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209-103
Originated: Delivered to:19-Feb-25Halliburton 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 # E SET#1 2C-03 50-029-20968-00 909817733 Kuparuk River Multi Finger Caliper Field & Processed 17-Jan-25 0 12 2M-22 50-103-20170-00 909865523 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 13 2M-29 50-103-20183-00 909817744 Kuparuk River Plug Setting Record Field- Final 12-Feb-25 0 14 2W-01 50-029-21273-00 9097400015 Kuparuk River Leak Detect Log Field- Final 1-Feb-25 0 15 2X-05 50-029-20985-00 909816964 Kuparuk River Plug Setting Record Field- Final 20-Jan-25 0 16 3C-10A 50-029-21356-01 909817450 Kuparuk River Leak Detect Log Field- Final 18-Jan-25 0 17 3C-10A 50-029-21356-01 909817450 Kuparuk River Multi Finger Caliper Field & Processed 18-Jan-25 0 18 3H-33A 50-103-20578-01 909817452 Kuparuk River Leak Detect Log Field- Final 27-Jan-25 0 19 3H-33A 50-103-20578-01 909817452 Kuparuk River Multi Finger Caliper Field & Processed 26-Jan-25 0 110 3Q-10 50-029-21675-00 909817087 Kuparuk River Multi Finger Caliper Field & Processed 28-Jan-25 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:T40117T40118T40119T40120T40121T40122T40122T40123T40123T40124183-089192-049192-097185-010183-107213-083209-103186-1872/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.02.20 11:45:36 -09'00'3H-33A50-103-20578-01 909817452Kuparuk RiverLeak Detect LogField- Final27-Jan-25019 3H-33A50-103-20578-01 909817452Kuparuk RiverMulti Finger CaliperField & Processed26-Jan-2501209-103 Originated: Delivered to:17-Jan-25Halliburton 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 TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 3B-04 50-029-21323-00 909740412 Kuparuk River Plug Setting Record Field- Final 3-Jan-25 0 12 3H-21 50-103-20094-00 909740216 Kuparuk River Multi Finger Caliper Field & Processed 5-Jan-25 0 13 3H-21 50-103-20094-00 909740216 Kuparuk River Plug Setting Record Field- Final 6-Jan-25 0 14 3H-33A 50-103-20578-01 909740217 Kuparuk River Plug Setting Record Field- Final 29-Dec-24 0 15 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 2-Nov-24 0 16 3I-13 50-029-21923-00 909619504 Kuparuk River Packer Setting Record Field- Final 3-Nov-24 0 17 3K-24 50-029-22935-00 909619038 Kuparuk River Multi Finger Caliper Field & Processed 7-Nov-24 0 18 3K-24 50-029-22935-00 909619503 Kuparuk River Plug Setting Record Field- Final 30-Oct-24 0 19 3Q-14A 50-029-21665-01 909740219 Kuparuk River Leak Detect Log Field- Final 8-Dec-24 0 110 3Q-14A 50-029-21665-01 909740219 Kuparuk River Multi Finger Caliper Field & Processed 9-Dec-24 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:T40008T40009T40009T40010T40011T40011T40012T40012185-061188-008209-103189-025198-249214-082T40013T400131/23/202543H-33A50-103-20578-01909740217Kuparuk RiverPlug Setting RecordField- Final29-Dec-2401188 008209-103189 025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:18:26 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10307'feet None feet true vertical 6092' feet None feet Effective Depth measured 10307'feet 7366', 7390', 7447', 7473', 7547' feet true vertical 6092'feet 5813', 5833', 5883', 5904', 5969' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7606' MD 6021' TVD Packers and SSSV (type, measured and true vertical depth) 7366' MD 7390' MD 7447' MD 7473' MD 7547' MD 2110' MD 5813' TVD 5833' TVD 5883' TVD 5904' TVD 5969' TVD 1998' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4315' 3610' Burst Collapse Production Liner 7981' 2269' Casing 6160' 2-3/8" 8020' 9944' 6145' 4274' 149'Conductor Surface Intermediate 16" 9-5/8" 109' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 209-103 50-103-20578-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025531 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3H-33A Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 70 Gas-Mcf MD 1348 Size 149' 728 137832 75 234183 188 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 34 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker Premier Prod Packer SSSV: Camco TRMAXX-5E Sfty VLV Shelby Sumrall shelby.sumrall@conocophillips.com (907) 265-6678Well Integrity Specialist 7676-9943' Slotted Liner 6083- 6145' Slotted Liner Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:14 pm, Jul 24, 2024 Digitally signed by Shelby Sumrall DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=Shelby.Sumrall@conocophillips.com Reason: I am the author of this document Location: Anchorage Alaska Date: 2024.07.24 09:48:47-08'00' Foxit PDF Editor Version: 13.0.0 Shelby Sumrall DTTMSTART JOBTYP SUMMARYOPS 6/21/2024 REPAIR WELL BRUSH n' FLUSH TBG TO 7500' RKB TBG OPEN 2.74" RECOVER TWO 2.5" CHUNKS OF RBP ELEMENT, CLEAN DRIFT W/ 2.72" x 24' DUMMY PATCH TO 7500' RKB. IN PROGRESS. 6/22/2024 REPAIR WELL SET LOWER 2.72" P2P @ 7390' RKB (ME) (4.01' OAL / SN: CPP35103), SET 3 1/2 TTS TEST TOOL IN 2.72" P2P @ 7390' RKB CMIT TBG x IA 2500 PSI FAILED (6.3 GPM LLR) PULLED 3 1/2 TTS TEST TOOL (GOOD LIGHT SCALE), SET TEST TOOL BACK IN PACKER @ 7390' RKB CMIT FAILED W/ SAME LLR (6.3 GPM), RAN 3 1/2 STUBBY HOLE FINDER TO TOP OF TEST TOOL @ 7382' RKB TESTING FAILED. IN PROGRESS. 6/23/2024 REPAIR WELL ATTEMPT CMIT TBG x IA (FAILED) WITH SAME ~100 PSI LOSS PER MINUTE, PULLED 3 1/2 TTS TEST TOOL FROM 2.72" P2P @ 7390' RKB, PULLED 2.72" P2P @ 7390' RKB, RAN 2.81 X-SELECTIVE TEST TOOL TO 2.81 X NIPPLE @ 7504' RKB (2500 PSI COMBO TBG x IA PASS), RAN 3 1/2 SMART HOLE FINDER TIE INTO LDL LOG FAILING COMBO @ 7462' RKB, DEPLOY 3 1/2 AVA STYLE CATCHER (51" OAL 2.76" BTM), PULLED 1.5" DV @ 7453' RKB. IN PROGRESS. 6/24/2024 REPAIR WELL SET 1.5" DV @ 7453' RKB, RAN 3 1/2 SMART HOLE FINDER TIE INTO LDL LOG, PASSING TEST @ 7475' RKB FAILING TEST @ 7467' RKB, PULLED DV @ 7453' RKB, PULLED 3 1/2 AVA CATCHER FROM LINER TOP @ 7583' RKB, SET 2.72" P2P @ 7475' RKB (ME) (OAL 4.01' / SN:CPP35115), CMIT TBG x IA 2500 W/ 3 1/2 TTS TEST TOOL IN LOWER 2.72" PACKER @ 7475' RKB (PASS). IN PROGRESS. 6/25/2024 REPAIR WELL SET 2.72" P2P SPACER ANCHOR LATCH ASSEMBLY @ 7449.95' RKB (CE) TOP @ 7447.5' RKB (OAL 25.89' / SN:CPP35225 / CPAL35070), RAN 3 1/2 TTS TEST TOOL TO UPPER 2.72" P2P @ 7447' RKB CMIT TBG x IA 2500 PSI (PASS), SET LOWER 2.72" P2P @ 7392' RKB (ME) (OAL 4.01' / SN:CPP35085), CMIT TBG x IA 2500 PSI W/ 3 1/2 TTS TEST TOOL IN LOWER 2.72" P2P @ 7392' RKB (PASS), SET UPPER 2.72" P2P SPACER ANCHOR LATCH ASSEMBLY @ 7368.6' RKB (ME) TOP @ 7366.15' RKB (OAL 27.41' / SN: CPP35173 / CPAL35144). IN PROGRESS. 6/26/2024 REPAIR WELL RUN 3.5 TTS TEST TOOL IN UPPER P2P PACKER @ 7366' RKB, ACHIEVED PASSING MIT-T TO 2500 PSI, ACHIEVED PASSING CMIT T x IA TO 2500 PSI. JOB COMPLETE. 3H-33A Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 3H-33A lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Tbg Patches 3H-33A 6/25/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: WELL SIDETRACKED - A, AL1, AL2, AL2-01 11/2/2009 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 149.0 149.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 41.5 4,315.1 3,609.7 40.00 L-80 BTC-m WINDOW AL1 8 6.00 7,660.0 7,665.0 6,073.2 26.00 L-80 WINDOW A 8 6.00 7,680.0 7,685.0 6,091.0 26.00 L-80 INTERMEDIATE 7 6.28 39.2 8,020.0 6,160.4 26.00 L-80 Hyd 563 LINER A 2 3/8 2.00 7,674.5 9,944.0 6,144.8 4.60 L-80 STL Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.9 Set Depth 7,606.3 Set Depth 6,021.0 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 HANGER 8.000 GEN V TUBING HANGER FMC P120191 -002B, 1061993 9, CIW type "H", SN 02M918 3.500 2,109.8 1,998.1 36.74 SAFETY VLV 5.176 CAMCO TRMAXX-5E SSSV w/2.812" X PROFILE (Flapper locked out 10/14/2009) 2.812 2,735.0 2,471.9 44.14 GAS LIFT 5.968 CAMCO MMG 2.920 4,444.2 3,698.4 46.93 GAS LIFT 5.968 CAMCO MMG 2.920 5,709.7 4,598.0 45.78 GAS LIFT 5.968 CAMCO MMG 2.920 6,789.1 5,362.3 44.45 GAS LIFT 5.968 CAMCO MMG 2.920 7,453.3 5,887.6 30.33 GAS LIFT 5.968 CAMCO MMG 2.920 7,504.1 5,931.5 29.92 NIPPLE 4.550 CAMCO 'X' NIPPLE 2.812 7,546.8 5,968.7 28.99 PACKER 5.980 BAKER PREMIER PRODUCTION PACKER 2.870 7,594.4 6,010.6 27.88 NIPPLE 4.500 CAMCO 'D' NIPPLE w/2.75" PROFILE - MILLED NIPPLE TO 2.80" ID 9/26/2009 2.800 7,605.8 6,020.6 27.71 WLEG 4.500 WIRELINE ENTRY GUIDE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,366.2 5,812.6 30.96 PACKER - PATCH - UPR 2.725" P2P UPR PKR MID- ELEMENT AT 7368.6', W/ SPACER PIPE AND ANCHOR LATCH, OAL 27.4' TTS P2P CPP3 5173 / CPAL 35144 6/25/2024 1.625 7,369.8 5,815.7 30.92 SPACER PIPE 2-1/16" P-110 SPACER PIPE 6/25/2024 1.600 7,380.0 5,824.5 30.81 LEAK - TUBING TBG Leak found W/ Relay 12/10/2023 2.992 7,389.6 5,832.7 30.71 PACKER - PATCH - LWR 2.725" P2P LWR PKR MID- ELEMENT AT 7392', OAL 4' TTS P2P CPP3 5085 6/25/2024 1.625 7,447.5 5,882.6 30.34 PACKER - PATCH - UPR 2.725" P2P UPR PKR MID- ELEMENT AT 7450', W/ SPACER PIPE AND ANCHOR LATCH, OAL 25' TTS P2P CPP3 5225 / CPAL 35070 6/25/2024 1.625 7,451.2 5,885.8 30.33 SPACER PIPE 2-1/16" P-110 SPACER PIPE 6/25/2024 1.550 7,472.0 5,903.7 30.34 LEAK - TUBING TBG LEAK AT ~7472' IDENTIFIED BY RELAY HOLEFINDER 6/24/2024 2.992 7,472.6 5,904.2 30.34 PACKER - PATCH - LWR 2.725" P2P LWR PKR MID- ELEMENT AT 7475', OAL 4' TTS P2P CPP3 5115 6/24/2024 1.625 7,664.5 6,072.8 27.02 WHIPSTOCK LATERAL AL1 WHIPSTOCK 10/15/2009 7,685.0 6,091.0 26.76 WHIPSTOCK SIDETRACK 'A' WHIPSTOCK 10/4/2009 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,735.0 2,471.9 44.14 1 GAS LIFT GLV RK 1 1/2 1,316.0 4/16/2024 8:00 CAMCO MMG 0.188 4,444.2 3,698.4 46.93 2 GAS LIFT DMY RK 1 1/2 0.0 4/16/2024 8:00 CAMCO MMG 0.000 5,709.7 4,598.0 45.78 3 GAS LIFT GLV RK 1 1/2 1,332.0 4/15/2024 6:30 CAMCO MMG 0.250 6,789.1 5,362.3 44.45 4 GAS LIFT OV RK 1 1/2 0.0 4/15/2024 3:00 CAMCO MMG 0.218 7,453.3 5,887.6 30.33 5 GAS LIFT OPEN 0.0 6/24/2024 9:00 CAMCO MMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,674.5 6,081.7 26.92 BILLET 2.625 ALUMINUM BILLET, milled off down to 7673' MD 1.995 DEVIATED, 3H-33A, 7/23/2024 3:06:06 PM Vertical schematic (actual) LINER A; 7,674.5-9,944.0 SLOTS; 7,676.0-9,943.0 INTERMEDIATE; 39.2-8,020.0 WHIPSTOCK; 7,685.0 WINDOW A; 7,680.0-7,685.0 WHIPSTOCK; 7,664.5 WINDOW AL1; 7,660.0-7,665.0 LINER AL2-01; 7,583.1-9,275.0 SLOTS; 7,583.0-7,679.0 NIPPLE; 7,594.4 PACKER; 7,546.8 NIPPLE; 7,504.1 PACKER - PATCH - LWR; 7,472.6 LEAK - TUBING; 7,472.0 SPACER PIPE; 7,451.2 GAS LIFT; 7,453.3 PACKER - PATCH - UPR; 7,447.5 PACKER - PATCH - LWR; 7,389.6 LEAK - TUBING; 7,380.0 SPACER PIPE; 7,369.8 PACKER - PATCH - UPR; 7,366.2 GAS LIFT; 6,789.1 GAS LIFT; 5,709.7 GAS LIFT; 4,444.2 SURFACE; 41.5-4,315.1 GAS LIFT; 2,735.0 SAFETY VLV; 2,109.8 CONDUCTOR; 40.0-149.0 KUP PROD KB-Grd (ft) 43.05 RR Date 2/14/2009 Other Elev 3H-33A ... TD Act Btm (ftKB) 10,307.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032057801 Wellbore Status PROD Max Angle & MD Incl (°) 104.27 MD (ftKB) 10,260.17 WELLNAME WELLBORE3H-33A Annotation Last WO: End DateH2S (ppm) 170 Date 6/29/2018 Comment SSSV: Flapper Locked Out Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,676.0 9,943.0 6,083.0 6,144.9 UNIT B, A-6, A- 5, A-4, A-3, A-2, A-3, A-2, 3H- 33A 10/9/2009 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends DEVIATED, 3H-33A, 7/23/2024 3:06:07 PM Vertical schematic (actual) LINER A; 7,674.5-9,944.0 SLOTS; 7,676.0-9,943.0 INTERMEDIATE; 39.2-8,020.0 WHIPSTOCK; 7,685.0 WINDOW A; 7,680.0-7,685.0 WHIPSTOCK; 7,664.5 WINDOW AL1; 7,660.0-7,665.0 LINER AL2-01; 7,583.1-9,275.0 SLOTS; 7,583.0-7,679.0 NIPPLE; 7,594.4 PACKER; 7,546.8 NIPPLE; 7,504.1 PACKER - PATCH - LWR; 7,472.6 LEAK - TUBING; 7,472.0 SPACER PIPE; 7,451.2 GAS LIFT; 7,453.3 PACKER - PATCH - UPR; 7,447.5 PACKER - PATCH - LWR; 7,389.6 LEAK - TUBING; 7,380.0 SPACER PIPE; 7,369.8 PACKER - PATCH - UPR; 7,366.2 GAS LIFT; 6,789.1 GAS LIFT; 5,709.7 GAS LIFT; 4,444.2 SURFACE; 41.5-4,315.1 GAS LIFT; 2,735.0 SAFETY VLV; 2,109.8 CONDUCTOR; 40.0-149.0 KUP PROD 3H-33A ... WELLNAME WELLBORE3H-33A Originated: Delivered to:9-Jul-24 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 # E SET# 1 2C-12 50-029-21222-00 909383030 Kuparuk River Correlation Record Field- Final 1-Jul-24 0 1 2 2H-03 50-103-20031-00 n/a Kuparuk River Plug Setting Record Field- Final 13-May-24 0 1 3 2P-432 50-103-20420-00 909422477 Kuparuk River Plug Setting Record Field- Final 30-Jun-24 0 1 4 2W-01 50-029-21273-00 n/a Kuparuk River Patch Setting Record Field- Final 20-May-24 0 1 5 2X-05 50-029-20985-00 909358554 Kuparuk River Multi Finger Caliper Field & Processed 28-May-24 0 1 6 2X-05 50-029-20985-00 909358554 Kuparuk River Patch Setting Record Field- Final 29-May-24 0 1 7 2Z-06 50-029-20957-00 n/a Kuparuk River Plug Setting Record Field- Final 23-May-24 0 1 8 3B-16A 50-029-21289-01 909336135 Kuparuk River Perforation Record Field- Final 18-May-24 0 1 9 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 22-Jun-24 0 1 10 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 24-Jun-24 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: T39162 T39163 T39164 T39165 T39166 T39166 T39167 T39168 T39169 T39169 184-206 184-070 202-091 185-010 183-107 183-077 223-125 209-103 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:26:17 -08'00' 9 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 22-Jun-24 0 1 10 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 24-Jun-24 0 1 T39169 T39169 209-103 Originated: Delivered to:9-Jul-24 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 # E SET# 1 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 25-Jun-24 0 1 2 3J-14 50-029-21496-00 909382822 Kuparuk River Patch Setting Record Field- Final 29-Jun-24 0 1 3 3N-06 50-029-21538-00 n/a Kuparuk River Plug Setting Record Field- Final 1-May-24 0 1 4 3S-610 50-103-20875-00 909539033 Kuparuk River Plug Setting Record Field- Final 31-May-24 0 1 5 3S-626 50-103-20878-00 909417481 Kuparuk River Cement Evaluation with CASTField & Processed 19-Jun-24 0 1 6 3T-621 50-103-20882-00 909382821 Kuparuk River Correlation Record Field- Final 20-Jun-24 0 1 7 3T-621 50-103-20882-00 909394238 Kuparuk River Sigma and Gadolinium AnalysField & Processed 22-Jun-24 0 1 8 9 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: T39140 T39141 T39142 T39143 T39144 T39145 T39145 209-103 185-288 186-027 223-126 224-007 224-022 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 11:36:20 -08'00' 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 25-Jun-24 0 1 209-103 T39140 Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 3H Ͳ33 A 3H Ͳ33 A 209 -1 03 DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091030 Well Name /No. KUPARUK RIV UNIT 3H -33A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -01 -00 MD 10307 TVD 6092 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes_ DATA INFORMATION Types Electric or Other Logs Run: none (data taken from Logs Portion of Master Well Data Maint Ill Well Log Information: Logl Electr Data Digital Dataset Log Log Run Interval 011 / Typ Med /Frmt Number Name Scale Media No Start Stop CH Received Comments D C Lis 19144 Induction /Resistivity 7516 10307 Open 1/13/2010 MPR plus graphics in Tiff, i PDF, & meta formats vLOg Induction /Resistivity 5 Col 7685 10307 Open 1/13/2010 MD MPR, GR Log Induction /Resistivity 2 Col 7685 10307 Open 1/13/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7685 10307 Open 1/13/2010 TVD MPR, GR D C Asc Directional Survey 40 10307 Open t Directional Survey 40 10307 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments III ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Chips Received? •- 71T Formation Tops b N Analysis '1`TN Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/25/2011 Permit to Drill 2091030 Well Name /No. KUPARUK RIV UNIT 3H -33A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20578 -01 -00 MD 10307 TVD 6092 Completion Date 10/30/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: Date: z V • • V Company Conoco Phillips, Alaska, Inc. BAKER Well Name 3H-33A HUGHES Date 1/6/2010 MITE() Conoco Phillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from Conoco Phillips Image files and/or Digital Data contact: Lisa Wri , ht, 907 263-4823 hardcop prints ja Conoco Phillips Alaska, Inc. lip Sharon Al !sup-Drake ., ' * Drilling Tech, ATO-1530 .. . . _ .... Conoco Phillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 , ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 , Conoco Phillips Alaska, Inc. - - ' -.