dumping returns to rock ', washer pit and hauling off. At report time the drill pipe pressure 290 psi, ,and annular 40 psi, pumping with 30 spm, 127 gpm flow rate, choke ~i 100% open, mud weight in 12.1, out 11.5 ppg. ', Continue to circulate through choke wl30 spm, 127 gpm flow rate, I, holding back pressure on drill string 310 psi, w/ choke fully open, and annulus 40 psi. jAfter 1st complete circulation, and displacing well bore and active with Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date From - To Hours 3/11/2006 I~ 00:00 - 05:00 ~I I ~~ 05:00 - 06:00 I 06:00 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:00 ~' 09:00 - 10:30 3/12/2006 ''..10:30 - 12:00 !..12:00 - 20:30 ' 20:30 - 22:00 22:00 - 00:00 00:00 - 03:30 03:30 - 04:00 ' 04:00 - 06:30 106:30 - 08:00 08:00 - 09:30 !.09:30 - 12:30 5.00 Code 'Code ''. Phase __ --- vELCT~ COND INTRM1 1.00 WELCTL~ OBSV ', INTRM1 1.00 ii DRILL ~, CIRC ' INTRM1 1.00 DRILL CIRC 0.50 DRILL CIRC 0.50 DRILL IITRIP i 1.50 DRILL ~ CIRC 1.50 DRILL I, CIRC i 8.501 DRILL ~~CIRC 1.501, DRILL I CIRC ' I 2.0011 DRILL I CIRC 3.50'1 DRILL ~ CIRC INTRM1 INTRMI INTRM1 INTRM1 INTRMI Page9of12 Spud Date: 2/25/2006 Start: 2/24/2006 End: 3/18/2006 Rig Release: 3/18/2006 Group: Rig Number: Description of Operations 12.1 ppg, returns 11.7 ppg, had to start adding MI Bar to active to raise mud weight, while starting the 2nd circulation of active. Pumping 30 spm, 127 gpm flow rate, w/310-340 psi, annulus 40 psi, choke wide open. After a complete circulation mud weight in 12.1 ppg, and mud weight out 12.1 ppg. Stop circulating, observed drill pipe pressure and annular pressure, both 0 psi, open annular bag preventer. Flow check for 30 min, well static. Start slowly circulating well with 30 spm, 168 gpm flow rate, 320 psi SPP, 35 spm, 148 gpm, 360 psi SPP, 40 spm, 440 psi SPP, 45 spm, 520 psi SPP, while working drill string, slowly increased pump rate to 50 spm, 211 gpm flow rate, 620 psi SPP, begin rotating string w/ 20 rpm, 14,000-15,000 fUlbs torgue. Slow pump to 40 spm, 169 gpm flow rate, 520 psi SPP, because of losses, total losses 14 bbl/hr, continue to lose mud slowed pumps to 35 spm, 148 gpm flow rate, 445 psi SPP. Continue to slow pumps down to 25 spm, 105 gpm flow rate, 380 psi SPP, while moving string, continue to lose mud, MI mud engineer begin to mix a 40 bbl LCM pill, w/15 Ib/bbl. Slowly pulled out of hole with 1 stand and set back in derrick, while waiting on LCM pill to be mixed. Monitor well for losses or gains. No flow, bit depth 10,876' MD. Pump 30 bbls of 15 Ib/bbl LCM pill, 25 spm, 105 gpm flow rate, 380 psi SPP. Spot LCM pill on bottom, 10,876' MD, work string 35' while pill soaked. Total losses 184 bbls. INTRM1 Circulated with 25 spm, 105 gpm flow rate, with 410 psi SPP. INTRM1 Mixed and pumped a 80 bbl, 30 Ib/bbl, LCM pill, pumped with 25 spm, 105 gpm flow rate, with 410 psi SPP, and displaced in to annulus, ~~ 2,000', and let soak. INTRMI I While waiting on LCM to soak in annulus, work drill string, and pump ~I 100 strokes to keep the TDS, and stand pipe from freezing. i Total losses 60 bbls in 12 hrs. INTRM1 0.50 ~, DRILL ' OBSV ~ INTRM1 2.50 !, DRILL 'CIRC INTRM1 1.50 DRILL CIRC INTRM1 1.50 ~ DRILL !REAM INTRMI 3.00~1~ DRILL iCIRC INTRM1 Slow pump rate: #1 30 spm-460 psi, 10,850' MD, 5,211'TVD. Circulating, and reciprocate string, with 25 spm, 106 gpm flow rate, with 420 psi SPP, and moving drill string 60' every 15 min, and slowly started rotating string with 5-10 rpm, with 19,000-20,000 fUlbs torque, and slowly reciprocating string 60' and increasing to 90'. Bit depth at 10,876', up weiht 155,000#, down weight 149,000#. Slowly started increasing pump rate, f/25 spm, U28 spm, and U30 spm, 127 gpm flow rate, @ 445 psi SPP, torque dropped off to 17,000-18,500 ft/Ibs. Shut annular preventer to check annular pressure, 20-25 psi, after 10 min., bleed off pressure, open annular bag preventer. Circulate BU 25 spm, 106 gpm flow rate, and 420 psi SPP. Flow check-OK- Pump 80 bbl LCM pill w/ 32 # per bbl concentration and spot at bit- 25 spm 380 psi- Pump 10 bbl out. Flow check- OK- No gains or losses during operation. Pump & backream out of hole- Stringing LCM pill out w/ 17 spm 200 psi f/ 10,876 to 9,935'. Correct hole fill during operation. Monitor well- Circulate BU w/ 35 spm (148 gpm)- Rotate 40 rpm- No Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Start: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Rig Name: Doyon 14 Rig Number: Date From - To 'Hours ' Code 'Sub Code 3/12/2006 09:30 - 12:30 12:30 - 14:30 14:30 - 17:00 I I I~~ 17:00 - 18:00 ~I 18:00 - 19:00 19:00 - 21:00 I it 21:00 - 21:30 21:30 - 00:00 3.00! DRILL ~I CIRC 2.00'x, DRILL REAM 2.501 DRILL REAM 1.00! DRILL REAM 1.00 2.00 0.50 2.50 3/13/2006 ! 00:00 - 01:30 01:30 - 02:00 'I 02:00 - 07:00 07:00 - 08:00 !; ~I 08:00 - 11:00 j i ~ 11:00 - 11:30 'I ~I 11:30 - 12:00 it 12:00 - 14:30 ~ 14:30 - 15:30 15:30 - 16:30 1.50 DRILL CIRC DRILL REAM DRILL ~, REAM DRILL ', REAM Page 10 of 12 Spud Date: 2/25/2006 End: 3/18/2006 Group: Phase ', Description of Operations INTRM1 'losses or gains during operation. INTRM1 Pump &backream out of hole w/ 35 spm 350 psi- 40 rpm 15,000-16,000 fUlbs of torque. Pulled 9 stands and found washout in '.joint # 2 on stand #19 (approx. depth 1,700' when on bottom). INTRM1 'Circulate bottoms up at 8,990', w/ 30 spm 610 psi. Getting heavy mud coming back due to bar settling in hole. Max. weight 12.9 ppg.- Max. !, back ground gas 1,050 units at bottoms up, continue to circulate until mud weight consistant in and out with 11.7 ppg. Note: Flow check- OK- MW in 11.8 ppg and increased to 12.0 ppg, back ground gas return to ',130 units, after mud weight was lowered. INTRMI Pump 8~ backream out of hole with 25 spm, 127 gpm flow rate, 360 psi SPP, mud weight in 11.7 ppg, out 11.8 ppg, as string was being pumped out and backreamed, all the MI Bar, weight material is being mixed into active system, and causing the returns to increase to 12.0+ coming out of the hole, and a increase in of stand pipe pressure, 540 psi. INTRM1 Circulate to condition mud @8,237', turn on solid control equipment, ~ and decrease mud weight, f/12.0+ down to 11.8 ppg. Note: MI Bar blanking off screens, packed off centrifuge. INTRM1 Pump &backream out of hole with 25 spm, 127 gpm flow rate, 360 psi SPP, mud weight in 11.7 ppg, out 11.8 ppg, as string was being pumped out and backreamed, all the MI Bar, weight material is being mixed into active system, and causing the returns to increase to 12.0+ coming out of the hole, and a increase in of stand pipe pressure, 540 psi. INTRM1 Circulate to condition mud @7,308', turn on solid control equipment, and decrease mud weight, f/12.0+ down to 11.8 ppg. INTRM1 i Continue to pump out &backream out of hole with 25 spm, 127 gpm flow rate, 360 psi SPP, mud weight in 11.7 ppg, out 11.8 ppg, as string was being pumped out and backreamed, @ 6,886' DRILL ', REAM I INTRMI 0.50' DRILL ~I CIRC ICI INTRM1 5.00: DRILL 1.00' DRILL 3.OO DRILL 0.501 DRILL 0.50 DRILL 2.50 DRILL 1.00 DRILL 1.OO DRILL REAM ;INTRMI CIRC INTRM1 REAM 'JNTRM1 CIRC (INTRMI TRIP ' INTRM1 PULD (INTRMI PULD IINTRM1 PULD INTRMI !i Total losses last 24 hrs. 11 bbls Continue to POOH in pump out mode, f/7,036'-U6,110', w/30 spm, 30 rpm, and 127 gom flow rate, and 340 psi SPP, watching mud weight, 11.8 ppg going in and out. At 6,110' mud weight coming out 12.0+ ppg, i stop POOH. Circulate w/ 30 spm, and 127 gpm flow rate, 380 psi SPP, @ 6,110', to 'reduce mud weight, f/12.0+ down to 11.8 ppg. Continue to POOH in pump out mode, f/6,110'-U3,364', w/35 spm, and '.148 gpm flow rate, w/ 30 rpm,and 380 psi SPP At 95/8" shoe, flow check. for 10 min, welt static Break circulation w/38 spm, and 158 gpm flow rate, 280 psi SPP, circulate bottom up. Max gas 150 units. Continue to POOH in pump out mode (/3,364'-U1,864', w/ 30 spm, and ;127 gpm flow rate, 240 psi SPP. ;Blow down TDS, and stand pipe, pulled pipe wet f/1,864'-t/73T, Flow 'check, well static. POOH and stand back in derrick all 5" HWDP and Hyd. Jars. PJSM, Stand back collars, and Break out and L/d BHA, and remove (sources, down load MWD. ~I Continue tt) Lhi ".f~lep~'ikst; mac! bit: i PJB, P/u 8rid M/u BHA#5, and RR Bit, without any jets, near bit stabilizer, 2 x drill collars, Mtergaj blade stabilizer, 12 x HWDP, drilling Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Contractor Name: d14cm@conocophillips.com Rig Name: Doyon 14 Date 3/13/2006 3/14/2006 3/15/2006 From - To Hours Code II Code - - - ~ _ - 15:30 - 16:30 III 1.00 DRILL PULD 16:30 - 19:00 2.50 DRILL TRIP 00:00 - 04:00 i 04:00 - 09:00 4.001 DRILL ~ REAM 5.001 DRILL 'CIRC 09:00 - 10:30 10:30 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01:30 01:30 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 11:00 11:00 - 11:30 1.501 DRILL (TRIP Phase INTRMI jars, 5 x HWDP. INTRM1 RIH slowly to 95!8" shoe, break circulation w/ 30 spm, 127 gpm flow cafe, 280 psi SPP, continue to RIH breaking circulation every 15 stands, f/3,452'-t/9,098', no problems. INTRM1 INTRMI INTRMI Page 11 of 12 Spud Date: 2/25/2006 Start: 2/24/2006 End: 3/18/2006 Rig Release: 3/18/2006 Group: Rig Number: Description of Operations 'Total losses 83 bbls. '~~ Kick drill @ shoe, 20 sec. !Continue to RIH slowly f/9,098'-t/10,600', break circulation w/ 30 spm, 127 gpm flow rate, 280 psi SPP, preventive wash and ream to bottom, ', no fill, no problems ;Circulate on bottom w/30 spm, 127 gpm flow rate, 480 psi SPP, and 'slowly increase flow rate to 254 gpm, 690 psi SPP, while circulating at 60 spm, average losses started out being 60 bbls/hr average- Encountering heavy mud weights (12.0-12.5 ppg)- At bottoms up BG 'gas 1750 units max.- Losses slowing- slowly increase flow rate 5 spm 'increments. Reached 85 spm (357 gpm) with losses dropping below 10 bbls/hr- Mix & pump 100 bbl LCM pill w/ 30# per bbl concentration- Spot ~ at bit + 10bbls out. Total losses while circulating 65 bbls. Flow check f/ 15 min.- Pump &backream out w/ 30 rpm 15k torque- ': Pump w/ 23 spm stringing LCM pill f/ 10,921 to ?9900'. PU wt 235k- SO 115k- 7 bbls fill f/ 10 stds. Flow check- OK 'Continue to pump &backream out of hole- Increase flow rate to 5 bpm 520 psi- String40 bbl Lube & "G" seal pill out at ?8200' & ?6000' while ICI pumping out Con't Pump out to BHA @644' LD BHA -HWDP -Jars -Collars -Bit j Clear rig floor -Pull wear ring -Install test plug 'Change out top VBR's to 7" casg rams 'Change Top rams to 7"- Test door seals to 1500 psi f/ 15 min. I PJSM- RU & run 4 1/2" 12.6# IBT tubing- 653' pipe I Circ. pipe volume+ RD 4 1/2" equip.- RU 7" equip. 'I PJSM- on running 7" casing Service rig ~i PU 4 1/2" XO w/ seal bore ext. & 7" pup jt.- Run 7" casing to 2200' ',Circ. w/ 50 spm (257 gpm) 510 psi- MW coming back 11.5- BG gas max-2000 units-Circ. BU ~~ Run 7" casing to 9 5/8" shoe at 3451' !,CBU at shoe- Max BG gas 1700 units ~~ Continue running 7" casing- Break circ. every 1000' to 6448' -Ran ~'11400' to 7848' -Break circulation lost 14 bbls on bottoms up -Ran 600' ~, to 8455' break circulation lost 28 bbls on bottoms up -Run 7" casing to 9562'-Total static gain 15 bbls-Total circulating losses 42 bbls. Continue circ. BU- 35 spm (150 gpm) 550 psi -Lost 36 bbls on bottoms up Run 7" casing f/ 9562' to 10,271" ~I Circ. BU- 35 spm 550 psi ~1 Run 7" casing f/ 10,271'- to 10873 - PU landing jt.- Pump 32 bbl LCM pill- Circ. last joint down to 10,908' w/ 32 spm (133 gpm) 550 psi CBU - 32 spm 520 psi RD Franks tool- RU cement head ~I Break circ. slowly 8, increase to 4 bpm (40 spm )- Losing mud- Approx. 60% of normal returns. Hold PJSM w/ all personel involved in cement ~, operation.Approx. losses prior to cementing, 170 bbls. 10.00 DRILL ' TRIP ! INTRM1 1.50 DRILL 1.00 DRILL 1.00 WELC 1.501 DRILL 2.50 CASE 0.50 CASE 1.50 CASE 0.50 CASE 0.50 ~ CASE 4.00 I~ CASE 0.501 CASE PULD PULD EORP OTHR PULR CIRC RURD SFTY OTHR RUNC CIRC INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRMI 11:30 - 13:00 I 1.501 CASE I RUNC ',INTRMI 13:00 - 13:30 ~i, 0.50 CASE i CIRC ,INTRMI 13:30 - 00:00 ~' 10.50 CASE I RUNC 'INTRMI 3/16!2006 100:00 - 01:00 ~I 01:00 - 02:00 02:00 - 02:30 ~~, 02:30 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 07:00 1.001, CASE I CIRC ', INTRM1 1.00 CASE RUNC '' INTRM1 0.50, 1.00 ~I CASE CASE CIRC I RUNC !INTRMI ',INTRMI 1.5011 CASE CIRC i INTRM1 0.50 ~I CEMEN RURD ; INTRM1 1.501 CEMENTCIRC 'INTRMI Printed: 4/21/2006 8:23:14 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2N-333 Common Well Name: 2N-333 Event Name: ROT -DRILLING Start: 2/24/2006 Contractor Name: d14cm@conocophillips.com Rig Release: 3/18/2006 Rig Name: Doyon 14 Rig Number: Date From - To 'Hours Code ', Sub 3/16/2006 ''...07:00 - 07:30 ' 07:30 - 08:00 ', II ',I 08:00 - 09:30 ! 09:30 - 10:30 10:30 - 12:00 .12:00 - 12:30 ! !,12:30 - 14:30 '', !,14:30-16:00 j I~ 16:00 - 17:30 ;17:30 - 00:00 ' 3/17/2006 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 ! 06:00 - 16:30 ', 16:30 - 18:00 Il I 18:00 - 21:00 '~ '.21:00 - 21:30 ! 21:30 - 00:00 ~, 3/18/2006 ', 00:00 - 02:00 ! , 02:00 - 02:30 !~ 02:30 - 03:00 ~I !, 03:00 - 03:30 I i 03:30 - 04:30 ! 04:30 - 05:00 ', 05:00 - 06:00 Code 0.50 CEMENTSEOT 0.50; CEMENTPUMP 1.501 CEMEN DISP I I 1.001 CEMENT PULD 1.50 CEMEN PULD 0.50 WELCTL EORP 2.00! WELCT EORP 1.50 ~ DRILL !!PULD 1.50' RIGMNT!, RSRV 6.50 DRILL j PULD 4.00', DRILL ', PULD 1.50 CMPLTN' DEOT I 0.501 CMPLTN RURD 10.50' CMPLTN RUNT 1.50!. CMPLTN SOHO 3.00' CMPLTNI OTHR ~~ 0.50 ! CMPLTN SEOT 2.50' CMPLTN NUND 2.00', CMPLTN NUND 0.501 CMPLTN SEOT 0.50' CMPLTN FRZP 0.50'! CMPLTN FRZP 1.00 CMPLTNI, FRZP I 0.50 1.00 Phase INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 I NTRM 1 INTRM1 INTRMI INTRM1 INTRM1 INTRM1 CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN CMPLTN !CMPLTN 'CMPLTN 'CMPLTN CMPLTN CMPLTN CMPLTN.OTHR CMPLTN CMPLTN OTHR CMPLTN Page 12 of 12 Spud Date: 2/25/2006 End: 3/18/2006 Group: Description of Operations ', Line up Dowell- Pump 5 bbls H2O- Test lines to 3000 psi '~ Pump 40 bbls 12.0 ppg mud push- 4 bpm 475 psi w/ 80% normal !I returns- Pumping cement w/ 5 bpm- 64 bbls (yield 1.17 cf/sk) 15.8 ppg I Class "G" GasBLOK cement w/ following additives; D047 .20 gal/sk- !, D065 .350% BWOC- B155 .010% BWOC- D600G 2.0 gal/sk- Drop top plug & kick out w/ 5 bbls H2O. Pumped cement w/ 80-90% of normal I~ireturns. Displacing cement w/ rig pumps- 9.9 ppg NACL-6 bpm 375 psi- catch !cement & displacing w/ 4.5 bpm w/ full returns- Reciprocate pipe ! through out cementing & displacing operations. Observe top plug enter 4 1/2" tubing w/ 384 bbls pumped- Bump plug w/ 394 bbls pumped. Bump plug w/ 1800 psi (500 psi over final circ. press.)- CIP at 09:30. Hold for 10 min.- Bleed off & check floats-OK- NOTE: Float collar at 10,844'- Shoe at 10,908' ~I RD casing & cement tools- Clear floor ~I LD 7" landing joint- Flush BOP stack for 9 5/8"x 7" packoff 11 Install packoff & test to 5000 psi f/10 min. I Change 7" casg rams to 2 7/8" x 5" VBR's - RU test equipment -Test !, rams -Choke valves 1, 3. 4, 6 and HCR kill - 250 low - 3500 high - 5 !,mins each test -Record on chart - as per Lou Grimauldi with AOGCC - Witness of test was waived by Lou Grimauldi tests were good - RD test equipment Clear rig floor of all casg equipment -Long bales -Cement head - RU 'floor to LD 5" DP from derrick - !,Cut drlg line -Service blocks -Top drive PJSM - LD 5" dp - 62 stands laid down 'I LD 5" DP from mast - Rlg up testing equipment -Test casg to 3500 psi fro 30 mins -Record on chart -Test good - RD testing equipment RU completion running equipment ~~ PU /Run 4 1/2" IBT-M - L-80 - 12.6# completion - RIH @ 10216' Il Break circ. w/ 20 spm 150 psi- Sting into seal bore ext.- Observe press. !,increase- Slack off & bottom out locator at top of SBE at 10,231'. PU & space out- Land tubing w/ seals at 10248' (2' up 'from bottom of SBE)- Run in LDS RU to test tubing and annulus -Test tubing to 3500 psi -Record on chart for 30 mins -Bleed tubing to 1500 psi -Shut in -Test annulus to !, 3500 psi -Record on chart for 30 mins -Bleed off tubing -Shear DCK 'valve -Bleed remaining pressure off annulus /tubing - RD test !I equipment - RD landing joint -Break pup / XO off landing joint -Lay (down landing joint 111 Install TWC -Test to 1000 psi - PJSM -Nipple down BOP's -Clear rig floor NU Tree Test adaptor T/5000, Test tree to 250/5000, Pull TWC !, RU Hot Oil, Test Lines to 3500 ~' Pump Freeze Protection Down Annulus taking Returns out Tubing 13BPM@1200PS1, 47BBL U-Tube Freeze Protection DN Tubing, freeze Protect OA 0.6BPM@1850-2300PSI, 37 BBL ',Install BPV and Test From the BTM to 1000psi I Secure Well **"*Rig Released 0600**** Printed: 4/21/2006 8:23:14 AM • Halliburton Company Global Report Company: ConocoPhillips Alaska Inc. llatr. 4/4/2006 Time: 14:41:34 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Refe rence: Well: 2N-333, True North Site: Kuparuk ZN Pad Vertical (TVD) Reference: 2N-333: 154.6 ' WeH: 2N-333 5cction (VS) Referenc e: Well (O.OON,O.OOE,265.OOAzi) ' Wellpath: 2N-333 Survey Calculation M ethod: Minimum Curvature llb: Oracle ', Survey: _ - _ Start Date: ~, Company: Engineer: Tool: Tied-to: Field: Kuparuk River Unit ', North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 '; Site: Kuparuk 2N Pad I Site Position: Northing: 5911970.20 ft Latitude: 70 10 13.596 N '; From: Map Easting: 460932.24 ft Longitude: 150 18 51.920 W '; Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.30 deg ' Well: 2N-333 Slot Name: ', Well Position: +N/-S -65.46 ft Northing: 5911906.18 ft Latitude: 70 10 12.952 N ', +E/-W -277.23 ft Easting : 460654.70 ft - Longitude: 150 18 59.952 W Position Uncertainty: 0.00 ft Wellpath: 2N-333 Drilled From: Well Ref. Point 501032052500 Tie-on Depth: 34.42 ft ~, Current Datum: 2N-333: Height 154.62 ft Above System Datum: Mean Sea Level Magnetic Data: 2/21/2006 Declination: 23.72 deg Field Strength: 57521 nT Mag Dip Angle: 80.62 deg ', Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ', ft ft ft deg ' 34.42 0.00 0.00 265.00 ', Survey Program for Definitive Wellpath , Date: 3/17/2006 Validated: No Version: 4 ~I Actual From To Survey Toolcode Tool Name ft ft 113.16 717.69 2N-333 gyro (113.16-717.69) CB-GYRO-SS Camera based gyro single shot L 745.87 10847.10 2N-333 (745. 87-10847.10) MWD+IFR-AK-CAZ- SC MWD+IFR AK CAZ SCC Survey y1D Intl .dim T'VD Sys TVD N/S E/W b1apN MapE Tool ft deg deg ft ft ft ft ft ft 34.42 0.00 0.00 34.42 -120.20 0.00 0.00 5911906.18 460654.70 TIE LINE 'i 113.16 0.39 251.89 113.16 -41.46 -0.08 -0.25 5911906.10 460654.44 CB-GYRO-SS '~ 169.04 0.72 279.14 169.04 14.42 -0.09 -0.78 5911906.10 460653.92 CB-GYRO-SS ~!, 262.69 1.13 231.18 262.68 108.06 -0.57 -2.08 5911905.62 460652.61 CB-GYRO-SS ', ~~ 352.69 2.26 190.00 352.64 198.02 -2.88 -3.08 5911903.32 460651.60 CB-GYRO-SS it ~i 441.69 4.43 189.45 441.48 286.86 -8.00 -3.95 5911898.21 460650.71 CB-GYRO-SS ~!~ ~ 534.69 6.68 199.14 534.04 379.42 -16.65 -6.31 5911889.56 460648.30 CB-GYRO-SS 622.69 9.48 205.16 621.16 466.54 -28.05 -11.08 5911878.19 460643.48 CB-GYRO-SS ', 717.69 12.95 225.78 714.37 559.75 -42.56 -22.04 5911863.74 460632.44 CB-GYRO-SS i~ 745.87 13.26 225.95 741.81 587.19 -47.01 -26.62 5911859.31 460627.84 MWD+IFR-AK-CAZ-SC ', 838.72 12.67 233.51 ~ 832.30 677.68 -60.47 -42.46 5911845.94 460611.93 MWD+IFR-AK-CAZ-SC ~ 929.57 14.69 247.01 920.59 765.97 -70.90 -61.09 5911835.61 460593.25 MWD+IFR-AK-CAZ-SC ', it 1025.39 15.16 249.25 1013.18 858.56 -80.08 -83.99 5911826.54 460570.31 MWD+IFR-AK-CAZ-SC ', 1119.41 17.04 256.92 1103.52 948.90 -87.56 -108.91 5911819.20 460545.35 MWD+IFR-AK-CAZ-SC ', 1212.59 21.60 266.47 ! 1191.45 1036.83 -91.71 -139.35 5911815.21 460514.89 MWD+IFR-AK-CAZ-SC , 1307.33 22.96 270.39 1279.12 1124.50 -92.66 -175.23 5911814.45 460479.00 MWD+IFR-AK-CAZ-SC ~~ 1400.02 27.47 272.01 1362.96 1208.34 -91.78 -214.70 5911815.52 460439.55 MWD+IFR-AK-CAZ-SC ~I 1492.88 31.18 275.27 1443.91 1289.29 -88.82 -260.06 5911818.72 460394.21 MWD+IFR-AK-CAZ-SC ' Halliburton Compan~ Global Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 2N Pad Well: 2N-333 ', Wcllpath: 2N-333 Sw-vev Date: 4/4!2006 Time: 14:41:34 Page: 2 Co-ordinatelNE) Reference: Well: 2N-333, True North Vertical (TVD) Reference: 2N-333: 154.6 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi) Survey Calculation Dtethod: Minimum Curvature llb: Oracle IV1D lncl Azim TVD Sys7vD N/S E/~V ft deg deg ft ft ft ft __ 1558.47 32. 49 276. 22 1499. 63 1345. 01 -85.35 -294. 48 1651.83 38. 65 267. 62 1575. 58 1420. 96 -83.85 -348. 62 1711.98 40. 51 267. 71 1621. 94 1467. 32 -85.41 -386. 91 1775.05 45. 01 269. 06 1668. 24 1513. 62 -86.59 -429. 70 1866.92 48. 40 271. 45 1731. 23 1576. 61 -86.25 -496. 55 1958.53 52. 99 273. 11 1789. 25 1634. 63 -83.40 -567. 35 2049.01 54. 52 273. 87 1842. 74 1688. 12 -78.96 -640. 19 2147.22 58. 51 272. 66 1896. 92 1742. 30 -74.31 -721. 95 2235.40 61. 44 269. 62 1941. 05 1786. 43 -72.82 -798. 26 2332.48 65. 98 268. 89 1984. 03 1829. 41 -73.96 -885. 27 2426.89 68. 73 268. 73 2020. 38 1865. 76 -75.78 -972. 37 2515.68 67. 82 264. 12 2053. 26 1898. 64 -80.91 -1054. 66 2607.81 66. 50 262. 71 2089. 02 1934. 40 -90.64 -1139. 01 2703.44 68. 95 263. 10 2125. 27 1970. 65 -101.56 -1226. 82 2799.35 68. 71 263. 30 2159. 90 2005. 28 -112.15 -1315. 62 2892.96 68. 25 263. 90 2194. 24 2039. 62 -121.86 -1402. 16 2988.55 68. 12 263. 44 2229. 77 2075. 15 -131.65 -1490. 37 3080.63 69.18 264.26 2263. 29 2108. 67 -140.83 -1575. 63 3168.43 68. 50 264.06 2294. 98 2140. 36 -149.16 -1657. 09 3268.02 70. 70 263.64 2329. 69 2175. 07 -159.16 -1749. 89 3363.18 70. 65 263.43 2361. 19 2206. 57 -169.28 -1839. 12 3411.93 70. 54 263.53 2377. 38 2222. 76 -174.50 -1884. 80 3522.26 70. 24 262.46 2414. 41 2259. 79 -187.17 -1987. 95 3617.99 69. 50 264.62 2447. 36 2292. 74 -197.29 -2077. 26 3714.05 68. 40 263.17 2481. 86 2327. 24 -206.82 -2166. 39 3805.23 67. 41 263.05 2516. 16 2361. 54 -216.95 -2250. 27 3899.28 67. 30 264.87 2552. 37 2397. 75 -226.08 -2336. 58 3998.17 66. 33 265.11 2591. 31 2436. 69 -234.02 -2427. 13 4093.91 68. 62 265.65 2627. 98 2473. 36 -241.14 -2515. 28 4187.24 68. 87 269.08 2661. 82 2507. 20 -245.14 -2602. 15 4280.96 68. 68 269.62 2695. 75 2541. 13 -246.13 -2689. 51 4374.46 69. 27 269.42 2729. 30 2574. 68 -246.86 -2776. 78 4469.12 68.10 269.49 2763.71 2609. 09 -247 .70 -2864. 96 ' 4564.40 68.26 268. 38 2799.12 2644. 50 -249 .34 -2953. 39 4658.64 69.35 268. 81 2833.19 2678. 57 -251 .50 -3041. 23 ' 4747.89 70.19 267. 20 2864.06 2709. 44 -254 .42 -3124. 92 4846.54 70.93 265. 66 2896.89 2742. 27 -260 .21 -3217. 76 4941.32 70.84 264.43 2927. 93 2773. 31 -267 .95 -3306. 98 5034.57 69.75 264. 77 2959. 37 2804. 75 -276 .21 -3394. 38 5129.14 69.36 263. 81 2992. 41 2837. 79 -285 .02 -3482. 55 5222.36 69.06 262. 01 3025. 50 2870. 88 -295 .78 -3569. 03 5313.68 68.91 261. 59 3058. 25 2903. 63 -307 .94 -3653. 40 5411.58 68.79 262. 74 3093. 57 2938. 95 -320 .38 -3743. 85 5505.63 68.43 261. 57 3127. 87 2973. 25 -332 .34 -3830. 60 5598.53 69.08 261. 00 3161. 53 3006. 91 -345 .46 -3916. 19 ~ 5693.98 69.14 261. 04 3195. 57 3040. 95 -359 .37 -4004. 27 5786.08 69.31 262. 28 3228. 24 3073. 62 -371 .86 -4089. 47 5872.14 69.42 261. 45 3258. 57 3103. 95 -383 .26 -4169. 20 5971.67 68.88 261. 51 3293. 99 3139. 37 -397 .04 -4261. 18 ' 6066.66 68.70 262. 25 3328. 36 3173. 74 -409 .55 -4348. 85 6157.83 67.92 263. 01 3362. 05 3207. 43 -420 .42 -4432. 86 6254.55 68.10 262. 73 3398. 27 3243.65 -431 .55 -4521. 85 11apN ft 5911822.37 5911824.16 5911822.79 5911821.83 5911822.52 5911825.74 5911830.56 5911835.63 5911837.52 5911836.83 5911835.47 5911830.77 5911821.47 5911811.00 5911800.88 5911791.62 5911782.30 5911773.56 5911765.65 5911756.13 5911746.48 5911741.50 5911729.36 5911719.71 5911710.65 5911700.95 5911692.27 5911684.80 5911678.14 5911674.60 5911674.06 5911673.78 5911673.40 5911672.22 5911670.52 5911668.04 5911662.73 5911655.46 5911647.65 5911639.29 5911628.99 5911617.27 5911605.29 5911593.80 5911581.12 5911567.66 5911555.62 5911544.64 5911531.33 5911519.28 5911508.85 5911498.19 M1IapF._ fool ft 460359.81 MWD+IFR-AK-CAZ-SC 460305.68 MWD+IFR-AK-CAZ-SC 460267.39 MWD+IFR-AK-CAZ-SC 460224.59 MWD+IFR-AK-CAZ-SC 460157.76 MWD+IFR-AK-CAZ-SC 460086.98 MWD+IFR-AK-CAZ-SC 460014.17 MWD+IFR-AK-CAZ-SC 459932.45 MWD+IFR-AK-CAZ-SC 459856.15 MWD+IFR-AK-CAZ-SC 459769.15 MWD+IFR-AK-CAZ-SC 459682.05 MWD+IFR-AK-CAZ-SC 459599.73 MWD+IFR-AK-CAZ-SC 459515.35 MWD+IFR-AK-CAZ-SC 459427.49 MWD+IFR-AK-CAZ-SC ' 459338.64 MWD+IFR-AK-CAZ-SC 459252.06 MWD+IFR-AK-CAZ-SC 459163.81 MWD+IFR-AK-CAZ-SC 459078.51 MWD+IFR-AK-CAZ-SC 458997.02 MWD+IFR-AK-CAZ-SC 458904.18 MWD+IFR-AK-CAZ-SC 458814.91 MWD+IFR-AK-CAZ-SC 458769.20 MWD+IFR-AK-CAZ-SC 458666.00 MWD+IFR-AK-CAZ-SC 458576.65 MWD+IFR-AK-CAZ-SC 458487.47 MWD+IFR-AK-CAZ-SC 458403.56 MWD+IFR-AK-CAZ-SC 458317.21 MWD+IFR-AK-CAZ-SC 458226.62 MWD+IFR-AK-CAZ-SC 458138.45 MWD+IFR-AK-CAZ-SC ' 458051.57 MWD+IFR-AK-CAZ-SC 457964.21 MWD+IFR-AK-CAZ-SC 457876.95 MWD+IFR-AK-CAZ-SC 457788.78 MWD+IFR-AK-CAZ-SC 457700.34 MWD+IFR-AK-CAZ-SC 457612.50 MWD+IFR-AK-CAZ-SC i 457528.81 MWD+IFR-AK-CAZ-SC 457435.95 MWD+IFR-AK-CAZ-SC 457346.70 MWD+IFR-AK-CAZ-SC ' 457259.27 MWD+IFR-AK-CAZ-SC 457171.06 MWD+IFR-AK-CAZ-SC 457084.53 MWD+IFR-AK-CAZ-SC 457000.10 MWD+IFR-AK-CAZ-SC I. 456909.60 MWD+IFR-AK-CAZ-SC 456822.80 MWD+IFR-AK-CAZ-SC 456737.15 MWD+IFR-AK-CAZ-SC 456649.01 MWD+IFR-AK-CAZ-SC 456563.75 MWD+IFR-AK-CAZ-SC ''~ 456483.97 MWD+IFR-AK-CAZ-SC ~~ 456391.93 MWD+IFR-AK-CAZ-SC !, 456304.21 MWD+IFR-AK-CAZ-SC ', 456220.15 MWD+IFR-AK-CAZ-SC ', 456131.11 MWD+IFR-AK-CAZ-SC Halliburton Compan~ Global Report Companr~: ConocoPhillips Alaska Inc. Uate: 4/4/2006 Time: 14 :41:34 Yage: 3 Field: Ku paruk River Unit Co-ord inatc(NE) Re ference: Well: 2N-333, True North Site: Ku paruk 2N Pa d Vertical (TVD) Refe rence: 2N-333: 154.6 R'ell: 2N -333 Section (VS) Reference: Well ( O.OON,O.OOE,265.OOAzi) ~Vellpath: 2N -333 Survey Calculation Method: Minimum Curvature Ub: Oracle Surve~~ DID Incl.. ... ~zim 71 U Svs I'V ~ D )V/S _ E/N MapN MapE Tool ft deg deg ft ft ft ft ft ft 6347.46 68. 97 263. 41 3432. 27 3277. 65 -441.98 -4607.69 5911488 .20 456045.23 MWD+IFR-AK-CAZ-SC ', ', 6441.77 69. 65 262. 61 3465. 59 3310. 97 -452.72 -4695.26 5911477 .92 455957.61 MWD+IFR-AK-CAZ-SC '~; 6535.85 71. 14 262. 40 3497. 16 3342. 54 -464.28 -4783.12 5911466 .82 455869.70 MWD+IFR-AK-CAZ-SC 6626.92 71. 71 262. 55 3526. 17 3371. 55 -475.58 -4868.71 5911455 .96 455784.07 MWD+IFR-AK-CAZ-SC 6721.26 70. 71 262. 93 3556. 55 3401. 93 -486.87 -4957.30 5911445 .13 455695.42 MWD+IFR-AK-CAZ-SC ''~, 6815.79 69. 80 263. 63 3588. 49 3433. 87 -497.28 -5045.66 5911435 .18 455607.02 MWD+IFR-AK-CAZ-SC ~' 6910.39 70. 15 263. 85 3620. 88 3466. 26 -506.98 -5134.01 5911425 .95 455518.63 MWD+IFR-AK-CAZ-SC ', 7003.65 69. 04 264. 74 3653. 40 3498. 78 -515.67 -5220.98 5911417 .71 455431.62 MWD+IFR-AK-CAZ-SC ', 7100.58 68. 59 265. 36 3688. 43 3533. 81 -523.47 -5311.02 5911410 .38 455341.55 MWD+IFR-AK-CAZ-SC 7193.89 68. 21 264. 99 3722. 78 3568. 16 -530.76 -5397.47 5911403 .53 455255.07 MWD+IFR-AK-CAZ-SC 7286.57 68. 24 263. 99 3757. 16 3602. 54 -539.03 -5483.14 5911395 .72 455169.37 MWD+IFR-AK-CAZ-SC 7379.60 70. 62 264. 56 3789. 84 3635. 22 -547.71 -5569.80 5911387 .48 455082.68 MWD+IFR-AK-CAZ-SC ', 7472.99 71. 53 265. 00 3820. 13 3665. 51 -555.75 -5657.77 5911379 .91 454994.67 MWD+IFR-AK-CAZ-SC 7566.78 72. 88 264. 75 3848. 79 3694. 17 -563.73 -5746.72 5911372 .39 454905.69 MWD+IFR-AK-CAZ-SC ~' 7662.42 72. 54 263. 99 3877. 22 3722. 60 -572.68 -5837.59 5911363 .91 454814.78 MWD+IFR-AK-CAZ-SC 7755.95 71. 90 262. 68 3905. 78 3751. 16 -583.02 -5926.05 5911354 .03 454726.28 MWD+IFR-AK-CAZ-SC '~ 7845.27 71. 13 263. 18 3934. 10 3779. 48 -593.45 -6010.12 5911344 .04 454642.17 MWD+IFR-AK-CAZ-SC 7943.30 69. 55 263. 39 3967. 08 3812. 46 -604.24 -6101.80 5911333 .73 454550.44 MWD+IFR-AK-CAZ-SC ', ' 8037.13 69. 31 263. 27 4000. 05 3845. 43 -614.44 -6189.05 5911323 .98 454463.15 MWD+IFR-AK-CAZ-SC '' 8130.80 67. 84 264. 13 4034. 26 3879. 64 -624.02 -6275.72 5911314 .86 454376.44 MWD+IFR-AK-CAZ-SC 8226.17 66. 54 262. 86 4071. 24 3916. 62 -633.97 -6363.06 5911305 .36 454289.06 MWD+IFR-AK-CAZ-SC 8319.14 66. 60 263. 96 4108. 21 3953. 59 -643.76 -6447.80 5911296 .01 454204.27 MWD+IFR-AK-CAZ-SC 8412.56 66. 79 264. 52 4145. 17 3990. 55 -652.37 -6533.16 5911287 .85 454118.88 MWD+IFR-AK-CAZ-SC 8507.19 68. 64 265. 27 4181. 05 4026. 43 -660.16 -6620.37 5941280 .51 454031.63 MWD+IFR-AK-CAZ-SC 8600.02 68. 65 264. 71 4214. 85 4060. 23 -667.71 -6706.50 5911273 .41 453945.48 MWD+IFR-AK-CAZ-SC ', 8693.32 68. 35 265. 73 4249. 05 4094. 43 -674.94 -6793.00 5911266 .63 453858.95 MWD+IFR-AK-CAZ-SC 8786.93 68. 85 264. 35 4283. 21 4128. 59 -682.48 -6879.83 5911259 .54 453772.09 MWD+IFR-AK-CAZ-SC ', 8882.05 69. 42 264. 51 4317. 08 4162. 46 -691.11 -6968.29 5911251 .38 453683.59 MWD+IFR-AK-CAZ-SC 8972.95 69. 38 263. 59 4349. 07 4194. 45 -699.93 -7052.92 5911243 .00 453598.93 MWD+IFR-AK-CAZ-SC 9068.26 69. 94 262. 97 4382. 20 4227. 58 -710.38 -7141.67 5911233 .00 453510.13 MWD+IFR-AK-CAZ-SC ~', i ', 9160.46 69. 90 262. 90 4413. 85 4259. 23 -721.04 -7227.61 5911222 .80 453424.15 I MWD+IFR-AK-CAZ-SC ', 9250.97 70. 43 262. 20 4444. 56 4289. 94 -732.08 -7312.03 5911212 .20 453339.68 MWD+IFR-AK-CAZ-SC ', ', 9348.32 69. 46 262. 91 4477. 95 4323. 33 -743.93 -7402.71 5911200 .82 453248.95 MWD+IFR-AK-CAZ-SC 9440.99 68. 86 263. 19 4510. 91 4356. 29 -754.41 -7488.68 5911190 .79 453162.94 MWD+IFR-AK-CAZ-SC ~' ~ 9532.69 69. 20 262. 43 4543. 73 4389. 11 -765.12 -7573.63 5911180 .51 453077.94 MWD+IFR-AK-CAZ-SC ~ 9625.96 68. 27 262. 88 4577. 56 4422. 94 -776.24 -7659.83 5911169 .85 452991.69 I MWD+IFR-AK-CAZ-SC !~ 9720.90 68. 23 263. 72 4612. 74 4458. 12 -786.52 -7747.41 5911160 .02 452904.07 MWD+IFR-AK-CAZ-SC 9813.07 69. 83 265. 90 4645. 73 4491. 11 -794.30 -7833.12 5911152 .69 452818.33 MWD+IFR-AK-CAZ-SC ', 9906.41 70. 06 266. 98 4677. 74 4523. 12 -799.74 -7920.63 5911147 .70 452730.80 MWD+IFR-AK-CAZ-SC 10000.91 67. 88 266. 83 4711. 65 4557. 03 -804.51 -8008.70 5911143 .40 452642.72 MWD+IFR-AK-CAZ-SC ~ 10094.68 64. 57 264. 26 4749. 45 4594. 83 -811.14 -8094.23 5911137 .20 452557.16 MWD+IFR-AK-CAZ-SC ~'~, ~I 10181.91 61. 30 262. 63 4789. 14 4634. 52 -819.99 -8171.39 5911128 .76 452479.96 MWD+IFR-AK-CAZ-SC ', 10283.09 58. 15 262. 62 4840. 14 4685. 52 -831.21 -8258.03 5911117 .99 452393.27 MWD+IFR-AK-CAZ-SC i 10378.47 55. 80 261. 89 4892. 12 4737. 50 -841.98 -8337.27 5911107 .64 452313.99 MWD+IFR-AK-CAZ-SC 'I 10423.97 54. 37 261. 02 4918. 16 4763. 54 -847.52 -8374.16 5911102 .29 452277.07 MWD+IFR-AK-CAZ-SC I 10472.39 52. 15 262. 10 4947. 13 4792. 51 -853.22 -8412.54 5911096 .79 452238.66 MWD+IFR-AK-CAZ-SC ~I '~ 10518.81 50. 44 261. 51 4976. 15 4821. 53 -858.38 -8448.40 5911091 .81 452202.79 MWD+IFR-AK-CAZ-SC ~I 10567.01 48. 86 260. 92 5007. 36 4852. 74 -863.99 -8484.70 5911086 .40 452166.46 MWD+IFR-AK-CAZ-SC ~, 10659.97 46. 52 259. 62 5069. 93 4915. 31 -875.59 -8552.45 5911075 .15 452098.66 MWD+IFR-AK-CAZ-SC ', 10753.03 43. 10 260. 01 5135. 94 4981. 32 -887.19 -8616.99 5911063 .88 452034.06 MWD+IFR-AK-CAZ-SC '', 10847.10 38. 78 260. 40 5206. 99 5052. 37 -897.69 -8677.71 5911053 .70 451973.29 MWD+IFR-AK-CAZ-SC ~ 10921.00 38. 78 260. 40 5264 .59 5109. 97 -905.41 -8723.35 5911046 .22 y 451927.62 - PROJECTED to TD 2N-333 Well Events Summary • DATE Summary of Operations 03/29/06 02:00 PM GAUGED TBG TO 3.705" TO 10799' RKB. IN PROGRESS. 03/30/06 06:00 AM DRIFTED TBG TO 10799' RKB WITH 23.25' x 3-3/8" DUMMY GUN. PULLED SDCK-2 SHEAROUT VALVE @ 10115' RKB. IN PROGRESS. 03/31/06 05:00 PM DISPLACED TBG & CSG TO DSL. COMBO MIT 3000 PSI, GOOD. SET 1/4" OV @ 10115' RKB & BLED TBG TO CONFIRM SET. WELL READY TO PERFORATE. 04/06/06 12:00 PM Perforate - 10759.3 - 10774.3 ft with 15ft 2 7/8" HSD 2906 PJ HMX. API SPECS: 25.3" PENETRATION. 0.38" ENTRANCE HOLE. Logged GR/CCL for Jewelry from TD to 10100'. 04/20/06 03:00 PM DRIFTED TBG & TAGGED FILL @ 10788' RKB. EST. 14' RATHOLE. IN PRROGRESS. ~t~rtt~coPhillps Aia ~, Inc, 2N-333 API: 501032( TUBING SSSV Type: NIPPLE (0-10248, OD:4.500, ID:3.958) Annular Fluid: SURFACE (o-3as1, Reference Lo :34.4' Rk oD:s.s25, Last Ta :10799 wrao.oo> Last Tag Date: 3/29/20( PRODUCTION (0-10234, OD:7.000, wc:zs.oo> SLEEVE 10166-10167, OD:5.300) NIP 10185-10186, OD:5.570) SEAL 10229-10230, OD:4.750) using String -ALL STRINGS • KRU aV-333 Angle @ TD: 39 deg @ 10921 Rev Reason: GLV C/O, PERF, j TD: ~ 10921 ftKB Max Hole Angle: 73 deg C~ i ~escri lion Size To Bottom TVD Wt Grade Thread SURFACE 9.625 0 3451 2390 40.00 L-80 BTC PRODUCTION 7.000 0 10234 4815 26.00 L-80 BTC-MOD CONDUCTOR 16.000 0 112 112 62.50 WELD LINER fubin Strin -TUBING 4.50.0___ 10234 10908 5.254 12.60 L-80 IBTM Size Top Bottom ~ TVD Wt Grade Thread 4.500 0 --- 'erforations Summary - - - Interval TVD 10248 4822 12.60 L-80 - - Zone Status Ft SPF Date T C IBTM mment 10759 - 10774 5140 - 5152 15 6 4/6/2006 (PERF 2 7/8" HSD, 2906 PJ HMX, 60 deg phase - - - - - 3as Lift MandrelslValves _ _ _ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO ' Date. Vlv Mfr Run Cmnt 1 3571 2431 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 3/17/2006 2 6981 3646 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 3/17/2006 3 8763 4274 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 3/17/2006 4 10115 4759 CAMCO ether lu s, a ui etc~_- ~~_ 4 _ P~~- _ De th TVD T e KBG-2 OV 1.0 BK-5 0.250 0 COMPLETION JEWELRY _ - - Descri lion 3/31/2006 _ ID 32 32 HANGER FMC 5M GEN V HANGER 4.500 497 497 NIP CAMCO'DS' LANDING NIPPLE w/3.875" NO GO 3.875 10166 4782 SLEEVE BAKER CMU SLIDING SLEEVE w/3.812" DS NO GO PROFILE 3.812 10185 4791 NIP CAMCO'D' NIPPLE NO GO PROFILE 3.750 10229 4813 SEAL 4.5" BAKER GBH-22 SEAL ASSEMBLY w/5.21" OD LOCATOR 3.870 10247 4822 WLEG BAKER WIRELINE GUIDE 3.870 LINER ;10234-10908, OD:4.500, Wt:12.60) Perf ;10759-10774) • • 12-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2N-333 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 34.42' MD Window /Kickoff Survey: 10,847.10' MD (if applicable) Projected Survey: 10,921.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 2N-333 • Suh~}ect:2N-333 I+rom: "~~Vinfi~ee, Michael Alc~ (Jr.)" <Mic}~~tel.%1.«'infrce@eonocophillips.conl> Date: Thu, 09 licb ?Otl6 16:54:37 -O9U0 To: tom maunder(u~.admin.stat~:.ak.us Tom, Section 14 of the "PERMIT IT" document for 2N-333 incorrectly states "Waste fluids generated during the drilling process will be disposed either by pumping authorized fluids into a permitted annulus on 7 C Pad, or by hauling the fluids to a KRU Class 11 disposal we1P'. Drilling waste fluids from 2N-333 will not be disposed of into a permitted annulus on 1C pad. The sentence should read "Waste fluid generated during the drilling process will be disposed of by hauling the fluids to a KRU Class 11 disposal well." Please find attached the pages from the corrected document. Thank you, -Mike Mike A. Winfree Drilling Engineer ConocoPhillips Alaska 907.265.6820 Direct 907.242.0246 Cell 2N-333 PERMIT IT Disposal Revision.DOC Content-Description: 2N-333 PERMIT IT Disposal Revision.DOC Content-Type: application/msword Content-Encoding: base64 1 of 1 2/10/2006 730 AM C ~ ~ ~ S ~ ~ ° 1 r - ~ a :~~' ..,~ _ ~ .. ~ ~.~ ~~ -~ ~~..,. ; .mom ~ f Q,-..r _~ m,. ~.a ,~, ~-., ALASSA OIL A1~TD ~`icA,S C011TSERQA7`I011T COMl-IISSIOIQ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 • FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk, 2N-333 ConocoPhillips Alaska, Inc. Permit No: 206-025 Surface Location: 103' FNL, 938' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 999' FNL, 4423' FEL, SEC. 4, T9N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)59-3607 (pager). J DATED this /D day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 7, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill 2N-333 Dear Commissioners, ~~ ~~~~ ~ ~~~ 1/ ~~~ a s Zoos Ale~~a Vii) ~ Gaa Cons. Conbni::ioln ~...._.. Anchorage ConocoPhillips Alaska, Inc hereby applies for a Permit to Dri/l for the onshore producer well 2N- 333. The well will be drilled and completed using Doyon Rig 14. The planned spud date for 2N- 333 is February 18th 2006. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike A. Winfree at 907- 265-6820. Sincerely, Randy Thomas Kuparuk Drilling Team Leader ~~~. STATE OF ALASKA /~ ~~~.,~~ w /~ FEB 0 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for. Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 , 11. Well Name and Number: 2N-333 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11051' ' ND: 5429' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 103' FNL, 938' FEL, Sec. 3, T9N, R7E, UM ~ 7. Property Designation: ADL 375074 ' Tarn Oil Pool Top of Productive Horizon: 955' FNL, 4013' FEL, Sec. 4, T9N, R7E, UM 8. Land Use Permit: ALK 4293 13. Approximate Spud Date: 2/18/2006 Total Depth: 999' FNL, 4423' FEL, Sec. 4, T9N, R7E, UM' 9. Acres in Property: 2560 14. Distance to 4,'~,~f~;` ~~c~, ~,- Nearest Property: <3 miles 7 ~'t-~n 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460655 ~ y- 5911906 ' Zone- 4 10. KB Elevation (Height above GL): 34' RKB feet 15. Distance to Nearest c ~ i- Well within Pool: 2N-343 , 1355' 18. Deviated wells: Kickoff depth: 250 ' ft. Maximum Hole Angle: 6g° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 2385 psig Surface: 1839 psig ' 18. Casing Program cif S ti Setting Depth Quantity of Cement Size pe ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 24" 16" 62.5# H-40 Welded 78' 34' 34' 112' 112' pre-installed 12.25" 9-5/8" 40# L-80 BTC 3426' 34' 34' 3460' 2400' • 426 sx AS Lite, 263 sx LiteCRETE 8.5" 7" 26# L-80 BTCM 10198' 34' 34' 10233' ' 4837' ' 290 sx Class G 8.5" 4.5" 12.6# L-80 IBT Mod 818' 10233' 4837' 11051' - 5429' see above 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch ^ Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike unfree @ 265-6820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature 1 Phone ~ ~'6 g 1 a Date Zl ~ ~~ (~ ` ~ P ha 11 D k Commission Use Only Permit to Drill `` _ Number: ~-~-~%(C~" ~~~ API Number: 50- %rj3" ~`j~~ -~~ Permit Approval Date: a - ~ (~'~_Q See cover letter for other requirements Conditions of approval : f box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: ©'' Samples req'd: Yes ^ No Qr~ Mud log req'd: Yes ^ No [,~ Other: ` ~~V ~~4 ~~„~HZS measures: Yes Q' No ^ Directional svy req'd: Yes ~ No ^ APPROVED BY THE COMMISSION DATE: ~_/D ~ 0 ,COMMISSIONER ~~ 4 ~rm 10-ised 12/2005 ~.-t t ~ ! ~ ~ Submit in Duplicate • Permit It -Tarn Well 2N-333 Application for Permit to Drill Document Il~l~W~ll IN~ximixE 1M~11 ypiue Table of Contents 1. Well Name .................................................................................................................2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 2N-333 PERMIT IT Page 1 of 7 Printed: 8-Feb-06 ~tion for Permit to Drill, Well 2N-333 Saved: 8-Feb-06 ~~8~ ~I ~~ ~ I~~'~;~l~~AI • ~tion for Permit to Drill, Well 2N-333 Saved:8-Feb-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plan ............................................................................................................... 1 Attachment 2 Drilling Hazards .............................................................................................2 Attachment 3 Well Schematic .............................................................................................3 Attachment 4 Cement Program Summary ............................................................................................. 4 1. Well Name Requirements of 20 AAC 25.005 (f) Each 4veff must be fder}tf#ied by a ur}fyue name designated by fhe operator and a t~nfque API nerrr.ber assigned by the can?mission under 20 AAG 25.t}~t3(b}. For a aveff with mufti~le :Fre{( r3ranches, each bran;;h must sirniiarfy be identified by a unique non?e and APf nurr;ber by adding a scrtfix to Phe name designated for the ;~reff by the oaeraPor and to tl?e number assigned to 2,#re, weft by fl?e commfssicn. The welt for which this application is submitted will be designated as 2N-333 2. Location Summary Requirements of 20 AAC 25.005(c)(2) At? application for a Permit to Grifl n}cfsP be accompanied by ecacl? of Phe tallcrving items, except for ar} iten} already on file with the carnmfssian and identf#ied in Phe appffcaiion: (2,; a f'fat ider}tifying the property and the property`s awr}ers and st}o~,~inc{ (A~the oaardir}ales of the prapos=~d location of the eve%{ at the scir#ace, at the top of eac#} o~{ectis'e farmatiar}, ar}d at total dE>pth, referenced to governrnenPaf se;ctlon {rues. !RI tl?e coordinates at the prrapased fecation of tl?e well at the su;faae, referenced to the spate plane coordinate system ter this state as maintained by Phe National Geodetic Sut~ey in tl?e Naticr?af CJeeanic and Atmospheric Administratio;?: (C, Phe proposed depth of the well at fhe top of each af?lecti~re fonnatfon and aP fatal depth; Location at Surface 102.51' FNL, 938.22' FEL, Sec 3, T9N, R07E, UM NGS Coordinates ' RKB Elevation 154.5 AMSL Northings: 5,911,906 Eastings: 460,655 Pad Elevation 120.2 Location at Top of Productive Interval (Bermuda Sands: T3 954.8' FNL, 4012.7' FEL, Sec 4, T9N, R07E, UM - NGS Coordinates Measured De th, RKB: 10,433' Northings: 5,911,102 Eastings: 452,298 Total Vertical Depth, RKB: 4969.5' Total Vertical De th, SS: 4815" Location at Total De th 999' FNL,4423' FEL, Sec 4, T9N, R07E, UM NGS Coordinates Measured De th, RKB: 11,052' Northings: 5,911,061 Eastings: 451,887 Total Vertical Depth, RKB: 5429' - Total Vertical Depth, SS: 5275' and :~i ether infornJaticn rr~=garired by 2f} AAG2.0:~(?l~i, Requirements of 20 AAC 25.050(b) ft a svef{ {s to be intentionaffy dev.Iated, the appficatian tar a Permit Po r~r{{l (Form t C?-~C?1; n:z~sP ;`'t1 include a pf~t, drawn to a suitable scale, sl}o;~~ir?g the pall? of Phe proposed ~vellbare, incfudinc7 alt adjac;enP :r'ef{Cores wr'thin 2!~U feet Ctf any ports"an of ti?e proposed weft; Please see Attachment 1: Directional plan for 2N-333 ar}d (21 for all wcf.%s mitt}lr% 23v #ec>P cf tt.e proposed weffbore to 7 fist Phe names at the oc7er-Mors o{ those :veils, to tt}e e%tenP that thane names t~rc ~noavn or cYis caveraf~ie in pt~~ffc records., ar?d sl?c~v that each named aperatcr f?as Leer? ftrrr~ished a copy of t!?e appficatiar by certified mai{; or 2N-333 PERMIT IT Page 2 of 7 Printed: 8-Feb-06 ~tion for Permit to Drill, Well 2N-333 Saved: 8-Feb-06 !~') state that the appffcant is the cnfy affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app.?}eatfar? for a PCrntit to flriff must be accompanied by each of the fvf}c.vfrrg item§, except for ar? }tern afready on ff#e with the commission and identified in the application: {3j a diagran? and description of tfre bfewout prevention egi7ipn?ent !BC.~PF,i as recuired by 2Q AAC 25.D35, 2Q RAC 25.036, ar 2C7 RRC?_5.031; as app#fcable; The BOPE includes a 13-5/8" RSRRA 5M stack. Please reference BOP schematics on file for Doyon 14 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to E7ri11 mc,st be accompanied by each at the falfc.ving item,§, except far an item already on fi#e ~v#t#~ the Gommi§sian ar?d identified +r? the apptfcatiorF: ~4; inform?at#cn on drifting hazards, inor~adfrtg !R? fire rnaxirr?urn dadn~r?hate Ares§ure that maybe encountered, criteria a§ed to determine #t, ar?d n7axirnirm potenta# surface pressure eased c; ff a methane gradien±; Current model predictions estimate a max BHP of 2400 psi at 4969' TVD for the 2N-333 location. Equivalent Mud Weight @TD = 2400 psi = 9.3 ppg ~ 4969'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 2N-333 is calculated using the predicted 2400 psi reservoir pressure, a 0.11 psi/ft gas gradient, and Bermuda TVD of 4969'. MPSP = ~GradientMud - Gradient~as TVD GradientMUd = 9.3 ppg x 0.052 = 0.48 f 11 t Gradient~as = 0.11 f i t TVD = 4969 ft MPSP = 0.48 pst - 0.11 pst 969 ft =1839 psi ft ft (B; a'afa an f?atentiaf gas zones; The 2N wells have encountered gas hydrates while drilling at -1200' TVD, just below the base of the permafrost. There are also gas shows at the base of the Westpt Sak --1900' TVD. and tJtV~r'~i' +~ctc.sc~Sc~~~ ~~"~ }l~ !C data concerning potential causes of f?o#e prvbierns §uch as abnorma##y gea-Ares§ured strata; #c?st circGr#atfan zones; anc# zor?es that have a proper;§ity far differenlie(stick~ingi Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An afiG?#fL<?tICif"t fC}r';~ t='er177it tU ~'ir#(} I7tU§tJe aCCC)???parl(cd bj/ ec,;:fl t~f 7}"te taffGW;nt~ tfet?7S, £":CeAJt fC1r 2n ffe??% <3,rE'c3i?t' C)r: f`te by?t}7 t}7e t,•ar.>?r?fission and rderrtrfied ir? t>?e aNp#ic:ativr?: !~? a dfi;scripfion of fits pror,~=d:?re tar cand~ecting fcrmati;~?n infegritf tests, ras reg~,iire:f <ander ~0 RAC 25.Q30(f); LOT/FIT will be conducted in accordance with the Kuparuk LOT/FIT procedure CPAI has on file with the AOGCC. A LOT/FIT will be performed at the surface shoe drill out and intermediate shoe drill out stages. 