----- - 7- 77 , - , Ricky Elgarico 1 Graphic Image 1 Disk*/ File"*/**" Electronic i. 7-0Q-G Street, CGM/TIFF LIS - . , Anohorage,A14-9„(4541- ■ , ,. _ , , ftp://b2bftp.conocophillips.com **** AOGCC 1 Hardcopy Print, „ 1 ,, '7 Christine Mahnken 1 Graphic image file 1 Disk"/ -, 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS 1111 BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ : David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, • 71 Glenn Fredrick 1 Graphic image file 1 Disk"/ P.O.Box 196247 in lieu of s epi a ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT :.--1-=:513-,T:'-qac7`.11.Tral State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer / Rig Foreman TOTAL Hardcop Prints 4 Page 1 of 4 RECEIVED ID STATE OF ALASKA 1 NIJV 2 0 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOF 'fi k A O u c ' CQ S1° la. Well Status: Oil II Gas ❑ SPLUG Ell Plugged ❑ Abandoned El Suspended ❑ 1b. Well Class: AnC Qrago 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 30, 2009 209 - 103 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 5, 2009 50 103 - 20578 - 01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM October 11, 2009 3H - 33A Top of Productive Horizon: 8. KB (ft above MSL): 77 ' RKB 15. Field /Pool(s): 746' FNL, 659' FEL, Sec. 12, T12N, R8E, UM GL (ft above MSL): 36' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2259' FSL, 828' FEL, Sec.12, T12N, R8E, UM 10307' MD / 6092' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498655 y 6000588 Zone 4 10307' MD / 6092' TVD ADL 25531 TPI: x - 502994 y - 6000912 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 502827 y 5998637 Zone 4 2110' MD / 1998' TVD 2657 18. Directional Survey: Yes ID No 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1738' MD / 1680' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none 7685' MD / 6091' TVD 23. 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" 62.5# 11-40 36' 149' 36' 149' 30" 97 sx AS 1 9.625" 40# L -80 36' 4315' 36' 3614' 12.25" 640 sx AS Lite, 178 sx LiteCRETE 7" 26# L -80 36' 8020' 36' 6396' 8.75" 309 sx Class G 2.375" 4.7# L -80 7675' 9944' 6083' 6145' 3" slotted liner 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7606' 7547' MD / 5969' TVD 7676' -9944' MD 6083' -6145' TVD alternating solid / slotted liner 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 7, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 11/11/2009 24 hours Test Period - -> 1179 1631 499 176 Bean 1383 Flow Tubing Casing Pressure Calculated OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - API (corr) Press. 145 psi 1319 24 - Hour Rate - 1179 1631 499 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ...'t .: i j6� . o.. NONE Form 10 -407 Revised 7/2009 CONTINUED ON REVERSE niy C 111)3 (mit original only L 28. GEOLOGIC MARKERS (List all formations and markers ncountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1738' 1680' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk A3 7720' 6120' Top Kuparuk A2 7750' 6142' Top Kuparuk A2 10180' 6122' Top Kuparuk A3 10270' 6102' N/A Formation at total depth: Kuparuk A2 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey r 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Gary Eller @ 263 - 4172 Printed Na \ Von Ca Title: CT Drilling Manager Signature ■ Phone 265 - 6306 Date l r/ 2j) () 7 prepared by Sharon Allsup -Drake INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 7/2009 3H -33 Actual CTD Sidetrack Schematic Updated: 11/2/2009 3 -1/2" Camco TRMAXX -5E SSSV at 2110' MD (2.813" X- profile) 3-1/2", 9.3 #, L -80 EUE 8rd Tubing to surface , n, 16 ", 62#, H -40 conductor 3 -1/2" Camco MMG gas lift mandrels at 2735, 4444', 5710', 6789', & 7453' shoe 149' MD 9.5/8 ", 40#, L -80 casing shoe at 4315' MD „mil . 40 X- nipple at 7504' MD (2.813" min ID) Baker Premier packer at 7547' MD. No sealbore or seal assembly. 2 -3/8" liner top at 7583' MD * ** BELOW 2 -3/8" LINER TOP at 7583' MD *** I Camco D- nipple @ 7594 MD (2.75" min ID, No -Go) Nipple milled out to 2.80" ID 3 -1/2" tubing tail. at 7606' MD (7602' ELM) Top of cement at tubing tail at 7606 MD AL2-01 Lateral (7974' - 9275') KOP #2 at 7665 MD 2 -3/8" liner 7583 - 9275 MD KOP #1 at 7685' MD M l Blank liner 7679' -7762' i • Z�� ) Baker monobore whipstock trays on •-......2..„ o Whole anchors at 7665 & 7685' w�% AL2 Lateral (7803' - 9382'1 ----- \ 2 -318" slotted liner 7984 - 9382' MD T 2 0" pilot hole in cement drilled to \ 11) 'ijl l ih' / / Anchor - Billet at 7974' 7715' MD E� \ \ \ \ ALI -P61 (8810' •9607) AL1 Lateral (7665' - 10,100') 2 -3/8" Iiner7803'- 10,100' A -sand perfs (sqz'd) ..,w • N� Anchor - Billet at 8810' 7740' - 7760' MD —� .. \ \ ® �BL Blank liner 8851' 8977 & —.- w �,,, ^ vz �., -. 9040'- 9178' ��� _ _ = — Liner junction @ 8662' MD w �� Aluminum billet at 7803' 7 ", 26 #, L -80 casing — _ _ _ _ _ _ _ _ \ shoe at 8020' MD --- — — _ — — — — _ J t A Sidetrack (7685' - 10.307'1 2 -3/8" slotted liner 7673' -9944 7'4.i ' Unlined hole 9944'- 10,307' " , KUP 0 3H -33A ConocoPh flips Well Attributes Max Angle & MD TD AlFsSN° tS Wellbore API/UWI Field Name Well Status Inc! MD (ft0B) Act Btm (ftKB) C.anocept+tlkps 501032057801 I (3 KUPARUK RIVER UNIT PROD 104.27 10260.17 10,3070 C nt H2S (ppm) Date ;Annotation End Date KB -Grd (1t) Rig Release Date Well cPn @g DEVIATED 3H-33A, 112rzW94 s3 3.: PM Ann ot0 PP t RevReanom S , , Last WO: End SSSV Fla er Locked Out 0 1/1/2009 Sclier^atc AGUaI Annotation Depth (ftKB) End Date Annotat on Last Mod ... Entl Date Tag SIDETRACK w/4 laterals total _ Imosbor 11/2/2009 Casin. Strings HANGER, 37 - : ,,' I Casing Description String 0... string ID .. Top (ft013) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd }. ?: CONDUCTOR 16 15.062 40.0 149.0 149.0 62.58 H-40 WELD ��. .: Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND( . String WI... String ... String Top ThN 'fi SURFACE 9 5/8 8.835 41.5 4,315.1 4201 6 40.00 L - 80 BTC - m ; - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND(. String WI... String ... String Top Thrd WINDOW AL1 8 6.000 7,660.0 7,665.0 6.072 3 26.00 L -80 Casing Description String 0... String ID ... Top (ftlCB) Set Depth (f... Sat Depth (ND) .. String WI... String ... String Tap Thrd WINDOW A 8 6.000 7,680.0 7,685.0 6,091.0 26.00 1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String - -- String Top Thrd " INTERMEDIATE 7 6.276 39.2 8,020.0 6.1604 26.00 L - 80 Hyd 563 Casing Description '.String 0... String ID... Top (ftKB) Set Depth (1... Set Depth (ND).. String Wt... String... String Top Thrd CONDUCTOR, LINER A 2 3/8 1.995 7,674.5 9,944.0 6,144.6 4.60 L -80 STL 40-149 Liner Details - __ - -_ - -- Top Depth (ND( Top Inc' v Top (ftKB) (ftKB( ( °) Item Description Comment .. ID (in) 7,674. 6,081.4 23.49 Aluminum Billet Billet milled off down to 7673' MD 1.995 SSSV, 2,110--- Z. Tubing Strings - -- _ Tubing Description String 0 String ID .. ITOp (ftKB( ) I S et Depth ff..I Set Depth (ND) .. String W1... String _. String Top Thrd TUBING 3 112 132 369 7,606 3 6,012.4 9.30 I L-80 I EUE8rdMOD GAS LIFT, C Completion Details _. 2,735 Top Depth -. -.. (ND) Top Inc! Top (ftKB), (906/ (3 Item Description Comment ID (in) 36.9 36.9 -2358... HANGER GEN V TUBING HANGER 3.500 _._ � 2,109.8 2,109.8 -1711. SSSV CAMCO TRMAXX-5E SSSV w/2.812" X PROFILE (Flapper locked out 2.812 10/14/2009) l SURFACE, 7,504.1 5,933.8 -29 64 NIPPLE CAMCO 'X' NIPPLE 2.812 42.4,315 7,546.8 5,958.4 -16.33 PACKER BAKER PREMIER PRODUCTION PACKER 2.870 GAS LIFT, •• 7,594.4 6,000.5 148 NIPPLE CAMCO Tr NIPPLE w/2.75 " PROFILE - MILLED NIPPLE TO 2.80" ID 2.800 4,44 - 9/26/2009 7,605.8 6,011.8 2.05 WLEG WIRELINE ENTRY GUIDE 3.000 GAS LIFT, -- Other. In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 5,710 Top Depth 1111 (TVD) Top Inc/ Top (8508) (RKB) l Description Comment Run Data ID (In) GAS LIFT, 6789 7,665 6,071.8 20.37 WHIPSTOCK LATERAL AL1 WHIPSTOCK 10/15/2009 �` - -- - 7,685 6,091.0 26 76 WHIPSTOCK SIDETRACK 'A' WHIPSTOCK 10/4/2009 GAS LIFT. 7.453 ta.a - Perforations & Slots ShM Top (TVD) Btm (TVD) Dees - _ Top (ftKBZ Btrn (ftKB] Zone Dale (sh- Type Comment 10/9/2009 32.0 SLOTS ALL PERFS IN WELLBORE: NIPPLE, 7,504 7,676 9,943 6 082 8 6,144.6 Alternating solid /slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered PACKER, 7,547 1 18 deg, 3' non slotted ends Notes: General & Safety _ Ir -- End Date Annotation 2/17,2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1 11/2/2009 NOTE: WELL SIDETRACKED -A, AL1, AL2, AL2 -01 , NIPPLE, 7,594 ir WLEG, 7,606 - SLOTS, , F 7,583 -7,679 a gj WINDOW AL1, 7,660 - 7,665 - a WHIPSTOCK, :.� 7,665 1 W at WINDOW A, 768 - 7,685 WHIPSTOCK, 7,685 ,Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Si.. TRO Run Stn Top ((ftKB) KB) (908) ( °) Make Model ('n) Sery Type Type (in) (psi) Run Date Com... vTERMEDIATE, 39.6620 e ,,,-� _. „°: 1 2,735.0 2,735.0 - 15. CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9222009 SLOTS. am . ..... 7,761 - 9,270 2 4,444.2 4,444.2 - 98... CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/22/2009 SLOTS, 7676 - 9,943 1 - '-` 3 5,709.7 5,709.7 - 58... CAMCO MMG 1 12 GAS LIFT DMY RK 0 000 0.0 9/22/2009 LINER AL2 - 01, - 7,583 - 8,275 -..« 4 6,789.1 6,358.6 25... CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/23/2009 li y - -' 5 7,453.3 5,928 6 -45... CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/18/2009 ..:.�� +ears+ LINER A, 7,675 - 9,944 A TD (314330), 10,307 ._.- .....___.__. \pp ConocoPhillips Alaska • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33A 501032057801 Q cr QQ' CO Baker Hughes I NTEQ Definitive Survey Report BAKER NUGHEB 03 November, 2009 Ne' . ConocoPhillips Ees� ConocoPhillips Definitive Survey Report Alaska II MS 1 17 - 77777 ConocoPh�l Inc. Local Co- ordinate Reference ,1:' 3H -33 .'Proje r9 Kuparuk River Unit 11/D Referend'e: !.r 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) S ite Kuparuk 3H Pad MD (Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) lilfelt: 3H -33 North Reference: , "Viellbote 3H -33 Survey Calculation Method: Minimum Curvature design: 3H-33 Databa$e: _s EDM Alaska Prod v16 Map Map /erticat MD � Inc Azi ' 71/D TVDSS + N / - +E/ W DUS t `Seddon Sunray Taol N ame Ann a Northing Fasting (ft} :,(�} 'Cl t� }, (�) (� yt�) ftt � (*/ 1- „ ' e ft) 4 0.00 0.00 40.75 -36.10 0.00 0.00 6,000,588.21 498,655.30 0.00 0.00 UNDEFINED 100.50 0.57 321.50 100.50 23.65 0.23 -0.19 6,000,588.44 498,655.11 0.95 -0.27 GYD -CT -CMS (1) 200.80 0.27 96.68 200.80 123.95 0.60 -0.26 6,000,588.81 498,655.04 0.78 -0.49 GYD -CT -CMS (1) 300.00 4.10 89.70 299.91 223.06 0.59 3.52 6,000,588.80 498,658.81 3.86 2.94 GYD -CT -CMS (1) s 400.20 8.33 83.73 399.50 322.65 1.40 14.32 6,000,589.61 498,669.62 4.26 12.38 GYD -CT -CMS (1) r 499.60 9.32 82.44 497.72 420.87 3.24 29.46 6,000,591.45 498,684.75 1.02 25.31 GYD -CT -CMS (1) 600.60 10.75 78.66 597.17 520.32 6.17 46.80 6,000,594.37 498,702.09 1.56 39.78 GYD -CT -CMS (1) 700.30 12.39 72.34 694.85 618.00 11.25 66.11 6,000,599.44 498,721.40 2.08 55.13 GYD -CT -CMS (1) 800.80 12.28 73.50 793.03 716.18 17.55 86.63 6,000,605.75 498,741.92 0.27 71.05 GYD -CT -CMS (1) 900.30 11.35 69.39 890.42 813.57 24.00 105.94 6,000,612.19 498,761.23 1.26 85.81 GYD -CT -CMS (1) 1,000.20 11.36 69.33 988.36 911.51 30.94 124.35 6,000,619.12 498,779.64 0.02 99.54 GYD -CT -CMS (1) 1 1,100.00 14.40 64.36 1,085.64 1,008.79 39.78 144.74 6,000,627.96 498,800.03 3.24 114.27 GYD -CT -CMS (1) 1,125.00 15.49 63.54 1,109.80 1,032.95 42.61 150.53 6,000,630.79 498,805.82 4.44 118.32 GYD - CT-CMS (1) 1,150.00 16.27 63.01 1,133.84 1,056.99 45.69 156.64 6,000,633.87 498,811.93 3.17 122.55 GYD -CT -CMS (1) 1,175.00 17.09 63.24 1,157.79 1,080.94 48.93 163.04 6,000,637.11 498,818.33 3.29 126.97 GYD -CT -CMS (1) 1,200.00 18.44 63.86 1,181.60 1,104.75 52.33 169.87 6,000,640.50 498,825.16 5.45 131.72 GYD -CT -CMS (1) ill 1,225.00 19.72 64.63 1,205.23 1,128.38 55.88 177.23 6,000,644.05 498,832.52 5.22 136.89 GYD -CT -CMS (1) t 1,250.00 20.21 65.34 1,228.72 1,151.87 59.49 184.97 6,000,647.66 498,840.26 2.19 142.37 GYD -CT -CMS (1) 1,275.00 20.28 65.46 1,252.18 1,175.33 63.09 192.83 6,000,651.26 498,848.12 0.33 147.97 GYD -CT -CMS (1) 1,300.00 20.29 65.63 1,275.63 1,198.78 66.68 200.72 6,000,654.84 498,856.01 0.24 153.59 GYD -CT -CMS (1) 1,325.00 20.13 65.84 1,299.09 1,222.24 70.23 208.60 6,000,658.39 498,863.88 0.70 159.22 GYD -CT -CMS (1) 1,350.00 19.11 66.55 1,322.64 1,245.79 73.61 216.28 6,000,661.78 498,871.56 4.19 164.74 GYD -CT -CMS (1) 1,375.00 18.19 67.24 1,346.32 1,269.47 76.75 223.63 6,000,664.92 498,878.92 3.78 170.08 GYD -CT -CMS (1) 1,400.00 18.25 66.73 1,370.07 1,293.22 79.81 230.82 6,000,667.97 498,886.11 0.68 175.30 GYD -CT -CMS (1) 1,425.00 18.65 66.24 1,393.79 1,316.94 82.97 238.08 6,000,671.13 498,893.36 1.72 180.53 GYD -CT -CMS (1) 1,450.00 19.77 65.80 1,417.39 1,340.54 86.31 245.59 6,000,674.47 498,900.88 4.52 185.93 GYD -CT -CMS (1) 1,475.00 20.71 66.36 1,440.85 1,364.00 89.82 253.50 6,000,677.97 498,908.79 3.84 191.60 GYD -CT -CMS (1) 1,500.00 21.65 67.66 1,464.16 1,387.31 93.34 261.81 6,000,681.50 498,917.10 4.20 197.64 GYD -CT -CMS (1) 1,525.00 22.43 69.28 1,487.33 1,410.48 96.78 270.54 6,000,684.93 498,925.83 3.96 204.09 GYD -CT -CMS (1) 1,550.00 23.64 70.07 1,510.34 1,433.49 100.18 279.71 6,000,688.33 498,935.00 5.00 210.96 GYD -CT -CMS (1) 11/3/2009 11:30:26AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Fri CCOPfhul- Definitive Survey Report Alaska - a ny kE ConocoPhillips(Alaska) Ina L Co ordinate' n 3H - rii r a Kuparuk River Unit 1V Reference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site �'' Kuparuk 3H Pad MD Referen 3H -33 R @ 76.85ft (D15 (40.75 +36.1)) *ell: 3H - North Reference True " llVellbore 3H - 33 S urvey Calculation Method: " Minimum Curvature design. 3H -33 Databa§e EDM Alaska Prod v16 Su i ! Map Map Vertical MD Inc A Azr TVD ,TV DSS +NI-S 4Ef -W Worthing - fa sting DL5 S ection Survey Too Name Annotat ` �► ` t 1; t°) ', { °,I - r ' > (ft)"' fir' tft) t 1 ' (ft) F ( °r� 4.60 � y 1,575.00 24.76 70.71 1,5 1,456.29 103.62 289.37 6,000,691.76 498,944.65 4.60 218.25 GYD -C -CM (1) 1,600.00 25.68 71.20 1,555.76 1,478.91 107.09 299.44 6,000,695.24 498,954.72 3.77 225.90 GYD -CT -CMS (1) = 1,625.00 26.13 71.39 1,578.25 1,501.40 110.59 309.78 6,000,698.74 498,965.07 1.83 233.79 GYD -CT -CMS (1) 1,650.00 26.27 71.35 1,600.68 1,523.83 114.12 320.24 6,000,702.26 498,975.53 0.56 241.77 GYD -CT -CMS (1) 1,675.00 26.11 71.54 1,623.11 1,546.26 117.63 330.70 6,000,705.77 498,985.99 0.72 249.76 GYD -CT -CMS (1) 1,700.00 25.92 71.63 1,645.58 1,568.73 121.09 341.11 6,000,709.23 498,996.39 0.78 257.72 GYD -CT -CMS (1) 1,725.00 26.06 71.87 1,668.05 1,591.20 124.53 351.51 6,000,712.66 499,006.79 0.70 265.69 GYD -CT -CMS (1) 1,750.00 26.29 72.37 1,690.49 1,613.64 127.91 362.01 6,000,716.04 499,017.29 1.27 273.76 GYD -CT -CMS (1) 1,775.00 26.76 73.17 1,712.86 1,636.01 131.22 372.67 6,000,719.35 499,027.95 2.36 282.02 GYD -CT -CMS (1) 1,800.00 27.31 73.78 1,735.12 1,658.27 134.45 383.56 6,000,722.58 499,038.84 2.46 290.52 GYD -CT -CMS (1) 1,825.00 28.12 74.72 1,757.26 1,680.41 137.60 394.75 6,000,725.73 499,050.03 3.68 299.32 GYD -CT -CMS (1) 1,850.00 29.30 75.79 1,779.18 1,702.33 140.66 406.37 6,000,728.78 499,061.65 5.15 308.55 GYD -CT -CMS (1) 1,875.00 29.83 76.25 1,800.93 1,724.08 143.64 418.34 6,000,731.76 499,073.62 2.31 318.13 GYD -CT -CMS (1) 1,900.00 30.09 76.51 1,822.59 1,745.74 146.58 430.47 6,000,734.70 499,085.75 1.16 327.88 GYD -CT -CMS (1) 337.70 GYD -CT -CMS (1) 1,925.00 30.19 76.59 1,844.21 1,767.36 149.50 442.68 6,000,737.61 499,097.96 0.43 1,950.00 30.54 76.70 1,865.78 1,788.93 152.42 454.98 6,000,740.53 499,110.25 1.42 347.60 GYD -CT -CMS (1) 1,975.00 31.51 77.44 1,887.20 1,810.35 155.30 467.53 6,000,743.41 499,122.81 4.17 357.76 GYD -CT -CMS (1) 2,000.00 32.43 78.05 1,908.41 1,831.56 158.11 480.47 6,000,746.22 499,135.75 3.90 368.29 GYD -CT -CMS (1) 2,025.00 33.68 78.36 1,929.36 1,852.51 160.89 493.82 6,000,749.00 499,149.09 5.05 379.20 GYD -CT -CMS (1) 2,050.00 35.56 78.73 1,949.93 1,873.08 163.71 507.74 6,000,751.82 499,163.01 7.57 390.62 GYD -CT -CMS (1) 2,075.00 36.32 78.95 1,970.17 1,893.32 166.55 522.13 6,000,754.65 499,177.41 3.08 402.45 GYD -CT -CMS (1) 2,100.00 36.70 79.19 1,990.27 1,913.42 169.37 536.74 6,000,757.47 499,192.01 1.62 414.49 GYD -CT -CMS (1) 2,125.00 36.79 79.35 2,010.30 1,933.45 172.16 551.43 6,000,760.25 499,206.70 0.53 426.62 GYD -CT -CMS (1) 2,150.00 36.82 79.37 2,030.32 1,953.47 174.92 566.15 6,000,763.01 499,221.42 0.13 438.79 GYD -CT -CMS (1) 2,175.00 36.85 79.59 2,050.33 1,973.48 177.66 580.89 6,000,765.75 499,236.16 0.54 450.98 