2N-333 PERMIT IT Page 3 of 7 Printed: 8-Feb-06 0^!GINAL • Surface Hole Mud Program (Spud Mud) tion for Permit to Drill, Well 2N-333 Saved: 8-Feb-06 Base of Permafrost to 9 5/8" Spud to Base of Permafrost Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 9.6 <9.8 <9.6 10.2 Funnel Viscosity 250 250 150-200 55-65 seconds Yield Point 35-45 35-45 30-35 12-15 cP pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate 6 6 4-6 4-6 cc 130 min Chlorides (mg/q <600 <600 <600 <600 Intermediate Hole Mud Program (LSND) 9 5/8"Casin Shoe to TD Initial Value Final Value Density (ppg) 9.6 9.9 Yield Point (cP) 18.20 15-18 pH 9-9.5 9-9.5 API Filtrate cc / 30 min 4-6 4-5 HTNP @ i50° (CC) <12 <12 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please refer to information on file for diagrams and descriptions of the fluid system of Doyon 14. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) Art appfic_r~ti;~n fora Pc~rrrift tv G?rii} .=rust be accorripar?ied by each of t}re fofl;rwing sterns, s.~xc~:pt fc?r ar= item alreacf!r on fitca ~~ittj t}'te GC,".r}r77f5Sit3FJ ;~P11~' f#.~G*f79?fist,'d 1r3 1}7L' dNL?}iC3tior?: ~1 for sin expfor::€tor~' cr str<ztirxrapl";;c test ~veff, a fab±,satic; tr Sr?tting Jtat th#? dnpttts of pre iiCtf=#i ~µbnnrmrx}ty geo-pressured strata <~s rec}uired by ~ 0 AAC 25.0 3(fj: N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An appfictzttorr for a Perr;;rt to Cr~fl mt,st be accornpar?iect by each of tl?e ,~fic~1•ir?g itQn,s, except fvr an ttem <.Ire<~dy on file Britt? tl~e c°omm?sston aria Ic~enttfted ;r? fhe apps?carton: (13? fvr ar% c*xpforatory c~! fratigrapfric test s~,~el{, a se=i7rrric refs<~ctloft or r~?f`ect=or.> anarysrs as rc*c{uired'~y 2{?Ar~G ~'S.tJE rt:~); NIA -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) Art ~tpplicatfc>r for ra Permit to Jriff must >=e accorr,partied by sxac}r of ti•?#; follo~vr"ng items, c=xc~*pt tr~r an itLrr? tx}rea:iy ort r,~}e s~~s#h th= c:lrrirrifssiort artd ft7=r?fifieri in the appiicatiort: (? , j for a ;Frefl #9r='fed fr on? art o;fshore c?fatfcrm; mnbi}r? b.~ttom-fc~trrt~r~;~ structure;. ;<~:~~r's-up rig. or t7oati,~tg dr%ftr'ng vessef, an anrafysis of seabed conditions as rec;uir ed by ~0 AAC 2:1.06 i ta?,- N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An appfi<;~ztton fora Perr;;tt to l3rffl must be z~cco3npar?ieq tJy each of Elie ,`effob~%ti?r~ iten;s, except fdJr a;, iter?t <.fl"aady tan fiie Sritl? ti"in <.`;3mn??&StLtn at?d iU°nttftE!C7;n the appi=LUF}DI?: fr>? eLricience sha;wing :That the requirements of 2r~ AAC 25.Ot~ rt~c~:~ca}n~ihave been me:;" 2N-333 PERMIT lT Page 5 of 7 Printed: 8-Feb-06 tion for Permit to Drill, Well 2N-333 Saved: 10-Feb-06 Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 1. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Doyon 14 on 2N-333 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (3460' MD/ 2400' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job or stage job with port collar (installed +/- 1000') if required to bring cement to surface. 5. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 5000 psi. Record results. 6. RIH clean out to float collar 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. 9. Directionally drill 8-1/2" hole to TD (11051' MD/ 5429' TVD). Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run 7" 26# L-80 BTCM by 4-1/2" 12.6# L-80 IBTMOD tapered casing string and cement. 11. Install packoff test BOPE 12. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results 13. Run and land 4-1/2" completion tubing string and pressure test tubing and annulus to 3000 psi. Record results. 14. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 15. Freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 16. Clean location and RDMO. 17. MIRU Coil or E-Line, perforate well 18. RU Dowell, frac well. 19. RD Dowell, secure well, handover to production 2. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 2N-333 PERMIT IT Disposal Revision.DOC Page 6 of 7 Printed: 10-Feb-O6 ~ation for Permit to Drill, Well 2N-333 Saved: 8-Feb-06 Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) Rn application for a Permit tc gill must be accompanied by each of the foiic.wing items, except for an item already on. file Frith c,orrrrnissiort and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic/ 1. MIRU Doyon 14 on 2N-333 Conductor. ~ ;~ 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (3460' MD/ 24 ' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as requi d for directional monitoring and formation data gathering. 4. Run and cement 9-518" 40.0# L-80 BTC casing to surface. Adequate excess ement will be pumped to ensure cement reaches the surface during the cement job.'Displace ce ent with mud. Perform top job or stage job with port collar (installed +/- 1000') if required to brin cement to surface. 5. Nipple down diverter and install wellhead and test to 5000 psi. Nipple p BOPE and test to 5000 psi. Record results. 6. RIH clean out to float collar 7. Shut in BOP's and pressure test casing to 3000 psi pr~O regulations. Record results. 8. Drill out cement and 20' minimum to 50' maxim m oflfiew le. Perform formation integrity test not to exceed 16.0 ppg EMW. ~ ~ ~ 9. Directionally drill 8-1/2" hole to TD (11051' M 5 9' VD}. Run MWD /LWD logging tools in drill string as required for directional mo ~ o ~ and for tion data gathering. 10. Run 7" 26# L-80 BTCM by 4-1/2" 12. - IBT OD tapered casing string and cement. 11. Install packoff test BOPE ~ °~.. 12. Shut in BOP's and pressure test c sing to 00 psi per AOGCC regulations. Record results 13. Run and land 4-112" completion ~ixk~iing ring and pressure test tubing and annulus to 3000 psi. Record results. 14. Pull landing joint. Install BPV. Nip e down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test oduction tree. Pull test plug. Secure well. 15. Freeze protect outer annua ith diesel to below the permafrost. Set BPV. Release rig. 16. Clean location and RDM 17. MIRU Coil or E-Line, rforate well ' 18. RU Dowell, frac w 19. RD Dowell, sec a well, handover to production 14. Discussion Mud and Cuttings Disposal and Annular Disposal Requirements f 20 AAC 25.005 (c)(14) Rn applicatioir ! a ;''errnit to ~riti mtsstc, tie accorrrlJrznied by each of the toiiaa.~ing iten3s, excel,t tar an item already on tits wvith the commissfo,~ ,d identified in the ~a;~~lic«th~r?: ,r l:~ i a gene - t deserlption of how the aperator plans to dispose of drilling muct and cuttings grad a statement vi >vftether the operator intends t' request autfrori~atior~ under 2£? ARC 25.:ifsC1 for art annular disposal op:~rativn in the v~~=.%3.; \ vJi~`E`x~~ ~~p+~,c~.\ ~'c>~`\r~ ~ ckc~ok~~ -cv~c~v~S r~rr~~~i,~c~ aC`~ Af~~ aS.045~ ~~C~ I ste fluids generated during the drilling process viii be disposed of either by pumping authorized fluids /~' ~~ to a ermitted annulus on 1 C Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested far hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 2N-333 PERMIT IT Page 6 of 7 Printed: 8-Feb-O6 (t .,~ ~ ~, • I~tion for Permit to Drill, Well 2N-333 Saved: 8-Feb-06 ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Attachment 3 Well Schematic Attachment 4 Cement Program Summary 2N-333 PERMIT IT Page 7 of 7 Printed: 8-Feb-06 -~ ~~~~ ~~ # ~ r r CanocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2N Pad Plan: 2N-333 Plan: 2N-333 Plan: ZN-333wp03 Proposal Report 30 January, 2006 U HALLI~t~fit7~V ORIGINAL Calculation MWwd: Mini ~ atve Enor System: ISCWSA Scan Medad: Trav. Cyl Inter North Error SUdace: Elliptical Conic Warning Mettwrl: Rules Based Geodetic OMUm: NA111927 (NADCON CONUS) Magnetic Model: BGGM2005 HRLLIBURTQN ,,,,e Level 120.21! Spsrty WfR7ag $srvicss RKB: Planned Doy .. -.:;.rgIASP Y: S9N906.18 1500 C .... 0 J -1500 ~-- -3 4 1/2" Csg - 8 1/2" Hole Kuparuk River Unit KPIanu2N 3334 21V-333wp03 Plan: 2N-333 SHL; 103' FNL & 938' FEL; Sec03-T09N-R07E " Kick-off Point; 2.5° DLS, 200° TFO, 250' MD, 250' TVD Continue Dir; 4° DLS, 90° TFO, 702' MD, 700' TVD ~~ Continue Dir; 5° DLS, -33.7° TFO, 1937' MD, 1768' TVD ~ '~ Start Sail; 69.3° INC, 2458' MD, 2044' TVD ~ 11 _ ~~ _ ~ , Start Sail; 46.5° INC, 183T MD, 1700' TVD ` ` _ _ ~ _ -~- 9-5/8" Csg Pt; 3460' MD, 2400' TVD r.~ Continue Dir; 5° DLS, 1$ Z , ~ ~; _ `-`- --` _ _ ~0° TFO, 9918' Ma, 4686' TVD 9 5/8" Csg - 12 1/4" Hole ~~ I w ' ~ 7" Csg Pt;~'I-0233' MD, 483T TVD; 9~9' FNL & 3863' FEL; Sec04-T09N-Rb7E I --~. _ t-~- _ ~ _ '; 7" Csg - 8 1/2" Hole w Target Top Bermuda -Start Drop; 1 °DLS, 180° TFO, 10433' MD, 4969' TVD I . Toe; 11051' MD, 5429' TVD, 999' FNL &4423' FEL; Sec04-T09N-R07E I 1 I i ( I -9000 -7500 -6000 -4500 -3000 -1500 0 -)/East(+) (1500 ft/i n 0 C ~.- 0 0 O N 2000 .,-. N t6 U m 4000 N H 6000 SHL; 103' FNL & 938' FEL; Sec03-T09N-R07E --- ~ -' " ~ Kick-off Point; 2.5° DLS, 200° TFO, 250' MD, 250' TVD 0 -- Continue Dir; 4° DLS, 90° TFO, 702' MD, 700' TVD 10 - - ~ Start Sail; 46.5° INC, 1837 MD, 1700' TVD i 24 i ~~o _"_ - Continue Dir, 5° DLS, -33.7° TFO, 1937 MD, 1768' TVD D~ - I 4io~ - - _ _ _ -Start Sail; 69.3° INC, 2458' MD, 2044' TVD C80 (K-10) C50 7" Csg Pt C37 C40 j \ T7 Targex ~3 (Too Bermudal' C-35 (K-3)eservoir) i -2000 0 ~ ~ 9-5/8" Csg Pt; 3460' MD, 2400' TVD3 5/8" Csg - 12 1/4" Hole Continue Dir; 5° DLS, 180° TFO, 9918' MD, 4686' TVD I ~, ~rn ~I 10233' MD, 483T!TVD; 939' FNL & I$863' FEL; Sec04-i -R07E ~I 7" Cs 8 1/2" Hole Top Bermuda - Start Drop; 1 °DLS, ~I 80° TFO, 10433' MD, 4969' YVD - ~ 4 1/2" Csg - 8 1/2" Hole ~ - -~ , - -Toe; 11051' MD, 5429' TVD, I~99' FNL & 4423' f~EL; Sec04-T09N-R07 ~ - 2N-333wp03 ~_ ,. ~ i - i 2000 4000 6000 8000 10000 ' ~•- ~+C?I~t3~~31~1~5 F~J ~sr<3 Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2N Pad Well: PIan:2N-333 Wellbore: PIan:2N-333 Design: 2N-333wp03 ferry Drilling Services HA4LtBtJRTON inning Report -Geographic _--,~-. _ _. _ ~.. ~-erry gritting Services Local Co-ordinate Reference: Well Plan: 2N-333 TVD Reference: Planned Doyon 14 @ 154.50ft {Doyon 14 (34.3+120.2) MD Reference: Planned Doyon 14 @ 154.50ft {Doyon 14 (34.3+120.2) North Reference: True Survey Calculation Method: Minimum Curvature - Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well PIan:2N-333 Well Position +N/-S +E/-W Position Uncertainty .00 ft Northing: 5,911,906.18ft 0.00 ft Easting: 4&0,654.70ft 0.00 ft Wellhead Elevation: ft __ Latitude: Longitude: Ground Level: __ ~ 70° 10' 12.952" N 150° 18'.59.952" W 120.20ft ~, Wellbore Plan: 2N-333 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 'I I L BGGM2005 - 2/15/2006__ 23.73 _ 80.61 `_ 57,520 -- - ___-- -- Design 2N-333wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 34.30 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (ft) {ft) (ft) (°) 34.30 0.00 0.00 265.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) {°) 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 702.94 11.32 200:00 700.00 -41.92 -15.26 2.50 2.50 0.00 200.00 1,837.87 46.49 279.04 1,700.00 -84.19 -484.60 4.00 3.10 6.96 90.00 1,937.87 46.49 279.04 1,768.85 -72.80 -556.23 0.00 0.00 0.00 0.00 2,458.12 69.26 263.96 2,044.84 -68.68 -991.96 5.00 4.38 -2.90 -33.70 9,918.36 69.26 263.96 4,686.93 -802.91 -7,929.93 0.00 0.00 0.00 0.00 10,403.53 45.00 263.96 4,948.29 -845.47 -8,332.13 5.00 -5.00 0.00 180.00 10,433.53 45.00 263.96 4,969.50 -847.70 -8,353.23 0.00 0.00 0.00 0.00 11,051.93 38.82 263.96 5,429.50 -891.14 -8,763.79 1.00 -1.00 0.00 180.00 9!30/2006 4:23:1 iPM Page 2 of 6 COMPASS 2003.9 9 Build 50 ORI6INn,L C?Ctt~C+DP~i~~I1 Aiask~a • Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2N Pad Wetl: PIan:2N-333 Wellbore: PIan:2N-333 Design: 2N-333wp03 __ i Planned Survey 2N-333wp03 I Sperry Drilling Services Planning Report -Geographic r~ U HALLIBU FiTO N Sperry tirilting 5®rvFess Local Co-ordinate Reference: Well Plan: 2N-333 ND Reference: Planned Doyon 14 @ 154.50ft (Doyon 14 (34.3+120.2) MD Reference: Planned Doyon 14 @ 154.50ft (Doyon 14 (34.3+120.2) North Reference: True Survey Calculation Method: Minimum Curvature MD Inclination Azimuth ND SSND (ft) (°) (°) (ft) (ft) 34,30 0.00 0.00 34.30 -120.20 SHL; 103' FNL & 938' FEL; Sec03-T09N-R07E 100.00 0.00 0.00 100.00 -54.50 200.00 0.00 0.00 200.00 45.50 250.00 0.00 0.00 250.00 95.50 Kick-off Point; 2.5° DLS, 200° TFO, 250' MD, 250' ND ° 300.00 1.25 200.00 300.00 145.50 400.00 3.75 200.00 399.89 245.39 500.00 6.25 200.00 499.50 345.00 600.00 8.75 200.00 598.64 444.14 700.00 11.25 200.00 697.11 542.61 702.94 11.32 200.00 700.00 545.50 Continue Dir; 4° DLS, 90° TFO, 70 2' MD, 700' ND 800.00 11.96 219.07 795.10 640.60 900.00 13.77 235.19 892.61 738.11 1,000.00 16.36 246.98 989.19 834.69 1,100.00 19.42 255.39 1,084.36 929.86 1,200.00 22.77 261.50 1,177.66 1,023.16 1,300.00 26.29 266.08 1,268.63 1,114.13 1,400.00 29.92 269.64 1,356.83 1,202.33 1,500.00 33.63 272.48 1,441.83 1,287.33 1,600.00 37.40 274.81 1,523.21 1,368.71 1,700.00 41.20 276.78 1,600.59 1,446.09 1,800.00 45.03 278.46 1,673.58 1,519.08 1,837.87 46.49 279.04 1,700.00 1,545.50 Start Sail; 46.5° INC, 1837 MD, 1700' ND 1,900.00 46.49 279.04 1,742.78 1,588.28 1,937.87 46.49 279.04 1,768.85 1,614.35 Continue Dir; 5° DLS, -33.7° TFO, 1937' MD, 1768' ND 2,000.00 49.09 276.76 1,810.59 1,656.09 2,100.00 53.38 273.45 1,873.20 1,718.70 2,200.00 57.74 270.48 1,929.75 1,775.25 2,300.00 62.17 267.80 1,979.82 1,825.32 2,400.00 66.64 265.32 2,023.02 1,868.52 2,458.12 69.26 263.96 2,044.84 1,890.34 Start Sail; 69.3° INC, 2458' MD, 2044' ND 2,500.00 69.26 263.96 2,059.67 1,905.17 2,600.00 69.26 263.96 2,095.08 1,940.58 2,700.00 69.26 263.96 2,130.50 1,976.00 2,800.00 69.26 263.96 2,165.91 2,011.41 2,900.00 69.26 263.96 2,201.33 2,046.83 3,000.00 69.26 263.96 2,236.74 2,082.24 3,100.00 69.26 263.96 2,272.16 2,117.66 3,200.00 69.26 263.96 2,307.58 2,153.08 3,300.00 69.26 263.96 2,342.99 2,188.49 3,400.00 69.26 263.96 2,378.41 2,223.91 Map Map +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 0.00 5,911,906.18 460,654.70 0.00 0.00 0.00 0.00 5,911,906.18 460,654.70 0.00 0.00 0.00 0.00 5,911,906.18 460,654.70 0.00 0.00 0.00 0.00 5,911,906.18 460,654.70 0.00 0.00 -0.51 -0.19 5,911,905.67 460,654.51 2.50 0.23 -4.61 -1.68 5,911,901.58 460,653.00 2.50 2.07 -12.80 -4.66 5,911,893.41 460,649.98 2.50 5.76 -25.06 -9.12 5,911,881.17 460,645.45 2.50 11.27 -41.38 -15.06 5,911,864.88 460,639.43 2.50 18.61 -41.92 -15.26 5,911,864.34 460,639.23 2.50 18.85 -58.69 -24.86 5,911,847.62 460,629.54 4.00 29.88 -73.54 -41.17 5,911,832.86 460,613.15 4.00 47.42 -85.84 -63.91 5,911,820.68 460,590.35 4.00 71.14 -95.55 -92.97 5,911,811.13 460,561.25 4.00 100.94 -102.60 -128.20 5,911,804.26 460,525.98 4.00 136.66 -106.98 -169.45 5,911,800.10 460,484.71 4.00 178.13 -108.65 -216.50 5,911,798.67 460,437.66 4.00 225.15 -107.60 -269.13 5,911,799.99 460,385.04 4.00 277.49 -103.85 -327.08 5,911,804.04 460,327.12 4.00 334.89 -97.42 -390.07 5,911,810.80 460,264.17 4.00 397.08 -88.32 -457.79 5,911,820.25 460,196.50 4.00 463.75 -84.19 -484.60 5,911,824.52 460,169.71 4.00 490.10 -77.11 -529.10 5,911,831.83 460,125.26 0.00 533.81 -72.80 -556.23 5,911,836.28 460,098.16 0.00 560.45 -66.49 -601.80 5,911,842.82 460,052.62 5.00 605.31 -59.63 -679.43 5,911,850.09 459,975.03 5.00 682.04 -56.86 -761.82 5,911,853.29 459,892.67 5.00 763.88 -58.20 -848.34 5,911,852.40 459,806.15 5.00 850.18 -63.65 -938.33 5,911,847.42 459,716.15 5.00 940.30 -68.68 -991.96 5,911,842.66 459,662.50 5.00 994.17 -72.81 -1,030.90 5,911,838.74 459,623.54 0.00 1,033.32 -82.65 -1,123.90 5,911,829.38 459,530.50 0.00 1,126.83 -92.49 -1,216.90 5,911,820.03 459,437.46 0.00 1,220.33 -102.33 -1,309.90 5,911,810.67 459,344.42 0.00 1,313.83 -112.17 -1,402.90 5,911,801.31 459,251.38 0.00 1,407.34 -122.02 -1,495.90 5,911,791.95 459,158.34 0.00 1,500.84 -131.86 -1,588.90 5,911,782.60 459,065.30 0.00 1,594.34 -141.70 -1,681.90 5,911,773.24 458,972.26 0.00 1,687.85 -151.54 -1,774.89 5,911,763.88 458,879.22 0.00 1,781.35 -161.38 -1,867.89 5,911,754.53 458,786.18 0.00 1,874.85 1/30/2006 4:23:11PM Page 3 of 6 COMPASS 2003.11 Build 50 ~~~~~~L i r~rt~+~+o~'hifips =.laska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2N Pad Wetl: PIan:2N-333 Wellbore: PIan:2N-333 Design: 2N-333wp03 Planned Survey 2N-333wp03 Sperry Drilling Services Planning Report -Geographic HALIr1BlJ~TC3N Sperry Dr911ing ServlcesL Local Co-ordinate Reference: Well Plan: 2N-333 TVD Reference: Planned Doyon 14 (c~ 154.50ft (Doyon 14 (34.3+120.2) MD Reference: Planned Doyon 14 (~ 154.50ft (Doyon 14 (34.3+120.2) North Reference: True Survey Calculation Method: Minimum Curvature Map Map j MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section ', (ft) (°) (°) (ft) (ft) (ft) {ft) (ft) (ft) (°t100ft) (ft) 3,460.97 69.26 263.96 2,400.00 2,245.50 -167.38 -1,924.60 5,911,748.82 458,729.45 0.00 1,931.86 9-5/8" Csg Pt; 3460' MD, 2400' ND - 95/8" Csg -12 1/4" Hole 3,500.00 69.26 - 263.96 2,413.82 2,259.32 -17122 -1,960.89 5,911,745.17 458,693.14 0.00 1,968.35 3,600.00 69.26 263.96 2,449.24 2,294.74 -181.07 -2,053.89 5,911,735.81 458,600.10 0.00 2,061.86 3,643.09 69.26 263.96 2,464.50 2,310.00 -185.31 -2,093.97 5,911,731.78 458,560.00 0.00 2,102.15 C80 (K-10j 3,700.00 69.26 263.96 2,484.65 2,330.15 -190.91 -2,146.89 5,911,726.45 458,507.06 0.00 2,155.36 3,800.00 69.26 263.96 2,520.07 2,365.57 -200.75 -2,239.89 5,911,717.10 458,414.02 0.00 2,248.86 3,900.00 69.26 263.96 2,555.49 2,400.99 -210.59 -2,332.89 5,911,707,74 458,320.98 0.00 2,342.37 4,000.00 69.26 263.96 2,590.90 2,436.40 -220.43 -2,425.89 5,911,698,38 458,227.94 0.00 2,435.87 4,100.00 69.26 263.96 2,626.32 2,471.82 -23027 -2,518.89 5,911,689.03 458,134.90 0.00 2,529.37 4,200.00 69.26 263.96 2,661.73 2,507.23 -240.12 -2,611.89 5,911,679.67 458,041.86 0.00 2,622.88 4,300.00 69.26 263.96 2,697.15 2,542.65 -249.96 -2,704.89 5,911,670.31 457,948.81 0.00 2,716.38 4,400.00 69.26 263.96 2,732.56 2,578.06 -259.80 -2,797.89 5,911,660.95 457,855.77 0.00 2,809.88 4,500.00 69.26 263.96 2,767.98 2,613.48 -269.64 -2,890.89 5,911,651.60 457,762.73 0.00 2,903.39 4,600.00 69.26 263.96 2,803.40 2,648.90 -279.48 -2,983.89 5,911,642.24 457,669.69 0.00 2,996.89 4,700.00 69.26 263.96 2,838.81 2,684.31 -289.33 -3,076.89 5,911,632.88 457,576.65 0.00 3,090.39 4,800.00 69.26 263.96 2,874.23 2,719.73 -299.17 -3,169.88 5,911,623.52 457,483.61 0.00 3,183.90 4,900.00 69.26 263.96 2,909.64 2,755.14 -309.01 -3,262.88 5,911,614.17 457,390.57 0.00 3,277.40 5,000.00 69.26 263.96 2,945.06 2,790.56 -318.85 -3,355.88 5,911,604.81 457,297.53 0.00 3,370.90 5,100.00 69.26 263.96 2,980.47 2,825.97 -328.69 -3,448.88 5,911,595.45 457,204.49 0.00 3,464.41 5,200.00 69.26 263.96 3,015.89 2,861.39 -338.53 -3,541.88 5,911,586.10 457,111.45 0.00 3,557.91 5,300.00 69.26 263.96 3,051.30 2,896.80 -348.38 -3,634.88 5,911,576.74 457,018.41 0.00 3,651.41 5,400.00 69.26 263.96 3,086.72 2,932.22 -35822 -3,727.88 5,911,567.38 456,925.37 0.00 3,744.92 5,500.00 69.26 263.96 3,122.14 2,967.64 -368.06 -3,820.88 5,911,55$.02 456,832.33 0.00 3,838.42 5,600.00 69.26 263.96 3,157.55 3,003.05 -377.90 -3,913.88 5,911,548.67 456,739.29 0.00 3,931.92 5,700.00 69.26 263.96 3,192.97 3,038.47 -387.74 -4,006.88 5,911,539.31 456,646.25 0.00 .4,025.42 5,800.00 69.26 263.96 3,228.38 3,073.88 -397.59 -4,099.88 5,911,529.95 456,553.21 0.00 4,118.93 5,900.00 69.26 263.96 3,263.80 3,109.30 -407.43 -4,192.88 5,911,520.60 456,460.17 0.00 4,212.43 6,000.00 69.26 263.96 3,299.21 3,144.71 -417.27 -4,285.88 5,911,511.24 456,367.13 0.00 4,305.93 6,100.00 69.26 263.96 3,334.63 3,180.13 -427.11 -4,378.88 5,911,501.88 456,274.09 0.00 4,399.44 6,200.00 69.26 263.96 3,370.05 3,215.55 -436.95 -4,471.87 5,911,492.52 456,181.05 0.00 4,492.94 6,300.00 69.26 263.96 3,405.46 3,250.96 -446.79 -4,564.87 5,911,483.17 456,088.01 0.00 4,586.44 6,400.00 69.26 263.96 3,440.88 3,286.38 -456.64 -4,657.87 5,911,473.81 455,994.97 0.00 4,679.95 6,500.00 69.26 263.96 3,476.29 3,321.79 -466.48 -4,750.87 5,911,464.45 455,901.93 0.00 4,773.45 6,600.00 69.26 263.96 3,511.71 3,357.21 -476.32 -4,843.87 5,911,455.09 455,808.89 0.00 4,866.95 6,700.00 69.26 263.96 3,547.12 3,392.62 -486.16 -4,936.87 5,911,445.74 455,715.85 0.00 4,960.46 6,800.00 69.26 263.96 3,582.54 3,428.04 -496.00 -5,029.87 5,911,436.38 455,622.81 0.00 5,053.96 6,900.00 69.26 263.96 3,617.95 3,463.45 -505.84 -5,122.87 5,911,427.02 455,529.77 0.00 5,147.46 7,000.00 69.26 263.96 3,653.37 3,498.87 -515.69 -5,215.87 5,911,417.67 455,436.73 0.00 5,240.97 7,100.00 69.26 263.96 3,688.79 3,534.29 -525.53 -5,308.87 5,911,408.31 455,343.69 0.00 5,334.47 7,116.13 6926 263.96 3,694.50 3,540.00 -527.12 -5,323.87 5,911,406.80 455,328.68 0.00 5,349.56 C50 7,200.00 69.26 263.96 3,724.20 3,569.70 -535.37 -5,401.87 5,911,398.95 455,250.65 0.00 5,427.97 7,300.00 69.26 263.96 3,759.62 3,605.12 -545.21 -5,494.87 5,911,389.59 455,157.61 0.00 5,521.48 7,400.00 69.26 263.96 3,795.03 3,640.53 -555.05 -5,587.87 5,911,38024 455,064.57 0.00 5,614.98 7,500.00 69.26 263.96 3,830.45 3,675.95 -564.90 -5,680.87 5,911,370.88 454,971.53 0.00 5,708.48 7,600.00 69.26 263.96 3,865.86 3,711.36 -574.74 -5,773.87 5,911,361.52 454,878.49 0.00 5,801.99 1/3012006 423:11PM Page 4 of 6 COMPASS 2003.11 Build 50 041GINAL tJl"1~CflI~"~II1~"J5 #tl~i~ca • Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2N Pad Well: PIan:2N-333 Wellbore: PIan:2N-333 Design: 2N-333wp03 Planned Survey 2N-333wp03 Sperry Drilling Services Planning Report -Geographic • HALLIBEJ#~T'C7N ~n'Y DrilMliing 5enricss __.. Local Co-ordinate Reference: Well Plan: 2N-333 TVD Reference: Planned Doyon '14 (~1 154.50ft (Doyon 14 (34.3+120.2) MD Reference: Planned Doyon 14 r~> 154.50ft (Doyon 14 (34.3+120.2) North Reference: True Survey Calculation Method: Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEY Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) {°J100ft) (ft) 7,680.86 69.26 263.96 3,894.50 3,740.00 -582.70 -5,849.06 5,911,353.96 454,803.26 0.00 5,877.59 C40 7,700.00 69.26 263.96 3,901.28 3,746.78 -584.58 -5,866.86 5,911,352.16 454,7$5.45 0.00 5,895.49 7,800.00 69.26 263.96 3,936.70 3,782.20 -594.42 -5,959.86 5,911,342.81 454,692.41 0.00 5,988.99 7,900.00 69.26 263.96 3,972.11 3,817.61 -604.26 -6,052.86 5,911,333.45 454,599.37 0.00 6,082.50 8,000.00 69.26 263.96 4,007.53 3,853.03 -614.10 -6,145.86 5,911,324.09 454,506.33 0.00 6,176.00 8,047.93 69.26 263.96 4,024.50 3,870.00 -618.82 -6,190.43 5,911,319.61 454,461.74 0.00 6,220.81 C37 8,100.00 69.26 263.96 4,042.94 3,888.44 -623.95 -6,238.86 5,911,314.74 454,413.29 0.00 6,269.50 8,200.00 69.26 263.96 4,078.36 3,923.86 -633.79 -6,331.86 5,911,305.38 454,320.25 0.00 6,363.00 8,300.00 69.26 263.96 4,113.77 3,959.27 -643.63 -6,424.86 5,911,296.02 454,227.21 0.00 6,456.51 8,400.00 69.26 263.96 4,149.19 3,994.69 -653.47 -6,517.86 5,911,286.66 454,134.17 0.00 6,550.01 8,500.00 69.26 263.96 4,184.61 4,030.11 -663.31 -6,610.86 5,911,277.31 454,041.13 0.00 6,643.51 8,600.00 69.26 263.96 4,220.02 4,065.52 -673.16 -6,703.86 5,911,267.95 453,948.09 0.00 6,737.02 8,700.00 69.26 263.96 4,255.44 4,100.94 -683.00 -6,796.86 5,911,258.59 453,855.05 0.00 6,830.52 8,800.00 69.26 263.96 4,290.85 4,136.35 -692.84 -6,889.86 5,911,249.24 453,762.01 0.00 6,924.02 8,900.00 69.26 263.96 4,326.27 4,171.77 -702.68 -6,982.86 5,911,239.88 453,668.97 0.00 7,017.53 9,000.00 69.26 263.96 4,361.68 4,207.18 -712.52 -7,075.86 5,911,230.52 453,575.93 0.00 7,111.03 9,100.00 69.26 263.96 4,397.10 4,242.60 -722.36 -7,168.85 5,911,221.16 453,482.89 0.00 7,204.53 9,200.00 69.26 263.96 4,432.51 4,278.01 -73221 -7,261.85 5,911,211.81 453,389.85 0.00 7,298.04 9,300.00 69.26 263.96 4,467.93 4,313.43 -742.05 -7,354.85 5,911,202.45 453,296.81 0.00 7,391.54 9,400.00 69.26 263.96 4,503.35 4,348.85 -751.89 -7,447.85 5,911,193.09 453,203.77 0.00 7,485.04 9,500.00 69.26 263.96 4,538.76 4,384.26 -761.73 -7,540.85 5,911,183.73 453,110.73 0.00 7,578.55 9,600.00 69.26 263.96 4,574.18 4,419.68 -771.57 -7,633.85 5,911,174.38 453,017.69 0.00 7,672.05 9,629.15 69.26 263.96 4,584.50 4,430.00 -774.44 -7,660.96 5,911,171.65 452,990.57 0.00 7,699.30 T7 9,700.00 6926 263.96 4,609.59 4,455.09 -781.42 -7,726.85 5,911,165.02 452,924.65 0.00 7,765.55 9,800.00 69.26 263.96 4,645.01 4,490.51 -791.26 -7,819.85 5,911,155.66 452,831.61 0.00 7,859.06 9,900.00 69.26 263.96 4,680.42 4,525.92 -801.10 -7,912.85 5,911,146.31 452,738.57 0.00 7,952.56 9,918.36 69.26 263.96 4,686.93 4,532.43 -802.91 -7,929.93 5,911,144.59 452,721.49 0.00 7,969.73 Continue Dir; 5° DLS, 180° TFO, 9918' MD, 4686' TVD 10,000.00 65.18 263.96 4,718.53 4,564.03 -810.83 -8,004.76 5,911,137.06 452,646.62 5.00 8,044.97 10,100.00 60.18 263.96 4,764.42 4,609.92 -820.17 -8,093.08 5,911,128.17 452,558.26 5.00 8,133.77 10,200.00 55.18 263.96 4,817.87 4,663.37 -829.06 -8,177.09 5,911,119.72 452,474.21 5.00 8,21823 10,233.00 53.53 263.96 4,837.11 4,682.61 -831.88 -8,203.76 5,911,117.04 452,447.54 5.01 8,245.04 7" Csg Pt; 10233' MD, 483T TVD; 939' FNL & 3863' FEL; Se c04-709N-R07E - 7" Csg - 8 1!2" Hole ~,t) ~~'~~~ ~~ ~ c~~\ ~eep~ 10,300.00 50.18 263.96 4,878.49 4,723.99 -837.43 -8,256.15 5,911,111.77 452,395.12 5.00 8,297.72 10,398.16 45.27 263.96 4,944.50 4,790.00 -845.07 -8,328.35 5,911,104.50 452,322.89 5.00 8,370.31 T3.1 10,400.00 45.18 263.96 4,945.80 4,791.30 -845.20 -8,329.65 5,911,104.37 452,321.59 5.00 8,371.62 10,403.53 45.00 263.96 4,94829 4,793.79 -845.47 -8,332.13 5,911,104.12 452,319.10 5.00 8,374.11 10,433.53 45.00 263.96 4,969.50 4,815.00 -847.70 -8,353.23 5,911,102.00 452,298.00 0.00 8,395.32 Target Top Bermuda -Start Drop ; 1°DLS, 180° TFO, 10433' MD, 4969' TVD - T3 (Top Bermuda) - 2N-333wp03 Top Bermuda - 2N-333wp01 T 10,500.00 44.34 263.96 5,016.78 4,86228 -852.62 -8,399.70 5,911,097.33 452,251.51 1.00 8,442.04 10,600.00 43.34 263.96 5,088.91 4,934.41 -859.90 -8,468.57 5,911,090.40 452,182.61 1.00 8,511.29 10,700.00 42.34 263.96 5,162.24 5,007.74 -867.06 -8,536.18 5,911,083.59 452,114.96 1.00 8,57927 10,800.00 41.34 263.96 5,236.74 5,082.24 -874.08 -8,602.51 5,911,076.92 452,048.61 1.00 8,645.96 ~~. 1/30/2006 4:23:11 PM Page 5 of 6 COMPASS 2003.11 Build 50 ORIGINAL • ~-' ,_ t`~Cl(~Ct?~~1~~1 ~-' S er Drillin Services p rY 9 Pi i R t G hi HALUBURT~JN __. ~ ann ng epor - eograp c Dr~lling a~iervice:s 5tperry Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2N-3:i3 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned Doyon 14 @ 154.50ft (Doyon 14 (34.3+120.2) Project: Kuparuk River Unit MD Reference: Planned Doyon 14 ~~__~ 154.50ft (Doyon 14 (34.3+120.2) Site: Kuparuk 2N Pad North Reference: True Well: Plan: 2N-333 Survey Calculation Method: Minimum Curvature Wellbore: PIan:2N-333 Design: 2N-333wp03 _ _ - Planned Survey 2N-333wp03 Map h9ap ', MD Inclination Azimuth TVD SSTVD +N/-S +El-W Northing Easting DLSEV Vert Section '~ (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,803.67 41.30 263.96 5,239.50 5,085.00 -874.33 -8,604.92 5,911,076.68 452,046.20 1.01 8,648.38 T2 (Base Reservoir) 10,836.86 40.97 263.96 5,264.50 5,110.00 -876.63 -8,626.63 5,911,074.50 452,024.47 1.00 8,670.21 C-35 (K-3) 10,900.00 40.34 263.96 5,312.40 5,157.90 -880.96 -8,667.53 5,911,070.38 451,983.55 1.00 8,711.33 11,000.00 39.34 263.96 5,389.19 5,234.69 -887.70 -8,731.24 5,911,063.97 451,919.82 1.00 8,775.38 11,051.93 ` 38.82 263.96 5,429.50 ~ 5,275.00 -891.14 -8,763.79 5,911,060.70 451,887.26 1.00 8,808.10 Toe; 11051' MD, 5429' TVD, 999' FNL &4423' FEL; Sec04-T09N-R07E - 41/2" Csg - 8 1!2" Hole - - - -- Geologic Targets Plan 2N-333 I TVD Target Name +N!-S +E!-W Northing .Easting (ft) -Shape ft ft (ft) (ft) 4,969.50 2N-333wp03 Top Bermuda -847.70 -8,353.23 5,911,102.00 452,298.00 - Point Prognosed Casing Points Measured Vertical Gasing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 3,460.97 2,400.00 9-5/8 12-1/d 10,233.00 4,837.11 7 8-112 11,051.92 5,429.50 4-1/2 8-1/2 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W Name (ft) (o) (o} (ft) (ft) (ft} 3,643.09 69.26 263.96 2,464.50 -185.31 -2,093.97 C80 (K-10) 7,116.13 69.26 263.96 3,694.50 -527.12 -5,323.87 C50 7,680.86 69.26 263.96 3,894.50 -582.70 -5,849.06 C40 8,047.93 69.26 263.96 4,024.50 -618.82 -6,190.43 C37 9,629.15 69.26 263.96 4,584.50 -774.44 -7,660.96 T7 10,398.16 45.27 263.96 4,944.50 -845.07 -8,328.35 T3.1 10,433.53 45.00 263.96 4,969.50 -847.70 -8,35323 T3 (Top Bermuda) 10,803.67 41.30 263.96 5,239.50 -874.33 -8,604.92 T2 (Base Reservoir) 10,836.86 40.97 263.96 5,264.50 -876.63 -8,626.63 C-35 (K-3) (/3012006 4:23:11 PM Page 6 of 6 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2N Pad Plan: 2N-333 Plan: 2N-333 2N-333wp03 Anticollision Report 19 December, 2005 • HALL~tBt~RTON Sperry Qriling Services ORIGINAL • • a 9l Paiiiry~yt` 47 i3f.~~i~~ d i'% p! ~~ i i ~1 ~~111 ~~~1~11 ~'Oe ~~ t ~e~r.a $.^. .°.;~ °o8e°O°e88°o Hcc$°m°J°$°$ d'PoO °e'°v. °c$$$$$$ ~co ~ 'J,c J.o~ ~ggn °a +'am~'r~~' YY ~: ~4WW V'g8a°T._°ry gvg ga teTTq.. t ~ T "Y ~: Y'Y W W °P P°,888 m'~a«v° r~9$8~3~~°'°' ~sasaa~~~~~ 8~eaad~dd o°8et&&==~~a 5~..,$oo'd'mv~$'"'~ 3. .. n.-,av.~erma.- d V V RI I I I I I I I I''I..... .. :,x. ~~ f _ ~ .' .~ 4 .. .- $ ~ r. ORIGINAL 5 C s t 4 t w E F a i Z I- ;o_e° m+~ E ~ m gas :o° qUv ~ g~ ae~ ~o~c ~,_~_ Z =ws~ - ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) P roied: Kuparuk River Unit Reference Site: Kuparuk 2N Pad Site Error. O.OOit Reference Well: Plan: 2N-333 Well Error O.OOfI Reference Wellbore Plan: 2N-333 Reference Design: 2N-333wp03 Sperry Drilling Services Anticollision Report HALLIBURTON Sperry Drilling Services Local Co-ordinate Reference: Well Plans 2N-333 TVD Reference: Planned Doyon 14 @ 154.50ft (Doyon 14 (34.3+120 2)) MD Reference: Planned Doyon 14 <o~ 154.50ft (Doyon 14 (34.3+1202)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1 00 sigma Datahase: EDM 2003.11 Single User Db Offset TVD Reference: Offset Datum teference 2N-333wp03 ~ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference nterpolation Method: MD Interval 25.OOft Error Model: ISCWSA Iepth Range: Unlimited Scan Method: Trav. Cylinder North tesutts Limited by: Maximum center-center distance of 1,301.76ft Error Surface: Elliptical Conic yarning Levels evaluated at 0.00 Sigma Survey Tool Program Date 12/19%2005 From To (ftl (ft) Survey (Wellbore) Tool Name Description 34.30 850.00 2N-333wp03 (Plan: 2N-333) CB-GYRO-SS Camera based gyro single shot 850.00 11,051.93 2N-333wp03 (Plan: 2N-333) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Site Name Offset Well -Wellbore -Design Kuparuk 2N Pad 2N-316 - 2N~16 - 2N-316 2N-317 - 2N-317 - 2N-317 2N-318 - 2N-318 - 2N-318 2N-319 - 2N-319 - 2N-319 2N-320 - 2N-320 - 2N-320 2N-321 - 2N-321 - 2N-321 2N-321 -2N-321A-2N-321A 2N-323 - 2N-323 - 2N-323 2N-325 - 2N-325 - 2N-325 2N-326-2N-326-2N-326 2N-326 -Plan 2N-326A -Plan 2N-326A (wp02 2N-329 - 2N-329 - 2N-329 2N-331 -2N-331 -2N-331 2N-332 - 2N-332 - 2N-332 2N-332 - 2N-332P61 - 2N-332P61 2N-335 - 2N-335 - 2N-335 2N-337 - 2N-337 - 2N-337 2N-337 - 2N-337A - 2N-337A 2N-339 - 2N-339 - 2N-339 2N-341 -2N-341 -2N-341 2N-343 - 2N-343 - 2N-343 2N345 - 2N-345 - 2N-345 2N-347 - 2N-347 - 2N-347 2N-348 - 2N-348 - 2N-348 2N-349 - 2N-349 - 2N-349 2N-349 - 2N-349A - 2N-349A 2N-350 - 2N-350 - 2N-350 Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation blaming Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 600.00 625.00 257.30 1128 246.14 Pass -Major Risk 326.33 325.00 240.31 5.60 234.71 Pass -Major Risk 579.54 600.00 223.75 10.39 213.62 Pass -Major Risk 326.84 325.00 210.07 5.69 204.39 Pass -Major Risk 271.69 275.00 196.10 4.78 191.33 Pass -Major Risk 538.10 550.00 178.20 10.34 167.94 Pass -Major Risk 538.10 550.00 178.20 10.34 167.94 Pass -Major Risk 540.49 550.00 150.04 10.32 139.79 Pass -Major Risk 377.03 375.00 118.87 6.32 112.64 Pass -Major Risk 585.99 600.00 98.70 10.90 88.00 Pass -Major Risk 605.31 625.00 101.02 11.17 90.08 Pass -Major Risk 304.89 300.00 61.06 5.29 55.77 Pass -Major Risk 428.76 425.00 29.23 7.84 21.40. Pass -Major Risk ~----: 400.65 400.00 11.79 7.18 4.67 Pass -Major Risk ~--~ 400.65 400.00 11.79 7.18 4.67 Pass -Major Risk 60621 600.00 18.46 10.74 7.79 Pass -Major Risk 1,017.51 1,000.00 60.07 20.45 42.14 Pass -Major Risk 1,017.51 1,000.00 60.07 20.45 42.14 Pass -Major Risk 663.86 650.00 84.10 12.14 72.01 Pass -Major Risk 538.83 525.00 119.98 9.50 110.56 Pass -Major Risk 514.86 500.00 149.10 9.12 140.00 Pass -Major Risk 1,592.91 1,500.00 134.97 35.34 107.19 Pass-Major Risk 432.79 425.00 209.95 7.61 202.40 Pass -Major Risk 2,628.59 2,425.00 86.47 61.90 4226 Pass -Major Risk 1,541.55 1,475.00 44.44 24.96 19.76 Pass -Major Risk 1,541.55 1,475.00 44.44 24.96 19.76 Pass -Major Risk 2,933.63 2,600.00 284.34 74.13 227.70 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation i21tg/2005 4:00:48PM Page 2 of 2 COMPASS 2003. i i Suild 50 ORIGINAL Plan: 2N-333wp03 (Plan: 2N-333/Plan: 2N-333) 2N-333wp03 2N-316, 2N-316, 2N-316 V9 2N-317, 2N-317, 2N-317 V2 2N-318, 2N-318, 2N-318 V4 2N-319, 2N-319, 2N-319 V2 2N-320, 2N-320; 2N-320 V2 2N-321, 2N-321, 2N-321 V2 ?N-321, 2N-321A, 2N-321 A V4 2N-323, 2N-323, 2N-323 V2 2N-325, 2N-325, 2N-325 V2 2N-326, 2N-326, 2N-326 V3 ~ 2N-326, Plan 2N-326A, Plan 2N-326A (wp(Y2) VO 2N-329, 2N-329, 2N-329 V2 2N-331, 2N-331, 2N-331 V2 2N-332, 2N-332, 2N-332 V6 2N-332, 2N-332PB 1, 2N-332PB1 V4 2N-335, 2N-335, 2N-335 V2 2N-337, 2N-337, 2N-337 V 1 2N-337, 2N-337A, 2N-337A Vl 2N-339, 2N-339, 2N-339 V8 2N-341, 2N-341, 2N-341 V9 2N-343, 2N-343, 2N-343 V l I 2N-345, 2N-345, 2N-345 V 1 2N-347, 2N-347, 2N-347 V 10 2N-348, 2N-348, 2N-348 V 18 2N-349, 2N-349, 2N-349 V4 2N-349, 2N-349A, 2N-349A VS 2N-350, 2N-350, 2N-350 V9 ~~~~ sir ~~~ ~FQ £~a~ ~~~ ~~~~ 7 M M M ~ M M C ~ d f h ~ Q N N N f` 7 ~ ` A m fh M aaaa Z YY~m N .. ~~a U ~ - ~ d •- ~ -o u~ ~ a a` °y~ ~~ '~~~~ ~~ ~~;~ ~~~~~~ ~~~30 d 6/'1! s r.r .... ~~ V V ~_ ~m ry$~~$gS "~r'nSi`S p Y Y K y N F a~ s~ Z 0 H M] W J J YJ m V ~t m h m L .` 0 `m a V/ ORIGINAL ODMNOI: con«OnnnIID{Alptko lKVDO(Vk) CiIEO«MOn: -0.]0 JoD NO: h12 Kupprvk Nrnv UMl Abp-YC D.[YMAOn'. x].)n Anf NO: WN: xN~JJJwDO] qp: 80.61 AN NO: IUD: YN/A Dp{ysp pa 100 Jyn.m (rvD)nN.r.nc.: - s.n«.1DDNwn Orlglnal VS Plane: 265.00 - fo,.Mw.f: Ian. xeaaJ p x nnaasn.~o Vlew VS Plasle: 265.00 ~ nnn X.b1X' lsa sa n v. 5911906.18 UnXSy~l.m: O ~~~ V .,.~.~ Z ~~ Coml L Q N O O V 1 O) k`- d T ,ants: Nearest wells in POOL. Plan View 1355.08 ft to 2N-343 -w t~.v ° 8 S 8 8 8 8 S S 8 S S g ~ ~ ° 1384.87 ft to 2 N - 331 w t~ C~ '~~~t~ } -~-~-~-fi--~~~-~-r-rt~~ i I I I I I I I I I 1551.96 ft to 2N-341 ~ -~ t ~ ~----1---1- --~----~---~----~----L---~--~-----~----~---~-- I I I I I I I I I I I I I I I I I I I I I I s915: I I I I I I I I I I -- 1 --~---~'---'~'---I-'---~---"~'---~"---I---"+---"~"---{'- z N I I I I I I I I I I I 5914: I I I I I I I I I I i I I I I I I I I I I t __'1-_._.t-__-t-._-f---.1-_.-f-__-~'---f ---1-_.-t--_-~'-_- ---~ 5913: I I ! I I I z i i i 2N-3~1 _-~__._.~- _~._ I I I F5912: I I 2N-33Bwp03 I ~ i !_. -- --- I I I I - -~---r__-~- - __ 591 I: __--__--- I I I I I I I I I section View I-~- 2N 333w 03 Plan -~- 2N-331 MWD --~- 2N-341 - 2N-343 MW DI I I 2N-34 I I I ~ - __-__._- 5910: I I I I I I __ _.___. _._._-_...-_- _. - _-__.1_.._.-- _.....____ _ .___._._ ._ _-.___._ _..___._ 1 ~--~-_.-~-__-+-._-~--~-_.-~-__-~---~--~---~-__-~-_---- 5909: PO L: 48 5' to 5085 Sub ea T D i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I --J--- ~ ---L---~ --J--- ~ ----L---L--~--- ~ ---- ~ ---L-- I I I I I I I I I 1 I I s9oa; I I I I I I I I I I I I I I I I I I I I I I I I --~----r---r----r---n----t----r---r---t----*----r- --r-- I I I I I I I I I I I I I I I I I I t I I I 5907: I I I I I I I I I I I I I I ---s- - 5906: East (•) / west (-) - _- - ~ ~ '-}~ 186 --_-____-. _ --_ --- 286 386 2N-3 1 N-341 2 _343 2N-33 03 ~ i - 586 ~ ~ ~ )3 )3 )3 )3 )3 )3 J3 l3 )3 )3 • [~ p p p p p a a a a pa. a a a a a ~ ~ ~ ~ ~ ~ ~ ['7 N aJ cal (p~ O O' n n f\ ~ n n n n n n n n n n ~ ~!1 O M (V (`1 M Y N -O I~ Op P O (V M V N ~O Vertical Section along "View VS Plane" -' Combo Preview Page 1 of 1 (Toolboxt.>ds) 12/192005 4:54 PM • Closest in POOL .'oi'°°°a'~'J ~i `~~ ~® i Closes t Approach: Reference We ll: 2N-3 33wp03 Plan Offset Well: 2 N-343 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist.. Depth Angle Azi. TVD E(+)/W(-) (265°) Comments Depth Angle Azi. ND E(+)/W(-) (265°) Comments in istance in istance (1355.08 ft) in (1355.08 ft) in POOL (4815 - 5085 POOL (4815 - 5085 Subsea TVD) to 2N- Subsea TVD) to 2N- 1355.08 10450 44.84 263.96 4826.423 5911101 452285.5 8407.053 343 MWD 9275 43.72 263.41 5081.494 5910592 453515.2 7223,124 333wp03 Plan Closes t Approach: Reference We ll: 2N-3 33wp03 Plan Offset Well: 2 N-331 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist.. Depth Angle Azi. TVD E(+)/W(-) (265°) Comments Depth Angle Azi. TVD E(+)/W(-) (265°) Comments in istance m istance (1384.87 ft) in (1384.87 ft) in POOL (4815 - 5085 POOL (4815 - 5085 Subsea TVD) to 2N- Subsea TVD) to 2N- 1384.87 10700 42.34 263.96 5007.481 5911084 452114 8579.384 331 MWD 10700 55.73 272.11 4823.424 5912418 451791.2 8791.802 333wp03 Plan Closes t Approach: Reference We ll: 2N-3 33wp03 Plan Offset Well: 2 N-341 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+)/S(-) View VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dist. Depth Angle Azi. TVD E(+)/W(-) (265°) Comments Depth Angle Azi. TVD E(+)/W(-) (265°) Comments POOL Min Distance POOL Min Distance (1551.96 ft) in (1551.96 ft) in POOL (4815 - 5085 POOL (4815 - 5085 Subsea TVD) to 2N- Subsea TVD) to 2N- 1551.96 10803.67 41.3 263.96 5084.738 5911077 452045.2 8648.501 341 11875 58 263.95 4823.055 5910795 450541.7 10170.04 333wp03 Plan 2N-333wp03 PoolSummary.xls 12/19/2005 4:57 PM • 2N-333 drilling Hazards iummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 12-1/4" Surface Hole / 9-5/8"" Casino Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~ Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Anti-collision Low Follow directional plan as close as practical. Run SSG ros on surface interval 8-1/2" Production Hole / 7" X 4-1/2" Casing Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, material on Pressure location for increased mud wei ht. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool, decreased mud wei ht Lost Circulation Moderate Reduced um rates mud rheolo LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out ~~ ~ ~ ~ ~ ~] ~ 2N-333 Drilling Hazards Summary TARN 2N-333 Proposed Completion Schematic 4-1/2" Completion String 16" 62.6# Conductor +/- 115' MD/TVD TAM 9-5/8" Port Collar Grade BTC Threads (+/- 1000' MD/TVD) Depths are based on Doyon 14 RKB ConocciPhillips 4-1 /2" FMC Gen 5 Tubing Hanger, 4-1/2" L-80 IBTMod pin down 4-1/2" 12.6# L-80 IBTMod Spaceout Pups as Required 4-1/2" 12.6# L-80 IBTMod Tubing to Surface 4-1/2" Camco 'DB' nipple w/ 3.875" No-Go Profile. 4-1 /2" x 6' L-80 handling pups installed above and below, IBT set at +/- 500' MD TUBING AND HANGER TO BE DRIFTED TO 3.92" (DB Lock OD = 3.910") Use of port collar at the discretion of the drilling team. 4-1 /2" 12.6# L-80 IBTMod tubing to landing nipple 4-1/2" x 1" Camco'KBG-2' Mandrels w/ DV's and BK latch's (Max. OD 5.985", ID 3.833"), IBTMod pin x pin, 4-1/2" x 6' L-80 IBTMod box x box handling pup installed above, 4-1/2" x 6' L-80 IBTMod box x pin handling pup installed below. Spaced out w/ 4-1/2" 12.6# L-80 IBTMod tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined Surface csg. 9-5/8" 40# L-80 BTC +/- 3460' MD/ 2400' TVD 4-1/2" x 1" Camco'KBG-2' mandrel w/ DCK-2 shear valve and BEK latch (Max. OD 5.985", ID 3.833"), IBTMod pin x pin, pinned for 3000 psi shear (casing to tubing differential), 4-1/2" x 6' L-80 IBTMod box x box handling pup installed above, 4-1/2" x 6' L-80 IBTMod box x pin handling pup installed below 1 jt 4-1/2" 12.6# L-80 IBTMod tubing 4-1/2" Baker'CMU' sliding sleeve w/ 3.81" Camco No-Go profile, IBTMod box x pin. 4-1/2" x 6' L-80 IBTMod handling pup installed above 4-1/2" Camco'DB' nipple w/ 3.75" No-Go profile. 4-1l2" x 16' L-80 IBTMod space out pup installed above, 4-1/2" x 6' handling pup installed below Intermediate csg 7" 26.0# L-80 BTCM +/- 10,233' MD / 4837' TVD Future Perforations 4-1/2" 12.6# L-80 IBTModMOD 4.92" Spec. Clearance +/- 11,051' MD / 5429' TVD 1 jt 4-1/2" 12.6# L-80 IBTMod tubing 4-1/2" Baker 80-47 GBH-22 casing seal assembly w/ 15' stroke, 4-1/2" L-80 IBTMod box up, 4-1/2" x 6' L-80 IBTMod handling pup installed on top Baker Casing Seal Receptacle, 194-47, 7" BTCM x 4-1/2" IBTMod Baker 7" (Max) OD x 4-3/4" ID 17' Seal Bore Extension CSR set at +/- 100' above top perforation ORIGINAL 2/6/2006 CemCADE Preliminary Job Design ~~~ 9 5/8" Surface Casing on purposes Rig: Doyon 14 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 1/25/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6#, H-40 grade at 110 ft. MD < Base of Permafrost at 1,225 ft. MD (1,200 ft. TVD) < Top of Tail at 2,100 ft. MD < 9 518", 40.0#, L-80 grade in 12 1/4" OH TD at 3,461 ft. MD (2,400 ft. TVD) Mark of Schlumberger Volume Calculations and Cement Systems (Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. Top of tail slurry is designed to be 875' below base of permafrost.) Lead Slurry (minimum pump time 215 min.)ASL @ 10.7 ppg, - 4.45 ft3/sk 0.7632 ft3/ft x (110') x 1.00 (no excess) = 84 ft3 0.3132 ft3/ft x (1225' - 110') x 4.00 (300% excess) = 1396.9 ft3 0.3132 ft3/ft x (2100' - 1225') x 1.50 (50% excess) = 411.1 ft3 84 ft3 + 1396.9 ft3+ 411.1 ft3 = 1892 ft3 1892 ft3 / 4.45 ft3/sk = 425.2 sks Round up to 426 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 166 min.) DeepCRETE @ 12.0 ppg - 2.57 ft3/sk 0.3132 ft3/ft x (3461' - 2100') x 1.50 (50% excess) = 639.4 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 639.4 ft3 + 34.1 ft3 = 673.5 ft3 673.5 ft3/ 2.57 ft3/sk = 262.1 sks Round up to 263 sks BHST = 61°F, Estimated BHCT = 76°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 6.0 336.9 56.2 91.2 DeepCRETE 5.0 119.9 24.0 115.2 Drop top plug 0.0 0.0 5.0 120.2 Water 5.0 20.0 4.0 124.2 Switch to rig 0.0 0.0 5.0 129.2 Mud 7.0 227.4 32.5 161.7 Slow & bump plug 3.0 9.0 3.0 164.7 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 141 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 1/25/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com < 7", 26.0#, L-80 grade in 8 1/2" OH < Top of Tail at 9,933 ft. MD < x-over at 10,233 ft. MD < Top of Bermuda , / at 10,433 ft. MD ~! < 4 1/2", 12.6#, L-80 grade in 8 1/2" OH TD at 11,052 ft. MD (5,430 ft. TVD) Mark of Schlumberger CemCADE Preliminary Job Design 7" x 4-'/2" Production String ~eliminary Job Design based on limited input data. For estimate purposes oN~ `. € ! I `, 6 ,, Volume Calculations and Cement Systems Volumes are based on 9.12" OH. Top of tail slurry is designed to be 500' above top of Bermuda Tail Slurry (minimum thickening time 165 mina GasBLOKvii/ Class G + D600G, 6155, D047, D065, per lab testing @ 15.8 ppg, 1.17 ft !sk 0.1268 ft3/ft x 300' x 1.50 (50% excess) = 57.1 ft3 0.2836 ft3/ft x (11052' - 10233') x 1.23 (23% excess) = 285.7 ft3 0.0854 ft3/ft x 60' (Shoe Joint) = 5:1 ft3 57.1 ft3 + 285.7 ft3 + 5.1 ft3 = 347.9 ft3 347.9 ft3/ 1.17 ft3/sk = 297:3 sks Round up to 298 sks BHST = 134°F, Estimated BHCT = 115°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop wiper 0.0 0.0 5.0 23.0 MUDPUSH II 5.0 40.0 8.0 31.0 GasBLOK 5.0 62.6 12.5 43.5 Drop combo plug 0.0 0.0 5.0 48.5 Water 4.0 12.0 3.0 51.5 Switch to rig 0.0 0.0 5.0 56.5 Mud 6.0 381.6 63.6 120.1 Slow & bump plug 3.0 9.0 3.0 123.1 MUD REMOVAL Recommended Mud Properties: 1 T ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 1-% centralizers perjoint across entire cemented interval with 2 per joint on the shoe track. ORIGINAL • SHARON. K. ALLSllP-DRAKE CONOCOPHILLIPS 1133 ATO 1530 , 700 G ST ANCHORgGE AK 99501 DaTE ~ VAC ,1 ` ~ ~%c'~'''CJ 56-T551/441 ORDER OFE ~/ ~I ~!; ~!' ~ JPMorganChase ~ ~ valid up To 000 ~ouars o.~,o~~.~. _ JPMorgan Chase Bank, N.A. Columbus, OH / y,~. MEMO !.`.(~j ~ ~ ~ ~:044LL55LL~:52B747L907927u -~_ • .~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ Z/V '" J~ PTD# 2--C~(~, ~V2~ t° ~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -`) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1!25/06 C:\j ody\transmitta(_checkl i st WELL PERMIT CHECKL[ST Field & Pool KUPARUK RIVER, TARN OIL - 490165 ___ _Well Name; KUPARUK RIV U TARN 2N-333 ____Program DEV Well bore seg ^ PTD#:2060250 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached_______------------- ~- Yes_---__ ____-.--______----_--_.--.--_--- --- - 2 Lease number appropriate - Yes - -------------------------------------- - - - 3 Uniquewell_nameandnumber__________________________ ____________ Yes____-- _--_ 4 Well located in_a_d_efinedpool___________________________ ________ ___Yes--____ _KUPARUK RIVER,_TARN_OIL-490165, governed by CO430A--________---_--________-_____ 5 Well located proper distance_fromdrilling unh_boundary- - - , - - - - Yes - - - - Well lies -3800 from-KRU and Tam PA-boundaries, - . - - - - --------------- 6 Well located proper distance from other wells_ - - - - - _ - - _ Yes Conforms to-required 10-acre spacing: nearest wells a[e--1300' & ~1600'_awa ._ . - y - 7 Sufficient acreageavail_ablein_tl_rillingunit____________________ ________ ___Yes_-___ _____.---_____----_--_-.-..--_- - -_- ------------------------------ 8 Iftleviated,is-wellboreplat_inclu_ded_________________.--__ ____---_____ Yes_--__ ___-___ - ~ - -- 9 Operator only affected parfy_ Yes _ _ _ 10 Operator has appropriate_bondinfgrce -- ----- --------- -- -- -- -Yes - -- -- --- -- - ----~---- -- --------- - - -------- -- -- 11 Permit can be issued without conservation order.