GYD -CT -CMS (1) ) 2,200.00 37.00 79.89 2,070.31 1,993.46 180.33 595.67 6,000,768.42 499,250.94 0.94 463.23 GYD -CT -CMS (1) 2,225.00 37.35 80.78 2,090.23 2,013.38 182.87 610.56 6,000,770.95 499,265.83 2.57 475.65 GYD -CT -CMS (1) 2,250.00 37.75 81.69 2,110.05 2,033.20 185.19 625.62 6,000,773.27 499,280.88 2.74 488.30 GYD -CT -CMS (1) 2,275.00 38.27 82.49 2,129.75 2,052.90 187.31 640.86 6,000,775.39 499,296.13 2.87 501.22 GYD -CT -CMS (1) 2,300.00 39.27 83.77 2,149.24 2,072.39 189.18 656.41 6,000,777.25 499,311.67 5.13 514.51 GYD -CT -CMS (1) 2,325.00 40.39 84.83 2,168.44 2,091.59 190.77 672.34 6,000,778.84 499,327.60 5.24 528.27 GYD-CT-CMS (1) 1 bb 11/3/2009 11:30:26AM Page 4 COMPASS 2003.16 Build 69 y ConocoPhillips Vail' Cmlocc)Filillips Definitive Survey Report BILICElt Alaska Company: " ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 3H -33 r Pr ` oj c t; , „ x'' Kuparuk River Unit T,VD Reference: :,, 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) I Site: Kuparuk 3H Pad MD Reference:4, '3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) !Mien: I 3H -33 North Reference: True aWelltbore ° 3H -33 , Survey Calculation Method: ,, Minimum Curvature Design 3H -33 Database EDM Alaska Prod v16 �tSUI'Vey �r � Map Map Vertical MD ,` ° -- Azi TVD TV DSS 4NT= +EIW ,,M= DLS Sectiot3" i ' : IP No ft) ' a tang Bowe fiool Name A nno t a ti on (�) � _) � r) ��� (ft) ` (ft) �. (ft) ({f) ";r. � (�) � /100) (ft) Y I. 2,350.00 41.51 85.85 2,187.32 2,110.47 192.10 688.67 6,000,780.17 499,343.93 5.22 542.50 GYD -CT -CMS (1) 2,375.00 42.06 86.42 2,205.96 2,129.11 193.22 705.29 6,000,781.28 499,360.55 2.67 557.08 GYD -CT -CMS (1) 2,400.00 42.20 86.63 2,224.51 2,147.66 194.24 722.03 6,000,782.30 499,377.29 0.79 571.81 GYD -CT -CMS (1) 2,425.00 41.87 86.82 2,243.07 2,166.22 195.19 738.74 6,000,783.25 499,394.00 1.41 586.55 GYD -CT -CMS (1) 2,450.00 41.45 86.96 2,261.75 2,184.90 196.09 755.33 6,000,784.15 499,410.59 1.72 601.20 GYD -CT -CMS (1) 2,475.00 41.20 87.05 2,280.53 2,203.68 196.96 771.82 6,000,785.01 499,427.07 1.03 615.77 GYD -CT -CMS (1) 2,500.00 41.07 87.30 2,299.35 2,222.50 197.77 788.25 6,000,785.82 499,443.50 0.84 630.30 GYD -CT -CMS (1) 1 1 2,525.00 41.19 87.40 2,318.18 2,241.33 198.53 804.67 6,000,786.57 499,459.92 0.55 644.86 GYD -CT -CMS (1) it 1 2,550.00 41.41 87.41 2,336.97 2,260.12 199.28 821.16 6,000,787.32 499,476.41 0.88 659.48 GYD-CT -CMS (1) 2,575.00 41.78 87.55 2,355.66 2,278.81 200.00 837.74 6,000,788.04 499,492.98 1.53 674.19 GYD -CT -CMS (1) 2,600.00 42.24 87.67 2,374.24 2,297.39 200.70 854.45 6,000,788.74 499,509.70 1.87 689.04 GYD -CT -CMS (1) 2,625.00 43.10 87.66 2,392.62 2,315.77 201.39 871.38 6,000,789.43 499,526.63 3.44 704.08 GYD -CT -CMS (1) 2,650.00 43.67 87.60 2,410.79 2,333.94 202.10 888.54 6,000,790.13 499,543.78 2.29 719.32 GYD -CT -CMS (1) 1 I. 2,675.00 43.96 87.60 2,428.83 2,351.98 202.83 905.83 6,000,790.86 499,561.08 1.16 734.68 GYD -CT -CMS (1) 2,700.00 44.09 87.59 2,446.80 2,369.95 203.56 923.19 6,000,791.58 499,578.43 0.52 750.10 GYD -CT -CMS (1) 2,725.00 44.14 87.59 2,464.75 2,387.90 204.29 940.58 6,000,792.31 499,595.82 0.20 765.54 GYD - CT-CMS (1) tio t 2,750.00 44.14 87.54 2,482.69 2,405.84 205.03 957.98 6,000,793.05 499,613.21 0.14 780.98 GYD -CT -CMS (1) 2,775.00 44.12 87.37 2,500.64 2,423.79 205.80 975.37 6,000,793.82 499,630.60 0.48 796.41 GYD -CT -CMS (1) 2,800.00 44.12 87.16 2,518.58 2,441.73 206.63 992.75 6,000,794.64 499,647.98 0.58 811.80 GYD -CT -CMS (1) I I. 44.18 86.86 2,536.52 2,459.67 207.54 1,010.14 6,000,795.55 499,665.37 0.87 827.17 GYD -CT -CMS (1) 2,850.00 44.22 86.54 2,554.45 2,477.60 208.54 1,027.54 6,000,796.55 499,682.77 0.91 842.51 GYD -CT -CMS (1) 2,875.00 43.95 85.82 2,572.40 2,495.55 209.70 1,044.89 6,000,797.70 499,700.12 2.28 857.74 GYD -CT -CMS (1) I 2,900.00 43.44 85.11 2,590.48 2,513.63 211.07 1,062.11 6,000,799.07 499,717.34 2.83 872.76 GYD -CT -CMS (1) s_ 2,925.00 43.15 84.80 2,608.68 2,531.83 212.57 1,079.19 6,000,800.57 499,734.41 1.44 887.59 GYD -CT -CMS (1) rE 2,950.00 42.77 84.72 2,626.97 2,550.12 214.13 1,096.15 6,000,802.12 499,751.38 1.54 902.30 GYD -CT -CMS (1) 2,975.00 42.67 84.66 2,645.34 2,568.49 215.70 1,113.04 6,000,803.69 499,768.26 0.43 916.93 GYD -CT -CMS (1) 3,000.00 42.69 84.64 2,663.72 2,586.87 217.28 1,129.91 6,000,805.27 499,785.14 0.10 931.55 GYD -CT -CMS (1) 3,025.00 42.77 84.67 2,682.08 2,605.23 218.86 1,146.80 6,000,806.84 499,802.02 0.33 946.18 GYD -CT -CMS (1) 3,050.00 42.55 84.90 2,700.47 2,623.62 220.40 1,163.68 6,000,808.38 499,818.89 1.08 960.81 GYD -CT -CMS (1) 3,075.00 42.28 85.22 2,718.92 2,642.07 221.85 1,180.48 6,000,809.83 499,835.69 1.38 975.42 GYD -CT -CMS (1) 3,100.00 42.27 85.36 2,737.42 2,660.57 223.23 1,197.24 6,000,811.21 499,852.45 0.38 990.01 GYD-CT-CMS (1) 11/3/2009 11:30:26AM Page 5 COMPASS 2003.16 Build 69 ." . • ConocoPhillips i Conoco 'h1111 Definitive Survey Report BAKE1t Alaska ifilitrPFILS Company :k . ConocoPhillip (laska) Inc. Local Co-ordinate reference; 3H-33 Project:' - Kuparuk River Unit T IJ Reference 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) bite= Kuparuk 3H Pad MD Reference: '` 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: = „ 3H -33 Nort*Referenee: t, True We) bore. 3H -33 Survey Calculation Method: * Minimum Curvature ceslgr 3H -33 Database: . EDM Alaska Prod v16 i ,, ry Map ': Map ` ` Verti M ' l , ,,� § i '( 1VDSS +NIS +e _Northing `Eastirig , DLS Sectidn Survey Tool Naive .Annotation ( ft ) ,. (°)ti, (°) , ( ft ) ' (ft)' „;_(ft) (ft) ( ft ) _-(ft) ( °I1ft0`) (ft) 3,125.00 42. 85.47 2,755.92 2,679.07 224.58 1,213.99 6,000,812.55 499,869.21 0.32 1,004.63 GYD -CT -CMS (1) 3,150.00 42.22 85.74 2,774.44 2,697.59 225.86 1,230.75 6,000,813.83 499,885.96 0.73 1,019.26 GYD -CT -CMS (1) 1 Y 3,175.00 42.33 85.92 2,792.93 2,716.08 227.09 1,247.52 6,000,815.05 499,902.73 0.65 1,033.93 GYD -CT -CMS (1) 3,200.00 42.48 85.96 2,811.39 2,734.54 228.28 1,264.34 6,000,816.24 499,919.55 0.61 1,048.66 GYD -CT -CMS (1) 3,225.00 42.61 86.03 2,829.81 2,752.96 229.46 1,281.20 6,000,817.42 499,936.41 0.55 1,063.44 GYD -CT -CMS (1) I 3,250.00 42.97 86.15 2,848.16 2,771.31 230.62 1,298.14 6,000,818.57 499,953.35 1.48 1,078.30 GYD -CT -CMS (1) 3,275.00 43.31 86.22 2,866.40 2,789.55 231.76 1,315.20 6,000,819.71 499,970.40 1.37 1,093.27 GYD-CT -CMS (1) I 3,300.00 43.49 86.22 2,884.57 2,807.72 232.89 1,332.34 6,000,820.84 499,987.54 0.72 1,108.31 GYD -CT -CMS (1) 3,325.00 43.41 86.37 2,902.71 2,825.86 234.00 1,349.50 6,000,821.95 500,004.70 0.52 1,123.38 GYD -CT -CMS (1) 3,350.00 43.06 86.66 2,920.93 2,844.08 235.04 1,366.59 6,000,822.98 500,021.79 1.61 1,138.43 GYD -CT -CMS (1) I 3,375.00 42.39 87.17 2,939.29 2,862.44 235.96 1,383.53 6,000,823.89 500,038.73 3.02 1,153.38 GYD -CT -CMS (1) 3,400.00 42.35 87.26 2,957.76 2,880.91 236.77 1,400.35 6,000,824.71 500,055.55 0.29 1,168.28 GYD -CT -CMS (1) 1 3,425.00 42.43 87.32 2,976.23 2,899.38 237.57 1,417.19 6,000,825.50 500,072.39 0.36 1,183.20 GYD -CT -CMS (1) 3,450.00 42.54 87.34 2,994.66 2,917.81 238.36 1,434.06 6,000,826.29 500,089.25 0.44 1,198.14 GYD -CT -CMS (1) 3,475.00 42.62 87.36 3,013.07 2,936.22 239.14 1,450.95 6,000,827.06 500,106.15 0.32 1,213.12 GYD -CT -CMS (1) 3,500.00 42.79 87.39 3,031.44 2,954.59 239.92 1,467.89 6,000,827.84 500,123.08 0.68 1,228.13 GYD -CT -CMS (1) a s k 1 3,525.00 43.13 87.44 3,049.74 2,972.89 240.68 1,484.91 6,000,828.60 500,140.10 1.37 1,243.22 GYD -CT -CMS (1) ler 3,550.00 43.51 87.52 3,067.93 2,991.08 241.44 1,502.05 6,000,829.35 500,157.23 1.54 1,258.43 GYD -CT -CMS (1) 1 3,575.00 43.76 87.47 3,086.02 3,009.17 242.19 1,519.28 6,000,830.11 500,174.47 1.01 1,273.72 GYD -CT -CMS (1) 3,600.00 43.83 87.56 3,104.07 3,027.22 242.94 1,536.57 6,000,830.85 500,191.75 0.37 1,289.06 GYD -CT -CMS (1) I 3,625.00 43.76 87.63 3,122.11 3,045.26 243.67 1,553.85 6,000,831.58 500,209.04 0.34 1,304.41 GYD -CT -CMS (1) i 3,650.00 43.49 87.77 3,140.21 3,063.36 244.36 1,571.09 6,000,832.26 500,226.27 1.15 1,319.73 GYD -CT -CMS (1) 3,675.00 43.47 87.92 3,158.35 3,081.50 245.01 1,588.28 6,000,832.91 500,243.46 0.42 1,335.03 GYD -CT -CMS (1) 3,700.00 43.61 87.91 3,176.47 3,099.62 245.63 1,605.49 6,000,833.53 500,260.67 0.56 1,350.36 GYD -CT -CMS (1) I 3,725.00 43.79 88.03 3,194.55 3,117.70 246.25 1,622.75 6,000,834.14 500,277.93 0.79 1,365.74 GYD -CT -CMS (1) I 3,750.00 44.09 88.02 3,212.55 3,135.70 246.84 1,640.09 6,000,834.73 500,295.26 1.20 1,381.19 GYD -CT -CMS (1) ( 3,775.00 44.54 88.03 3,230.44 3,153.59 247.45 1,657.54 6,000,835.33 500,312.72 1.80 1,396.74 GYD -CT -CMS (1) 3 44.76 88.06 3,248.22 3,171.37 248.04 1,675.10 6,000,835.93 500,330.27 0.88 1,412.40 GYD -CT -CMS (1) 3,825.00 45.01 88.01 3,265.93 3,189.08 248.65 1,692.73 6,000,836.53 500,347.90 1.01 1,428.11 GYD -CT -CMS (1) 0 3,850.00 45.22 88.11 3,283.58 3,206.73 249.25 1,710.44 6,000,837.13 500,365.60 0.89 1,443.90 GYD -CT -CMS (1) 3,875.00 45.36 88.12 3 3,224.31 249.83 1,728.19 6,000,837.71 500,383 36 0.56 1,459.73 459.73 GYD -CT CMS (1) 11/3/2009 11 :30 :26AM Page 6 COMPASS 2003.16 Build 69 fit,. ConocoPhillips C OPhIIIIPS Definitive Survey Report . BAILER ES Alaska IRON Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: • 3H 33 t 1 l' P ct , ' , � Kuparuk River Unit TVD teference: ,b 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) " Site': t, , Kuparuk 3H Pad MD Reference: = 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 3H -33 North Reference: „ True �Weiiboro;« 3 H -33 Survey Calculation. Method: Minimum Curvature i Design: 3H -33 Database: EDM Alaska Prod v16 ,w,:, Survey' ,�i � �,. r ' � M Map Ma Vertical '�' (ftD i `o, ' �i a rs 3eft) T VDSS ± NI-S +E Northing E a ( sft)n g 0 Section Surv CMS Name Annotrntron ; 3,900.00 45.23 88.33 ,318.75 3,241.90 250.38 1,745.95 6,000,838.26 500,401.12 0.79 1,475.59 GYD -CT -CMS (1) 3,925.00 44.46 88.55 3,336.48 3,259.63 250.86 1,763.58 6,000,838.73 500,418.74 3.14 1,491.35 GYD -CT -CMS (1) 3,950.00 44.23 88.68 3,354.35 3,277.50 251.29 1,781.04 6,000,839.15 500,436.21 0.99 1,507.00 GYD -CT -CMS (1) 3,975.00 44.44 88.71 3,372.24 3,295.39 251.68 1,798.51 6,000,839.55 500,453.67 0.84 1,522.65 GYD -CT -CMS (1) 4,000.00 44.84 88.66 3,390.02 3,313.17 252.09 1,816.07 6,000,839.95 500,471.23 1.61 1,538.39 GYD -CT -CMS (1) 4,025.00 45.28 88.52 3,407.68 3,330.83 252.52 1,833.76 6,000,840.38 500,488.92 1.80 1,554.23 GYD -CT -CMS (1) 4,050.00 45.62 88.46 3,425.22 3,348.37 252.99 1,851.57 6,000,840.85 500,506.73 1.37 1,570.17 GYD -CT -CMS (1) ) 4,075.00 45.80 88.46 3,442.68 3,365.83 253.47 1,869.46 6,000,841.32 500,524.62 0.72 1,586.17 GYD -CT -CMS (1) 4,100.00 45.85 88.56 3,460.10 3,383.25 253.94 1,887.39 6,000,841.79 500,542.54 0.35 1,602.21 GYD -CT -CMS (1) 4,125.00 45.85 88.96 3,477.51 3,400.66 254.33 1,905.32 6,000,842.17 500,560.47 1.15 1,618.29 GYD -CT -CMS (1) I I 4,150.00 45.91 89.29 3,494.92 3,418.07 254.60 1,923.27 6,000,842.44 500,578.41 0.98 1,634.43 GYD -CT -CMS (1) 4,175.00 45.98 89.37 3,512.30 3,435.45 254.81 1,941.23 6,000,842.65 500,596.38 0.36 1,650.62 GYD -CT -CMS (1) 1 4,200.00 45.84 89.59 3,529.70 3,452.85 254.98 1,959.19 6,000,842.81 500,614.33 0.84 1,666.81 GYD -CT -CMS (1) 4,225.00 45.67 89.82 3,547.14 3,470.29 255.07 1,977.10 6,000,842.90 500,632.24 0.95 1,683.00 GYD -CT -CMS (1) 4,250.00 45.78 89.86 3,564.59 3,487.74 255.12 1,995.00 6,000,842.94 500,650.14 0.45 1,699.19 GYD -CT -CMS (1) 4,275.00 45.96 89.97 3,582.00 3,505.15 255.14 2,012.94 6,000,842.97 500,668.08 0.79 1,715.43 GYD -CT -CMS (1) 4,300.00 46.22 90.05 3,599.34 3,522.49 255.14 2,030.95 6,000,842.96 500,686.09 1.07 1,731.75 GYD -CT -CMS (1) 4,325.00 46.37 90.19 3,616.61 3,539.76 255.10 2,049.02 6,000,842.92 500,704.16 0.72 1,748.14 GYD-CT-CMS (1) 4,350.00 46.51 90.28 3,633.84 3,556.99 255.03 2,067.14 6,000,842.84 500,722.27 0.62 1,764.58 GYD -CT -CMS (1) Ii 4,375.00 46.63 90.18 3,651.03 3,574.18 254.96 2,085.29 6,000,842.77 500,740.43 0.56 1,781.06 GYD CT CMS (1) 4,400.00 46.79 90.16 3,668.17 3,591.32 254.90 2,103.49 6,000,842.71 500,758.62 0.64 1,797.57 GYD -CT -CMS (1) 4,425.00 46.88 90.09 3,685.27 3,608.42 254.86 2,121.73 6,000,842.67 500,776.86 0.41 1,814.10 GYD -CT -CMS (1) i 4,450.00 46.94 90.02 3,702.35 3,625.50 254.84 2,139.98 6,000,842.64 500,795.11 0.32 1,830.65 GYD -CT -CMS (1) t 4,475.00 47.06 89.99 3,719.40 3,642.55 254.84 2,158.27 6,000,842.64 500,813.39 0.49 1,847.21 GYD -CT -CMS (1) 4,500.00 46.92 89.68 3,736.45 3,659.60 254.90 2,176.55 6,000,842.69 500,831.67 1.07 1,863.75 GYD -CT -CMS (1) 4,525.00 46.74 89.24 3,753.56 3,676.71 255.07 2,194.78 6,000,842.86 500,849.90 1.47 1,880.19 GYD -CT -CMS (1) 4,550.00 46.50 88.82 3,770.73 3,693.88 255.38 2,212.95 6,000,843.16 500,868.07 1.55 1,896.52 GYD -CT -CMS (1) 4,575.00 46.28 88.62 3,787.97 3,711.12 255.78 2,231.04 6,000,843.56 500,886.16 1.05 1,912.74 GYD -CT -CMS (1) 4,600.00 46.16 88.41 3,805.27 3,728.42 256.25 2,249.09 6,000,844.03 500,904.20 0.77 1,928.89 GYD -CT -CMS (1) 4,625.00 45.59 87.71 3,822.67 3,745.82 256.85 2,267.02 6,000,844.63 500,922.14 3.04 1,944.88 GYD -CT -CMS (1) 4,650.00 44.67 86.57 3,840.31 3,763.46 257.74 2,284.72 6,000,845.51 500,939.83 4.90_ 1,960.54 GYD -CT -CMS (1) 11/3/2009 11:30:26AM Page 7 COMPASS 2003.16 Build 69 Conoco Phillips „- Como:A:ill Hips Definitive Survey Report BAKER Alaska MINES om pa n y. ^ . C ,7' h .- :41' .1. (Alaska) Inc. Local Co- ordinate Reference: 3H -33 = Project: Kuparuk River Unit TVD Reference€ 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) E Site: r ' Kuparuk 3H Pad "MD°Referencee_ 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) rir Well: 3H -33 North Reference: x ai,. rw True Iftrailbo 3H -33 *Survey Calculation Method: Minimum Curvature EDM Alaska Prod v16 best 3H -33 � yy Da ase � t. Survey l r � t, ° r ` MI a (ft) ,Nib n) } _ Inc i „ TVD ' TVDSS +N1-S +E1V11 Northing'' Ehsting ' ,Section Survey, Tool Name Annotation ' (ft) s (R) t. , 4 A � � : (R) o ( " J1°°) (ft) 4,675.00 44.48 86.13 3,858.12 3,781.27 258.85 2,302.23 6,000,846.62 500,957.34 1.45 1,975.93 GYD -CT -CMS (1) 4,700.00 44.38 85.99 3,875.97 3,799.12 260.06 2,319.69 6,000,847.82 500,974.80 0.56 1,991.23 GYD -CT -CMS (1) ( 4,725.00 44.33 86.10 3,893.85 3,817.00 261.26 2,337.12 6,000,849.03 500,992.23 0.37 2,006.52 GYD -CT -CMS (1) 4,750.00 44.28 86.08 3,911.74 3,834.89 262.45 2,354.54 6,000,850.21 501,009.65 0.21 2,021.79 GYD -CT -CMS (1) 4,775.00 44.31 86.10 3,929.63 3,852.78 263.64 2,371.96 6,000,851.40 501,027.07 0.13 2,037.07 GYD -CT -CMS (1) 4,800.00 44.47 86.17 3,947.50 3,870.65 264.82 2,389.41 6,000,852.58 501,044.52 0.67 2,052.38 GYD -CT -CMS (1) 4,825.00 44.57 86.16 3,965.32 3,888.47 265.99 2,406.90 6,000,853.74 501,062.00 0.40 2,067.72 GYD -CT -CMS (1) 4,850.00 44.63 86.11 3,983.12 3,906.27 267.18 2,424.42 6,000,854.92 501,079.52 0.28 2,083.09 GYD -CT -CMS (1) 4,875.00 44.72 86.03 4,000.90 3,924.05 268.38 2,441.95 6,000,856.13 501,097.05 0.42 2,098.46 GYD-CT -CMS (1) 4,900.00 44.44 85.96 4,018.71 3,941.86 269.61 2,459.46 6,000,857.35 501,114.55 1.14 2,113.80 GYD -CT -CMS (1) 4,925.00 44.02 85.83 4,036.62 3,959.77 270.86 2,476.85 6,000,858.59 501,131.95 1.72 2,129.03 GYD -CT -CMS (1) II 4,950.00 43.73 85.82 4,054.64 3,977.79 272.12 2,494.13 6,000,859.85 501,149.23 1.16 2,144.15 GYD -CT -CMS (1) a 1 ' 4,975.00 43.67 85.90 4,072.72 3,995.87 273.36 2,511.36 6,000,861.10 501,166.45 0.33 2,159.23 GYD -CT -CMS (1) 5,000.00 43.62 86.16 4,090.81 4,013.96 274.56 2,528.57 6,000,862.29 501,183.66 0.75 2,174.32 GYD -CT -CMS (1) 5,025.00 43.51 87.42 4,108.92 4,032.07 275.52 2,545.77 6,000,863.25 501,200.86 3.50 2,189.49 GYD -CT -CMS (1) 5,050.00 43.47 87.97 4,127.06 4,050.21 276.22 2,562.96 6,000,863.94 501,218.05 1.52 2,204.77 GYD -CT -CMS (1) 1 S I 5,075.00 43.35 88.26 4,145.22 4,068.37 276.78 2,580.14 6,000,864.50 501,235.22 0.93 2,220.09 GYD -CT -CMS (1) 5,100.00 43.12 88.27 4,163.44 4,086.59 277.30 2,597.25 6,000,865.01 501,252.34 0.92 2,235.37 GYD -CT -CMS (1) 5,125.00 43.05 88.34 4,181.69 4,104.84 277.80 2,614.32 6,000,865.52 501,269.41 0.34 2,250.62 GYD -CT -CMS (1) 5,150.00 42.96 88.35 4,199.98 4,123.13 278.30 2,631.37 6,000,866.01 501,286.45 0.36 2,265.85 GYD -CT -CMS (1) 5,175.00 43.12 88.50 4,218.25 4,141.40 278.77 2,648.42 6,000,866.47 501,303.50 0.76 2,281.11 GYD -CT -CMS (1) I 5,200.00 43.39 88.64 4,236.46 4,159.61 279.19 2,665.55 6,000,866.90 501,320.63 1.15 2,296.44 GYD -CT -CMS (1) I 5,225.00 43.94 88.92 4,254.54 4,177.69 279.56 2,682.81 6,000,867.26 501,337.88 2.33 2,311.92 GYD -CT -CMS (1) 5,250.00 44.21 89.15 4,272.50 4,195.65 279.85 2,700.19 6,000,867.55 501,355.27 1.26 2,327.54 GYD -CT -CMS (1) I 5,275.00 44.49 89.50 4,290.38 4,213.53 280.06 2,717.67 6,000,867.75 501,372.74 1.49 2,343.29 GYD -CT -CMS (1) i 5,300.00 44.82 89.57 4,308.16 4,231.31 280.20 2,735.24 6,000,867.89 501,390.31 1.33 2,359.14 GYD -CT -CMS (1) i 5,325.00 44.94 89.67 4,325.88 4,249.03 280.32 2,752.88 6,000,868.01 501,407.95 0.56 2,375.07 GYD -CT -CMS (1) I. 5,350.00 44.92 89.84 4,343.58 4,266.73 280.39 2,770.53 6,000,868.08 501,425.60 0.49 2,391.03 GYD -CT -CMS (1) I 5,375.00 44.82 89.79 4,361.29 4,284.44 280.45 2,788.17 6,000,868.13 501,443.24 0.42 2,406.99 GYD -CT -CMS (1) 1 1 5,400.00 44.68 89.90 4,379.05 4,302.20 280.50 2,805.77 6,000,868.18 501,460.84 0.64 2,422.91 GYD -CT -CMS (1) I 5,425.00 44.64 89.89 4,396.83 4,319.98 280.53 2,823.34 6,000,868.21 501,478 41 0.16 2,438.82 GYD CT -CMS (1) _..,,,,, - ,,,, , - -- ...