-_____________ ___________Yes___-. .----- .__--__----.----__-_--_-.._-- -____.._..----_--___---..---.- Appr Date 12 Pe[mitcanbeissuedwithoutadministrative_approval------------- ----- ------Yes--___ _-----____----_____.-.._____-__----...-_-__--_- .....-.________-.-- SFD 21912006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_ Injection Order # (put_1O# in_comments)_(Fpr- NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - ... - - - _ _ _ _ - - . - _ . - - - _ _ - - _ _ _ _ - - - . - - 15 All wells-within 114-milearea_ofreyiewidentified(FOrservicewellonly)___ ____________ NA___-__- __-_----_-_._.-.--.. _..__.__-_-..-_..------.--..----__.--_.-_...----- 16 Pre-produced injector; duration of preproduction I_essthan 3 months_(For_service well only) - - NA- _ - - - ACMP_Findingof Consistency_hasbee_nissued_forthisproject_-__-__ _____-.-.-._ NA_______ __________________________..--..__--__.--.--.-_- -_.-_-. --. ___ Engineering 18 Condu_ctorstcing-provided-________ _ - - ______---- -Yes______ _______________. - 19 Surface casing_protectsallknownUSDWs--- ---- ---------- ------_-..- NA_____-- .All aquifersexemped40_CFR147:102(b)(3}.____-----_______-----________-_-_---__ 20 CMT-vol_adequ_ate_tocircul_ate-onconducto[&surf_csg____________ __________-Yes_____ _----_____----____ _..-________---_...-.-__-__--_..-...-_--__-_---- 21 CMT_v_ol_ adequ_ate_to tie-in long string to surf csg_ - - - - . _ _ - No- - All hydrocarbon zones will_ be_covered. Annular disposal- may-be_proposed, - - - - - - 22 _C_MT-willcoyerallknown_protluctivehorizons__________________ __________ _Yes__-__ ___ --._ 23 Casing designs adequate forC,TB&_permafrost_______________ ____________Yes__.--. .-_____-----_____-.._--______---.-.---_____-.--.----__--____--..----- 24 Adequate tankage-or reserve pit - - - - . - _ .. - - Yes - _ - _ - Rig is-e-quipped with steel-pits. _NO reserve_pitplanned, All waste to approved disposaiwells._ - . - 25 Ifa-re-drill,has_a_1.0-403 forabandonmentbeenapproved__________ ____________ NA-__-___ _----______-___----.____-__--__- -._-_--__-_---...----___---_--_ 26 Adequate wellbore separation,proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ . _ _ - -Proximity analysis performed. Traveling cylinder path calculated, Gyros possible in surface_ hole. _ _ _ _ _ _ _ _ - _ 27 Ifdiverterrequired,doesitmeetregulations___________________ ____________Yes-_____ -----____-.---____ -_-__________..-.----____.__-.--.-___--_-----._ Appr Date 28 Drilling fluid_program schematic & equip list adequate- ... - - - - - ... - - - - Yes . - - - Maximum expected formation pressure 9.3_EMW._ Planned MW up to_9.9 ppg, - - - _ - - - _ TEM 219!2006 29 BOPEs,_tlo they meet regulatipn _ _ _ _ Yes _ - _ _ .... . 30 BOPS-press rating appropriate; test to_(put prig in commenis)- - - - - . - - - Yes _ _ - MA$P calculated at 1839 psi, 3000-psi_appropriate. CPAI usually-testes to 5000psi, - - _ _ - 31 Choke_manifoldcomp_lieswlAPI_Rf?-53(tvlay84)---______---___ __________ _Yes-__--- _-____-.----___...--_--_-.-_---..-_--___---..-_-_ 32 Work willoccur-withoutoperationshutdown------------------- ------------Yes_---_. .--___ ---_____ _..--__-_-..-----__---._-..---_---__--.-._.--_ 33 Is presence_of H2Sgos-probable - - - - - - - - Yes H2S has been reported in offset wells. Mud should-preclude on rig. _Rig has sensors_and alarms. 34 Mechanical condition of wells within AOR verified (For s_etvice well only - NA_ - - - _ _ Geology 1 35 Permitean be issued wlo hydrogen-sulfide measures - - - - - - - - - - - - - - - - - - - -- - - - -N_o_ _ _ - - - - - Nearby_wells 2N-329_a_nd 2N-341 measured 10 & 20 ppm H2S,_respectively, during_Nov 2004. _ - _ - ... - . _ _ 36 Data_presented on_ potential overpressure zones- - _ - - - - Yes _ - - Expected r_eservoirpressure is 9.3-ppg EMW; will be drilled with 9.6 - 9.9 ppg mud. _ _ - - - - Appr Date 37 Seismic analysis-of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ - - - - -Application notes hydrates have been_encQUntered at X1200' ND &-the W_$ak sands have_gas shows at~1900'.- SFD 21912006 38 Seabed condition suryey_(ifoff-shore) _ - . - ~ - _ - - _ -- NA - - - - 39 Contact name/phone for weekly_progressreports-[exploratoryonly]_____ _____ ____ _ NA-______ __----____------___--.-______ ---..__..--____...__.-______--_-.-- Geologic Engineering Commissioner: Date: Com issioner: Date C mis r Date p ~5 ~ I ,oJ,~ Z~o~6 a-,o -~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infommation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 18 17:26:25 2006 Reel Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF RECEIVED AUG 3 0 2006 Alaska 08 & Gas cons. commission Anchorage Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: 2N-333 API NUMBER: 501032052500 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-AUG-06 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004236152 W-0004236152 LOGGING ENGINEER: C. ZAWADZKI R. FRENCH OPERATOR WITNESS: E. VAUGHN J. HABERTHUR SURFACE LOCATION SECTION: 3 TOWNSHIP: 9N RANGE: 7E FNL: 103 FSL: FEL: 938 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 154.62 GROUND LEVEL: 120.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 3451.0 2ND STRING 3RD STRING PRODUCTION STRING • c~Co~-Oa5 '~~Zl~b~ REMARKS: • • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), ACOUSTIC CALIPER (ACAL), GEOPILOT ROTARY-STEERABLE BHA (GP), AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 8/17/06, FROM D. KLEIBACKER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 2N-333 WITH API#: 50-103-20525-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10921'MD/5264'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,ACAL-DERIVED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 9.6-10.4 PPG MUD SALINITY: 400-700 PPM CHLORIDES FORMATION WATER SALINITY: 31000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......~08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3429.0 10887.0 NPHI 3435.0 10835.5 FONT 3435.0 10835.5 NCNT 3435.0 10835.5 PEF 3435.0 10849.0 RPS 3435.0 10879.0 DRHO 3435.0 10849.0 FET 3435.0 10879.0 RPD 3435.0 10879.0 RPX 3435.0 10879.0 RPM 3435.0 10879.0 RHOB 3435.0 10849.0 ROP 3463.0 10921.0 CALA 3471.5 10838.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3429.0 10029.0 MWD 4 10029.0 10921.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 ~ • FET MWD HOUR 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3429 10921 7175 14985 3429 10921 CALA MWD INCH 8.32 10.29 8.76319 12957 3471.5 10838.5 FCNT MWD CNTS 617.31 2747.98 1022.4 14802 3435 10835.5 NCNT MWD CNTS 115208 180840 137014 14802 3435 10835.5 RHOB MWD G/CM 0.461 2.701 2.32181 14829 3435 10849 DRHO MWD G/CM -2.64 0.213 0.0509601 14829 3435 10849 RPD MWD OHMM 0.27 2000 9.54509 14889 3435 10879 RPM MWD OHMM 0.26 2000 5.85419 14889 3435 10879 RPS MWD OHMM 0.3 2000 5.15371 14888 3435 10879 RPX MWD OHMM 0.74 1274.4 4.80401 14889 3435 10879 FET MWD HOUR 0.28 72.53 1.27773 14889 3435 10879 GR MWD API 34.69 232.54 119.183 14917 3429 10887 PEF MWD BARN 1.42 13.04 2.60571 14829 3435 10849 ROP MWD FT/H 1.07 1145.81 105.596 14917 3463 10921 NPHI MWD PU-S 9.15 52.63 33.6537 14802 3435 10835.5 First Reading For Entire File..........3429 Last Reading For Entire File...........10921 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 3429.0 PEF 3435.0 FET 3435.0 RPX 3435.0 NPHI 3435.0 STOP DEPTH 9995.5 9957.0 9987.5 9987.5 9944.0 0 • RPS 3435. 9987.5 RHOB 3435.0 9957.0 RPD 3435.0 9987.5 FCNT 3435.0 9944.0 DRHO 3435.0 9957.0 RPM 3435.0 9987.5 NCNT 3435.0 9944.0 ROP 3463.0 10029.0 CALA 3471.5 9947.0 LOG HEADER DATA DATE LOGGED: 07-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10029.0 TOP LOG INTERVAL (FT) 3462.0 BOTTOM LOG INTERVAL (FT) 10029.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.5 MAXIMUM ANGLE: 72.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 186328 ACAL Acoustic Caliper 1 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 3451.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.65 MUD VISCOSITY (S) 51.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 4.100 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.720 114.8 MUD FILTRATE AT MT: 6.200 74.0 MUD CAKE AT MT: 3.600 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing........... • ......60 .lIN • Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MWD030 G/CM 4 1 68 16 5 DRHO MWD030 G/CM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MWD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 ROP MWD030 FT/H 4 1 68 52 14 NPHI MWD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3429 10029 6729 13201 3429 10029 CALA MWD030 INCH 8.33 9.98 8.75796 11635 3471.5 9947 FCNT MWD030 CNTS 617.31 2556.61 997.952 13019 3435 9944 NCNT MWD030 CNTS 115208 179785 136137 13019 3435 9944 RHOB MWD030 G/CM 0.461 2.701 2.31411 13045 3435 9957 DRHO MWD030 G/CM -2.64 0.213 0.049849 13045 3435 9957 RPD MWD030 OHMM 0.27 2000 10.0352 13106 3435 9987.5 RPM MWD030 OHMM 0.26 2000 5.87604 13106 3435 9987.5 RPS MWD030 OHMM 0.3 2000 5.08411 13106 3435 9987.5 RPX MWD030 OHMM 0.74 1274.4 4.70211 13106 3435 9987.5 FET MWD030 HOUR 0.28 72.53 1.01624 13106 3435 9987.5 GR MWD030 API 34.69 232.54 118.078 13134 3429 9995.5 PEF MWD030 BARN 1.42 13.04 2.53743 13045 3435 9957 ROP MWD030 FT/H 4.94 224.34 111.049 13133 3463 10029 NPHI MWD030 PU-S 14.79 52.63 34.5066 13019 3435 9944 First Reading For Entire File..........3429 Last Reading For Entire File...........10029 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Previous File Name......~LIB.002 • Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 9944.5 NCNT 9944.5 FONT 9944.5 CALA 9950.0 DRHO 9957.5 RHOB 9957.5 PEF 9957.5 RPS 9988.0 RPD 9988.0 RPX 9988.0 FET 9988.0 RPM 9988.0 GR 9996.0 ROP 10029.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10835.5 10835.5 10835.5 10838.5 10849.0 10849.0 10849.0 10879.0 10879.0 10879.0 10879.0 10879.0 10887.0 10921.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESI5. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 07-MAR-06 Insite 68.18 Memory 10921.0 10029.0 10921.0 .0 64.6 TOOL NUMBER 216265 157645 1844674407370955 186328 1 8.500 3451.0 Fresh Water Gel 9.80 51.0 9.0 400 4.2 4.000 79.0 2.660 122.0 6.000 79.0 3.250 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT CALA MWD040 FCNT MWD040 NCNT MWD40 RHOB MWD040 DRHO MWD040 RPD MWD040 RPM MWD040 RPS MWD040 RPX MWD040 FET MWD040 GR MWD040 PEF MWD040 ROP MWD040 NPHI MWD040 Name.. Service .Unit DEPT FT CALA MWD040 INCH FCNT MWD040 CNTS NCNT MWD40 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM RPD MWD040 OHMM RPM MWD040 OHMM RPS MWD040 OHMM RPX MWD040 OHMM FET MWD040 HOUR GR MWD040 API PEF MWD040 BARN ROP MWD040 FT/H NPHI MWD040 PU-S Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 INCH 4 1 68 4 2 CNTS 4 1 68 8 3 CNTS 4 1 68 12 4 G/CM 4 1 68 16 5 G/CM 4 1 68 20 6 OHMM 4 1 68 24 7 OHMM 4 1 68 28 8 OHMM 4 1 68 32 9 OHMM 4 1 68 36 10 HOUR 4 1 68 40 11 API 4 1 68 44 12 BARN 4 1 68 48 13 FT/H 4 1 68 52 14 PU-S 4 1 68 56 15 First Last Min Max Mean Nsam Reading Reading 9944.5 10921 10432.8 1954 9944.5 10921 8.32 10.29 8.80918 1322 9950 10838.5 799.25 2747.98 1200.95 1783 9944.5 10835.5 123403 180840 143417 1783 9944.5 10835.5 2.135 2.691 2.37815 1784 9957.5 10849 -0.004 0.167 0.0590846 1784 9957.5 10849 1.52 21.87 5.94262 1783 9988 10879 1.47 21.83 5.69358 1783 9988 10879 1.44 22.93 5.66584 1783 9988 10879 1.44 22.51 5.55305 1783 9988 10879 0.36 29.67 3.19982 1783 9988 10879 50.82 172.05 127.324 1783 9996 10887 1.91 5.83 3.10506 1784 9957.5 10849 1.07 1145.81 65.4526 1784 10029.5 10921 9.15 39.74 27.4259 1783 9944.5 10835.5 First Reading For Entire File..........9944.5 Last Reading For Entire File...........10921 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number..........~.0 Date of Generation.......06/08/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/08/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File ~~ ~ -o~s~~ ~~ la~~ .- ConocoPhillips Alaska, lnc. FINAL WELL REPORT ' MUDLOGGING DATA 2N-333 ._.~ ~ __ d ~ b~-%` Lens Browne Jr. Date: 3/15/2006 EPOCH ConocoPhillips Alaska, lnc. FINAL WELL REPORT MUDLOGGING DATA 2N-333 Provided by: [~ EPOCH RECEIVED SEP 0 ~ 2006 Alaska Oil & Gas Cans, Commission Ancharags Approved by: Derik Kleibacker Compiled by: Lees F. Browne Jr. Date: 3/15/06 Distribution: CQracac~P'h~~ip~s 2N-333 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT &CREW ......................................................................................................2 1.1 Equipment Summary ................................................................ ............................................................2 1.2 Crew .......................................................................................... ............................................................ 3 2 WELL DETAILS ................................................................................ ............................................................~ 2.1 Well Summary .......................................................................... ............................................................ 2.2 Hole Data .................................................................................. ............................................................4 3 GEOLOGICAL DATA ....................................................................... ............................................................6 3.1 Lithostratigraphy ........................................................................ ............................................................6 3.2 Mudlog Summary .................................................................... .............................................................7 3.3 Gas Samples ........................................................................... ...........................................................15 3.4 Connection Gases ................................................................... ...........................................................17 3.5 Sampling Program /Sample Dispatch ................................... ...........................................................18 4 PRESSURE /FORMATION STRENGTH DATA ......................................................................................19 4.1 Formation Integrity/Leak Off Tests .......................................... ...........................................................19 4.2 Wire line Formation Tests ....................................................... ...........................................................19 4.3 Pore Pressure Evaluation Introduction ................................... ...........................................................19 4.4 Pore Pressure Evaluation Conclusions .................................. ...........................................................19 4.5 Pore pressure evaluation ......................................................... ...........................................................22 5 DRILLING DATA ............................................................................. ...........................................................23 5.1 Survey Data .............................................................................. ...........................................................23 5.2 Bit Record ................................................................................. ...........................................................26 5.3 Mud Record .............................................................................. ...........................................................27 6 MORNING REPORTS ..................................................................... ...........................................................28 Enclosures 2"/100' Formation Log (MD) 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log ~~~~~H ~Q~14Ct?P~'1l~~~pS 2N-333 1 MUDLOGGING EQUIPMENT 8~ CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas 8~ chromatography. Insulated umbilical with three of low lines. 0 No problems, no missing data. Hook Load / Wei ht on bit H draulic ressure transducer 0 No roblems, no missin data. Rate of penetration Primary draw-works block position indicator O tical encoder on draw-works 0 No problems, no missing data. Mudlo in unit com uter s stem HP Coma Pentium 4 X2 DML & Ri watch 0 On UPS should ower shut down on ri Mudlo in unit DAC box In-unit data collection/distribution center 0 On UPS should ower shut down on ri Mud Flow In Derived from Strokes/Minute and Pum Out ut 0 see um stroke counters below Pum stroke counters 2 um s Ma netic roximi sensors 0 No roblems, no missin data. Epoch commenced logging the 2N-333 on 2/25/06 at 7:18 AM with 50' samples being caught by Epoch sample catchers. Some minor problems with ditch gas were encountered early. The base plate on the gas trap allows mud into the trap through a 2" diameter hole. A %<" mesh screen covering the hole to prevent large rocks from entering the trap and breaking agitator prongs, was partially plugging in the thick mud and restricting flow into the trap. This screen was removed at 1200', as large rocks or cement fragments were no longer in the mud, and the flow was efficient thereafter. Shallow hole clays presented a minor problem with periodic plugging of the Epoch gas trap. Routine cleaning of the gas trap prevented most pack offs on the gas trap. Occasionally the trap would be washed out as a preventive measure to help ensure reliable gas readings during shows. Also, two spare polyflow gas lines were utilized should freezing or plugging occur. One spare was rigged up to rig air to blowback lines to keep free of moisture and drilling mud. The second spare was kept as a back up gas line. Periodic rig power outages (highline generator) presented no problem to the Epoch unit, as all computers and sensors were on UPS. The few power outages were of a short duration, and never drained the UPS batteries. ~~~~~ 2 1.2 Crew Unit Type Arctic Series 10 Skid i ~.,a ni~~..,tie~ ~ nni non ~tatlQCa~'~'1f~~IF?5 2N-333 Mudloggers Years Da~rs Sample Catchers Years Days Technician Days Trainees Days Steven Pike 2 16 Patrick Walker 1 30 Lees F. Browne Jr. 24 20 James Kvidera 2 3 Jason Duncan 1 17 ~' Years experience as Mudlogger .2 Days at well site between spud and total depth of well Additional Comments Technician required to work on DAC box. ~l~ ~~~ 3 ~t~C10GQf~1t'~~I~'??S 2N-333 2 WELL DETAILS 2.1 Wetl Summary Well: 2N-333 API Index #: 50-103-20525-00 Field: Tarn Surface Co-Ordinates: 103' FNL, s38' FEL SEC 3, T9N, R7E, UM Borough: North Slope Primary Target Depth: 10433' MD State: Alaska TD Depth: 10921' Rig Name /Type: Doyon #14 /Arctic Triple Suspension Date: None Primary Target: Bermuda Permit #: 206-025 Spud Date: 2/25/06 Ground Elevation: 154.62' Completion Date: 3/16/06 RT Elevation: 34.42' Completion Status: Production Liner Run Secondary Target De the None Classification: Development TD Date: 3/12/06 TD Formation: Bermuda Days Testing: None Days Drilling: 15 2.2 Hole Data Maximum De th TD Mud Shoe th Hole Section MD ~ TVDSS ~ Formation Weight PA9) Deviation (inc) Coring Casing Liner MD ~ TVDSS ~ FIT (ppg) Conductor 119 32 Permafrost 10.0 0 NA 16" 119 32 NA 12.25" 3462' C-50 10.3 70.54 NA 9 518" 3462 12.5 8.5" 10921 C-35 11.7 38.78 NA 7" 10921 Additional Comments The 2N-333 was spud on 2/25/06 with surface hole drilled to 3462' {239403 TVD). Surface hole was drilled outwith 10.0 ppg spud mud. Surface hole clays presented a minor problem by plugging off the gas trap. Routine cleaning helped remedy this problem. Drill rates were fast 150- 200 ft/hr. Hole angle was 0° degrees at spud and 70.54° degrees at surface casing TD. Mud weights were increased from 10.0 to 10.3 by 1700' to combat high background gases (hydrates) (and held to casing TD). Atrip out ofthe hole at 2477' was noted to change out the BHA. Trip gas was 1020 units. Normal sliding and rotating were used to keep the hole on target. Both trips pulled clean with no hole sticking. Gas hydrates first appeared at 1155' and gave a background gas of 200 units to 900 units until surface TD at 3462'. Swab gas at TD circulation was 1610 units. The hole was wiped to the HWDP which produced on1y451 units of wiper gas. Minimal sliding was then needed to maintain tangent to 3462', when the mill tooth bit and mud motor assembly was pulled in favor of the geo-pilot. No mud losses occurred through the surtace hole. The 2N-333 included an 8'/" intermediate hole from 3462' to 10921' and through the Bermuda reservoir, from 10539' to total depth at 10921'. The intermediate hole was drilled as a long 69° {plus or minus) degree tangent until dropping down to 50.44 degrees just above the Bermuda reservoir. Drilling through the Bermuda the angle was dropped from the inclination of 50.44° at the top to 38.78° at the base at 10846'. No major mud loss was reported during the drilling formation aspect of the well. Wiper trips were made at 5439' and 100028' with short seven and nine stand wiper trips at 8556' and 9241' for FPC~C'H ~+aThDGD~'il~~l~}5 2N-333 washed out drill pipe. During all trips itwas necessaryto pump aut, buttrips in mostlywentwellwith very little or no drag. The production hole commenced 3/8/06 at 10028' (after a round trip to surtace to download the MWD data and inspect the drill bit)', and went well, drilled to a total depth of 10921'. Drilling proceeded at a slow rate to contain ECD, averaging 47 feet per hour and to maximize MWD data and sample collection. Ten foot samples commenced at 10350'. Background gas remained under thirty units unti110028', in which, a trip out of the hole to down load the MWD data and load the nuclear sources was preformed. Trip gas was 1250 units at "bottoms up" and drilling resumed with background gas increasing from 20 units to 150 units. Background gas remained at 150 to 200 units (MW 9.6) to 10110', in which, background gas increased to an average of 650 units. C-5 (Pentane) was noted at 10065' in ppm's above 800, which increased to 2000 ppm's at 10200'. Background gas took another "kick" at 10318', in which background increased from 200 units to over 1900 units and was held and drilling continued through the Bermuda to the C35 formation. The weH was flowing and giving water, in so, ~e mud weight was increased from 9.7 at 10700' to 11.00 with continued background gas over 1000 units. Chlorides increased from 400 