-. -„ „.. -> _ „. 11/32009 11:30:26AM Page 8 COMPASS 2003.16 Build 69 N .' ConocoPhillips SNEER ConocoPhil i Definitive Survey Report Alaska inGIUS Company, �' ConocoPhillips( Inc. Lo =Co - ordinate Reference 3H 33 Project Kuparuk River Unit lvD Reference , -i t' 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) f -Sitr� ` , Kuparuk 3H Pad MD Reference: F ,4 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well -1 , 3H -33 f North Reference:; r ;,True illi We ��' r 3H Surrey Calculation M ethod ,,Minimum Curvature Deli` "n: 3H -33 Database: EDM Alaska Prod v16 Survey` ., i 3i i M p Map vertical , 1 33 MD lnc, %1zr WD ' D ° 1VDSS +N1 W ' Northing Fasting +Et - D LS • Section ; Survey Tool Name Anriotation _ : -, {{) ( °) ( (ft) , ,. (ft) (ft)4 _ (f " (ft) (ft) /1ti0) ,. (ft) 5,450.00 44.62 89.96 4,414.62 4,337.77 280.55 2,840.91 6,000,868.23 501,495.97 0.21 2,454. 2 YD -CT -CMS (1) 5,475.00 44.59 90.02 4,432.42 4,355.57 280.56 2,858.46 6,000,868.23 501,513.52 0.21 2,470.62 GYD -CT -CMS (1) 5,500.00 44.79 90.08 4,450.19 4,373.34 280.54 2,876.04 6,000,868.21 501,531.10 0.82 2,486.55 GYD -CT -CMS (1) 5,525.00 45.06 90.26 4,467.90 4,391.05 280.49 2,893.70 6,000,868.15 501,548.76 1.19 2,502.57 GYD -CT -CMS (1) 5,550.00 45.11 90.51 4,485.55 4,408.70 280.37 2,911.40 6,000,868.03 501,566.46 0.74 2,518.66 GYD -CT -CMS (1) 5,575.00 45.04 90.57 4,503.20 4,426.35 280.20 2,929.10 6,000,867.86 501,584.16 0.33 2,534.76 GYD -CT -CMS (1) 5,600.00 44.88 90.65 4,520.89 . 4,444.04 280.02 2,946.77 6,000,867.67 501,601.82 0.68 2,550.84 GYD -CT -CMS (1) 5,625.00 44.99 90.34 4,538.59 4,461.74 279.86 2,964.42 6,000,867.51 501,619.47 0.98 2,566.90 GYD -CT -CMS (1) I 5,650.00 45.25 89.26 4,556.23 4,479.38 279.93 2,982.14 6,000,867.57 501,637.19 3.23 2,582.92 GYD -CT -CMS (1) 5,675.00 45.58 88.01 4,573.78 4,496.93 280.35 2,999.94 6,000,867.99 501,654.98 3.80 2,598.87 GYD -CT -CMS (1) 5,700.00 45.81 87.40 4,591.24 4,514.39 281.07 3,017.81 6,000,868.71 501,672.86 1.97 2,614.76 GYD -CT -CMS (1) 5,725.00 45.72 87.14 4,608.68 4,531.83 281.92 3,035.71 6,000,869.56 501,690.75 0.83 2,630.60 GYD -CT -CMS (1) 5,750.00 45.54 87.14 4,626.16 4,549.31 282.81 3,053.55 6,000,870.44 501,708.60 0.72 2,646.39 GYD -CT -CMS (1) 1 5,775.00 45.36 87.12 4,643.70 4,566.85 283.70 3,071.35 6,000,871.33 501,726.39 0.72 2,662.14 GYD -CT -CMS (1) 5,800.00 45.48 87.17 4,661.25 4,584.40 284.59 3,089.13 6,000,872.22 501,744.17 0.50 2,677.87 GYD -CT -CMS (1) 5,825.00 45.48 87.18 4,678.78 4,601.93 285.47 3,106.94 6,000,873.09 501,761.97 0.03 2,693.63 GYD -CT -CMS (1) ' 5,850.00 45.45 87.25 4,696.31 4,619.46 286.33 3,124.74 6,000,873.95 501,779.77 0.23 2,709.38 GYD -CT -CMS (1) • 5 45.22 87.16 4,713.89 4,637.04 287.20 3,142.49 6,000,874.82 501,797.53 0.95 2,725.11 GYD -CT -CMS (1) 5,900.00 45.13 87.19 4,731.51 4,654.66 288.08 3,160.20 6,000,875.69 501,815.24 0.37 2,740.78 GYD -CT -CMS (1) 5,925.00 44.99 87.15 4,749.17 4,672.32 288.95 3,177.88 6,000,876.56 501,832.91 0.57 2,756.42 GYD -CT -CMS (1) I I 5,950.00 45.01 87.18 4,766.85 4,690.00 289.82 3,195.54 6,000,877.43 501,850.56 0.12 2,772.04 GYD -CT -CMS (1) 5,975.00 44.98 87.12 4,784.53 4,707.68 290.70 3,213.19 6,000,878.31 501,868.22 0.21 2,787.66 GYD -CT -CMS (1) 6,000.00 44.95 86.97 4,802.21 4,725.36 291.61 3,230.83 6,000,879.21 501,885.86 0.44 2,803.26 GYD -CT -CMS (1) 6,025.00 44.95 86.95 4,819.91 4,743.06 292.55 3,248.47 6,000,880.15 501,903.49 0.06 2,818.84 GYD -CT -CMS (1) 1 6,050.00 44.92 86.99 4,837.61 4,760.76 293.48 3,266.10 6,000,881.08 501,921.13 0.16 2,834.42 GYD -CT -CMS (1) 6,075.00 44.92 86.94 4,855.31 4,778.46 294.42 3,283.73 6,000,882.01 501,938.75 0.14 2,849.99 GYD -CT -CMS (1) - 6,100.00 44.97 86.95 4,873.00 4,796.15 295.36 3,301.37 6,000,882.95 501,956.39 0.20 2,865.57 GYD -CT -CMS (1) 6,125.00 44.98 86.95 4,890.69 4,813.84 296.30 3,319.01 6,000,883.88 501,974.03 0.04 2,881.16 GYD -CT -CMS (1) 6,150.00 45.02 87.28 4,908.37 4,831.52 297.19 3,336.67 6,000,884.77 501,991.68 0.95 2,896.77 GYD -CT -CMS (1) 6,175.00 44.90 87.87 4,926.06 4,849.21 297.94 3,354.32 6,000,885.51 502,009.33 1.74 2,912.45 GYD -CT -CMS (1) 6,200.00 44.86 88.05 4,943.77 4,866.92 298.56 3,371.95 6,000,886.14 502,026.96 _0.53 2 GYD -CT -CMS (1) 11/3/2009 11:30:26AM Page 9 COMPASS 2003.16 Build 69 IV ConocoPhillips tll ConocoKiiiiips Definitive Survey Report BAKER Alaska. FROGIOS Company: I ConocoPhillips(Alaska) Inc. , Local Co- ordinate Reference. 3H -33 Project: , ! Kuparuk River Unit 1VD Reference: "' ; 43H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) � P -Sits ' " 4P Kuparuk 3H Pad , MD Reference :` 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well: 1 3H -33 North Reference: True l Weitbore:' ' 3H -33 Survey Calculation Method: Minimum Curvature i luesign: ��` -4, 31-1-33 Database EDM Alaska Prod v16 mm �..��..- am ? _ - Map- Map Vertical MD Inc ; Azi TVD TVDSS 44Nl S , +Et W , Northing Seating D1O( Se ction iftl , O c f) S a `Survey Annotation Taro) Name ° ' ° � � � � (ft) � {�) : � (ft) t (ft) t �� oo) (ft) 6,225.00 44.69 88.17 4,961.52 4,884.67 299.15 3,389.54 6,000,886.72 502,044.56 0.76 2,943.85 GYD -CT -CMS (1) 6,250.00 44.76 88.11 4,979.28 4,902.43 299.72 3,407.13 6,000,887.28 502,062.14 0.33 2,959.53 GYD -CT -CMS (1) 6,275.00 44.77 87.95 4,997.03 4,920.18 300.32 3,424.72 6,000,887.89 502,079.73 0.45 2,975.21 GYD -CT -CMS (1) 6,300.00 44.76 87.80 5,014.78 4,937.93 300.97 3,442.32 6,000,888.54 502,097.32 0.42 2,990.88 GYD -CT -CMS (1) 6,325.00 44.79 87.65 5,032.53 4,955.68 301.67 3,459.91 6,000,889.23 502,114.91 0.44 3,006.52 GYD -CT -CMS (1) 6,350.00 44.81 87.55 5,050.27 4,973.42 302.41 3,477.51 6,000,889.97 502,132.51 0.29 3,022.15 GYD -CT -CMS (1) 6,375.00 44.73 87.35 5,068.01 4,991.16 303.19 3,495.10 6,000,890.75 502,150.10 0.65 3,037.75 GYD -CT -CMS (1) E 6,400.00 44.61 87.26 5,085.79 5,008.94 304.02 3,512.66 6,000,891.57 502,167.65 0.54 3,053.31 GYD -CT -CMS (1) 6,425.00 44.66 87.09 5,103.58 5,026.73 304.89 3,530.20 6,000,892.43 502,185.20 0.52 3,068.83 GYD -CT -CMS (1) 6,450.00 44.57 86.89 5,121.38 5,044.53 305.81 3,547.73 6,000,893.35 502,202.73 0.67 3,084.32 GYD -CT -CMS (1) 6,475.00 44.49 86.81 5,139.20 5,062.35 306.77 3,565.24 6,000,894.31 502,220.23 0.39 3,099.77 GYD -CT -CMS (1) 6,500.00 44.45 86.89 5,157.04 5,080.19 307.73 3,582.73 6,000,895.27 502,237.72 0.28 3,115.21 GYD -CT -CMS (1) 6,525.00 44.68 87.20 5,174.85 5,098.00 308.64 3,600.24 6,000,896.17 502,255.24 1.27 3,130.70 GYD -CT -CMS (1) 6,550.00 44.85 87.65 5,192.60 5,115.75 309.43 3,617.83 6,000,896.96 502,272.82 1.44 3,146.29 GYD -CT -CMS (1) 6,575.00 44.97 87.90 5,210.31 5,133.46 310.11 3,635.47 6,000,897.64 502,290.46 0.85 3,161.98 GYD -CT -CMS (1) 6,600.00 45.03 87.96 5,227.99 5,151.14 310.75 3,653.13 6,000,898.27 502,308.12 0.29 3,177.71 GYD -CT -CMS (1) • 6,625.00 44.92 87.93 5,245.67 5,168.82 311.39 3,670.79 6,000,898.91 502,325.78 0.45 3,193.44 GYD -CT -CMS (1) 6,650.00 44.85 87.90 5,263.38 5,186.53 312.03 3,688.42 6,000,899.54 502,343.41 0.29 3,209.14 GYD -CT -CMS (1) 6,675.00 44.77 87.85 5,281.12 5,204.27 312.68 3,706.03 6,000,900.19 502,361.01 0.35 3,224.81 GYD -CT -CMS (1) 6,700.00 44.74 87.86 5,298.87 5,222.02 313.34 3,723.62 6,000,900.85 502,378.60 0.12 3,240.47 GYD -CT -CMS (1) 6,725.00 44.65 87.76 5,316.65 5,239.80 314.01 3,741.19 6,000,901.52 502,396.17 0.46 3,256.10 GYD -CT -CMS (1) 6,750.00 44.62 87.65 5,334.44 5,257.59 314.72 3,758.74 6,000,902.22 502,413.72 0.33 3,271.70 GYD -CT -CMS (1) 6,775.00 44.55 87.54 5,352.24 5,275.39 315.45 3,776.27 6,000,902.95 502,431.25 0.42 3,287.27 GYD -CT -CMS (1) 6,800.00 44.37 87.47 5,370.08 5,293.23 316.21 3,793.77 6,000,903.71 502,448.74 0.75 3,302.80 GYD -CT -CMS (1) 6,825.00 43.94 87.50 5,388.02 5,311.17 316.98 3,811.17 6,000,904.47 502,466.14 1.72 3,318.23 GYD -CT -CMS (1) 6,850.00 43.21 87.37 5,406.13 5,329.28 317.75 3,828.38 6,000,905.24 502,483.35 2.94 3,333.50 GYD -CT -CMS (1) 6,875.00 42.91 87.25 5,424.40 5,347.55 318.55 3,845.43 6,000,906.04 502,500.40 1.24 3,348.61 GYD -CT -CMS (1) -i-l'c'll'1..il 6,900.00 42.76 87.16 5,442.73 5,365.88 319.38 3,862.41 6,000,906.86 502,517.38 0.65 3,363.64 GYD -CT -CMS (1) 6,925.00 42.40 87.19 5,461.14 5,384.29 320.21 3,879.30 6,000,907.69 502,534.27 1.44 3,378.59 GYD -CT -CMS (1) 6,950.00 41.75 87.04 5,479.70 5,402.85 321.06 3,896.04 6,000,908.53 502,551.00 2.63 3,393.39 GYD -CT -CMS (1) 6,975.00 41.57 86.90 5,498.37 5,421.52 321.93 3,912.63 6,000 909.41 502,567.59 0.81 3,408.05 GYD -CT CMS (1) 11/3/2009 11:30:26AM � Page 10 COMPASS 2003.16 Build 69 y ConocoPhillips frfli ConocoPtiillips Definitive Survey Report 4 , Alaska c , r orrrpeny: ConocoPhillips(Alaska) Inc.' ' ,t ocal,Co- ordinate Reference: 3H -33 i Projedt: p t „ Kuparuk River Unit TVD Reference:' 2 ,`` 4., 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) = Site Kuparuk 3H Pad MD' Referen , ! � 3H -33 Rig 76.85ft (D15 40.75 +36.1 Weil 3H - 33 North Reference: True Wellbote: 3H -33 Surve Calculati Method:_ J M Curvature Desrgn A ' , 3H -33 DatabaseAla v16 EDM Alaska Prod v1 , Survey oS R , . +. j: i`P 1 , xq} ,,t' t � .� 4,a t `" - 0 , - 0 , - , Map' Map 1 ``' MD i n c a ~ �. .� � p b�rtrcal Azr TVD ., `NOBS 4/4 E/ W ( ) "° ( °) °) (ft) (ft) (ft tft) Northing ; ' Fasting a� �, Section Survey Toot Name Annotation i� � r�� . � ) � � t it) e ; 7,000.00 41.40 87.33 5,517.10 5,440.25 322.77 3,929,17 6,000,910.24 502,584.13 1.33 3,422.68 GYD -CT -CMS (1 7,025.00 40.85 87.97 5,535.93 5,459.08 323.44 3,945.60 6,000,910.91 502,600.56 2.77 3,437.28 GYD -CT -CMS (1) 7,050.00 40.14 88.81 5,554.95 5,478.10 323.90 3,961,83 6,000,911.37 502,616.78 3.58 3,451.78 GYD -CT -CMS (1) 7,075.00 39.76 89.12 5,574.11 5,497.26 324.19 3,977,88 6,000,911.65 502,632.83 1.72 3,466.20 GYD -CT -CMS (1) 7,100.00 39.51 89,01 5,593.36 5,516.51 324.45 3,993,82 6,000,911.91 502,648.78 1.04 3,480.53 GYD -CT -CMS (1) 7,125.00 38.70 88.94 5,612.76 5,535.91 324.73 4,009.59 6,000,912.19 502,664.54 3.24 3,494.70 GYD -CT -CMS (1) e 7,150.00 37.31 89.37 5,632.46 5,555.61 324.96 4,024.98 6,000,912.41 502,679.93 5.66 3,508.54 GYD -CT -CMS (1) 7,175.00 36.00 90.11 5,652.52 5,575.67 325.03 4,039.90 6,000,912.48 502,694.85 5.53 3,522.03 GYD -CT -CMS (1) 7,200.00 34.82 90.51 5,672.89 5,596.04 324.95 4,054.39 6,000,912.40 502,709.34 4.81 3,535.19 GYD -CT -CMS (1) 7,225.00 34.06 90.89 5,693.51 5,616.66 324.78 4,068.52 6,000,912.23 502,723.47 3.16 3,548.07 GYD -CT -CMS (1) 7,250.00 33.66 90.85 5,714.27 5,637.42 324.57 4,082.45 6,000,912.01 502,737.40 1.60 3,560.77 GYD -CT -CMS (1) 7,275.00 33.22 90.59 5,735.13 5,658.28 324.39 4,096.23 6,000,911.84 502,751.17 1.85 3,573.33 GYD -CT -CMS (1) 7,300.00 32.23 89.94 5,756.16 5,679.31 324.33 4,109.74 6,000,911.77 502,764.69 4.20 3,585.60 GYD -CT -CMS (1) 7,325.00 31.60 89.47 5,777.38 5,700.53 324.40 4,122.96 6,000,911.83 502,777.90 2.71 3,597.54 GYD -CT -CMS (1) 7,350.00 31.14 89.41 5,798.73 5,721.88 324.53 4,135.97 6,000,911.96 502,790.91 1.84 3,609.27 GYD -CT -CMS (1) 7,375.00 30.86 89.51 5,820.16 5,743.31 324.65 4,148.85 6,000,912.08 502,803.79 1.14 3,620.89 GYD-CT -CMS (1) • 7,400.00 30.61 89.54 5,841.65 5,764.80 324.75 4,161.62 6,000,912.18 502,816,56 1.00 3,632.42 GYD -CT -CMS (1) 7,425.00 30.46 89.55 5,863.18 5,786.33 324.85 4,174.32 6,000,912.28 502,829,26 0.60 3,643.88 GYD -CT -CMS (1) 7,450.00 30.33 89.72 5,884.74 5,807.89 324.93 4,186.97 6,000,912.36 502,841.91 0.62 3,655.30 GYD -CT -CMS (1) 7,475.00 30.34 89.72 5,906.32 5,829.47 325.00 4,199.60 6,000,912.42 502,854.53 0.04 3,666.72 GYD -CT -CMS (1) 7,500.00 30.00 89.83 5,927.94 5,851.09 325.05 4,212.16 6,000,912.47 502,867.10 1.38 3,678.08 GYD -CT -CMS (1) 7,525.00 29.49 89.92 5,949.64 5,872.79 325.07 4,224.57 6,000,912.49 502,879.50 2.05 3,689.30 GYD -CT -CMS (1) 7,550.00 28.92 90.22 5,971.46 5,894.61 325.06 4,236.77 6,000,912.47 502,891.70 2.35 3,700.36 GYD -CT -CMS (1) 7,575.00 28.25 90.40 5,993.42 5,916.57 324.99 4,248.73 6,000,912.41 502,903.66 2.70 3,711.22 GYD -CT -CMS (1) 7,600.00 27.78 90.57 6,015.49 5,938.64 324.89 4,260.47 6,000,912.31 502,915.40 1.91 3,721.90 GYD -CT -CMS (1) 7,625.00 27.48 90.87 6,037.64 5,960.79 324.75 4,272.06 6,000,912.16 502,926.99 1.32 3,732.46 GYD -CT -CMS (1) 7,650.00 27.18 91.11 6,059.84 5,982.99 324.55 4,283.54 6,000,911.96 502,938.46 1.28 3,742.94 GYD -CT -CMS (1) 7,675.00 26.91 91.46 6,082.11 6,005.26 324.30 4,294.90 6,000,911.70 502,949.83 1.25 3,753.35 GYD -CT -CMS (1) TIP 3H -33 7,685.00 26.76 91.42 6,091.03 6,014.18 324.18 4,299.42 6,000,911.59 502,954.34 1.51 3,757.48 MWD (2) KOP 7,716.17 36.48 88.93 6,117.55 6 040 70 324.18 4,315.73 6,000,911 58 502,970.66 31.46 3,772.27 MWD (2) Interpolated AZI 7,747.50 49.78 87.50 6,140.36 6,063 51 324.88 4,337.09 6,000,912 28 502,992.01 42 56 3 7 91.32 MWD (2) Interpolated AZI 11/3/2009 11:30.:26AM Page 11 COMPASS 2003.16 Build 69 IF" Conoco Phillips vain COflOCOP UIIIpS Definitive Survey Report BiLIIIIR Ataslra': __.. n � W .L Lbcat Cci- ordinate Tteference: " 3H -33 -- I i Compan" , Kuparuk River Unit , ConocoPhillips(Alaska) Inc. ' . , , nip Reference: 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) I si , Kuparuk 3H Pad M D,Reference ' , ri . 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Well 3H-33 North FReference: ,, True I Wellboret 3H -33 ' Survey Calculation Method: Minimum Curvature Design; - 3H -33 " Database: EDM Alaska Prod v16 r- r ,G Survey ,� �„ May 5 Vet - kcal. � � r, nMap TV N / +$ _ +E! - DLS se n MD Inc /itzi WO ft) (ft) (ft) , N 0, nig , Eas g (0/100') c I Survey ° Annotation {\ 2 Interpolated 6,080.86 326.32 4,363.97 6,000,913.71 503,018.89 46.29 3,815.06 M WD (2) rp olated AL 7,77!.61 64.62 86.47 6,157.71 G,iii 1 1 7,809.57 76.10 85.69 6,167.76 6,090.91 328.25 4,392.07 6,000,915.64 503,046.99 38.39 3,839.69 MWD (2) 7,839.49 90.52 84.38 6,171.24 6,094.39 330.82 4,421.60 6,000,918.20 503,076.51 48.39 3,865.35 MWD (2) 7,869.95 93.44 97.88 6,170.18 6,093.33 330.23 4,451.96 6,000,917.60 503,106.87 45.31 3,893.11 MWD (2) i 7,900.04 93.44 112.65 6,168.36 6,091.51 322.34 4,480.86 6,000,909.71 503,135.76 49.00 3,922.63 MWD (2) 7,930.08 91.57 124.90 6,167.05 6,090.20 307.92 4,507.11 6,000,895.29 503,162.01 41.21 3,952.52 MWD (2) 7,960.06 91.90 139.86 6,166.13 6,089.28 287.78 4,529.18 6,000,875.14 503,184.08 49.89 3,981.04 MWD (2) 8,000.15 97.14 161.27 6,162.94 6,086.09 253.20 4,548.72 6,000,840.57 503,203.61 54.80 4,013.39 MWD (2) r 8,030.28 97.70 164.95 6,159.04 6,082.19 224.62 4,557.40 6,000,811.99 503,212.28 12.25 4,033.36 MWD (2) 4` 8,060.14 98.07 168.72 6,154.95 6,078.10 195.82 4,564.14 6,000,783.19 503,219.01 12.57 4,051.65 MWD (2) 1 8,090.37 97.54 172.24 6,150.84 6,073.99 166.29 4,569.09 6,000,753.66 503,223.96 11.67 4,068.65 MWD (2) 8,120.10 96.86 174.97 6,147.11 6,070.26 136.98 4,572.37 6,000,724.36 503,227.24 9.39 4,084.03 MWD (2) L 8,150.17 96.31 178.32 6,143.66 6,066.81 107.17 4,574.12 6,000,694.54 503,228.98 11.22 4,098.25 MWD (2) 8,180.25 95.10 180.89 6,140.67 6,063.82 77.24 4,574.33 6,000,664.62 503,229.18 9.41 4,111.11 MWD (2) 8,210.24 93.87 183.19 6,138.33 6,061.48 47.36 4,573.26 6,000,634.74 503,228.11 8.68 4,122.80 MWD (2) 4 I. 8,240.22 94.58 187.04 6,136.12 6,059.27 17.59 4,570.60 6,000,604.97 503,225.44 13.02 4,132.99 MWD (2) 0 8,269.79 94.09 189.32 6,133.88 6,057.03 -11.60 4,566.40 6,000,575.79 503,221.24 7.86 4,141.55 MWD (2) 1 8,299.95 93.35 192.95 6,131.93 6,055.08 -41.12 4,560.59 6,000,546.27 503,215.42 12.26 4,148.79 MWD (2) 8,329.99 92.03 196.24 6,130.52 6,053.67 -70.15 4,553.03 6,000,517.24 503,207.86 11.79 4,154.24 MWD (2) 8,360.14 90.49 199.23 6,129.85 6,053.00 -98.86 4,543.85 6,000,488.54 503,198.67 11.15 4,158.08 MWD (2) I 8,390.07 88.89 202.02 6,130.01 6,053.16 - 126.87 4,533.31 6,000,460.54 503,188.13 10.75 4,160.39 MWD (2) 8,420.19 88.22 205.04 6,130.77 6,053.92 - 154.47 4,521.29 6,000,432.94 503,176.11 10.27 4,161.19 MWD (2) 8,450.45 87.82 208.55 6,131.82 6,054.97 - 181.46 4,507.66 6,000,405.96 503,162.47 11.67 4,160.28 MWD (2) 8,480.02 87.57 211.83 6,133.01 6,056.16 - 207.00 4,492.80 6,000,380.43 503,147.61 11.12 4,157.63 MWD (2) 8,510.12 88.43 215.30 6,134.06 6,057.21 - 232.06 4,476.17 6,000,355.37 503,130.98 11.87 4,153.18 MWD (2) 8,540.11 87.18 217.17 6,135.21 6,058.36 - 256.23 4,458.46 6,000,331.21 503,113.26 7.50 4,147.38 MWD (2) il 4( 8,570.08 85.54 214.36 6,137.11 6,060.26 - 280.49 4,440.98 6,000,306.95 503,095.78 10.84 4,141.82 MWD (2) 8,600.24 85.33 211.38 6,139.51 6,062.66 - 305.74 4,424.67 6,000,281.70 503,079.46 9.87 4,137.73 MWD (2) 8,630.02 85.08 208.08 6,142.00 6,065.15 - 331.51 4,409.95 6,000,255.94 503,064.75 11.07 4,135.31 MWD (2) 8,660.40 83.17 204.42 6,145.11 6,068.26 - 358.61 4,396.59 6,000,228.85 503,051.38 13.53 4,134.68 MWD (2) 8,690.10 83.54 201.53 6,148.55 6,071.70 - 385.76 4,385.07 6,000 201.70 503,039.86 9.75 4,135.76 MV VD 76 MD (2) " "" " 11/3/2009 11:30:26AM Page 12 COMPASS 2003.16 Build 69 r�,, j ConocoPhillips Milli Definitive Survey Report Aca MOMS Company d'; Con I Local Co- ordinate Reference 3H-33 Pfojece, ; Kuparuk River Unit tTVD Reference : ■ - 3H -33 Rig © 76.85ft (D15 (40.75 +36.1)) 1 = Sitp Kuparuk 3H Pad MD Reference: 3H - Rig @ 76.85ft (D15 (40.75 +36.1)) Well4 t 3H -33 North Refere T rue F Wellbore NN, 3H -33 Survey C alculat i on Method M Curvature fi �lgn; 3H -33 Database' EDM Alaska Prod v16 -� - , Map -0° Vertical , '`Map { • s MD inc , - I 1 TVD .. TVDSS ° ' +NAs ,- t + ' c/ 11{f Northing, Eastiirg Dias Section Sur Teal Name Ann€�t _ t er i 14 ' r� 197.83 6t 152. ; 4 u tfl1 075.19 ., tftl - 413.92 ft ifs fit) , t r�oo� ( ' 8,720.21 83.,0 6, 4,375.00 6,000,173.55 503,029.79 12.28 4,138.56 MWD (2) 8,750.30 84.68 195.24 6,155.24 6,078.39 - 442.60 4,366.49 6,000,144.87 503,021.27 9.97 4,142.99 MWD (2) 8,770.35 86.31 193.30 6,156.81 6,079.96 - 461.97 4,361.56 6,000,125.50 503,016.34 12.61 4,146.73 MWD (2) 8,800.17 87.02 190.10 6,158.55 6,081.70 - 491.11 4,355.53 6,000,096.36 503,010.30 10.97 4,153.61 MWD (2) 8,829.81 86.38 185.90 6,160.25 6,083.40 - 520.41 4,351.41 6,000,067.07 503,006.18 14.31 4,162.29 MWD (2) 8,860.11 88.28 182.65 6,161.67 6,084.82 - 550.59 4,349.16 6,000,036.90 503,003.92 12.41 4,173.02 MWD (2) 8,890.05 88.89 178.35 6,162.41 6,085.56 - 580.51 4,348.89 6,000,006.98 503,003.65 14.50 4,185.46 MWD (2) 8,920.26 89.88 175.25 6,162.73 6,085.88 - 610.67 4,350.58 5,999,976.82 503,005.33 10.77 4,199.76 MWD (2) 8,950.12 89.26 171.87 6,162.95 6,086.10 - 640.33 4,353.93 5,999,947.16 503,008.67 11.51 4,215.36 MWD (2) 8,980.15 90.03 168.79 6,163.14 6,086.29 - 669.93 4,358.97 5,999,917.56 503,013.71 10.57 4,232.46 MWD (2) 9,010.24 91.38 164.54 6,162.77 6,085.92 - 699.20 4,365.91 5,999,888.29 503,020.64 14.82 4,251.14 MWD (2) 1 9,040.17 91.50 164.94 6,162.02 6,085.17 - 728.07 4,373.79 5,999,859.43 503,028.51 1.39 4,270.50 MWD (2) 9,070.13 92.24 167.48 6,161.04 6,084.19 - 757.15 4,380.92 5,999,830.35 503,035.64 8.83 4,289.28 MWD (2) 9,100.22 93.13 170.98 6,159.63 6,082.78 - 786.67 4,386.54 5,999,800.83 503,041.25 11.99 4,306.87 MWD (2) 9,140.16 92.39 175.13 6,157.71 6,080.86 - 826.26 4,391.36 5,999,761.24 503,046.07 10.55 4,328.01 MWD (2) 9,174.96 92.15 179.25 6,156.33 6,079.48 - 860.98 4,393.06 5,999,726.52 503,047.77 11.84 4,344.26 MWD (2) 0 9,200.57 92.27 182.14 6,155.34 6,078.49 - 886.57 4,392.75 5,999,700.94 503,047.45 11.29 4,354.82 MWD (2) 9,230.38 93.59 184.89 6,153.82 6,076.97 - 916.28 4,390.93 5,999,671.23 503,045.62 10.22 4,365.75 MWD (2) 9,260.48 95.07 188.20 6,151.54 6,074.69 - 946.10 4,387.51 5,999,641.42 503,042.20 12.02 4,375.27 MWD (2) 9,290.75 95.44 190.62 6,148.77 6,071.92 - 975.83 4,382.58 5,999,611.69 503,037.26 8.05 4,383.40 MWD (2) 9,320.62 95.69 193.63 6,145.87 6,069.02 - 1,004.89 4,376.34 5,999,582.63 503,031.02 10.06 4,390.06 MWD (2) 1 9,350.61 93.56 195.55 6,143.45 6,066.60 - 1,033.82 4,368.81 5,999,553.71 503,023.48 9.55 4,395.49 MWD (2) 9,380.54 93.44 199.15 6,141.63 6,064.78 - 1,062.33 4,359.90 5,999,525.20 503,014.57 12.01 4,399.49 MWD (2) 9,410.55 92.12 201.75 6,140.17 6,063.32 - 1 W ,090.41 4,349.43 5,999,497.13 503,004.09 9.71 4,401.90 MWD (2) 9,440.35 90.52 204.49 6,139.48 6,062.63 - 1,117.81 4,337.73 5,999,469.74 502,992.39 10.65 4,402.91 MWD (2) 9,470.51 90.03 202.49 6,139.34 6,062.49 - 1,145.46 4,325.71 5,999,442.08 502,980.37 6.83 4,403.73 MWD (2) 9,500.52 90.28 199.17 6,139.26 6,062.41 - 1,173.51 4,315.04 5,999,414.04 502,969.69 11.09 4,405.94 MWD (2) 9,530.41 91.17 196.10 6,138.88 6,062.03 - 1,201.99 4,305.99 5,999,385.57 502,960.64 10.69 4,409.80 MWD (2) '` 9,560.69 90.58 192.63 6,138.42 6,061.57 - 1,231.31 4,298.48 5,999,356.25 502,953.12 11.62 4,415.42 MWD (2) 9,590.56 89.45 189.80 6,138.41 6,061.56 - 1,260.61 4,292.67 5,999,326.95 502,947.31 10.20 4,422.56 MWD (2) 9,620.72 86.34 185.92 6,139.52 6,062.67 - 1,290.46 4,288.55 5,999,297.11 502,943.18 16.48 4,431.47 MWD (2) 11/3/2009 11:30:26AM Page 13 COMPASS 2003.16 Build 69 le ' ConocoPhillipst WEIS CC11lip5 ive Survey Rep ort Alaska Definitive I Company. ConocoPhillips(Alaska) Inc. Local Ca- ordinate Reference 3H -33 Project: Kuparuk River Unit TtiD Reference:" 3H 33 Rig @ 76.85ft (D15 (40.75 +36.1)) Sid#: �aa ` Kuparuk 3H Pad MD Reference. 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) WeD: ' 3H -33 North rehce. True Wettbore: 3H -33 Survey Ca Method: Minimum Curvature �De i 3H -33 Daiebase: EDM Alaska Prod v16 �" ' 'emu 5lii � , ., Ve , "l , ., _ ::_,,,,_ _____, ,•,. i MD ∎' ` T W TVDSS +N1-S } Ef Vll N rthing Eas "ting I 1 ' edt Survey Tool Name Annotation tion r . _` ( ) ' Inc n do z (ft) s. (ft) ( } (ft) ({ } (ftl (114b } (ft} 9,650.31 86.07 182.62 6, 141 .48 6,0 64.63 1,3 4,2 86.35 5,99 502,940.98 11.17 4,441.95 MWD (2) F 9,680.51 86.87 178.95 6,143.34 6,066.49 - 1,350.03 4,285.94 5,99 502,940.56 12.42 4,454.34 MWD (2) 9,710.58 87.54 175.81 6,144.80 6,067.95 1,380.03 4,287.31 5,999,207.55 502,941.93 10.67 4,468.29 MWD (2) 9,740.40 87.64 171.86 6,146.06 6,069.21 -1,409.64 4,290.51 5,999,177.93 502,945.12 13.24 4,483.73 MWD (2) 9,770.41 89.20 174.70 6,146.88 6,070.03 1,439.43 4,294.02 5,999,148.15 502,948.63 10.79 4,499.52 MWD (2) 9,806.14 89.82 177.41 6,147.19 6,070.34 1,475.07 4,296.48 5,999,112.51 502,951.08 7.78 4,516.84 MWD (2) 9,836.24 91.04 181.19 6,146.96 6,070.11 1,505.16 4,296.84 5,999,082.42 502,951.44 13.20 4,529.92 MWD (2) 9,866.23 89.72 184.23 6,146.77 6,069.92 - 1,535.12 4,295.43 5,999,052.47 502,950.02 11.05 4,541.32 MWD (2) 9,896.01 90.52 187.80 6,146.70 6,069.85 -1,564.73 4,292.31 5,999,022.87 502,946.89 12.29 4,551.04 MWD (2) 9,926.24 93.04 189.60 6,145.76 6,068.91 -1,594.59 4,287.74 5,998,993.01 502,942.32 10.24 4,559.54 MWD (2) Interpolated AZI 9 93.01 194.35 6,143.67 6,066.82 1,633.40 4,279.50 5,998,954.20 502,934.08 11.94 4,568.52 MWD (2) 9,997.05 93.81 197.70 6,141.82 6,064.97 1,663.21 4,270.94 5,998,924.40 502,925.51 11.07 4,573.39 MWD (2) 10,028.61 95.26 200.87 6,139.32 6,062.47 1,692.90 4,260.56 5,998,894.71 502,915.12 11.02 4,576.56 MWD (2) 10,050.34 95.84 203.37 6,137.22 6,060.37 1,712.93 4,252.41 5,998,874.68 502,906.98 11.76 4,577.67 MWD (2) 10,080.32 95.16 207.09 6,134.34 6,057.49 1,739.92 4,239.70 5,998,847.70 502,894.25 12.56 4,577 MWD (2) 10,110.29 95.59 205.47 6,131.54 6,054.69 -1,766.68 4,226.48 5,998,820.95 502,881.04 5.57 4,576.94 MWD (2) 10,139.75 97.60 203.39 6,128.15 6,051.30 1,793.32 4,214.38 5,998,794.31 502,868.93 9 4,577.26 MWD (2) 10,169.62 99.72 200 6,123.66 6,046.81 1,820.75 4,203.46 5,998,766.89 .35 MWD (2) 502,858.01 13.25 4,578.98 MWD (2) 10,200.00 101.96 197.12 6,117.94 6,041.09 1,849.03 4,193.96 5,998,738.61 502,848.51 11.90 4,582 • 10,229.78 103.76 193 6,111 6,034.46 1,877.02 4,186.28 5,998,710.63 502,840.82 13.16 4,587.25 MWD (2) 10,260.17 104.27 190.37 6,103.95 6,027.10 1,905.86 4,180.17 5,998,681.79 502,834.71 10.29 4,593 MWD (2) 10,307.00 104.27 190.37 6,092.41 6,015.56 1,950.50 4,172.00 5,998,637.15 502,826.53 0.00 4,605.44 PROJECTED to TD 11/3/2009 11:30:26AM Page 14 COMPASS 2003.16 Build 69 • • Conoco Phillips Time Log & Summary 4Nellview Web Reporting Report Well Name: 3H - 33 Rig Name: NABORS CDR2 - AC Job Type: DRILLING SIDETRACK Rig Accept: 10/1/2009 6:00:00 PM Rig Release: 10/31/2009 1:00:00 PM Time Logs Date - ° . =from To Dui' S. Depth E. Depth Phase Code Subcode . .T' °= Comment.. 10/01/2009 24 hr Summary Released from 3C -02, RDMO. MIRU on 3H -33. NU BOPE and start cutting CT for coil life maintenance. Nabors CDR2 Rig Accept on 3H -33 @ 18:00 on 10/01/09 04:00 18:00 14.00 MIRU MOVE MOB P Rig move from 3C pad to 3H pad. 18:00 19:00 1.00 0 0 MIRU WHDBO PRTS P Accept CDR2 Rig on 3H -33 @ 18:00 on 10/01/09. Pressure test tree and BOP connection 4K 19:00 21:30 2.50 0 0 MIRU WHDBO BOPE P PJSM. Load lubricator, pull BPV, unload lubricator 21:30 00:00 2.50 0 0 MIRU WHDBO SLPC P PJSM. Prep equipment for CT cuts. Pump slack, and blow reel dry from free end. Cutting 2000' of CT. 10/02/2009 Finish sutting coil. Test BOPE 250/4500 psi. Remove ice from tiger tank line. Inspect injector head for source of pipe damage. 00:00 03:00 3.00 0 0 MIRU WHDBO SLPC P Continue to cut CT for coil life management. Cut a total of 2000'. Total string length is now -12,000'. 03:00 05:30 2.50 0 0 MIRU WHDBO SLPC P RD cutting equipment. MU coil connector, pull test 30K. Clean rig floor. 05:30 07:30 2.00 0 0 MIRU WHDBO BOPE P PU testing equipment. PJSM. Test 250/4500 psi, annular 250/2500. Test waived by AOGCC Rep. Bob Noble 9/29/09 @ 17:00. Tested all tree valves and MP line. 07:30 09:00 1.50 0 0 MIRU WHDBO BOPE T Rio components testing - Upper Blind rams failed. Changed out both upper and lower Blind rams. 09:00 12:00 3.00 0 0 MIRU WHDBO BOPE P Continue with BOP tests, procedure steps 2 - 12 completed. 12:00 15:30 3.50 0 0 MIRU WHDBO BOPE P Complete testing BOP's 15:30 17:00 1.50 0 0 MIRU WHDBO RGRP T Inspect injector chains, cleaned, serviced and CT pipe for surface marks & damage 17:00 18:00 1.00 0 0 MIRU WHDBO PRTS P Pressure test PDL's to 4500 psi (Not part of the BOP test) 18:00 21:30 3.50 0 0 MIRU WHDBO PRTS P New crew first shift. Walk through rig up and ESD for adjacent well, frozen tiger tank line, start tearing down.. Set back PDL. MI injector and fluid pack reel. Press test coil connector to 4K. Page 1 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/02/2009 24 hr Summa Finish sutting coil. Test BOPE 250/4500 psi. Remove ice from tiger tank line. Inspect injector head for source of pipe damage. 21:30 22:00 0.50 0 0 PROD1 WHPST PULD T Install check valves, blind sub and nozzle for run to inspect CT damage. 22:00 00:00 2.00 0 0 PROD1 WHPST CIRC T Frozen line to tiger tank - Steam hardline, tiger tank riser and wheel house line. RU hardline. 10/03/2009 RIH to 2650' repairing pipe damage and looking for new marks. Swapped out well fluids and drilled 2.80" pilot hole from 7578' to 7715 for the whipstock. 00:00 00:30 0.50 0 0 PROD1 WHPST CIRC T Fill tiger tank line with diesel. Press test line 4.5K. 00:30 01:30 1.00 0 0 PROD1 WHPST PRTS P PJSM. Fill riser and press test 4K. Circ 1 CT vol @ 2 bpm 3600 psi. 01:30 06:00 4.50 0 0 PROD1 WHPST TRIP T RIH filing down burrs on each damaged spots on CT. Damage spots on the CT are 10.5' apart, consistent with repetitive chain damage. Very prevelent for some sections then diminishing. This trend seems to cycle along 2150' of CT. Worst damage is 1800' -2200' from the coil connector. Flagged this section in ReelTrak. Continue to RIH 2650' looking for more damage. POOH looking for new damage. 06:00 07:00 1.00 0 0 PROD1 WHPST CIRC T CT at surface, circulate fluid at surface to ensure CT is clear. 07:00 08:00 1.00 0 0 PROD1 WHPST RGRP T Inspect rollers on gooseneck, inspect counter on gooseneck to ensure nothing else is lose on top of the injector 08:00 09:00 1.00 0 0 PROD1 WHPST PULD P Change pack off on injector and P/U BHA #2 with 2.80" mill 09:00 11:00 2.00 0 7,300 PROD1 WHPST TRIP P RIH circulating fluid to Tiger tank with water. IA 14, OA 80. Weight check & pipe inspection @ 4000'. Looked good. 11:00 11:48 0.80 7,300 7,578 PROD1 WHPST DLOG P P/U - weight check @ 7350' 25,000# Begin pumping Flo -pro down CT. Tie in depth - 7390' ( + 3 FT) Start taking returns into pits. Good flo -pro to surface. Stop pumping. Close EDC. RIH slowly at min. rate and tagged TOC @ 7578'. 11:48 12:36 0.80 7,578 7,580 PROD1 WHPST MILL P P/U weight 25,000# Increase pump rate to 1.5 bpm, 3100 psi, BHP 3650, ECD 12.0, WHP 40 psi, stable mud returns. Start milling cement. Pump leaking, P/U swap out after 5 ft drilled. 12:36 20:30 7.90 7,580 7,715 PROD1 WHPST MILL P Milling cement - 1.5 bpm, 3600 psi, CT weight 4000, WHP 40, BHP 3700, ECD 12.1, WOB 2.6, ROP 20 fpm. Page 2 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:15 0.75 7,715 7,715 PROD1 WHPST DLOG P PUH to 7545'. RIH tie in to GR minus 1 ft correction. Flag EOP at 7600'. Dry tag at 7715'. 21:15 22:00 0.75 7,715 7,500 PROD1 WHPST OWFF P PUH to 7600' EOP and flag. PUH to 7500', up wt = 25K. Monitor well for flow for 30 min. No Flow. 22:00 00:00 2.00 7,500 830 PROD1 WHPST TRIP P POOH 60 fpm, wt = 22K, open EDC, pumping 1.5 bpm 2550 psi. 10/04/2009 Caliper cement pilot hole. X -ray inspect damaged pipe. Drifted pilot hole with dummy whipstock. Set whiostock @ 7685'. 00:00 00:15 0.25 830 200 PROD1 WHPST TRIP I P Continue to POOH 00:15 00:30 0.25 200 200 PROD1 WHPST OWFF P Monitor well for flow 15 min. PJSM 00:30 00:45 0.25 200 60 PROD1 WHPST TRIP P Continue to POOH to surface. 00:45 02:15 1.50 60 48 PROD1 RPEQPI PULD P RD drilling BHA #2. MU PDS memory caliper BHA #3. 02:15 04:30 2.25 48 7,712 PROD1 RPEQP1TRIP P RIH with PDS caliper 60 fpm. EDC open pumping 1 bpm 1500 psi. Tie in depth with previous EOP flag at 7600', plus 3' correction. RIH to 7712', wait for calipers to open and PUH at 45 fpm. 04:30 05:00 0.50 7,712 7,100 PROD1 RPEQPI DLOG P Wait for calipers to open and PUH at 45 fpm, wt 23K. PDS log stopped recording @ - 7160'. 05:00 07:00 2.00 7,100 48 PROD1 RPEQP1TRIP P POOH to surface with PDS caliper log BHA #3. 07:00 09:00 2.00 48 0 PROD1 RPEQPI PULD P Lay down BHA #3, P/U BHA #4 - Coiltrac and dummy WS 09:00 11:00 2.00 0 7,710 PROD1 RPEQP1TRIP P RIH with BHA #4 . Tie in depth 7560'. ( +2) correction. Continue RIH down to 7710' No weight bobbles, looked good. P/U check flag depth 7600 EOP. Depths are on mark. 11:00 13:00 2.00 7,710 2,100 PROD1 RPEQP1TRIP P POOH 13:00 15:30 2.50 2,100 2,100 PROD1 RPEQPI RGRP T Stop at pipe damaged area to X -ray CT for fatigue cracks. Stop pumping, shut in well, power down BHI tools and cable. Set out barriers around the rig. (Note: X -rays proved inconclusive since pipe was filled with fluid. Decided to continue on with reel.) 15:30 16:30 1.00 2,100 0 PROD1 RPEQP1TRIP P POOH to surface. 16:30 18:15 1.75 0 71 PROD1 RPEQPI PULD P Lay down BHA # 4 , P/U BHA #5 whipstock run. 18:15 21:40 3.43 71 7,550 PROD1 RPEQP1TRIP P RIH with whipstock BHA #5, 40 fpm with EDC open 1 bpm 1800 psi. 21:40 21:55 0.25 7,550 7,671 PROD1 RPEQP1 DLOG P Reduce speed to 2 fpm, tie in with GR, + 3 ft correction. RIH to EOP flag 7600' (7671' bit depth), confirm tie in Up wt = 20K, down wt = 11K. Page 3 of 27 • • Time Logs Date From. To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:55 22:29 0.57 7,671 7,660 PROD1 RPEQP1WPST P RIH to 7697', PUH to 7693.7', top of whipstock @ 7685' orientated high side. Shut down pump. CT press 3280, ann press 3430, diff press -150 psi. Wait for diff press to equalize, staying constant. Closed choke, no change. Rolled pump with closed choke, no change. Open choke and pumped 6 bbl © 1 bpm, stopped and observe, still -150 psi diff. Close EDC. Pump up pressure to 3800 psi, pressure broke back indicating set. PUH 25' open EDC. 22:29 23:59 1.50 7,660 3,400 PROD1 RPEQP1TRIP P POOH 23K circ 1 bpm @ 1850 psi. 10/05/2009 Milled "A" lateral window. Top of window 7685.4', bottom of window 7690.5'. 00:00 01:00 1.00 3,400 63 PROD1 RPEQP1TRIP P Continue POOH with whipstock setting tool BHA #5. 01:00 03:30 2.50 63 71 PROD1 WHPST PULD P RD BHA #5, MU milling BHA #6. Greased reel and injector head. 03:30 06:00 2.50 71 7,560 PROD1 WHPST TRIP P RIH with milling assembly BHA #6. EDC open pumping 1 bpm @ 1550 psi. 06:00 07:30 1.50 7,560 7,685 PROD1 WHPST SFTY P Tie in @ 7560 ' correction +3 ft, P/u weight 21,000# . Shut down pumps. Close EDC and have a pre -spud meeting./ crew change out morning call before starting window milling. 