mg/I to 5300 at 10968'. Connection gases averaged 300 unitsthroughoutthis interval. The large increases in background gas were most likely from surrounding injection wells. Drilling progressed to 10918', in which 245 bbls of formation fluid had entered the well bore with drilling mud diverted through the gas buster. The oil/water ratio increased from 3/85%vol. at 10737'to 10/77%at 10968'. Strong petroleum odor was noted in the shaker room with common to abundant dark brown oil on the pits with noticeable gas breaking out of the drilling mud. Oit shows from most samples were probably elevated by this recycle of oil and gas. The mud weightwas increased from 11.0 !b/gal at 10800' to 11.3 Iblgal at 10921' and the hole was circulated and shut in. The well was displaced with new 12.1 ppg LSND mud and circulated through the choke until 12.1 returned. Total depth reached was 19021' and the well was checked for flow and the well was dead. Circulation was continued at 128 gpm and the well lost partial returns. A 30 bbl LCM pill was spatted on bottom and the well was circulated at 107 gpm and spotted a 100 bbl prfl of 30 ppb LCM on the bottom. The drill pipe was rotated and the hole reciprocated and pumped 10 bbls every 15 minutes. A total of 245 bbls was lost to the formation. Background gas was running 90 to 300 units throughoutthis interval of circulation. The 12.1 Iblgal mud had decreased to 11.8 by this point. The well was shut in and the pressure was zero. The well was circulated out and 100 bbls of LCM pumped to the bottom and tripping out of the hole begun. At 10031' the well was circulated out and continued to pump out to 9285' and 563 units was circulated out. One washed out drill pipe was laid down and pumping out continued with routine circulations of bottoms up. Background gas pumping up was averaging 70 to 150 units at 11.8 Iblgal. A final clean out run was secured and 1760 units of trip gas was noted before tripping out and 7" casing run. FP(~~',H ~OI1QCOf~'tllll~]5 2N-333 3 GEOLOGICAL DATA 3.1 Lithostratiaraphy Drilling picks & actual wire line tops refer to provisional picks provided by the well site Geologist. Intermediate and Production Hole PROGNOSED ACTUAL WIRELINE PICK HIGH/LOW FORMATION MDRT ft TVDSS ft MDRT ft TVDSS ft (~) Permafrost -Base 1200 NA NA C80 (K10) 3643 3663' 2308 C50 7116 7062' 3520 C40 7681 7742' 3746 C37 8047 8092' 3863 Iceberg Zone -Est 7764 NA NA T7 NA 9613' 4419 T3.1 10398 10483' 4799 T3 Top Bermuda 10433 10539' 4834 T2 Base Reservoir 10803 10828' 5038 C35 (K3) 10836 10846' 5051 TD 11051 10921' ~C7yl"llt~f~l~"t[~~f~]5 2N-333 3.2 Mudlog Summary Surface to C80 (K10) ~ ~o~ +.. ~a~~~ nnn r_,r,~,~~ to _73nR~ TVr)SSl Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 3921 1 170 1921 0 263 This section was a massive claystone with interbedded siltstone and coarse grain to medium grain sands, conglomerate sands and loose conglomerate. The claystone was uniform in consistency and tenacity through out the entire zone. Composed of very soupyto running clays, light brownish gray to medium light gray and various colors of both, very soft to soft; lumpy to clumpy, clustered to clotted, gelatinous, mushy to pasty, tacky to slimy with non to very slk~ht cohesnreness and generally moderate adhesiveness, amorphous to earthy fractures and habits, dull earthy luster and a clayeyto silty texture. This is a massive gradational to homogeneous bed of predominantly clay with minor beds of silt and becoming thick and sticky between 100' and 800'. Interbedded siltstone was pale yellowish brown to light brownish gray, moderately to very clayey, very poorly indurated, with some very fine to fine sand grains, and minor carbon silts and fines. Overall there was very poor visible porosity and permeability, with no fluorescence or oil cuts. Shallow sands from 100' to 400' were very light gray, clayt size ranges from coarse grain to medium grain; no abundant size factions, subround to sub angular, some scattered angular bit impacted fragments, moderate sorting, polished to pitted surface textures, sub-mature nature, non to very weak silic cement, abundant clay structured matrix,(loosely attached and going into solution), dominant matrix support and composed predominantly of quartz with scattered various lithic fragments, poor porosity and permeability with no show of fluorescence or oil cuts. Sands from 400' to 3400' were very light gray and had a percentage of fewer than 50% of the samples with a persistent clay matrix. Clast sizes decreased to fine upper to very fine lower, subround; moderate occasionally well developed sphericity; moderate sorting, impacted to pitted textures; sub-mature nature, non to very weak silic cement, dominant to abundant clay matrix which is loosely attached and very hydrophilic, dominant mats support and composed of 90% quartz,10% meta, ign, greenstone and various lithic fragments, poor porosity and permeability with no shows of sample fluorescence or cuts. Conglomerate sands were noted befinreen 770' to 1000' and composed of various colors with an overall salt and pepper appearance with clast size ranging from coarse upper to coarse lower with some scattered coarse upper to pebbles, subangular, moderate sphericity grading to poor in parts with some angular bit impacted fragments, moderate to poor sorting, the main faction being generally coarse grains, polished to chipped and some pitted textures, sub-mature in nature, non to very weak silic cement, dominantgrain support, locally clean with non to very slight clay/silt matrix and very soluble, appears as a sub-graywacke composed of 50% quartz, 10% chert, 40% dark gray to black lithic fragments: metamorphics, igneous and various fragments, some good porosity and permeability in parts, no show of fluorescence or cut. Background gases were between 0 and twenty units from surface to 1100'. Hydrate gaseswere encountered at 1155', in which background gases in creased from 25 units to 1910 units at 1250'. Background gases maintained a consistent reading of 300 to 700 units until 2477', in which a trip out of the hole to change the BHA resulted in background gases running between100 to 150 units. Trip gas was 1020 units. Mud weight was increased from 10.0 ppg to 10.3 ppg at the first notice of hydrate gases. Background gases slowly increased from 150 units to a steady background of 500 to 600 units. At 3462' surface casing was set and background gases were under 50 units to the base of the C-80 zone. Mud weight from under casing was 9.7 ppg. Some connection gases were noted from 2700' to 3000' with most connection gases being very small ~A'C7(]'CQ'~'1t~~1~}5 2N-333 or being incorporated into the high background mud system. Note: Beginning at 3505' high readings of C-5 and C-4 were recorded. Both gases recorded higher than C-2 and C-3. The unusual high readings of C-4 and C-5 continued to 3840' in which both gases slowly dissipated into the mud system. By 4200' both gases had been removed from the mud system. These two gases are most likely the result of some type of injection from the surrounding wells. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 1257 1921 373902 13 - - - 1676 932 174940 - - - - C80 (K10) to C50 ~~a~~ +., ~n~~~ nnn r_~~nR' to _~57n' TV~SSI Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 167 13 108 49 1 19 The C-80 section is composed of three sections. The upper zone is predominantly 90%claystone from 3663'to 4200', in which the claystone grades into a uniform siltstone for the middle zone, which starts to slightly grade into sandstone at 5000' and continues to be present in the siltstones to the base of the formation. The sandstones never attain anymore than 30% of the samples and are hard to discern between siltstone and sandstone in some parts. No gas kicks noted through the entire interval. Maximum gas attained through the C- 80 was 49 units with C-2 incorporated into the background gas at 5 to 10 ppm. The upper claystone section from 3663' to 4100' was light brownish gray to pale yellowish brown and various light hues of both, very soft to soft with various consistency and tenacity: lumpy to clumpy, clustered to clotted, gelatinous, mushy to pasty, #acky to slimy, non to very slight cohesive, moderate adhesive, amorphous fracture, massive habit, moderate earthy luster, clayey to colloidal texture, massive homogeneous bed of clay which is very soluble and composed of 90% clay, 10% silt and various detrital material in very fine grains. Overall, the clays were very similar in nature throughout the upper zone. siltstones were gradational in appearance at 4100' and never attained more than 80% of the samples. A persistent clay was always present in the silts. The siltstone was dark gray to medium dark gray with some medium light gray in parts; slightly lumpy to clumpy with increased clay content in parts and some becoming slightly stiff in more pronounced silt sections, overall mostly brittle with some exhibiting slightly stiff tenacity, mostly irregular fractures throughout with some slight blocky fractures in places, predominantly amorphous cuttings habit and a dull earthy luster, very silty texture with grading to clayey in parts, massive bedding features with thin interbedded layers of clay. The lower section is noted as grading into very fine to fine grained sandstone. Not overly abundant with its percentage ranging no higher than 30%. Sandstones appear to be in very thin beds or interbedded within the siltstones. The sandstone is dark yellowish brown to very light gray to light gray when associated with cleaner bedding, clayt size is uniform throughout the zone ranging from very fine upper to veryfine lower and grading to siltstone. A few fine grains are noted but not relevant, subangular occasionally subround, moderate developed sphericity, poor sorting, polished to chipped with occasional impacted texture, immature tosub-mature nature, slight to moderate siliceous cement, non calcareous, moderate silt and clay packed matrix, moderately attached and pore filling matrix material, dominant matrix support and some grain support in very thin clean beds, scattered quartz overgrowths, composed of 90% quartz, 10% chert, argillite and traces of various lithic fragments, poor visible porosity and permeability, no show of oil fluorescence or oil cuts. ~ El'C)C;~ ~1^I(ICjG-~'ll~~l~'35 2N-333 DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 3751 49 8703 55 6 83 270 7014 47 9264 105 25 - AVE 19 3753 16 1 3.1 11 C50 to C40 7062' to 7742' MD (-3520' to -3746' TVDSS) Drill Rate ftJhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 151 16 96 68 10 27 The C50 section included mostly claystone and siltstone, with incipient fissility grading to shale and locally common carbonaceous partings grading to carbonaceous shale. Sandstone was poorly developed or thinly bedded. Local thin calcite beds were also noted. Gas did not increase noticeably aver background through any sandy intervals and only slightly through the bottom carbonaceous shales from 30 units to 70 units. C-4 was noted in the mud system at 7600' as the increase in carbon shale was observed in the samples. Sandstone was moderate yellowish brown with other brownish hues in the lower carbon sections, very fine to ' fine grained, angular tosub-rounded, poorly to moderately sorted, thinly bedded and laminated in siltstone and silty claystone, variably silty and argillaceous, and both grain and matrix supported. Most sandstone was poorly to moderately consolidated with clay matrix and slight calcareous cement. Some dense well consolidated sandstone had siliceous cement including quartz overgrowth. Composition included 70-90% quartz, and 30- 10% mostly carbon silts and fines, slight glauconite or chlorite, and traces of tan interstitial matter possibly siderite. Visible porosity appeared to be very poor. Sandstone did not appear to fluoresce or cut, and some weak fluorescence and cut from mud products contamination was indistinguishable from passible oil cuts. claystone, carbonaceous shale to shale, and siltstone was medium gray to dark gray, often with various brownish hues, moderately soft to firm with a crunchy to crumbly to brittle tenacity, and soluble to slightly soluble, except locally where slightly siliceous and brittle. Cuttings were subblocky to sub-platy to occasional slightly elongate splinters, with common incipient fissility noted by terraced sub-platy fracture or tabular habit. Traces to slight sifts, fines and flakes, and scattered partings of carbonaceous matter persisted throughout. Graded to carbonaceous clay with increasing carbon clay content or locally increased micro partings of carbon residue. Graded to argillaceous siltstone and argillaceous silty sandstone with mostly quartz grains, and traces of glauconite (or chlorite), especially as grades to sandstone. Slight calcareous debris persisted throughout. Slight disseminated mica flakes were noted on some non carbonaceous shale. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7728 68 13327 265 52 20 - AVE 27 5002 76 11 4 - .G~~~~ Cetaac ~"hilli ~ 2N-333 C40 to C37 7742' to 8092' MD (-3746' to -3863' TVr)SSl Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 164 58 122 66 19 47 The C40 was very clayey, with carbonaceous shale, claystone, shale, siltstone, some sandstone laminae. Carbonaceous shale was black to grayish black mottled blackish red to dusky brown and various hues of all, overall brittle with variably carbonaceous (organic) clays, and scattered to book leaf micro partings of carbonaceous matter and carbon residue with gradation to moderately soft claystone with lessening organics and carbon matter, while the darker firmer cuttings exhibited more shaliness. Cuttings included traces of micro mica and micro pyrite, were mostly non calcareous, and some slightly to occasionally moderately calcareous, all carbon was very fine in size, flexible with micro planar fracture and flaky to paper habits, all cuttings are very small with a dull earthy to greasy luster and occurs as thinly bedded or laminae. Siltstone was light brownish gray to medium gray with brownish hue to medium tight gray, poor indurations to brittle in parts, with earthy to resinous luster, and silty to matte texture. Grains were dominantiyquariz, with slight carbon silts and flakes, and traces of chlorite and other silicates. Clay content appeared to be bath ashy and argillaceous, with a trace of pin point effervescence in 10% HCL. Scattered throughout were micro partings of carbon residue and slight disseminated micro micas. Siltstone was gradational with claystone and shale and minor very fine grained sandstone, and also occurred as laminations as did sandstone. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 7744 66 13000 255 50 18 - AVE 47 8747 205 43 26 3 Top C37 to Iceberg Zone 8092' to xxxx` MD (-3863' to -xx~oc' TVDSSI Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 143 34 114 39 1 21 The G37 section included claystone, siltstone, shale, and sandstone. claystone and very minor shale was pale yellowish brown to brownish gray and various hues of both, very soft to soft, with various consistency and tenacity: lumpy to clumpy, clustered to clotted, gelatinous, mushyto pasty, tacky but not slimy, non to slight cohesiveness, moderate adhesiveness, amorphous fracture and massive habif, dull earthy luster, colloidal to clayey texture, massive bed of clay interbedded with thin beds of siltstone and silty shale with slight carbonaceous laminae. Siltstone was medium light gray to light brownish gray occasionally pale yellowish brown and various hues of all, poor occasionally moderate induration, brittle to slightly stiff in parts, crumbly to crunchy, slight to moderate cohesiveness, non to slight adhesive in clayey sections, subplanar fracture, sub-platy tosub-nodular habit, dull earthy luster, silty to gritty texture, thin to thick beds of clayey siltstone, composed of 70% silt, 30% clay and some grading to silty shale in very thin beds. Sandstone was very light gray with pate yellowish brown to light brownish gray matrix hues, clast size ranges from fine lower to very fine lower, subround occasionally subangular, moderate developed sphericity, moderate to poor sorting, impacted texture, submature nature, predominantly silic cement, slight to moderate and some abundant clay and ash matrix occasionally becoming bedding in parts, matrix supported with secondary grain support in parts, overall pore filling matrix, composed of 90% quartz,10% chert, ash and minor tithics, distinct ~~~~~ 10 Conoco`P'hiili ~ 2N-333 aggregate pyrite scattered throughout, poor porosity and permeability, very dull sample fluorescence with no oil cuts. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 8092 39 7481 165 40 24 2 AVE 21 3810 92 28 13 .7 Iceberg Zone to T3.1 nie +„ ~nAa~~ nnn i_Nn tr. ~74a' TVDSSI Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 192 65 136 87 11 31 The Iceberg Zone includes massive beds of mostly poorly unconsolidated sand with intervals of mostly siltstone and claystone, including some carbonaceous shale, and interbedded claystone, shale, siltstone and sandstone. There were no shows observed through this zone. Sands were clear to translucent with some dark yellowish brown and moderate yellowish brown, predominantly quartz grains throughout, clayt size ranges from very fine upper to lower with some fine grain lower, moderate sorting throughout, subround to sub angular with some well rounded grains, overall moderate sphericity and unconsolidated with no visible cement support, polished grains slightly pitted, no show of fluorescence or oil cuts. claystone was medium gray to medium dark gray with some brownish gray and various hues of all, predominantly lumpy to clumpy with some slightly pasty in parts, elastic to slightly stiff tenacity, amorphous fracture and cuttings habit, dull to slightly greasy luster, were slightly mottled with slight dark carbonaceous matter and flakes in non to slightly carbonaceous light clays, and were non to very slightly calcareous. Some sandy cuttings indicated possible thin inter beds or streaks of sandstone, very thinly bedded. Siltstone overall was medium light gray to medium gray with some light gray in parts, mostly clumpy to stiff in parts, very brittle in others, predominantly blocky to subblocky fracture with some slightly planar to somewhat splintery fractures, massive to somewhat platy to flaky cuttings habit, very earthy to moderate dull luster, predominantly silty texture with some slightly clayey to gritty textures, very thinly bedded siltstone interbedded with very thin stringers of claystone, shale and sandstone. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 8743 87 15815 336 128 70 6 AVE 31 5529 128 45 25 - T3.1 to T3 (Top Bermuda} ~ ndf2Z' +.. a nS~a~ nnn r~7aa~ to _48~4~ TVDSSI Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 69 46 58 1740 1507 1630 A short section of only 56' composed of gradational siltstone and sandstone. Continued very high background gas averaging 1630 units throughout the interval. Ccmoco~hilli 5 ~ 2N-333 The siltstone is pale yellowish brown to light brownish gray grading to light gray to medium light gray in cleaner ,, sections, very poor to poor induration, brittle, crumbly, very slight cohesive, very slight adhesive, earthy to subplanar fracture, subplaty to subtabular to subnodular habit, dull earthy luster, silty texture, thick to massive bed of uniform silt grading to very fine grain sandstone in parts, composed of 90% silt, 10% clay with minor carbon specs and various detrital material with traces of detrital material. Sandstone is gradational in parts with some ranging from siltstone to very fine grained sandstones in parts. Overall, very light gray with clast size ranging from fine lower to very fine lower and some grading to siltstone, subangular to subround, moderate developed sphericity, moderate to poor sorting in silty zones, polished to impacted textures, submature nature, slight silic cement, slight areas ofgrain support, some quartz overgrowths giving a dense appearance, composed of 85% quartz,15% chert, argillite, tuffand various lithic fragmer>ts, poor porosity and permeability, sample fluorescence was 40% at the top of the T3.1 and increased to 80% moderate light green even to patchy sample fluorescence giving an instant dull light blue green hazyfluorescent cut and a very pale straw residue stain and a general poor overall cut. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 10485' 1740 159293 32734 25462 23719 8831 AVE 1630 167433 28285 21714 19271 7408 T3 {Top Bermuda) to T2 (Base Reservoir) 10539' to 10828' MD ~-4.834 to -5o3s~ Tvnss~ Drill Rate ftihr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 92 12 45 2015 1071 1642 The T3 sandstone reservoir was easily distinguished from the overlying sandstones. The sandstone was light gray to medium light gray to occasionally yellowish gray (matrix material), medium lower to fine grained with scattered medium upper and very fine upper grains, subangular to angular, moderate to poor sorted from the top (10539' to 10600') and increasing to moderate sorting, gradational siiic cement. The matrix from 10539' to 10ti00' was non to moderate silt, clay and tuff with traces of calcite; with both matrix and grain support with dense fenestral matrix overgrowths and grading from tight sandstone to loose sand. From 10600' to the base of the T3 the matrix was slight to moderate silt, clay and ash and generally matrix supported with secondary grain support in parts. Most matrix material was pore filling and occasionally acted as a lithitying agent with scattered dense quartz overgrowths. Grains were mostly consolidated in samples, some lightly frosted with clay, but often cuttings were variably well to poorly consolidated with same siliceous and traces of calcareous cement. Composition included 90%quartz, and 10% gray to black to dark brown to rare green and trace tan lithics including partially siliceous lithics and silicates. Some fair porosity is inferred, but visible sandstone porosity was poor. Oil properties included traces of light brown stain on clay, and 80-90% moderate to bright even to patchy sample fluorescence with moderate blue green fluorescent oil cut with a slow increase to a hazy blue white and a very pale straw residue stain from the top of the T3 (10539') to 10600'. From 10-600' to the base of the T3 (10828') continued 80-90% moderate to bright yellow green sample fluorescence with an increase to an instant moderate to bright blue green cut with moderate increase to a hazy blue white cut and a straw visible residue stain. Through the zone the well was giving water to the mud system (probably from surrounding injection wells) with an increasing petroleum odor in the shaker room and in the samples with visible oil sheen in the samples, as well as common oil in the drilling mud. Butane and Pentane (C4 and CS} ppm's increased through the show zone. Unsure if this was from the reservoir or the combination of injections from surrounding wells plus the formation and / or recycled oil in the mud system. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m ~,1~ ~l._~~ 12 ~onvcxa~Phitli ~' 2N-333 10686 2015 98573 21149 22982 29390 15319 10527 1590 168204 26246 20453 18272 7071 10569 1850 132823 46298 36865 29373 6883 10578 1900 108948 43634 42893 33090 11982 AVE 1638 118890 25356 25686 25915 11573 T2 (Base Reservoir) to C35 {K3) 10828' to 10846' MD -5038' to -5051' TVDSS Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 46 23 37 2183 1845 2111 Below the base of the reservoir and a thin shaley carbonaceous cap, is sandstone from approximately 10828'- 10846' of similar composition and grain size as the reservoir, but overall moderately well consolidated with siliceous cement, some apparent intebedded shale and siltstone, and only decreasing show indicators. Maximum gas was 2183 units, with slowly increasing oil shows from recycled oil in the mud system and injection contaminations. Atotal of 245 barrels of formation fluid entered the well bore drilling the T2 and C35 The remaining section included shale, gradational to claystone and carbonaceous shale, siltstone and sandstone. The sand and sandstone was very light gray to grayish orange (matrix) with its clayt size ranging from fine grain lower to very fine upper with scattered upper fine, moderately sorted, well rounded to subrounded with some grading to subangular to very angular in parts giving a wide range in developed sphericity, both unconsoludated and weak consolidated sands with scattered silic support, general petroleum sheen in samples with 80 to 90% light yellow green sample fluorescence with slight hydrocarbon staining, instant blue green cut with a slow to moderate increase to a moderate blue white and a pale straw residue stain with continued common oil in the mud with strong petroleum odor. Shale/claystone and carbonaceous shale was medium gray to medium dark gray with some brownish hues, slightly firm to moderately firm, with clayey to silty texture, and earthy to resinous luster. Slight to moderate irregular micro partings of carbonaceous matter in variably organic/carbonaceous clays diminishes to trace carbon silts and flakes as grades to a silty texture and a medium light gray siltstone. Traces of isolated micro pyrite associated with carbonaceous matter and residue, and traces of disseminated micro mica flakes are scattered throughout. Cuttings exhibit non to trace pin point effervescence in 10% HCL. DEPTH GAS units C1 m C2 m C3 m C4 m C5 m 10846 2183 113871 30582 41000 39903 16712 AVE 2111 119266 28772 37545 37134 16115 C35 (K3) to TD 4 f1f2AF.' +., 1 f1Q71 ~~ nnn r_~n~~ ~ to _xxmr~ TVr)SSl Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 87 28 60 2277 701 1813 The C35 is dominantly sand with some minor interbedded siltstone throughout. The sands were very uniform with slight local increases in grain size. The sands were very light gray to light gray, with very fine lower to very fine upper grains, and locally some fine grains', subangular to subrounded with EI'(JC~~I 13 CcanocciPhilli s 2N-333 overall moderate developed sphericity with some scattered poor, moderate to some well sorted. Sands were ~~,; mostly unconsolidated in samples, with an inferred overall very slight clay/silt matrix. Some poorly consolidated sandstone had a non to very slight siliceous cement; and a non to very slight clay/silt matrix. Composition included mostly quartz with very minor chert, argillite, and trace various lithic fragments. Porosity and permeability is estimated fair to good. Samples displayed a 70-80% moderate to bright light green even to patchy sample fluorescence with an instant moderate blue white hazy to milky cut with moderate increase to hazy/milky bright blue white, very pale to pale straw residue stain with a strong petroleum odor and common to abundant oil in the mud system with recycled oil and gas from injection saturation from up hole giving possible elevated oil shows in the sands at 10900'. DEPTH GAS units C9 m C2 m C3 m C4 m C5 m 10864 2277 98806 33636 47332 44773 17526 10847 2211 114224 31060 41761 40575 16927 AVE 1813 53084 20098 33628 37281 17129 F,~~~~ 14 COC1t~C[)~'tl~~i)33S 2N-333 3.3 Gas Samples (Cali Bond Gas Baps) 1unit = 0.05% Methane Equivalent .._ o_ ~..... „a:~.e u..~e ~W~ Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05% M.E. {ppm) (ppm {ppm) (ppm) (ppm) (ppm) (ppm) 1 500 10 1329 2 1000 11 2056 3 1169 130 25837 4 1212 960 190011 9 5 1260 1860 362075 13 6 1500 334 65690 7 1584 844 166631 8 1585 834 164692 9 1644 700 138313 10 2000 270 57175 11 2520 123 12205 12 2752 166 63360 13 3032 850 124936 14 3500 9 2846 8 15 3808 36 6534 37 2 38 20 88 82 16 3998 16 2877 17 4500 16 2865 18 4588 24 4207 13 19 5000 25 3426 20 5500 18 3222 20 21 6000 18 3354 26 6 22 6500 18 3228 23 7000 29 6141 68 16 24 7500 35 6500 32 25 8000 49 9482 224 49 15 10 8 26 8500 23 2120 15 27 9000 30 3038 81 32 17 28 9512 20 4325 106 36 9 6 29 10028 18 2957 129 73 14 25 30 10081 623 89596 5748 4467 1030 1572 41 49 31 10115 898 147832 1622 982 733 445 160 183 32 10198 705 76366 8737 7075 1573 4130 1030 1062 33 10209 550 60186 8200 6601 1448 3840 950 988 34 10301 380 39879 6047 4556 964 2536 587 668 35 10327 1900 198884 3053 22765 4771 12516 2838 3318 ~l ~I~JH 15 ~QC](DG~O~1~~1~'}5 2N-333 n.._~...a: u..l.. Sam le De th Units C1 C2 C3 iC4 nC4 iC5 nC5 # (feet) 1 u=0.05% M.E. (ppm) (ppm) (ppm) (ppm) (ppm) {ppm) (ppm) 1 10131 1600 93643 2438 1800 671 983 271 289 2 10405 1420 151122 23432 18839 4367 11737 2568 3246 3 10516 1570 162040 26946 20581 4894 13118 3016 3827 4 10530 1580 168119 25676 20133 4864 13230 3103 3942 5 10550 1610 157181 28531 23078 5144 14295 3408 4409 6 10570 1850 129486 45747 37308 7940 21668 6115 1280 7 10590 1740 105498 33465 34605 9346 23647 5092 6345 8 10611 1740 108753 29837 32028 8453 24501 4743 5624 9 10630 1790 113222 27211 33417 10025 26788 6267 7767 10 10650 1850 108665 38114 39179 9514 24736 5610 6686 11 10690 1240 98573 21149 22982 7638 21752 6563 8756 12 10710 1260 86137 10176 10860 4249 13305 4899 6796 13 10730 1550 137397 16228 14926 5223 15730 5441 7439 14 10750 1260 102618 11349 10873 3691 11335 4068 5664 15 10770 1680 167260 22190 19542 5423 15863 6145 7941 16 10800 1730 198232 38076 33359 8191 22725 6595 8755 17 10820 1640 93227 26390 34894 8945 24405 6543 8617 18 10840 2000 157104 42179 67743 19531 54741 14309 18638 19 10860 2224 182304 59300 90973 24533 64879 15703 20056 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 22 23 24 25 CAt'tOC~i~'11~~I~S 2N-333 3.4 Connection Gases The surface hole noted a few minor connection gases after large hydrate background gas sections, but no continuing connection gases. Routine connection gases were present in the C-80 section starting at 460D' and continuing throughoutthe hole. These gases ranged from 20 to 60 units over background gas. The higher connection gases are noted below: 1 unit = 0.05% Methane Equivalent Depth(TVD) feet Gas unitsBG Depth(TVD) feet Gas units/BG Depth(TVD) feet Gas units/BG 7691'/3886' 90 10123'/4762' 500 10407'/4908' 360 8723'/4259' 60 10312'/4855' 1100 10501'/4965' 460 ~~~~;~ 17 ~or~oavPhilli ~ 2N-333 3.5 Sampling Program /Sample Dispatch From surface to Intermediate and Production Hole 12N-3331 Set T e / Pu ose Fre uenc Interval Dis etched to Bayview Warehouse A Unwashed Biostratigraphy 50' 100' -10350` MD ConocoPhillips Alaska, Inc. ABV 100 CPAI 10' 10350' -10921' MD 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. P o'skYM. McCracken Washed, screened & dried 50, 100' -10350` MD Bayview Warehouse ConocoPhillips Alaska, Inc. ABV 100 B Reference Samples 10, 10350' -10921' MD 8105 Eleusis Drive CPAI Anchorage, AK 99502 Attn: D. P o' ki/M. McCracken Washed, screened & dried 50' 100' -10350` MD Bayview Warehouse ConocoPhillips Alaska, Inc. ABV 100 C Reference Samples 10' 10350' -10921' MD 8105 Eleusis Drive CPAI Anchorage, AK 99502 Attn: D. P 'skUM. McCracken Washed, screened & dried 50' 100' -10350` MD Bayview Warehouse ConocoPhillips Alaska, Inc. ABV 100 D Reference Samples 10' 10350' -10921' MD 8105 Eleusis Drive CPAI gncho r~qe, AK 99502 Attn: D. Przywo'ski/M. McCracken Gas Bags E Routine intervals (500') or 500' -10921' MD lsotech Laboratories, Inc. significant peaks above 500 Show Peaks 1308 Parkland Court back round Champaign, IL 61821 Isotubes F 20-foot samples through ' 10134' -10921' MD Isotech Laboratories, Inc. Bermuda reservoir and 25- 20-50 Show Peaks 1308 Parkland Court 50 sam les to TD. Champaign, IL 61821 SET A: 3 BOXES each 1 cubic foot (Do Not Freeze) SET B,C,D: 1 each 6-pack bundle 10"x10"x16" {total 3) SET E: 2 BOX -10"X10"X18" -Hazardous Gas, 21 CALI-BOND Gas Bags (warehouse to re-package) SET F: 1 BOX - 8'/z" X 8 %2" X 10'/z" -Hazardous Gas, 19 metal Isotubes (warehouse to re-package) Total 9 boxes ~~~~~ 18 ~Ot"10CC3~"II~~IF3a 2N-333 4 PRESSURE /FORMATION STRENGTH DATA 4.1 Formation Integrity/Leak Off Tests E uivalent mud wei ht EM is calculated from rota table MD ft TVDSS ft) FIT /LOT (p EMVV) FORMATION 3462' 12.5 LOT (Leak Off Test) in bold italics. 4.2 Wire line Formation Tests HYDROSTATIC DEPTH TVD TVDSS Before After F Press Mobili PPG Calc Formation No Data 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Trip Gas (TG) Downtime Gas (DTG) Mud Weight (MW) Resistivity (RES) Wiper Gas (WG} Corrected D exponent (DXC) Hote Conditions (HC) Connection Gas {CG) Pressure Test Wire line {PT) Survey Gas {SG) Pore Pressure (PP) Equivalent Circulating Density (ECD) Quantitative Methods The primary indicators used for PP evaluation were gas trends, including 8G, CG, TG, WG, and DTG, and HC including flows and gas from swabbing or back reaming. Wire line testing was not conducted on this well. Epoch was not monitoring RPM, necessary for DXC calculations, and therefore DXC plots were not utilized. Factors such as controlled drill rates, alternate sliding and rotating intervals, variations in angle building, PDC bits, and the absence of clean shale baselines to establish compaction trends, tend to make DXC plots unreliable, anyway. RES plots tend to be reliable in determining a permafrost base, and suggesting compaction trends with depth, although the presence of hydrocarbons skews this data. However, generally, low RES and low gas indicate shaliness. 4.4 Pore Pressure Evaluation Conclusions 8 '/z" Intermediate hole (MD; 3462' to 1 Q921 "; TVD: 2394'-5264') Pore pressure in the intermediate hole remained below the mud weight of 9.6 to 9.6+ even with connection gases throughout the intermediate section, pore pressure remained below the 9.6 to 9.7 mud weights recorded throughout the intermediate hole. Each wiper or trip the hole was "clean" with no drag and slight COC1000~11~~1p5 2N-333 • cuttings saturation. ECDs were fairly constant in the intermediate section with readings slowly increasing from 10.3 at 3462', 10.4 at 3826, 10.9 at 7075', 11.0 at 9854' The production hole was drilled starting with a 9.6 ppg mud. ECD gradually increased from 10.99 ppg in the clay rich Iceberg, to 12.27 ppg in massive C35 sands. Drilling from 10029' to 10687' the mud weight was raised because of the background gas, constant over 1000 units starting at 10320', and gradually increased to 2200 units just above 10918', indicating a pressure trend. Drilling from 10687' to 10874' the mud weight was raised to 11.2 and the well drilled to 10921', in which the well was flowing and shut in. The well was circulated on the choke and the mud weight rose to 11.3 ppg. The well was circulated and displaced to new 12.1 ppg LSND mud driving the background gases from 2000 units to 200 units. A trip at total depth resulted in 1760 units of trip gas with a 11.7+ ppg mud . Pore pressure in the production hole is estimated to have increased to 11.0 ppg entering the reservoir, increasing again to 11.2 entering the C35, and trending upward to total depth to 12.1 ppg. Some losses occurred while drilling and much of the flow is likely due to the formation breathing after being charged by the high ECD, and not solely attributed to pore pressure. Also injections from surrounding wells charging the formation. PP,MW,ECD, and GAS vs ND - 8.5" 1s n • 1s 15 14 13 12 11 10 Via; 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 C. --~ GAS(mel5+8 • ~P(PP9) • Mw(PP9) ~~ EP(~f;H 20 • • • COr1000~'II~~IpS 2N-333 DXC and GAS vs ND - 8.5" 3 i~ lceb g "te a (~ 109' M 4~8 4' VD Casing Dint ~ ,a, 3~tt,2 Mrs ?;ya' 'TV~ ~ ~ r .r . . • , 2 0 2000 looo 2500 3000 3500 4000 4500 5000 5500 PP,MW,ECD,RES, and GAS vs TVD - 8.5" • Ioeburg Zon ~~ 1x539' M Casing P nt 4834' T 3462' D 2394' '~'D • r • .~ _r_ 7' ~ i ~'~. i ~ ~ ~ ~ ~ , ' . f 100 10 1 2000 2500 3000 3500 4000 4500 5000 5500 • DXC Linear (DXC) GAS(me+1) • PP(PPg) • MW(PPg) ECD(ppg) • RES(deep) 21 • 4.5 Pore pressure evaluation ,~,. *~ • CCM'~wC~'11~I1~ 2N-333 Primary Secondary Interval To s Pore Pressure EMW T d Source of Formation Interval Lithology (%) Lithology (%) MD ft TVD ft Min Max Trend ren Indicators Quantitative Estimate 9.625" Casin CI st 80% Sltst 20% 3462' 2394 10.0 10.4 Flat BG RES C80 CI st 50% Siltst 50% 3663' 2308 10.0 10.4 Flat BG,TG RES C50 CI st 50% Siltst 50% 7062' 3520 9.6 9.6 Flat BG RES C40 CI st 80% Siltst 20% 7742' 3746 9.6 9.6 Flat BG RES Iceber Zone 9.6 9.6 U BG RES T3 Bermuda Ss 90% Siltst 10% 10539' 4834 9.9 9.9 U BG RES C35 Sd 60% Siltst 40% 10846' 5051 10.9 11.0 U BG,CG RES TD Sd 50% Siltst 50% 10921' 5265 11.7 12.1 U BG, CG,TG RES NOTE: Clyst = Claystone/Clay, Sd =Sand, Sltst = Siltstone, Sh =Shale, Ss =Sandstone EPOCH 22 ~Ont~'11~~I~ 2N-333 • DRILLING DATA 4.6 Survey Data (includes surface hole data from 2N-333) • Measured Depth (ft) Incl. ° O Azim. ° O True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ft) 113.16 0.39 251.89 113.16 0.08S 0.26W 0.26 0.49 169.04 0.72 279.14 169.04 0.09S 0.78W 0.79 0.74 262.69 1.13 231.18 262.68 0.57S 2.08W 2.12 0.90 352.69 2.26 190.00 352.64 2.88S 3.08W 3.32 1.77 441.69 4.43 189.45 441.48 8.OOS 3.95W 4.63 2.44 534.69 6.68 199.14 534.04 16.65S 6.32W 7.74 2.61 622.69 9.48 205.16 621.16 28.05S 11.08W 13.48 3.32 717.69 12.95 225.78 714.37 42.56S 22.04W 25.66 5.53 745.87 13.26 225.95 741.81 47.01 S 26.62W 30.62 1.11 838.72 12.67 233.51 832.30 60.47S 42.47W 47.57 1.93 929.57 14.69 247.01 920.59 70.90S 61.09W 67.03 4.14 1025.39 15.16 249.25 1013.18 80.08S 83.99W 90.65 0.78 1119.41 17.04 256.92 1103.52 87.56S 108.91 W 116.12 3.02 1212.59 21.60 266.47 1191.45 91.71 S 139.35W 146.81 5.94 1307.33 22.96 270.39 1279.12 92.66S 175.23W 182.64 2.13 1400.02 27.47 272.01 1362.96 91.78S 214.70W 221.88 4.92 1492.88 31.18 275.27 1443.91 88.82S 260.06W 266.81 4.35 1558.47 32.49 276.22 1499.63 85.35S 294.48W 300.80 2.14 1651.83 38.65 267.62 1575.58 83.84S 348.62W 354.60 8.49 1711.98 40.51 267.71 1621.94 85.41 S 386.91 W 392.88 3.09 1775.05 45.01 269.06 1668.24 86.59S 429.70W 435.62 7.28 1866.92 48.40 271.45 1731.23 86.25S 496.55W 502.18 4.15 1958.53 52.99 273.11 1789.25 83.40S 567.36W 572.47 5.20 2049.01 54.52 273.87 1842.74 78.95S 640.19W 644.63 1.82 2147.22 58.51 272.66 1896.92 74.31 S 721.95W 725.68 4.19 2235.40 61.44 269.62 1941.05 72.82S 798.26W 801.57 4.47 2332.48 65.98 268.89 1984.03 73.96S 885.27W 888.34 4.72 2426.89 68.73 268.73 2020.38 75.77S 972.37W 975.27 2.92 2515.68 67.82 264.12 2053.26 80.905 1054.66W 1057.70 4.93 2607.81 66.50 262.71 2089.02 90.64S 1139.01 W 1142.57 2.01 2703.44 68.95 263.10 2125.27 101.56S 1226.82W 1231.00 2.59 2799.35 68.71 263.30 2159.90 112.15S 1315.62W 1320.39 0.32 2892.96 68.25 263.90 2194.24 121.86S 1402.17W 1407.45 0.77 2988.55 68.12 263.44 2229.77 131.64S 1490.37W 1496.17 0.47 3080.63 69.18 264.26 2263.29 140.83S 1575.63W 1581.91 1.42 3168.43 68.50 264.06 2294.98 149.16S 1657.09W 1663.78 0.80 3268.02 70.70 263.64 2329.69 159.16S 1749.89W 1757.10 2.24 3363.18 70.65 263.43 2361.18 169.275 1839.12W 1846.87 0.21 L~~~~ 23 •. ~OE']tDC[?~'1t~~1~ 2N-333 • • • Measured Depth (ft) Incl. ° ~) Azim. ° ~) True Vertical Depth ft Latitude (ft) Departure lft) Vertical Section (ft) Dogleg Rate (°/100ft) 3411.93 70.54 263.53 2377.38 174.49S 1884.80W 1$92.84 0.30 3522.26 70.24 262.46 2414.41 187.17S 1987.95W 1996.70 0.95 3617.99 69.50 264.62 2447.36 197.28S 2077.26W 2086.55 2.26 3714.99 68.40 236.17 2481.86 206.81 S 2166.39W 2176.18 1.82 3805.23 67.41 263.05 2516.16 216.95S 2250.27W 2260.61 1.09 3899.28 67.30 264.87 2552.37 226.08S 2336.58W 2347.39 1.79 3998.17 66.33 265.11 2591.31 234.02S 2427.14W 2438.30 1.01 4093.91 68.62 265.65 2627.98 241.14S 2515.28W 2526.72 2.45 4187.24 68.87 269.08 2661.82 245.13S 2602.15W 2613.61 3.44 4280.96 68.68 269.62 2695.75 246.12S 26$9.51 W 2700.72 0.57 4374.46 69.27 269.42 2729.30 246.86S 2776.78W 2787.73 0.66 4469.12 68.10 269.49 2763.71 247.69S 2864.96W 2875.64 1.24 4564.40 .68.26 268.38 2799.12 249.34S 2953.40W 2963.89 1.09 4658.64 69.35 268.81 2833.19 251.49S 3041.23W 3051.58 1.23 4747.89 70.19 267.20 2864.06 254.41 S 3124.92W 3135.20 1.94 4846.54 70.93 265.66 2896.89 260.20S 3217.76W 3228.20 1.65 4941.32 70.84 264.43 2927.93 267.94S 3306.98W 3317.75 1.23 5034.57 69.75 264.77 2959.37 276.20S 3394.38W 3405.53 1.22 5129.14 69.36 263.81 2992.40 285.02S 3482.55W 3494.14 1.04 5222.36 69.06 262.01 3025.49 295.77S 3569.03W 3581.23 1.83 5313.68 68.91 261.59 3058.24 307.93S 3653.40W 3666.34 0.46 5411.58 68.79 262.74 3093.57 320.38S 3747.86W 3757.53 1.10 5505.63 68.43 261.57 3127.87 332.33S 3$30.61 W 3844.99 1.22 5598.53 69.08 261.00 3161.53 345.45S 3916.19W 3931.40 0.90 5693.98 69.14 261.04 3195.57 359.37S 4004.27W 4020.36 0.07 5786.08 69.31 262.28 3228.24 371.86S 4089.47W 4106.32 1.27 5872.14 69342 261.45 3258.57 383.25S 4169.20W 4186.74 0.91 5971.67 68.88 261.51 3293.99 397.03S 4261.19W 4279.58 0.55 6066.66 68.70 262.25 3328.36 409.54S 4348.85W 4368.00 0.75 6157.83 67.92 263.01 3362.05 420.41 S 4432.87W 4452.64 1.15 6254.55 68.10 262.73 3398.27 431.54S 4521.86W 4542.26 0.33 6347.46 68.97 263.41 3432.27 441.97S 4607.69W 4628.68 1.16 6441.77 69.65 262.61 3465.59 452.71 S 4695.26W 4716.85 1.07 6535.85 71.14 262.40 3497.15 464.27S 4783.13W 4805.39 1.60 6626.92 71.71 262.55 3526.16 475.58S 4868.71 W 4891.63 0.65 6721.26 70.71 262.93 3556.55 486.86S 4957.30W 4980.87 1.13 6815.79 69.80 263.63 3588.49 497.27S 5045.66W 5068.80 1.19 6910.39 70.15 263.85 3620.88 506.97S 5134.01 W 5158.66 0.43 7003.65 69.04 264.74 3653.40 515.66S 5220.99W 5246.06 1.49 7100.58 68.59 265.36 3688.42 523.46S 5311.03W 5336.44 0.76 7193.89 68.21 264.99 3722.77 530.75S 5397.48W 5423.20 0.55 7286.57 68.24 263.99 3757.16 539.02S 5483.14W 5509.26 1.00 24 COI7Qt70~'11~~1~75 2N-333 • • ~J Measured Depth (ft) Incl. o O Azim. ~ O True Vertical Depth ft Latitude (ft) Departure (ft) Vertical Section (ft) Dogleg Rate (°/100ft) 7379.60 70.62 264.56 3789.84 547.705 5569.80W 5596.34 2.62 7472.99 71.53 265.00 3820.13 555.74S 5657.78W 5684.68 1.07 7566.78 72.88 264.75 3848.79 563.71 S 5746.72W 5773.98 1.46 7662.42 72.54 263.99 3877.22 572.67S 5837.60W 5865.29 0.84 7752.95 71.90 262.68 3905.77 583.01 S 5926.06W 5954.32 1.50 7845.27 71.13 263.18 3934.09 593.43S 6010.12W 6038.98 1.01 7943.30 69.55 263.39 3967.07 604.23S 6101.80W 6131.25 1.62 8037.13 69.31 263.27 4000.04 614.43S 6189.06W 6219.06 0.28 8130.80 67.84 264.13 4034.25 624.OOS 6275.72W 6306.23 1.79 8226.17 66.54 262.86 4071.23 633.96S 6363.07W 6394.10 1.83 8319.14 66.60 263.96 4108.19 643.75S 6447.80W 6479.38 1.09 8412.56 66.79 264.52 4145.15 652.36S 6533.17W 6565.17 0.59 8507.19 68.64 265.27 4181.04 660.14S 6620.38W 6652.72 2.09 8600.02 68.65 264.71 4214.84 667.69S 6706.51 W 6739.18 0.56 8693.32 68.35 265.73 4249.04 674.93S 6793.01 W 6825.98 1.07 8786.93 68.85 264.35 4283.19 682.47S 6879.84W 6913.14 1.47 8882.05 69.42 264.51 4317.07 691.09S 6968.30W 7002.01 0.62 8972.95 69.38 263.59 4349.06 699.91 S 7052.93W 7087.09 0.95 9068.26 69.94 262.97 4382.18 710.37S 7141.68W 7176.42 0.85 9160.46 69.90 262.90 4413.84 721.02S 7227.62W 7262.96 0.08 6250.97 70.43 262.20 4444.55 732.Q6S 7312.04W 7348.02 0.93 9348.32 69.46 262.91 4477.93 743.91 S 7402.71 W 7439.38 1.21 9440.99 68.86 263.19 4510.90 754.39S 7488.68W 7525.94 0.71 9532.69 69.20 262.43 4543.72 765.11 S 7573.63W 7611.50 0.86 9625.96 68.27 262.88 4577.55 776.22S 7659.84W 7698.34 1.09 9720.90 68.23 263.72 4612.73 786.51 S 7747.42W 7786.48 0.82 9813.07 69.83 263.72 4612.73 794.29S 7$33.12W 7872.54 2.81 9906.41 70.06 266.98 4677.73 799.735 7920.63W 7960.19 1.11 10000.91 67.88 266.83 4711.64 804.49S 8008.70W 8048.34 2.31 10094.68 64.57 264.26 4749.44 811.13S 8094.24W 8134.13 4.33 10181.91 61.30 262.63 4789.13 819.98S 8171.39W 8211.76 4.10 10283.09 58.15 262.62 4840.13 831.19S 8258.04W 8299.06 3.11 10378.47 55.80 261.89 4892.11 841.98S 8337.28W 8378.93 2.55 10423.97 54.37 261.02 4918.15 847.50S 8374.17W 8416.17 3.51 10472.39 52.15 262.10 4947.11 853.205 8412.55W 8454.90 4.92 10518.81 50.44 261.51 4976.14 858.36S 8448.40W 8491.06 3.81 10567.01 48.86 260.92 5007.35 863.975 8484.70W 8527.72 3.41 10659.97 46.52 259.62 5069.92 875.585 $552.45W 8596.22 2.72 10753.03 43.10 260.01 5135.93 887.18S 8616.99W 8661.53 3.69 10847.10 38.78 260.40 5206.97 897.67S 8677.72W 8722.94 4.60 ~;I'OC,H 25 • 4.7 Bit Record ~, • • GOCIOCOF~1t~~t~S 2N-333 Depth In Total Bit Aug' WOB PP Bit Make Type Jets / TFA MD / TVDSS Footage Hrs ROP (Klbs) RPM lpsi) Wear BHA ft ftthr 12.25" hole 1 HTC MILL 3X15 1X13 129' 3350' 27:46 175 24 na na 1-2 TOOTH , 8.5" hole 2 SEC FSF-2565 3462' 7459' 80:21 107 12 na na 10 ~~~~H 26 • 4.8 Mud Record Contractor :MI SWACO Mud Tvae :LSND to TD ~° • • COnOCt~ti~~lp5 2N-333 Date Depth MW VIS s~ t PV YP Gels FL cc FC Sols % O/W Ratio Sd % MBT pH CI mUl Ca ml/1 2/25/06 657 10.0 188 25 50 33!60/85 8.3 3/ 8 0192 .3 26 9 700 40 2/26/06 2400 10.3 100 23 34 25/38/62 7.6 3! 