07:30 08:30 1.00 7,685 7,685 PROD1 WHPST MILL P RIH slowly and dry tag TOWS @ 7685' P/U 10' CT weight 24,000# Start pumping @ 1.5 bpm, 3000 psi, WHP 40, BHP 3700 psi,. Stall @ 7585.4 P/U and start milling from 7585'. Time drill & had stall 7685.4, P/U and start auto drill mode from 7585'. Pump problem, P/U and start again. 08:30 10:30 2.00 7,685 7,687 PROD1 WHPST MILL P Auto drill - Smooth milling from 7585 - to7586'. 1.5 bpm, 3000 psi, WOB 1.2, ECD 11.81, BHP 3662, ROP . 5 _ - 1 fph. 10:30 12:00 1.50 7,687 7,687 PROD1 WHPST MILL P Getting metal shaving back to shakers. WOB 1.6 @ 1 fph. 12:00 15:00 3.00 7,687 7,688 PROD1 WHPST MILL P past the mid point, good metal shaving overs shakers. WOB 1.9 ROP 1 fph. 15:00 17:00 2.00 7,688 7,689 PROD1 WHPST MILL P Noticed light paint chips over shakers (red /yellow). Continue milling 1 fph. 17:00 00:00 7.00 7,689 7,691 PROD1 WHPST MILL P Increase WOB to 2K. Motor work avg. 100 to 150 psi. Started to mill off at 12:00 pm bottom of the window 7690.5'. Continue to time drill. Page 4 of 27 • • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T > Comment 10/06/2009 24 hr Summary Finished milling window and and 15' formation. Dressed window and swapped well over to new 10.0 mud. 9 pP ppg Tripped for drilling BHA and drilled build to 7780'. Short in BHA, tripped to repair. 00:00 06:00 6.00 7,691 7,705 PROD1 WHPST DRLG P Continue with window milling operations. Milling 10' of formation, dress window and drift with pump down. 06:00 09:00 3.00 7,705 0 PROD1 WHPST TRIP P Swap well over to new 10.0 PPG mud and POOH 09:00 11:30 2.50 0 0 PROD1 WHPST PULD P Lay down window milling BHA 11:30 13:30 2.00 0 0 PROD1 DRILL RGRP T Repair electrical connections on top drive. Nabors rig repair, 2 hours billable. 13:30 15:00 1.50 0 0 PROD1 DRILL PULD P PU BHA # 7 15:00 17:00 2.00 0 7,550 PROD1 DRILL TRIP P RIH with BHA #7 for build section 17:00 17:12 0.20 7,550 7,571 PROD1 DRILL DLOG P Tie in +2' 17:12 20:00 2.80 7,705 7,780 PROD1 DRILL DRLG P Continue RIH, tag at 7706, PU and start drilling. 1.4 BPM, 3550 CTP, 4000 BHP, 20:00 00:00 4.00 7,780 0 PROD1 DRILL TRIP T MWD failure, trouble shoot and POOH. At surface discovered a short in the LQC. Inteq Downtime 10/07/2009 Completed drilling build section, tripped for BHA and drilled lateral. 00:00 00:30 0.50 0 0 PROD1 DRILL PULD T Change out LQC, make up injector and test BHA. Continue Inteq down time 00:30 03:00 2.50 0 7,500 PROD1 DRILL TRIP T RIH with BHA #8 03:00 03:30 0.50 7,500 7,780 PROD1 DRILL DLOG T Tie in , close EDC and RIH 03:30 07:00 3.50 7,780 7,930 PROD1 DRILL DRLG P Drilling ahead. 1.4 BPM, 3850 CTP with 300 WHP, 22000 PUW, 2000 RIW, 1.5 to 2K WOB 07:00 07:30 0.50 7,930 7,930 PROD1 DRILL WPRT P Wiper Trip to window 20K PUW 1.44 BPM @ 3790 PSI 4345 BHP 07:30 09:30 2.00 7,930 7,960 PROD1 DRILL DRLG P 7930, Drill Ahead 5 K RIW 1.42 BPM @3790 PSI FS 4320 BHP, 95 to 100R TF 09:30 10:15 0.75 7,960 7,960 PROD1 DRILL WPRT T Wiper trip while waiting for anticipated Directional Plan change 10:15 11:00 0.75 7,960 8,000 PROD1 DRILL DRLG P 7960, Drill ahead with revised targets 1.42 BPM @ 3790 FS 11:00 13:30 2.50 8,000 75 PROD1 DRILL TRIP P 8000', End Of Build Section, 20K PUW 1.4 @3790 PSI Clean coming up through window, Open EDC 13:30 14:30 1.00 75 0 PROD1 DRILL TRIP P Test SSSV, Trap 900 PSI, S/D Pumps, dump WHP through choke. Well continued to flow, Shut in and starts building pressure, 100 PSI in three minutes. Pump well back up, cycle sssv and repeat test. Same results Page 5 of 27 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 0 0 PROD1 DRILL PULD P Pressure undeploy BHA #8 16:30 17:00 0.50 0 0 PROD1 DRILL PULD P Put PDL on well with BHA #9 on well. Well secure for rig floor welding project 17:00 18:00 1.00 0 0 PROD1 DRILL RGRP T Rig repairs, welding on V -door railing 18:00 18:30 0.50 0 0 PROD1 DRILL SFTY P PJSM for pressure deployment 18:30 19:30 1.00 0 0 PROD1 DRILL PULD P Continue with pressure deployment Co p p y of BHA # 9 19:30 21:00 1.50 0 7,500 PROD1 DRILL TRIP P RIH 21:00 21:12 0.20 7,500 7,550 PROD1 DRILL DLOG P Tie in, 21:12 22:30 1.30 7,550 8,000 PROD1 DRILL CIRC P Circulate out crude cut returns. Determined that BHP on Inteq is off by 120 psi. Close EDC and continue RU-I. (Note: Later determined that Inteq pressure was fine. The viscous FloPro mud was inhibiting pressure transfer when not circulating.) 22:30 00:00 1.50 8,000 8,120 PROD1 DRILL DRLG P Drilling ahead. 1.4 BPM, 4000 CTP, 160 WHP, 4110 BHP(4230 on inteq). 21K PUW, 6K RIW. 10/08/2009 Drilled lateral from 8120' to 9040' 00:00 00:18 0.30 8,120 8,150 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 4000 CTP, 160 WHP, 4110 BHP(4230 on inteq). 21K PUW, 6K RIW. 00:18 01:30 1.20 8,150 7,705 PROD1 DRILL DLOG P Mad pass from 8000' to 7705' 01:30 01:48 0.30 7,705 8,150 PROD1 DRILL WPRT P wiper trip to bottom 01:48 03:48 2.00 8,150 8,300 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 4000 CTP, 160 WHP, 4110 BHP(4230 on inteq). 21K PUW, 6K RIW. 03:48 04:42 0.90 8,300 8,300 PROD1 DRILL WPRT P Wiper trip to window 04:42 09:00 4.30 8,300 8,450 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3900 CTP, 160 WHP, 4100 BHP (4220 Inteq). 22K PUW, 8K RIW. 09:00 10:42 1.70 8,450 8,450 PROD1 DRILL WPRT P Wiper trip to window with tie in to RA Marker ( -1 foot correction) 22K PUW, 1.41 BPM @ 3880 FS BHP =4280 10:42 12:42 2.00 8,450 8,595 PROD1 DRILL DRLG P 8595, Drill ahead 5.7K RIW 1.40 BPM @ 3900 PSI FS, TF =95R ROP =75 DH WOB =1.8K BHP =4122. (Note: Started trusting Inteq BHP sub fagain.) 12:42 14:24 1.70 8,595 8,595 PROD1 DRILL WPRT P 8595, Wiper trip to window, First one since tie in. 21K PUW, 1.40 BPM @ 3900 BHP =4110 Good, clean trip no overpulls or setdowns 14:24 16:24 2.00 8,595 8,745 PROD1 DRILL DRLG P 8595 Drill Ahead RIW =3K1.4 BPM @ 3900 PSI FS DH WOB =1.4 TF =100L BHP =4110 Page 6 of 27 • Time Logs Date From To Dur S. Deoth E. Depth Phase . Code Subcode T Comment 16:24 18:00 1.60 8,745 8,745 PROD1 DRILL WPRT P 8745, Wiper to window 22 K PUW 1.4 BPM @ 3900 PSI BHP =4170 18:00 20:00 2.00 8,745 8,895 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3850 CTP, 40 WHP, 4130 BHP, 8K RIW, 13.1 ECD, 1 -2K WOB, 200 -350 motor work, 60 -100 ROP 20:00 20:48 0.80 8,895 7,710 PROD1 DRILL WPRT P Wiper trip to window 20:48 21:00 0.20 7,710 7,730 PROD1 DRILL DLOG P Tie in at RA, -2' 21:00 21:48 0.80 7,730 8,895 PROD1 DRILL WPRT P Wiper to bottom 21:48 00:00 2.20 8,895 9,040 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 3850 CTP, 40 WHP, 4130 BHP, 8K RIW, 13.1 ECD, 1 -2K WOB, 200 -350 motor work, 30 -100 ROP 10/09/2009 Drilled lateral from 9040' to 9795' 00:00 00:18 0.30 9,040 9,045 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 3850 CTP, 40 WHP, 4120 BHP, 8K RIW, 13.1 ECD, 1 -2K WOB, 200 -350 motor work, 20 ROP. Drill solids at 0.9 %, 38K LSRV. 00:18 01:24 1.10 9,045 7,705 PROD1 DRILL WPRT P Wiper trip to window 01:24 02:12 0.80 7,705 7,705 PROD1 DRILL OWFF P Shut in well and monitor BHP. 4050 psi at 6067' subsea TVD. 02:12 03:00 0.80 7,705 9,045 PROD1 DRILL WPRT P Wiper to bottom 03:00 05:45 2.75 9,045 9,155 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 3900 CTP, 50 WHP, 4160 BHP, 8K RIW, 13.1 ECD, 1 -3K WOB, 200 -350 motor work, 30 -100 ROP 05:45 08:00 2.25 9,155 9,155 PROD1 DRILL WPRT P Wiper Trip to window, 25K PUW 1.44 BPM @ 3950 PSI FS BHP =4190 Clean trip, no overpulls or setdowns 08:00 10:00 2.00 9,155 9,345 PROD1 DRILL DRLG P 9155' Drill Ahead, 5.5K RIW 1.41 BPM @ 3800 PSI FS 1.2K WOB, 75 FPH ROP, 11 OR TF BHP =4140 10:00 12:45 2.75 9,345 9,345 PROD1 DRILL WPRT P 9345, Wiper trip to window with Tie in PUW 24K 1.4 @ 3760 FS BHP =4150 -1 foot correction at Tie In 12:45 14:30 1.75 9,345 9,495 PROD1 DRILL DRLG P 9345 Drill ahead 1.48 BPM @ 4050 PSI * * ** Swapped to new Mud @ Bit when set down * * *. Had drilled 1660' on this mud system. BHP =4150 14:30 17:00 2.50 9,495 9,495 PROD1 DRILL WPRT P 9495, Wiper trip to window 25k PUW, BHP =4140 17:00 18:42 1.70 9,495 9,645 PROD1 DRILL DRLG P Drill Ahead, 5.5K RIW 1.41 BPM @ 3800 PSI FS 1.2K WOB, 75 FPH ROP, BHP =4140 18:42 21:12 2.50 9,645 9,645 PROD1 DRILL WPRT P Wiper trip to window, 24K PUW, 4150 BHP Page 7 of 27 f • Time Logs Date From To Dur S. Depth E. Depth Phase - Code Subcode T Comment 21:12 23:00 1.80 9,645 9,795 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 3900 CTP, 50 WHP, 4160 BHP, 8K RIW, 13.1 ECD, 1 -3K WOB, 200 -350 motor work, 30 -100 ROP 23:00 00:00 1.00 9,795 8,015 PROD1 DRILL WPRT P Wiper to window, 24K PUW, 4155 BHP 10/10/2009 Drilled lateral from 9795' to 9795' 00:00 00:48 0.80 8,015 7,500 PROD1 DRILL WPRT P Continue wiper trip 00:48 01:30 0.70 7,500 7,580 PROD1 DRILL DLOG P Tie in in cased hole. Inteq depth counter was slipping so pulled up into tubing to repair. 01:30 03:00 1.50 7,580 9,795 PROD1 DRILL WPRT P Wiper trip to bottom 03:00 06:30 3.50 9,795 9,950 PROD1 DRILL DRLG P Continue drilling from 9795'. 1.5 BPM, 3900 CTP, 4155 BHP, 60 WHP, 6K RIW, 06:30 10:30 4.00 9,950 9,950 PROD1 DRILL WPRT P 9950, wiper to window, Tie in +5 foot. Pull up through window for chain inspection, One damaged carrier block run back to bottom, MADD pass from 9215 to 9430 on way in PUW =24K, RIW 6.5K1.48 BPM @ 3800 10:30 12:30 2.00 9,950 10,030 PROD1 DRILL DRLG P 9952', Drill ahead 3.3K RIW 1.5 BPM @ 3875 FS 12:30 13:30 1.00 10,030 10,096 PROD1 DRILL DRLG P 10030 Getting a little gas at shaker 3 BBI gain from this morning increase choke pressure to 50 PSI monitor in and out BHP =4070 13:30 14:30 1.00 10,096 7,666 PROD1 DRILL WPRT X 10096, Wiper to window 1.47 BPM @ 4089 PSI PUW 27K BHP =4089 Change of scope due to drilling beyond planned TD of 10,050'. 14:30 15:00 0.50 7,666 7,666 PROD1 DRILL OWFF X 7660 Trap 900 PSI WHP, 4145= BHP monitor 30 Minutes, BHP =4012, 13.1 will Kill well RIH to drill 15:00 16:45 1.75 7,666 10,096 PROD1 DRILL WPRT X RIH through window to drill, RIW =10K 16:45 18:30 1.75 10,096 10,245 PROD1 DRILL DRLG X 10096, drill ahead towards revised TD of 10,300' 1.38 BPM @ 3750 PSI FS BHP =4130 18:30 22:45 4.25 10,245 10,245 PROD1 DRILL WPRT X Wiper trip to window. Counter issues, PU into cased hole and adjust counter, tie in. 22:45 00:00 1.25 10,245 10,300 PROD1 DRILL DRLG X Continue drilling. 1.5 BPM, 3900 CTP, 4155 BHP, 60 WHP, 2K RIW, 10/11/2009 TD at 10307', POOH laying in KWF. Became detained in the SSSV. Pumped down well to get past SSSV. PU liner and RIH Page 8 of 27 410 410 Time Logs Date From To , Dur S. Depth E. Depth Phase Code Subcode T ` Comment 00:00 00:30 0.50 10,300 10,307 PROD1 DRILL DRLG X Continue drilling from 10300'. 1.5 BPM, 3900 CTP, 4155 BHP, 60 WHP, OK RIW. TD at 10307'. 00:30 02:30 2.00 10,307 7,705 PROD1 DRILL WPRT P Wiper to window 02:30 03:00 0.50 7,705 7,750 PROD1 DRILL DLOG P Tie in at RA, -1' 03:00 04:45 1.75 7,750 10,307 PROD1 DRILL WPRT P Wiper to bottom. Tag up at 9950', 9930', 9963'. Pulled up hole and ran in clean, continue to TD 04:45 05:00 0.25 10,307 10,050 PROD1 DRILL WPRT P Tagged bottom at 10307', PUH to 10050' 05:00 06:00 1.00 10,050 10,307 PROD1 DRILL DLOG P MAD pass from 10050 to 10307' 06:00 09:15 3.25 10,307 2,074 PROD1 DRILL TRIP P POOH laying in beaded liner running pill then KWF 09:15 14:15 5.00 2,074 2,000 PROD1 DRILL TRIP T 2074.0, Tag up in SSSV, had 4400 PSI applied pressure. Completed pumping KWF to surface. Well dead with no flow. Attempted multiple running speeds and tool orientation. Not showing any change on WOB sub - appear to be hanging up at coil connector. Increased control pressure to 5K. Cycled valve - no luck. Contact wells super. SSSV specialist to location. Cycled valve and increased applied pressure Still no luck. Lined up and pumped down backside, pulled right through. Total pumped 3 bbls with no indication of breakdown on pressure logs. 14:15 14:45 0.50 2,000 0 PROD1 DRILL TRIP P Continue out of well 14:45 16:15 1.50 0 0 PROD1 DRILL PULD P At surface, PJSM for BHA removal from Well. Remove injector from well Inspect coil for signs of flapper valve contact - nothing definite Blow down BHA and remove from well with top drive. Break down and lower to pipe shed 16:15 16:45 0.50 0 0 COMPZ CASING SFTY P Function test Blind Shear Rams - R/U floor to run liner - PJSM to run Liner 16:45 18:00 1.25 0 0 COMPZ CASING PUTB P M/U Liner 18:00 19:30 1.50 0 0 COMPZ CASING RGRP T Repair roller in Injector gooseneck. 1.5 Hours of repair time for Nabors Rig Repair Billable Time 19:30 20:00 0.50 0 0 COMPZ CASING SVRG P Maint. on injector 20:00 22:30 2.50 0 2,300 COMPZ CASING PUTB P Continue PU liner 22:30 23:00 0.50 2,300 3,200 COMPZ CASING RUNL P RIH with liner. 0.3 BPM pump rate, 0.5 BPM return rate. 23:00 00:00 1.00 3,200 3,200 COMPZ CASING RGRP T Repair injector encoder. 1 Hour of repair time for Nabors Rig Repair Billable Time Page 9 of 27 • Time Logs Date From To ''. Dur S. Depth E. Depth Phase . Code Subcode T Comment 10/12/2009 24 hr Summary Ran liner into open hole and had to work down from initial stacking at 9617'. Left liner at 9944' with aluminum billet in pilot hole at 7668'. 00:00 01:00 1.00 4,500 9,235 COMPZ CASING RUNL P Continue RIH with liner, correct depth at flag, +4', all counters tracking within 6'. 23K PUW above window. 8K RIW. Started losing returns. Shut down pump and reduce RIH speed to 60 FPM. Slowed to 40 FPM. returns diminished and finally unable to get reurns while RIH. Able to get returns with coil static and pumping .3 BPM. 01:00 02:00 1.00 9,235 9,655 COMPZ CASING RUNL P Stack weight at 9235', 30K PUW, OK RiW, continue RIH. Stack weight at 9582', 32K PUW, OK RIW, Continue RIH. Stack weight at 9617', 32K PUW, OK RIW, Cont. 02:00 06:00 4.00 9,655 9,830 COMPZ CASING RUNL T Stack weight at 9655', 33K PUW Continue RIW, stacking out every 5 -10', PU and continue. 9675' and on only getting 1 - 3' each time. Lost about 30 Bbls during trip in and while working pipe. 06:00 12:00 6.00 9,830 9,953 COMPZ CASING RUNL T Crew change, continue working pipe Avg 14 FPH 12:00 12:30 0.50 9,953 9,800 COMPZ CASING RUNL T Bring pumps on 0.9 bpm @ 4700 P/U and release from Liner PUW =29K. Stop and 9865' and RIH to confirm liner release. Able to RIH with setdown at billet, PUH to 9800' for tie in 12:30 13:30 1.00 9,800 9,834 COMPZ CASING DLOG P 9800' Start tie in pass, correct -7' to 9827 BHI Counter. Puts top of deployment sleeve @ 7670.5'. Guide shoe @ 9946.7. Correct all counters to end of tool string having released liner: - 2276.5' Correction 13:30 14:45 1.25 7,558 3,500 COMPZ CASING RUNL P PUH to swap fluid back to 10.0 Flo Pro 14:45 15:15 0.50 3,500 2,700 COMPZ CASING RUNL P 3500' MD. Attempt to get one for one returns. 0.52 bpm in, 0.3 bpm out. Continue PUH 15:15 18:45 3.50 2,700 7,600 COMPZ CASING CIRC P 2700' MD. 0.5 bpm in, 0.42 bpm out. Go to 10.1 PPG down coil Coil pressure 2450, RIH swapping out fluid 18:45 19:00 0.25 7,600 7,550 COMPZ CASING DLOG T Tie in, -5'. 19:00 20:00 1.00 7,550 7,668 COMPZ CASING TRIP T Continue attempts to push liner down hole while mixing up flo -pro pill with beads and 6% lubes. Tagged billet at 7668' MD. Page 10 " of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 23:00 3.00 7,668 7,668 COMPZ CASING DISP T Circulate in beads, shut in well and bullhead beads at 1 BPM, 4000 CTP, 1300 WHP, 4600 BHP. Total of 28 Bbls. Worked pipe while pumping down well from maximum push of -20K at surface, 12K downhole to 40K PUW, -15K down hole. No movement of liner string. After 28 Bbls pumped below billet, shut down pump and consult with town engineer. 23:00 23:18 0.30 7,668 7,668 COMPZ CASING CIRC T Waiting on orders... 23:18 00:00 0.70 7,668 4,400 COMPZ CASING TRIP T POOH for hip- tripper. 10/13/2009 RIH with accelorator and hip tripper to 7668'. Attempt to push liner to TD. No Luck. POOH, Hang up at SSSV. Get free. RU Slick Line to lock out SSSV. 00:00 01:12 1.20 4,400 0 COMPZ CASING TRIP T Continue POOH. Did not see anything at the SSSV. 01:12 02:00 0.80 0 0 COMPZ CASING PULD T Undeploy liner running tools 02:00 03:00 1.00 0 0 COMPZ CASING SVRG T Waiting on BOT for hip- tripper. Servicing injector, rebuild choke B 03:00 03:12 0.20 0 0 COMPZ CASING SFTY T Safety meeting for pressure deployment 03:12 04:27 1.25 0 0 COMPZ CASING PULD T Deploy BHA # 11 - hip- tripper. 04:27 06:15 1.80 0 7,532 COMPZ CASING TRIP T RIH with BHA #11 with Hip Tripper, EDC shut 06:15 07:00 0.75 7,532 7,555 COMPZ CASING DLOG T Gamma Ray tie in No Correction, PUH for CCL log, RIH and tag TOL 07:00 09:30 2.50 7,555 7,667 COMPZ CASING FISH T Tag TOL @ 7667 Pumps off, Tag @ 7665 Pumps On, Start Hip Tripping .9 BPM @ 3150 PSI / RIW 10k 09:30 10:30 1.00 7,667 7,667 COMPZ CASING FISH T Hip- tripper working off and on. No sign of movement. 10:30 11:30 1.00 7,667 7,667 COMPZ CASING DLOG T PUH and tie in to gamma. Re -tag to confirm depth. Billet top at 7667' MD. 11:30 13:00 1.50 7,667 2,108 COMPZ CASING TRIP T POOH 13:00 15:00 2.00 2,108 2,108 COMPZ CASING TRIP T Tagged up on SSSV. Had 6300 psi on control line. start pumping down backside. 1 BPM, 1500 WHP, still tagging 2 BPM, 1800 WHP, still tagging 2.5 BPM, 1900 WHP, still tagging Cycle SSSV and pressure up to 7000 control line pressure while RIH at 10 FPM, bleed off WHP. Start pumping down well at 3 BPM, 2000 WHP. No luck. 15:00 15:30 0.50 2,108 2,000 COMPZ CASING TRIP T Confer with town and wells superintendent. pump down well at 4 BPM, 2300 WHP and able to get past SSSV. Pumped total of 45 Bbls into formation Page 11 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:30 1.00 2,000 0 COMPZ CASING TRIP T Continue POOH 16:30 18:00 1.50 0 0 COMPZ CASING PULD T Undeploy BHA 18:00 19:00 1.00 0 0 COMPZ CASING PULD T Crew Change! PJSM, Continue LD BHA, Clean up floor for SL operations 19:00 22:45 3.75 0 0 COMPZ CASING SLKL T PJSM, Begin RU of SL, First time RU of SL onto CDR 2. IU /RD several times to make RU safe and efficient. Bullhead in 31 bbl KCL. 22:45 23:15 0.50 0 0 COMPZ CASING SLKL T RIH with brushes to clean and try to get valve to operate. No luck POOH 23:15 00:00 0.75 0 0 COMPZ CASING SLKL T RIH with Z5 tool to latch in to flow tube, Pull SL in tension. Bleed SSSV psi. Monitor SL weight looking for weight loss on SL weight indicator. Nothing. This indicating the flow tube is not stroking. Psi up hyd. psi 5000psi. RIH with SL monitor hyd. psi for hyd. psi loss. Nothing. RIH assure latching of Z5 tool into flow tube. PUH release Z5 tool from flow tube. 10/14/2009 Perform SL ops locking out SSSV. Perform SM cutting 250' of CT. 42' to find E -line. Mill alluminum billet 7665' to 7673'. 00:00 01:30 1.50 0 0 COMPZ CASING SLKL T POOH LD tools, Z5 tool still attached to SL. PU brushes to RIH and clean for one more attempt to get SSSV to operate. 01:30 02:00 0.50 0 0 COMPZ CASING SLKL T No luck POOH, LD brushes, PU Lock out tool to Lock out SSSV 02:00 02:15 0.25 0 0 COMPZ CASING SLKL T RIH, tag spang down to get seals to seal. Pressure up well 1160psi above SITP. Pressure sealing above SL tool. Spank down stroking and locking out SSSV. After 30 spangs pressure equalizes. 02:15 02:30 0.25 0 0 COMPZ CASING SLKL T POOH, 400- 600Ibs over pull. 02:30 03:15 0.75 0 0 COMPZ CASING SLKL T At surface, LD lock out tool. Rod stroked all but one inch. Indicating sleeve stroked to lock out SSSV. PU brushes to confirm. RIH 03:15 03:45 0.50 0 0 COMPZ CASING SLKL T RIH through brushes confirming. No tag with brushes, confirming SSSV flapper is fully opened. POOH 03:45 05:45 2.00 0 0 COMPZ CASING SLKL T At surface, LD tools. RD SL, RU to do Slack Management 05:45 07:15 1.50 0 0 COMPZ CASING SLPC T Reverse in fresh water. Reverse circulate at 3 BPM, 4500 psi. 07:15 09:45 2.50 0 0 COMPZ CASING SLPC T Cut 250' coil, found wire at 42'. 09:45 11:45 2.00 0 0 COMPZ CASING SLPC T Install CTC, pull test to 30K. Rehead E -line. PT to 4000. MU injector to well and PT lubricator to 4500 PSI. Circulate forward through coil at 3 BPM, 4500 CTP. Page 12 of 27 • 4110 Time Logs Date From To Dur S. Depth E. Depth Phase Code ' Subcode T Comment 11:45 13:15 1.50 0 0 COMPZ CASING PULD T Deploy BHA #12 13:15 15:45 2.50 0 7,500 COMPZ CASING TRIP T RIH displacing KCL from well to TT. 15:45 16:00 0.25 7,500 7,550 COMPZ CASING DLOG T Tie in, +0.5' 16:00 16:45 0.75 7,550 7,665 COMPZ CASING MILL T Tag billet at 7665', PU and close EDC. 1.44 BPM, 3700 CTP, 4050 BHP, 200 WHP, 13.1 ECD 22K PUW, 8K RIW Time milling at 1 FPH to remove enough billet to set next whipstock. 16:45 17:36 0.85 7,665 7,666 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 FPH 17:36 18 :33 0.95 7,666 7,668 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2FPH 18:33 19:18 0.75 7,668 7,669 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2FPH 19:18 20:18 1.00 7,669 7,670 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2 FPH 20:18 22:03 1.75 7,670 7,671 COMPZ CASING MILL T Milling Ahead 1K DHWOB, HS TF, 100psi motor work 1 -2 FPH 22:03 22:18 0.25 7,671 7,550 COMPZ CASING WPRT T Milled down 8' of billet, PUH to tie in 7550'. PUW =21 K. 22:18 22:27 0.15 7,550 7,570 COMPZ CASING DLOG T Tie in depth to gamma. Correction +1'. 22:27 22:42 0.25 7,570 7,674 COMPZ CASING WPRT T Offline with pumps. RIH to dry tag top of liner. Tag TOL 7674'. POOH to TT pumping minimum rate. 22:42 00:00 1.30 7,674 800 COMPZ CASING TRIP T Open EDC in TT, POOH, 800' MM and choke plug off. Stop blow back, RIH 1000' pumping 1.4BPM using choke to keep BHP constant, Cleaning hole. 10/15/2009 Pack off surface lines during POOH from milling Allum. Billet. Circulate to free all debris from surface lines. RIH for Clean Out run to assure hole clean. RIH with Whipstock setting at 7673, TOW= 7665'. 00:00 01:00 1.00 937 937 COMPZ CASING TRIP T Choke A plugged off. Choke A is not holding pressure, possible wash out. Shut in well on tree. Open up well to MP line to monitor WHP. Shut in well on stack. Blow back choke A. 01:00 01:39 0.65 937 0 COMPZ CASING TRIP T Choke clear of debris. Cont. POOH. Plugging still going on. 01:39 02:00 0.35 0 0 COMPZ CASING PULD T PJSM, Undeploy BHA, Choke is plugged, once undeployed need to flush choke manifold /choke A and choke B & MicroMotion. 02:00 02:45 0.75 0 0 COMPZ CASING CIRC T Stop undeploying operations. BHA is in 2 3/8" P/S deployment rams. Pressure bleed off above deployment rams. Having problems bleeding off during undeploying. Change operations to flushing surface lines and choke to free all lines of Aluminum. Undetermined if hole is clean of aluminum. Possible rerun BHA in rams for clean out run. Page 13 of 27 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:15 0.50 0 0 COMPZ CASING CIRC T Choke B is washed out. Choke A is flushed out. Lots of aluminum across shakers. 03:15 04:30 1.25 0 0 COMPZ CASING RGRP T Rebuilding Choke B 04:30 06:00 1.50 0 0 COMPZ CASING RGRP T Cannot get choke B to work properly. Call electrician out to c alibrate choke B. 1.5 hours of Nabors rig repair time. 06:00 06:30 0.50 0 0 COMPZ CASING SFTY T Crew change, PJSM 06:30 09:00 2.50 0 7,673 COMPZ CASING TRIP T RIH with EDC open, pumping 0.7 BPM 09:00 11:18 2.30 7,673 0 COMPZ CASING TRIP T Close EDC, pump 0.7 BPM. Tag liner top. POOH, increase rate to 1.5 BPM through the bit. Started plugging up the choke around 2000', RIH and swap to choke A. Clear choke and go back to choke B. Continue POOH, tag stripper and RIH 300'. POOH 11:18 13:18 2.00 0 0 COMPZ CASING PULD T Undeploy BHA, bit is still 2.73" go/ 2.72" no go. 13:18 15:30 2.20 0 0 PROD2 RPEQP1PULD P Deploy whipstock, BHA #13. 15:30 17:30 2.00 0 7,560 PROD2 RPEQP1TRIP P RIH. Kept anchor orientation sideways to minimize chance of hanging up on aluminum debris. 17:30 17:45 0.25 7,560 7,575 PROD2 RPEQP1DLOG P Tie in, +1.5', Close EDC and continue RIH Holding 900 WHP 17:45 18:00 0.25 7,575 7,673 PROD2 RPEQP1WPST P RIH to 7673.7', stacking 1K WOB. PU to 7670 and RIH to 7673.2', 0 WOB. Top of whipstock 7664.5'. Orient whipstock to high side. Pump down coil at 0.25 BPM. Sheared at 4500 CTP to set anchor. 18:00 19:30 1.50 7,673 0 PROD2 RPEQP1TRIP P POOH 19:30 23:00 3.50 0 0 PROD2 RPEQP1PULD P PJSM, Undeploy whipstock BHA. Deploy milling BHA #14. A 23:00 00:00 1.00 0 — PROD2 WHPST TRIP P RIH with milling BHA to mill window #2 10/16/2009 Mill window TOW= 7665', BOW= 7670', Drill 10' of rat hole to 7680'. POOH, Perform BOP test. 00:00 00:30 0.50 6,700 7,550 PROD2 WHPST TRIP P Cont. RIH 00:30 00:45 0.25 7,550 7,583 PROD2 WHPST DLOG P Tie in Depth. Correction +4' `' 00:45 01:15 0.50 7,666 7,666 PROD2 WHPST MILL P RIH for dry tag, Dry tag 7666'. PUH v 22''�� to 7657'. Online with pumps 1.3BPM, 2 �/7 3700psi CTP, 399 diff psi. off bottom. JJ RIH to 7665.7. Start to see motor t work 450 diff psi. Stop CT let it mill off. 01:15 06:00 4.75 7,666 7,669 PROD2 WHPST MILL P Set auto driller to 1 FPH, Mill ahead 9K CTW, 3600 CTP, 500 DHWOB, 162psi WHP, 487 diff psi. 06:00 10:18 4.30 7,669 7,670 PROD2 WHPST MILL P Milling with 2000 to 2500 WOB. This is about 100 PSI of motor work. Page 14 of 27 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:18 11:18 1.00 7,670 7,672 PROD2 WHPST DRLG P Appear to have exited casing, mill at 1 FPH. 2000 WOB, 50 -100 PSI motor work 11:18 13:54 2.60 7,672 7,680 PROD2 WHPST DRLG P Milling formation at 3 FPH, 2000 WOB, 100 PSI motor work 13:54 14:42 0.$0 7,680 7,660 PROD2 WHPST REAM P Ream window at 1 FPM up and down. 14:42 14:54 0.20 7,660 7,680 PROD2 WHPST REAM P Shut down pump and drift through window. No indication of WOB. 14:54 15:18 0.40 7,680 7,575 PROD2 WHPST DLOG P Tie in from 7550', -1' correction 15:18 15:42 0.40 7,575 7,580 PROD2 WHPST CIRC P RIH and swap well to new mud. 15:42 17:42 2.00 7,580 0 PROD2 WHPST TRIP P POOH 17:42 17:57 0.25 0 0 PROD2 WHPST PULD P Undeploy milling BHA 17:57 18:27 0.50 0 0 PROD2 WHPST SFTY P Crew change, PJSM. 18:27 19:42 1.25 0 0 PROD2 WHPST PULD P Continue Undeploying milling BHA 19:42 20:45 1.05 0 0 PROD2 WHPST CIRC P MU nozzle to CT, Flush BOP's and choke. 20:45 21:45 1.00 0 0 PROD2 DRILL BOPE P Grease Tree and stack valves, PU test joint. 21:45 22:00 0.25 0 0 PROD2 DRILL BOPE P Hold PJSM for BOP testing. State witness. (Lou Grimaldi) 22:00 00:00 2.00 0 0 PROD2 DRILL BOPE P Start BOP testing. 10/17/2009 Perform full BOP test. Deploy Build section BHA #15, 2.6AKO. Drill build section 7680'- 7970'. 00:00 05:00 5.00 0 0 PROD2 DRILL BOPE P BOP testing complete in 7 hours. State witnessed. Tested to 250/4500 psi, annular to 250/2500 psi. All components passed. 05:00 06:00 1.00 0 0 PROD2 DRILL BOPE P Displace reel back to new mud. 06:00 06:30 0.50 0 0 PROD2 DRILL SFTY P PJSM for deploying BHA 06:30 09:00 2.50 0 0 PROD2 DRILL PULD P Start deployment procedure. Confirm adustment on AKO on motor to 2.6 deg. Tool string hung up below master valve, worked free and then worked down past with aggressive SL action. 09:00 11:12 2.20 0 7,550 PROD2 DRILL TRIP P RIH 11:12 11:24 0.20 7,550 7,575 PROD2 DRILL DLOG P Tie in, +1.5' 11:24 11:42 0.30 7,575 7,680 PROD2 DRILL TRIP P RIH to drill 11:42 18:42 7.00 7,680 7,830 PROD2 DRILL DRLG P Drilling ahead„ 1.3 BPM, 3700 CTP, 41140 BHP, 50 WHP (wide open choke). 19K PUW, 8K RIW 18:42 19:12 0.50 7,830 7,685 PROD2 DRILL WPRT P Wiper trip back to 7685'. 21K CTW. 19:12 00:00 4.80 7,830 7,949 PROD2 DRILL DRLG P Drill ahead 1.3 BPM, 3800psi CTP, 4170 BHP, 50psi WHP, fully opened choke. 10/18/2009 Land build section AL1 with 51.58 deg dogleg average. POOH, Undeploy BHA #15, Service injector head, Deploy BHA #16, Drill AL1 lateral section from 7970' to 8559'. Page 15 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 7,949 7,970 PROD2 DRILL DRLG P Drilling Ahead 00:45 02:45 2.00 7,970 0 PROD2 DRILL TRIP P Land Build section AL1, 51.58 deg dogleg average for build section. PUH wiping hole back to window. Looks good. PUH through window, Open EDC, POOH 1.5BPM following MP trip schedule. 02:45 03:00 0.25 0 0 PROD2 DRILL SFTY P At surface, Hold PJSM for undeploy 03:00 04:30 1.50 0 0 PROD2 DRILL PULD P Undeploy BHA #15 04:30 06:00 1.50 0 0 PROD2 DRILL SVRG P Service injector head 06:00 06:18 0.30 0 0 PROD2 DRILL SFTY P PJSM for deployment 06:18 07:18 1.00 0 0 PROD2 DRILL PULD P Deploy BHA #16 for drilling lateral 07:18 08:48 1.50 0 7,550 PROD2 DRILL TRIP P RIH 08:48 09:18 0.50 7,550 7,720 PROD2 DRILL DLOG P Tie in, +1' correction. Log RA, RA depth is 7670.5', this makes TOW 7665.2', BOW 7670.0 09:18 09:30 0.20 7,720 7,970 PROD2 DRILL WPRT P Continue RIH 09:30 14:18 4.80 7,970 8,120 PROD2 DRILL DRLG P Tag at 7970 and drill ahead. 3800 CTP, 50 WHP, 4230 BHP, 21K PUW, 9K RIW 14:18 14:30 0.20 8,120 7,840 PROD2 DRILL WPRT P Wiper trip to window 14:30 15:30 1.00 8,070 7,690 PROD2 DRILL DLOG P MAD pass from 8070 to 7690 15:30 15:42 0.20 7,690 8,120 PROD2 DRILL WPRT P Continue Wiper to bottom 15:42 17:57 2.25 8,120 8,270 PROD2 DRILL DRLG P Drilling ahead, 3650 CTP, 56 WHP, 4152 BHP, 211K PUW, 9K RIW 17:57 18:48 0.85 8,270 7,690 PROD2 DRILL WPRT P Wiper trip to 7690', 21K CTW 18:48 20:48 2.00 8,270 8,420 PROD2 DRILL DRLG P Drill Ahead 90 FPH, .9K DHWOB, 1.35BPM, 3950psi CTP. Fully open choke 20:48 22:00 1.20 7,690 8,420 PROD2 DRILL WPRT P Wiper trip to 7690', 21 K CTW. Trap pressure tie in depth to RA marker. 0 correction, RBIH 22:00 00:00 2.00 8,420 8,570 PROD2 DRILL DRLG P Drill Ahead 100FPH, 8K CTW, 1.2K DHWOB, 1.4BPM, 4000psi CTP. Fully Open choke 10/19/2009 Drill AL1 from 8559' to 9319'. 00:00 01:30 1.50 8,570 7,695 PROD2 DRILL WPRT P Wiper trip to 7695'. 21K CTW 01:30 04:15 2.75 8,570 8,720 PROD2 DRILL DRLG P Drill Ahead 50- 60FPH, 1.3K DHWOB, 1.3BPM, 3850psi CTP 04:15 05:45 1.50 8,720 8,720 PROD2 DRILL WPRT P Wiper trip. 05:45 08:30 2.75 8,720 8,870 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4200 BHP, 50 WHP (wide open choke), 21K PUW, 8K RIW 08:30 10:00 1.50 8,870 8,870 PROD2 DRILL WPRT P Wiper trip to window with tie in at RA, -0.5' 10:00 13:30 3.50 8,870 9,020 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4200 BHP, 50 WHP (wide open choke), 21K PUW, 8K RIW Page 16 of 27 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:30 2.00 9,020 9,020 PROD2 DRILL WPRT P Wiper trip to window 15:30 19:00 3.50 9,020 9,170 PROD2 DRILL DRLG P Drilling ahead, 1.4 BPM, 3800 CTP, 4170 BHP, 25 WHP (wide open choke), 21K PUW, 8K RIW 19:00 20:45 1.75 9,170 7,690 PROD2 DRILL WPRT P Wiper trip to window, 21K CTW 20:45 00:00 3.25 9,170 9,319 PROD2 DRILL DRLG P Drill Ahead 2K DHWOB, 40 FPH, 1.3BPM, 4100psi CTP, 4170psi BHP, 13.3ECD, 0 WHP, fully open choke. 10/20/2009 TD lateral AL1 @ 9607'. POOH and P/U 2.625" anchored Al. Billet BHA. RIH pumping . 2 bpm through EDC. Tie in above window with 1.5 ft correction. 00:00 01:09 1.15 9,319 7,670 PROD2 DRILL WPRT P Wiper trip back to window, Bypass Micro Motion to repair choke B. 01:09 01:15 0.10 7,695 7,709 PROD2 DRILL DLOG P Tie in depth to RA marker. No correction 01:15 02:15 1.00 7,709 9,319 PROD2 DRILL WPRT P RIH to drill 02:15 04:45 2.50 9,319 9,457 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM, 3700 CTP, 4163 BHP, 21 WHP with wide open choke. 21K PUW, 4.5K WOB, 1:1 returns. Last mud check still good, 1650' on mud system. 04:45 08:00 3.25 9,457 7,692 PROD2 DRILL WPRT P Wiper for a geologist time out. Choke B acting up again. 08:00 11:51 3.85 9,457 9,607 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM, 3750 CTP, 4180 BHP, 30 WHP with wide open choke. 21K PUW, 4.5K WOB, 1:1 returns. Swap mud. 11:51 14:51 3.00 9,607 0 PROD2 DRILL TRIP X TD called for AL1. POOH for open hole geo- sidetrack. POOH. 14:51 15:06 0.25 0 0 PROD2 DRILL SFTY X At surface, PJSM undeploying BHA. 15:06 18:06 3.00 0 0 PROD2 DRILL PULD X Undeploy BHA #16, Orient anchor on billet 20R, face 20L. Service injector head, clean gripper blocks, check stripper rubber. 18:06 19:36 1.50 74 74 PROD2 STK PULD X Deploy BHA #17 with 2.625" OH Anchored Billet. 19:36 23:36 4.00 74 7,560 PROD2 STK TRIP X Equalize pressure and open EDC. RIH 250 ft. BHI comp[uter locked up, stop RIH to re -set computers to read BHA. fixed. Continue RIH 40 fpm pumping @ .2 bpm through EDC holding back pressure on the choke. 23:36 00:00 0.40 7,560 7,570 PROD2 STK DLOG X Tie in depth - + 1.5 ft correction. Weight check before out window 22K. Stop pumping, Close EDC, Continue RIH. 10/21/2009 Set top of Anchored Billet @ 8810. P/U BHA #18 with 1.0 AKO & 2.73 Bi- center. Tag TOB 8810.2', Hard time getting Ko started. Numerous stalls, started to improve after 2 ft drilled, 100' wiper trip due to shaving balling up near bit. Completed Billet KO from 8810 - 8815'. Page 17 of 27 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:48 0.80 7,570 8,821 PROD2 STK WPST X RIH, no weight bobbles through window or build section. Orient tool face to 20 left. Pressure up to 4100 psi, tool set. Set down 5K on tool. Looked good. P/U weight 23.5K. Top of Billet @ 8810'. 00:48 03:48 3.00 8,821 0 PROD2 STK TRIP X POOH pumping 1/2 bpm. up to window. Shut down open EDC and POOH as per pressure schedule. 03:48 06:57 3.15 0 0 PROD2 STK PULD X Lay down BHA # 17, P/U BHA # 18 with 1.0 AKO & 2.70" Bi- center. 06:57 08:27 1.50 0 7,550 PROD2 DRILL TRIP X RIH with BHA #18. 