10 .5/89.5 .33 27 9 550 20 2/27/06 3462 10.3+ 94 35 35 24/44/65 7.8 2/ 11.5 .5/88 .33 28 9 550 20 2/28/06 3462 10.3 68 26 21 12/19/24 7.4 2/ 11.5 .5/88 .5 28 9 550 20 3/1 /06 3462 10.3 68 26 21 12/19/24 7.4 2/ 11.5 .5/88 .5 28 9 550 20 3/2/06 3826 9.7 52 11 18 8/11 /12 7.8 2/ 6.5 0/93.5 tr 7 9 400 20 3/3/06 4900 9.6 52 19 22 $/15/19 5.6 2/ 7 1.5/91.5 .25 15 9.5 500 20 3!4/06 7075 9.6 51 20 25 9/19/25 5.8 2/ 8 2/90 .25 15 9 400 20 3/5/06 8270 9.6 53 16 23 9115/26 5.0 2/ 8 2/90 .25 17 $.5 500 20 3/6/06 9854 9.6 51 15 23 9/14120 5.4 2/ 8 2/90 .25 20 8.5 500 20 3/7/06 10029 9.6 52 15 19 9/14!18 5.8 2! 8 2190 tr 17 9 500 20 3/8/06 10687 9.8 51 13 22 9/13/19 4.2 2/ 7 3/90 tr 18 9 400 20 3/9/06 10921 11.3 51 17 21 10/18/25 5.5 2/ 13 10/77 tr 10 9.5 5300 60 3!10/06 10921 12.1 80 28 32 10/12/17 5.4 2/ 15 0/85 0 7 9 300 20 3/11/06 10921 11.8 82 26 32 9/15/19 5.3 2l 14 1185 tr 8 9.5 800 20 3/12/06 10921 11.7+ 67 27 28 9/12118 4.1 2/ 14 2.5/83.5 tr 10 8.5 1000 1 ~ Abbreviations MW =Mud Weight Gels =Gel Strength Sd =Sand content WL = Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids YP =Yield Point ECD =Effective Circulating Density FC =Filter Cake O/W =Oil to Water ratio ~1'OCH 27 ~~10CUP~'1~~~1~5 2N-333 • 5 MORNING REPORTS ~~ • -, ~.Clrlou~lllps 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: HABERTHUR/BROWN KLEIBACKER Date: 2/26/06 Time: 12 AM Current Depth: 1051 Yesterdays Depth: 129 24 hr Footage: 922' Operation: DRILLING rlrillinn Paramctcrc ROP: Current: 133 Max: 1021 Torque: Current: 0 Max: 0 WOB: Current 19 Max: 51 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 1500 Time: 14 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Mud Proper4es MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume; Gas Data Ditch Gas: Current: ~o Max: 2s De the 599 (_ae Fvcn+c WIPER GAS De th TG C1 C2 C3 C41 C4N C51 CSN TRIP GAS De th TG C1 C2 C3 C41 C4N C51 CSN Connection Gas AVE 0 Paakc De th TG C1 C2 C3 C41 C4N C51 CSN 599 26 5350 (,ac Ranc Camnlcc /rrrwl No. De th TG C1 C2 C3 C41 C4N C51 C5N 1 500 10 1329 2 1000 11 2056 3 Lithologies: Current: CLAY 60%, COAL 10%, SAND 10%, SILT 20% Last 24 hrs: CLAY, CONGLOMERATE SAND, SILT, COAL, CARBON SHALE Operational Summary: Spud well and drill Calibrations: YES Failures: none EPOCH DAYRATE _ ~27Q0.00 ~Or1oCUP11~IIIpS 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/BROWN KLEIBACKER Date: 2/27/06 Time: 12 AM Current Depth: 2477 Operation: WIPER TRIP Yesterdays Depth: 1051 24 hr Footage: 1426' flrillinn Paramafiarc ROP: Current: 120 Max: 289 Tor ue: Current: 0 Max: 0 WOB: Current 27 Max: 54 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3149 Time: 29 Circulation: Strokes: 11667 Time: 117 ECD: Current: 0 Max: Marl Drnncrfinc MW: 10.3 FV: 100 PV: 23 YP: 34 FL: 7.6 Gels: 25/38/62 Sol: 10 H: 9 CI- 550 ~ Ca++ 20 MW Change: Depth: 1585' From: 10.1 To: 10.3 Reason: BAs Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 4~5 Max: X921 De the 1257 (.ac G..nnfic WIPER GAS De th TG C1 C2 C3 C41 C4N C51 CSN TRIP GAS De th TG C1 CZ C3 C41 C4N C51 CSN Connection Gas AVE 0 Pcakc De th TG C1 C2 C3 C41 C4N C51 C5N 1257' 1921 373902 13 C~ac Ranc /rmv\ No. De th TG C1 C2 C3 C41 C4N C51 C5N 10 2000 270 57175 9 1644 700 138313 8 1585 1700 7 1584 844 166631 Operational Summary: drill to 2477' and arculate bottoms up and begin wiper trip. Lithologies: Current: CLAY 50%, SAND 50% Last 24 hrs: CLAY, SILT, SAND Drill formation to 1586' arculate and wait on town for close approach issue Calibrations: yes Failures: none EPOCH DAYRATE _ X2700.00 • KLEIBACKER Date: 2/28/06 Time: 12 AM Current Depth: 3462 Opera~on: WIPER TRIP @ TD Yesterdays Depth: 2477 24 hr Footage: 985' CQC1oC7aPl'1tII1pS 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN/BROWN 1'lrillinn D'Jr~MC'FcrC ROP: Current: 161 Max: 319 Tor ue: Current: 0 Max: 0 WOB: Current 31 Max: 48 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4343 Time: 34 Circulation: Strokes: 11667 Time: 117 ECD: Current: 10.76 Max: Mnr~ Prnncrticc MW: ~ 10.3 FV: 100 PV: 23 YP: 34 FL: 7.6 Gels: 25/38/62 Sol: 10 H: 9 CI" 550 Ca" 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 33o Max: 993 De h: 3114 C~ac Fvantc WIPER GAS De th TG C1 C2 C3 C41 C4N C51 CSN 2477' 1020 SWAB GAS De th TG C1 C2 C3 C41 C4N C51 GSN 3462' ~s~o Connection Gas AVE 0 Dn~4c De th TG C1 C2 C3 C41 C4N C51 C5N 3114' 993 198648 2477' 893 159368 24 C~ac Ranc (marl No. De th TG C1 C2 C3 C41 C4N C51 C5N 13 3032 850 124936 12 2752 270 63360 11 2520' 123 12205 10 2000' 270 57175 Operational Summary: hole (swab gas = 1610 units), POOH to HWDP, trip to bottom Lithologies: Current: CLAY 90$, SILT 10% Last 24 hrs: CLAY, SILT, SAND Finish wiper trip (wiper gas = 1020 units) drill to casing point 3462' circulate Calibrations: no Failures: none EPOCH DAYRATE _ X2700.00 u r~ U cc~llllps 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN Date: 3/1/06 Time: 12 AM Current Depth: 3462 Operation: NIPPLE DOWN Yesterdays Depth: 3462 24 hr Footage: 0 1'lrillinn D~r~mninrc ROP:v Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current: 0 Max: Mi ir• Prnnarfias MW: 10.3 FV: 68 PV: 26 YP: 21 FL: 7.4 Gels: 12/19/24 Sol: 11.5 H: 9 CI- 550 Ca++ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: 103 De the 3462' r~~ G..o.,+~ De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks WIPER GAS Depth TG C1 C2 C3 C41 C4N C51 C5N 3462' 451 SWAB GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 0 No. De th TG C1 C2 C3 C41 C4N C51 C5N 13 3032 850 124936 12 2752 270 63360 11 2520' 123 12205 10 2000' 270 57175 gas Ba s (max Lithologies: Current: 90% CLAY, 10% SILT Last 24 hrs: Finish wiper trip (Wiper Gas = 451 units), circulate bottoms up 3X, Pump out of Operational Summary: the hole to HWDP (Max Gas pumping out 83 units), UD BHA and clean and clear the rig floor. Rig up and run 9 5/8 casing. Rig up cement head and start to cement. Calibrations: no Failures: none EPtJCH DAYRATE _ X2704.00 • • ~At10C0~1'1{IIipS 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2L-309 Report for: VAUGHN Date: 3/2/06 Time: 12 AM Current Depth: 3462 Operation: M/U BHA Yesterdays Depth: 3462 24 hr Footage: 0 nryllinn o~r~.,,n+nrc ROP: __ Current: 0 Mau: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 0 Time: 0 Circulation: Strokes: 0 Time: 0 ECD: Current; 0 Max: Marl Prnnprtips MW: 10.3 FV: 68 PV: 26 YP: 21 FL: 7.4 Gels: 12/19/24 Sol: 11.5 H: 9 CI-~ 550 Ca++~ 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: o De h: r~~ ~..o.,+~ De th TG C1 CZ C3 C41 C4N G51 C5N eaks WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N SWAB GAS De th TG C1 CZ C3 C41 C4N C51 CSN Connection Gas AVE 0 No. De th TG C1 C2 C3 C41 C4N C51 C5N 13 3032 850 124936 12 2752 270 63360 11 2520' 123 12205 10 2000' 270 57175 gas Ba s max Lithologies: Current: Last 24 hrs: Operational Summary: Finish cementing hole. Nipple down and nipple up. P/U and M/U DP and rack back. M/U BHA Calibrations: no Failures: none EPOCH DAYRATE _ X2700.00 • • • Report for: VAUGHN/KING KLEIBACKER Date: 3/3/06 Time: 12 AM tlrillinn P~r~matcrc Current Depth: 3931 Yesterdays Depth: 3462 24 hr Footage: 469 Operation: DRILLING ROP: Current: 106 Max: 185 Tor ue: Current: 0 Max: 0 WOB: Current 10 Max: 14 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 1916 Time: 16 Circulation: Strokes: 6582 Time: 56 ECD: Current: 10.43 Max: ~Anrl Drnnnrflnc MW: 10.3 FV: 68 PV: 26 YP: 21 FL: 7.4 Gels: 12/19/24 Sol: 11.5 H: 9 CI-~ 550 Ca++~ 20 MW Change: Depth: 3462 From: 10.3 To: 9.7 Reason: ~sNt° to Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 33 Max: 92 De the 3693' (`_~c G.,nntc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 3462' 28 WIPER GAS De h TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 0 Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3643 92 15928 118 19 86 81 297 345 C~ac Ranc (maYl No. De h TG C1 C2 C3 C41 C4N C51 CSN 15 3808 36 6534 37 2 38 20 88 82 14 3500 9 2846 8 Lithologies: Current: 90% CLAY, 10% SILT Last 24 hrs: 90% CLAY, 10% SILT MU BHA, single in hole, cut and slip new drill line, test casing, drill out cement Operational Summary: plugs, cement and 20' of new hole. Displace hole with LSND drill mud @ 9.6 ppg. Run F.I.T to 12.5 ppg and drill formation. Calibrations: yes Failures: none EPOGH DAYRATE = X2700.00 ~OI'1OCOPI'11111~!S 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 • Report for: VAUGHN/KING KLEIBACKER Date: 3/4106 Time: 12 AM rlrillinn Paramptprs Current Depth: Yesterdays Depth 24 hr Footage: 5438 Operation: WIPER TRIP ROP: Current: 107 Max: 155 Tor ue: Current: 0 Max: 0 WOB: Current 7 Max: 16 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 2656 Time: 23 Circulation: Strokes: 6582 Time: 56 ECD: Current: 10.43 Max: Mud Proper4es MW: 9.6 Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 33 Max: ~ De the 3693' C~ac Fvcnfic TRIP GAS De h TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 23 Ppakc De th TG C1 C2 C3 C41 C4N C51 C5N 4596 31 6264 15 C:ac Ranc /maul No. De th TG C1 C2 C3 C41 C4N C51 C5N 19 5000 25 3426 18 4588 24 4207 13 17 4500 16 2865 16 3998 16 2877 Operational Summary: the shoe. Lithologies: Current: 60% SILT, 30% SANDSTONE, 10% CLAY Last 24 hrs: SILT, CLAY, SANDSTONE Drill formation to 5438' arculate out samples and bottoms up 3X Wiper Trip to CAE1C?CfJI'I'1lIIIpS 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 Calibrations: no Failures: none EPOGH DAYRATE _ $2700,00 • • I~ Report for: VAUGHN/KING KLEIBACKER Date: 315106 Time: 12 AM flrillin.. D.~romn#nrc Current Depth: Yesterdays Depth 24 hr Footage: 7223 Operation: DRILLING ________ _ ROP: _____________ Current: 105 Max: 161 Torque: Current: 0 Max: 0 WOB: Current 12 Max: 27 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3475 Time: 30 Circulation: Strokes: 8662 Time: 76 ECD: Current: 10.43 Max: ~Anri Prnncr6cc MW: 9.6 FV: 51 PV: 20 YP: 25 FL: 5.8 Gels: 9!19/25 Sol: 8 H: 9 CI: 400 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: a~ Depth: 7014 !'!.,.. C..en#~ TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 5438 75 Connection Gas AVE 23 Paakc De th TG C1 C2 C3 C41 C4N C51 CSN 7014 47 9264 105 25 roc Ranc /rrov\ No. De th TG C1 C2 C3 G41 C4N C51 C5N 23 7000 29 6141 68 16 22 6500 18 3228 0 21 6000 18 3354 26 6 20 5500 18 3222 20 Lithologies: Current: CLAY 50%, SILT 40%, SHALE 10% Last 24 hrs: SILT, SANDSTONE, CLAY, CARBON CLAY Operational Summary: Finish Wiper Trip Wiper Gas = 75 units, drill formation Calibrations: no Failures: none EPOCH DAYRATE = 52700.00 ~Ol~llillllp5 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 CO-tIOCOP'111111p5 2N-333 ConocoPhillips Alaska Inc. i, Exploration Well 2N-333 Report for: VAUGHNlKING KLEIBACKER • Date: 3/6/06 Time: 12 AM Current Depth: 8300 Yesterdays Depth: 7223 24 hr Footage: 1077 rlrillinn D~r~mn#crc Operation: DRILLING ROP: Current: 111 Max: 163 Tor ue: Current: 0 Max: 0 WOB: Current 15 Max: 35 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3969 Time: 29 Circulation: Strokes: 9705 Time: 71 ECD: Current: 10.99 Max: Mnr1 Prnnnrfitac MW: 9.6 FV: 53 PV: 16 YP: 23 FL: 5.0 Gels: 9/15/26 Sol: 8 H: 8.5 CI: 500 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 34 Max: ~ De the 7728 (-`mac wnn+c TRIP GAS De th TG C1 C2 C3 C41 CON G51 C5N WIPER GAS De th TG C1 CZ C3 C41 CON C51 C5N 7408' ss Connection Gas AVE 33 Po ~ Irc De th TG C1 C2 C3 C41 CON C51 C5N 7728 68 13327 265 52 13 7 C~ac Rans (maYl No. De th TG C1 C2 C3 C41 CON C51 C5N 25 8000 49 9482 224 49 15 10 8 Operational Summary: 5340', RIH to bottom Wiper Gas = 95 units, drilling....... Litholagies: Current: SANDSTONE 30% SAND 10% SILT 20% CLAY 40% Last 24 hrs: CLAY, SILT, CARBON SHALE Drill formation to 7408' arculate bottoms up 2X and pump out of the hole to Calibrations: no Failures: none EPOCH DAYRATE _ $2700.00 n U • Report for: VAUGHN/KING KLEIBACKER Date: 3R/06 Time: 12 AM rlrillinn Paramaficrc Current Depth: 9748 Yesterdays Depth: 8300 24 hr Footage: 1448 Operation: DRILLING ROP: Current: 129 Max: 192 Tor ue: Current: 0 Max: 0 WOB: Current 16 Max: 35 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4675 Time: 35 Circulation: Strokes: 9705 Time: 71 ECD: Current: 10.99 Max: Mi ~rl Prnnnrfinc MW: 9.6 FV: 53 PV: 16 YP: 23 FL: 5.0 Gels: 9/15!26 Sol: 8 H: 8.5 CI: 500 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2e Max: 87 De the 8743 (.ac Gvnntc WIPER GAS Depth TG C1 C2 C3 C41 C4N C51 C5N 8556 169 WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N 9241 cos Connection Gas AVE 33 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 8743 87 15815 336 128 23 47 (;AS RAC1R (n1AY~ No. De th TG C1 C2 C3 C41 C4N C51 C5N 28 9512 20 4325 106 36 9 6 27 9000 30 4038 81 32 17 26 8500 23 2120 15 25 8000 49 9482 224 49 15 10 8 Lithologies: Current: SILT 40%, CLAY 30%, SAND 20%, CARBON SHALE 10% Last 24 hrs: CLAY, SILT, CARBON SHALE, SAND SANDSTONE Drill to 8556', pull nine stands for wash out, trip to bottom 169 units of wiper L~ Operational Summary: gas, drill to 9241' pull seven stands out for wash out, trip to bottom, wiper gas = 106 units, drill ahead Calibrations: no Failures: none EPQCH I7AYRATE _ X2700.00 Cor~ocoP!'1~IIIpS 2N-333 ConocoPhillips Alaska Inc. Exploration We112N-333 ~= Gon©ccaPhlilllps 2N-333 ConocoPhillips Alaska Inc. • Exploration Well 2N-333 Report for: VAUGHN/KING KLEIBACKER • Date: 3/8/06 Time: 1 Z AM Current Depth: Yesterdays Depth 24 hr Footage: I'lrillinn D~romntcrc ROP:V Current: 117 Max: 151 Tor ue: Current: 0 Max: 0 WOB: Current 24 Max: 36 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 4763 Time: 35 Circulation: Strokes: 9930 73 71 ECD: Current: 11.01 Max: ~Anrl Drnncrflcc MW: 9.6 FV: 51 PV: 15 YP: 23 FL: 5.4 Gels: 9/14/20 Sal: 8 H: 8.5 CI: 500 Ca++: 20 MW Change: Depth; From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 20 Max: 20 De the 9808 (`_~c Gvcntc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 15 Dcolrc De th TG C1 C2 C3 C41 C4N C51 C5N 9808 30 5532 168 71 13 21 - - Comas Ranc lmaYl No. De th TG C1 C2 C3 C41 C4N C51 CSN 29 10028 20 2957 129 73 14 25 28 9512 20 4325 106 36 9 6 27 9000 30 3038 81 32 17 26 8500 23 2120 15 Operational Summary: Inspect BHA and down load MWD data, TIH Lithologies: Current: 40% SILT, 40% CLAY, 10% SHALE, 10% CARBON SHALE Last 24 hrs: SILT, CLAY, SAND, SHALE, CARBON SHALE Drill formation to 10028' and arculate out samples and bottoms up and POOH. 10028 Operation: TRIP IN HOLE • Calibrations: YES Failures: none EPOCH DAYRATE _ X2700.00 C. Report for: KING COPII~IIIpS 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 KLEIBACKER Date: 3/9/06 Time: 12 AM flrillinn D~r~mn4nnc Current Depth: Yesterdays Depth 24 hr Footage: 10685 Operation: CIRC HI GAS ROP:V Current: 67 Max: 131 Tor ue: Current: 0 Max: 0 WOB: Current 8 Max: 24 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5064 Time: 38 Circulation: Strokes: 9930 Time 71 ECD: Current: 11.01 Max: Mud Pro ernes MW: Gels: MW Change: Depth: 10685' From: 9.7 To: 10.0+ Reason: sas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2000 Max: 21~ De h: 10685 (.ac F~,cntc TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N 10028 1240 WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE 445 Paakc De th TG C1 C2 C3 C41 C4N C51 C5N 10685 2100 181577 63620 86626 27196 71044 16176 19953 10335 1995 208675 32459 23900 4993 13089 2948 3477 Icn Tnhcc (mav\ No. De th TG C1 C2 C3 C41 C4N C51 C5N 1 10121 1600 110654 1714 1152 622 581 180 198 2 10405 1420 151122 23432 18839 4367 11737 2568 324fi 3 10516 1570 159833 26678 20333 4824 12927 2970 3765 4 10530 1580 168119 25676 20133 4864 13230 3103 3942 Operational Summary: p ' arculate high gas and condition mud. Lithologies: Current: 10686' = 80% sandstone, 20% sansd Last 24 hrs: Sandstone, sand, silt, clay Tri to bottom and arculate out 1240 units of trip gas drill to 10686' and • Calibrations: YES Failures: none EPOCH DAYRATE _ $2700A0 ~,, ConoaoPh~llrps 2N-333 ConocoPhillips Alaska Inc. • Exploration Well 2N-333 Report for: KING KLEIBACKER Date: 3/10/06 Time: 12 AM Current Depth: 10917 Yesterdays Depth: 10685 24 hr Footage: 232' I'lrillinn Daramn4crc Operation: CIRC HI GAS ROP: Current: 0 Max: 86 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 9 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5171 Time: 39 Circulation: Strokes: 10821 Time: 93 ECD: Current: 11.07 Max: Mud Properties MW: Gels: MW Change: Depth: 10917 From: 9.7 To: 11.3 Reason: Hign Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: ~~ Max: ~~ De the 10917 (.ac F..nnfc TRIP GAS Depth TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 CSN Connection Gas AVE Dna4c De th TG C1 C2 C3 C41 C4N C51 C5N 10864 2277 98806 33636 47332 12486 32287 7729 9797 10779 1820 154292 20314 20572 6106 17762 5764 7878 Icn Tuhac lmav\ No. De th TG C1 C2 C3 G41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 Operational Summary: 10917' arculate mud and raise mud weight from 11.0 to 11.3. Current mud cut is 11.3 in / 10.5 out. Background gas 1800 units. Lithologies: Current: 10917' = 50% SAND, 50% SILT Last 24 hrs: SAND, SANDSTONE, SILT Finish circulating mud, raise mud weight from 9.7 to 11.0, drill from 10688' to Calibrations: no Failures: none EPC}CN DAYRATE = $2700.00 ~,.. ConocoPhllltps 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 Report for: KING KLEIBACKER • Date: 3/11/06 Time: 12 AM Current Depth: 10917 .Operation: CIRC HI GAS Yesterdays Depth: 10917 24 hr Footage: 0' flrillinn P~r~mcfcrc ROP: Current: 0 Max: 86 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 9 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5171 Time: 172 Circulation: Strokes: 10972 Time: 378 ECD: Current: 12.227 Max: Mnr1 Prnnarfips MW: 11.3 FV: 51 PV: 17 YP: 21 FL: 5.5 Gels: 10/18/25 Sol: 13 H: 9.5 CI: 5300 Ca++: 60 MW Change: Depth: 10917 From: 11.3 To: 12.0+ Reason: Hisn Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 2~ Max: ~o De the 10917 (`_~c Gvcntc De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 G5N Connection Gas AVE No. De th TG C1 C2 C3 C41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 so Tubes max Lithologies: Current: 10917' = 50% SAND, 50% SILT Last 24 hrs: SAND,SILT Operational Summary: Continue to arculate high background gas and increase the mud weight to 12.0, background gas decreasing from 800 units to 200 units. Calibrations: no Failures: none EPOCH ©AYRATE _ X2700.00 U l~A'170Ct~'1[111~35 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 Report for: KING/HABATHUR KLEIBACKER Date: 3/12/06 Time: 12 AM Current Depth: 10917 Operation: CIRC GAS Yesterdays Depth: 10917 24 hr Footage: 0' rlrillinn P~r~mc+crc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 5171 Time: 172 Circulation: Strokes: 10972 Time: 378 ECD: Current: 12.227 Max: Marl grnncrficc MW: 12.1 FV: 80 PV: 28 YP: 32 FL: 5.4 Gels: 10/12/17 Sol: 15 pH: 9.0 CI: 300 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: so Max: s2~ Depth: 10917 r_a~ F"anr~ Depth TG C1 C2 C3 C41 C4N C51 C5N eaks TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS Depth TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE No. Depth TG C1 C2 C3 C41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 ~o Tubes max Lithologies: Current: 10917' = 50% SAND, 50% SILT Last 24 hrs: SAND,SILT Operational Summary: Continued circulating of drilling mud. Background gas dropping from a high of 321 units to currently 90 units • Calibrations: no Failures: none EPOCH C?AYRATE _ $270fl.flfl r..- ~AI'tt)COlal'1~II113iS 2N-333 ConocoPhillips Alaska Inc. • Exploration Well 2N-333 Report for: KING/HABATHUR KLEIBACKER ~J Date: 3/13/06 Time: 12 AM Current Depth: 10921 Operation: TRIP OUT Yesterdays Depth: 10921 24 hr Footage: 0' rlrillinn P~r~mc4crc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 5171 Time: 172 Circulation: Strokes: 10972 Time: 378 ECD: Current: 11.8 Max: Mnri Prnnrnrfiiac MW: 11.8 FV: 82 PV: 26 YP: 32 FL: 5.3 Gels: 9/15/19 Sol: 14 H: 9.5 CI: 800 Ca++: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: ~5 Max: ss3 De h: 9597' POOH (`_~c wcntc De th TG C1 C2 C3 C41 C4N C51 C5N peaks TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 CZ C3 C41 C4N C51 C5N Connection Gas AVE No. De th TG C1 C2 C3 C41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 so Tubes max Lithologies: Current: 10921' = 50% SAND, 50% SILT Last 24 hrs: SAND,SILT Operational Summary: Continue to arculate drilling mud. Begin to pull out of the hole. Pump out and arculate Calibrations: no Failures: none EPQGH DAYRATE _ $2700.00 • ConoacaP'hrllths 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 Report for: KING/HABATHUR KLEIBACKER Date: 3/14/06 Time: 12 AM Current Depth: 10921 Operation: TRIP IN Yesterdays Depth: 10921 24 hr Footage: 0' Ilrillinn D~r~mctcrc ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3301 Time: 106 Circulation: Strokes: 7601 Time: 245 ECD: Current: 12.81 Max: ~4ur1 Drnnnrfinc MW: 11.7+ FV: 67 PV: 27 YP: 28 FL: 4.1 Gels: 9/12/18 Sol: 14 H: 8.5 CI: 1000 100 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 5o Max: 2so Depth: 3265 POOH ('-mac G.rcnfc De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks TRIP GAS De th TG C1 C2 C3 C41 C4N C51 C5N WIPER GAS De th TG C1 C2 C3 C41 C4N C51 C5N Connection Gas AVE No. De th TG C1 C2 C3 C41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 ~o Tubes max Lithologies: Current: 10921' = 50% SAND, 50% SILT Last 24 hrs: SAND,SILT Operational Summary: POOH and UD BHA and MWD M/U new BHA and TIH for clean out run Calibrations: no • Failures: none EPOCH DAY RATE = $2700.00 Car~ocoPhlll"rps 2N-333 ConocoPhillips Alaska Inc. Exploration Well 2N-333 Report for: BROWN/HABATHUR KLEIBACKER • Date: 3/15/06 Time: 12 AM Current Depth: 10921 Operation: PREP FOR CSG Yesterdays Depth: 10921 24 hr Footage: 0' Ilrillinn D~r~mctcrc ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 La Strokes: 3301 Time: 106 Circulation: Strokes: 7601 Time: 245 ECD: Current: 12.81 Max: Mart Prnnarfias MW: 11.7+ FV: 67 PV: 27 YP: 28 FL: 4.1 Gels: 9/12/18 Sol: 14 H: 8.5 CI: 1000 100 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: o Max: 470 De the POOH r~ac Fvnntc De th TG C1 C2 C3 C41 C4N C51 C5N 'eaks TRIP GAS De th TG C1 C2 C3 C41 C4N C51 CSN 10921 1760 225858 49645 44125 8047 19482 5584 5378 WIPER GAS De th TG C1 C2 C3 C41 C4N C51 CSN Connection Gas AVE No. De th TG C1 C2 C3 C41 C4N C51 C5N 21 10913 1920 28412 17295 36013 10952 31046 8235 10783 20 10893 1220 7949 5392 15208 5774 18949 6341 8901 19 10860 2225 98786 31815 44318 11729 30441 7372 9377 18 10840 2000 106915 26697 35155 9478 25103 6465 8366 so Tubes max Lithologies: Current: 10921' = 50% SAND, 50% SILT Last 24 hrs: SAND,SILT TIH to bottom, arculate out 1760 units of trip gas and circulate and condition Operational Summary: mud. Pump out of the hole maximum gas pumping out: 470 units. Break down BHA and prep for running casing. Calibrations: no Failures: none EPOCki DAYRATE _ $2700.00