08:27 08:42 0.25 7,550 7,670 PROD2 DRILL DLOG X Tie in depth with gamma, +1 correction 08:42 09:42 1.00 7,670 8,811 PROD2 DRILL TRIP X RIH to Billet 09:42 09:57 0.25 8,811 8,801 PROD2 STK TRIP X Dry tag billet PUH 10' online with pumps. 1.3BPM, 3550psi CTP set auto driller for 1 FPH 09:57 10:42 0.75 8,810 8,811 PROD2 STK KOST X Start time milling 20L TF 1 FPH with auto driller. 396psi diff psi, 0 DHWOB 10:42 11:42 1.00 8,811 8,811 PROD2 STK KOST X Stall X 2 offline with pumps, PUH, RIH time mill 1 FPH 11:42 12:42 1.00 8,811 8,811 PROD2 STK KOST X Stall x 2, PUH, RIH time drill 1 FPH 12:42 12:48 0.10 8,811 8,811 PROD2 STK KOST X Restart time drilling .1 /6min. trying to get started pump 5bbrls 776 12:48 15:03 2.25 8,811 8,811 PROD2 STK KOST X Stall PUH try working down time drilling .05 /6min, pump 5 bbrls 776 15:03 16:18 1.25 8,810 8,811 PROD2 STK KOST X Time mill down trying to get started StaII,X2 16:18 16:48 0.50 8,811 8,811 PROD2 STK KOST X PUH 50', RIH 2OFPM stop at 8810.5' time mill in hole trying to get started, 16:48 17:48 1.00 8,811 8,810 PROD2 STK KOST X Stall x2 PUH, RIH try to get started.. Total of 10 stalls since trying to get started. 17:48 19:12 1.40 8,811 8,812 PROD2 STK KOST X Slowed down Drill speed to 1/2 fpm, taking .1 every 5 min. Starting to get light Al. returns to surface. Continue KO with .1 incriments every 5 min. had 8 advancements then a stall. WOB zero, CT weight 7K. Choke B starting to plug off. Work through by -pass and blow back. ECD & Annular increased by 200 psi. 19:12 20:12 1.00 8,812 8,812 PROD2 STK WPRT X Choke is clean, P/U weight 24 K, pressure went back to normal during 100ft wiper. WOB is greater on bottom now. back to normal. 20:12 21:30 1.30 8,812 8,812 PROD2 STK KOST X Back on bottom milling. WOB 1.0, ECD 13.1, BHP 4100, WHP 100, CT weight 10K, Circ 3800 psi, 1.48 bpm. Stall @ 8812.1. Heavy Al. returns to surface. P/U 70 ft weight & pressure is stacking out again. Page 18 of 27 • Time Logs Date From To Dur S. Depth, E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 8,812 8,814 PROD2 STK KOST X BOBD - 8811.5 - motor work detected. Continue time drilling up to 8812.2 then set auto drill 1.5 fph to 8813, Al. filing are slowing down, increase to 2 fph to 8814.3, increase to 3 fph to 8815.4, then 10 fph. Gained 2 bbls. 10/22/2009 KO billet from 8810 - 8815. Continue drilling Lateral as per plan, starting to lose CT weight while drilling © 9450'. 00:00 02:00 2.00 8,814 8,840 PROD2 STK KOST X Drill 10 fph for 1 ft, then 20 fph for 30 ft. WOB 1 K, Ct weight 9K, circ press 3800 @ 1.46 bpm, BHP 4100, ECD 13.1, ROP 20 fph. Light Al and formation in returns. 02:00 03:42 1.70 8,840 8,840 PROD2 STK WPRT X P/U weight 27K, wiper up to window, flush choke B. Then RIH & dry through billet. Total of 2 bbl gain since midnight. Dry tags looked clean through billet. 03:42 05:57 2.25 8,840 8,901 PROD2 DRILL DRLG X Drilling ahead - CT weight 8k, circ press 3800, 1.45 bpm, ROP 40 fph, WHP 150, BHP 4150, ECD 13.2. 05:57 08:12 2.25 8,901 7,690 PROD2 DRILL WPRT X P/U to window for geo wiper. Waiting on Geo from town. 08:12 10:27 2.25 8,901 9,055 PROD2 DRILL DRLG X On bottom drilling following plan 10:27 11:57 1.50 9,055 7,690 PROD2 DRILL WPRT X Wiper trip back to the window 11:57 14:12 2.25 9,055 9,205 PROD2 DRILL DRLG X Drill ahead, 1.8K DHWOB, 100FPH, 1.4BPM, 4000psi CTP, 150psi WHP, 13.2ECD, 4150psi BHP. 14:12 15:24 1.20 9,205 7,695 PROD2 DRILL WPRT X Wiper trip to window 15:24 15:30 0.10 7,695 7,712 PROD2 DRILL DLOG X Tie in depth with RA marker. +2 correction 15:30 16:15 0.75 7,712 9,205 PROD2 DRILL WPRT X RIH to Drill 16:15 18:15 2.00 9,205 9,355 PROD2 DRILL DRLG X Drill Ahead 60FPH 1.2K DHWOB, 1.4BPM 3880psi CTP, 90psi WHP, 4128psi BHP. 18:15 20:15 2.00 9,355 9,355 PROD2 DRILL WPRT X Wiper trip to window. CT weight 22K off bottom 20:15 22:00 1.75 9,355 9,505 PROD2 DRILL DRLG X BOBD - Ct weight 2k, Circ - 3900, 1.45 bpm, WHP 100, BHP 4170, ECD 13.3, ROP 75, Hit good sand (A -3) at 9480'. 22:00 00:00 2.00 9,505 9,505 PROD2 DRILL WPRT X Wiper trip to window, Ct weight 23k off bottom. Setting up pits for a mud swap. 10/23/2009 Continue drilling lateral to TD of 10,100'. Wiper trip, prepare KWF & liner pills. 00:00 00:30 0.50 9,505 9,505 PROD2 DRILL WPRT X Complete Wiper trip, set up pits for mud swap. 00:30 02:00 1.50 9,505 9,588 PROD2 DRILL DRLG X BOBD - CT weight 2k, circ - 4000 psi, 1.44 bpm, WHP 60, BHP 4160, ECD 13.2, ROP 80 fph, WOB 1.7 - in good sand. Start pumping new mud when on bottom drilling. Page 19 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:18 1.30 9,588 9,655 PROD2 DRILL DRLG X New Mud B /U, Drilling pressures - Circ 4000 psi, 1.44 bpm, BHP 4150, WHP 50, ECD 13.2, WOB .83, Ct weight 1 K, ROP 50. Continue drilling ahead and watch for change. 03:18 04:54 1.60 9,655 7,660 PROD2 DRILL WPRT P Wiper trip to window. P/U weight 22k off bottom. Perfrom Static test & Tie on wiper. 04:54 05:24 0.50 7,660 7,660 PROD2 DRILL OWFF P Perfrom static test for 30 min. Started pressures WHP 930 psi, BHP 4170, ECD 13.4./ 15 minutes - WHP 867, BHP 4030, ECD 13.04./ 30 minute - WHP 848, BHP 4020, ECD 13.0. 05:24 06:45 1.35 7,660 9,655 PROD2 DRILL WPRT P RIH Tie -in, trip to bottom. 06:45 08:00 1.25 9,655 9,805 PROD2 DRILL DRLG P Drill Ahead .25K DHWOB, 75- 100FPH, 1.4BPM, 3800psi CTP, 08:00 11:00 3.00 9,805 7,690 PROD2 DRILL WPRT P Wiper trip to window 21K CTW 11:00 12:21 1.35 9,805 9,955 PROD2 DRILL DRLG P Drill ahead, 1.6K DHWOB 80 -100 FPH, 1.4BPM 3931 psi CTP 12:21 15:21 3.00 9,955 7,690 PROD2 DRILL WPRT P Wiper trip to window, 23K CTW 15:21 16:06 0.75 9,955 10,050 PROD2 DRILL DRLG P Drill Ahead 16:06 16:36 0.50 9,900 10,050 PROD2 DRILL WPRT P BHA Wiper 16:36 18:06 1.50 10,050 10,100 PROD2 DRILL DRLG P Drill Ahead, TD AL1 lateral at 10,100' MD. 18:06 21:36 3.50 10,100 9,110 PROD2 DRILL WPRT P P/U weight off bottom - 22k, Wiper to window, perform Tie -in. ( +2.5), mixing up pill pits & swapping pits for liner run. 21:36 22:06 0.50 9,110 9,250 PROD2 DRILL WPRT P While RIH tagged up @ 9110'. P/U weight 22k at first then starting to see tool drag, up to 30 K at surface, leveled out after 30 ft. Toolface was HS, POOH 200 ft and stabilize conditions. RIH and watch area & TF, RIH small weight bobbles, run dow to 9250 & wipe up through area again. 22:06 23:36 1.50 9,250 10,100 PROD2 DRILL WPRT P P/U weight 22k, Slight drag up to 24 k @ 9170', continue POOH up to 8830' to ensure the hole is clean. Looks good, continue RIH. Tag bottom @ 10100.4' Start pumping beads down through CT. 23:36 00:00 0.40 10,100 10,100 PROD2 DRILL DISP P Begin pumping beads down CT, bypass high presssure screens. Pumped 22 bbls, wait on KWF pill, have to swap pits to weight up a little more. Trap pressure on well and slowly move pipe. 10/24/2009 Lay in liner pill from 10100 up to 7800' lay in KW bead pill up to 7200' then KWF to surface killing the well. Monitor well, P/U lower liner assembly spot from 10100 to 8661'. POOH pumping KWF. P/U upper liner assembly. Page 20 of 27 4 • Time Logs Date From To Dur S. Depth E. Depth Phase - Code Subcode T Comment 00:00 01:00 1.00 10,100 10,100 PROD2 DRILL DISP P Weighing up KWF - slowly moving CT up /down while pumping 5 bbl KWF beads in CT. 01:00 02:30 1.50 10,100 7,300 PROD2 DRILL TRIP P Start POOH flag pipe 8474' laying in liner pill 1:1 up to 7800' then KWF pill to 7300'. Stop pumping and Open EDC. 02:30 04:30 2.00 7,300 0 PROD2 DRILL TRIP P POOH laying in KWF follwing MP. EOP flag 6083'. Good KWM to surface @ 1100', Stop POOH and change screens on shaker. Continue POOH to surface. 04:30 05:00 0.50 0 0 PROD2 DRILL OWFF P Monitor well for 20 minutes. Have tool box talk on laying down BHA & Top drive maint. 05:00 06:00 1.00 0 0 PROD2 DRILL PULD P lay down BHA, prepare to P/U Liner BHA. 06:00 08:45 2.75 0 COMPZ CASING SVRG P Inspect derrick and PDL lifting slings and shackles, service injector head, Thaw top drive of ice and operate up and down. Prepare floor to run liner 08:45 09:00 0.25 0 0 COMPZ CASING SFTY P PJSM to run liner 09:00 12:00 3.00 0 0 COMPZ CASING PUTB P Start picking up first segment of liner 12:00 13:30 1.50 1,483 7,561 COMPZ CASING RUNL P RIH with liner 13:30 13:36 0.10 7,561 7,563 COMPZ CASING DLOG P Tie in depth to EOP flag +2' correction 13:36 13:42 0.10 7,563 7,600 COMPZ CASING RUNL P Continue RIH to top of window. Record up and down weights 21K up and 8K down. 13:42 14:12 0.50 7,600 10,100 COMPZ CASING RUNL P RIH through window 5 -10 FPM. Once through window RIH 60 FPM, slowing down 20FPM at the billet at 8810'. 14:12 14:27 0.25 10,100 8,659 COMPZ CASING RUNL P 1st segment of liner on Bottom, tag at 10107.8'. Calling 10100' bottom. PUH to record pick up weight. 31 K CTW. RIH placing CT into compression. Come online with pumps .75 BPM 2890 psi CTP. PUH to release off of liner. Released off of liner 21 K pick up weight. Line up to pump across top of stack. Subtract 1440' out of BHA length. 14:27 17:27 3.00 8,642 7,742 COMPZ CASING RUNL P POOH, pumping across the top. Paint EOP flag at 7743.2MD, EOP 7700'. Continue POOH through window. Tie in depth with RA marker. -3' correction. Line up to pump down the CT. POOH 17:27 19:27 2.00 0 0 COMPZ CASING SFTY P CT @ surface, monitor well during hand -over. Hold safety meeting for P/U liner #2 assembly. Perfrom Safety Stand drill with night crew. 19:27 21:27 2.00 0 903 COMPZ CASING PUTB P Start P/U liner assembly. Page 21 of 27 • • Time Logs Date From To Dur ; S. Depth E. Depth Phase Code Subcode T ' Comment 21:27 22:27 1.00 903 903 COMPZ CASING RGRP T While P/U Coiltrac the safety lock out pins on the top drive came out. System is disabled but not working correctly. Stop and repair. (By -pass hydraulic override manually) 22:27 23:27 1.00 903 903 COMPZ CASING PULD P Complete lowering in Coiltrack and inspect injector prepare to RIH. 23:27 00:00 0.55 903 903 COMPZ CASING RUNL P RIH with BHA # 20: 2nd segment of liner. 10/25/2009 RIH set upper liner & billet top © 7804.4', POOH. P/U BHA # 21 - 1.3 AKO with Bi- center - Rlh swap to 10 # drilling mud. Kick off Top of Billet from 7803 - 7808'. Continue drilling lateral in A -2 formation. 00:00 02:00 2.00 8,662 8,662 COMPZ CASING RUNL P RIH from 2000' EOP flag on depth @ 6000', continue RIH with liner. Perform weight check prior to exiting window. 22k, RIH slowly 20 fpm through window, no problems, RIH tag liner top from 1st segment @ 8662.4 - sat down 5k at surface. Start pumping . 1 bpm, build pressure to 3000 psi & release from liner. 02:00 04:00 2.00 7,804 0 COMPZ CASING RUNL P Top of billet is 7803.7, POOH pumping down CT to keep hole full of KWF while POOH 04:00 05:30 1.50 0 0 COMPZ CASING PULD P At surface, Check the well for flow (15 min.) lay down BHA #20. 05:30 06:45 1.25 0 0 PROD3 DRILL PULD P Service injector head, check stripper rubber, PU BHA #21. 1.3deq AKO, 06:45 08:54 2.15 0 7,565 PROD3 DRILL TRIP P RIH with lateral BHA #21 with EDC open, pumping 0.4 BPM to sidetrack AL2 08:54 09:03 0.15 7,565 7,582 PROD3 DRILL DLOG P Tie in depth to gamma +3' correction 09:03 09:12 0.15 7,582 7,806 PROD3 DRILL TRIP P Close EDC RIH through window no pumps. Online with pumps RIH hrough build section. Offline with pumps tag billet 7806'. 09:12 10:12 1.00 7,806 7,350 PROD3 DRILL CIRC P PUH circulating 13.1 ppg KWM out of hole. 10:12 11:24 1.20 7,350 780 PROD3 DRILL TRIP P RIH to mill 11:24 14:24 3.00 7,803 7,805 PROD3 STK KOST P Start time milling .03 /6min. Aluminum over the shakers 14:24 15:00 0.60 7,805 7,806 PROD3 STK KOST P Increase ROP to .05' /6min 15:00 15:39 0.65 7,806 7,807 PROD3 STK KOST P Increase ROP to 2' /hour 15:39 16:09 0.50 7,807 7,808 PROD3 STK KOST P Increase ROP to 3' /hour 16:09 16:30 0.35 7,808 7,825 PROD3 DRILL DRLG P Confirmed Sidetrack with near bit inclination. 7805- 7808'. PUH through sidetrack and 10' above, did not see anything. Offline with pumps, RIH through sidetrack dry, did not see anything. 16:30 18:30 2.00 7,825 7,955 PROD3 DRILL DRLG P Drill ahead 1K DHWOB, 30- 50FPH, 1.4BPM 3990psi CTP, 4100psi BHP, 13.1 ECD, 240psi WHP Page 22 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:12 0.70 7,955 7,955 PROD3 DRILL WPRT P Wiper to window, P/U weight 22k 19:12 20:42 1.50 7,955 8,105 PROD3 DRILL DRLG P BOBD - CT weight 2K, circ - 3900, 1.44 bpm, BHP 4144, ECD 13.14, WHP 150, ROP - 80 fph. Drilling in A -2 formation but crossed a fault @ 8040', possible nosed up to A -3. 20:42 21:42 1.00 8,105 8,105 PROD3 DRILL WPRT P Wiper trip - P/U weight 22K 21:42 23:00 1.30 8,105 8,255 PROD3 DRILL DRLG P BOBD - CT weight 3300, circ 3900psi, 1.45 bpm, WOB 1.7, ROP 90, BHP 4145, ECD 13.2, WHP 150. 23:00 00:00 1.00 8,255 8,255 PROD3 DRILL WPRT P Wiper trip to window, perfrom tie in +1 ft correction 10/26/2009 Drilled ahead to 9245', perfromed mud swap @ 8709'. 00:00 01:36 1.60 8,255 8,405 PROD3 DRILL DRLG P BOBD - CT weight 3000, circ 3900, 1.44 bpm, BHP 4187, WHP 150, ECD 13.2, WOB 1.6, ROP 100fph. 01:36 03:06 1.50 8,405 8,405 PROD3 DRILL WPRT P Wiper trip - P/U 22k - Samples indicate A -2 03:06 04:06 1.00 8,405 8,463 PROD3 DRILL DRLG P BOBD - CT weight 2300, circ 3900, 1.40 bpm, BHP 4166, WHp 120, WOB 2.0, ECD 13.2, ROP 80 fph. Samples indicate A -2 sand 04:06 06:06 2.00 8,463 7,690 PROD3 DRILL WPRT P Wiper trip early (ROP slowed) going out the top of A2. Geo's calling town. 06:06 08:06 2.00 8,463 8,615 PROD3 DRILL DRLG P Drill Ahead 08:06 09:06 1.00 8,615 7,690 PROD3 DRILL WPRT P Wiper trip back to window 21K CTW 09:06 09:15 0.15 7,670 7,710 PROD3 DRILL DLOG P Tie in to RA marker, correction -no correction 09:15 09:45 0.50 7,710 8,621 PROD3 DRILL WPRT P RIH to drill 09:45 11:45 2.00 8,621 8,765 PROD3 DRILL DRLG P Drill Ahead, start pumping new mud down hole. New mud back to surface 11 am. 11:45 13:18 1.55 8,765 7,690 PROD3 DRILL WPRT P Wiper trip back to window 23K CTW 13:18 15:03 1.75 8,765 8,915 PROD3 DRILL DRLG P Drill ahead 15:03 16:42 1.65 8,915 7,690 PROD3 DRILL WPRT P Wiper trip back to window 16:42 18:06 1.40 8,915 9,065 PROD3 DRILL DRLG P Drill Ahead 18:06 20:06 2.00 9,065 9,065 PROD3 DRILL WPRT P Wiper trip to window with tie in ( zero correction). CT weight off bottom 23K. 20:06 21:36 1.50 9,065 9,215 PROD3 DRILL DRLG P BOBD - CT weight 3000, circ - 3800, 1.44 BPM, WOB 1.3K, ECD 13.2, BHP 4180, WHP 100, ROP 90 fph 21:36 22:06 0.50 9,215 9,248 PROD3 DRILL DRLG P Wiper trip - 200 ft - weight check 23K, RIH drill another 30 ft. 22:06 00:00 1.90 9,248 9,248 PROD3 DRILL WPRT P Wiper trip to window, Geo's feel we need to drill another 100'. P/U weight off bottom. 23K. Static test. 10/27/2009 Drilled AL2 lateral to depth 9382'. RIH and dropped off liner at TD up to 7984'. MU open hole anchor and aluminium billet BHA and RIH Page 23 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 9,248 7,650 PROD3 DRILL OWFF P 7650' - 30 minute static test - WHP 700 psi, ECD 12.92. BHP - 4023 psi. END - WHP 815, ECD 12.93, BHP - 3991. 00:30 02:00 1.50 7,650 9,248 PROD3 DRILL WPRT P RIH 02:00 03:18 1.30 9,248 9,380 PROD3 DRILL DRLG P BOBD - CT weight 2000, circ - 3900, BHP 4170, ECD 13.2, ROP - 80fph, Drilling for data, turning down 80 degrees. TD lateral @ 9380' - 6110' TVD. 03:18 04:48 1.50 9,380 7,690 PROD3 DRILL WPRT P Wiper trip to window, P/U weight 25K 04:48 05:03 0.25 7,670 7,680 PROD3 DRILL DLOG P Tie in depth to RA marker, +2 correction. 05:03 06:33 1.50 7,680 9,380 PROD3 DRILL WPRT P RIH to TD 06:33 09:33 3.00 9,383 0 PROD3 DRILL DISP P Tag TD 9382.69', POOH laying in 13.1 ppg liner pil to window. Swap to non - beaded 13.1 ppg at window. POOH killing well 09:33 11:03 1.50 0 0 PROD3 DRILL TRIP P POOH to surface 11:03 11:33 0.50 0 0 COMPZ CASING SFTY P Watch for flo at surface. Hold a BHA lay down iner running safety meeting. 11:33 15:33 4.00 0 1,442 COMPZ CASING PUTB P Make up liner & P/U Coiltrac assembly ( BHA # 22). total lenght 1442.28 15:33 17:05 1.54 1,442 9,000 COMPZ CASING RUNL P RIH @ 45 fmp (20 fpm through window). Wt check @ 9000 ft 30K#. 17:05 19:05 2.00 9,000 9,382 COMPZ CASING RUNL P Tag btm @ 9382 with liner. Pump off liner @ 1.2 bpm 4100 psi. PU wt 22K #.Topofliner @7984 19:05 21:20 2.25 7,984 45 COMPZ CASING RUNL P POOH 80 fpm pumping 0.8 bpm. 21:20 22:20 1.00 45 74 COMPZ CASING PULD P Tag up, monitor well. PJSM. Rig down liner running BHA. 22:20 23:20 1.00 1,900 PROD4 STK PULD P RU AL billet on openhole anchor (BHA #23). test tool, open EDC. 23:20 23:59 0.66 74 1,900 PROD4 STK TRIP P RIH 45 fpm with open hole anchor and AL billet. Pumping 0.25 bpm 670 psi. 10/28/2009 Run and set aluminium KO billet for AL2 -01. Mill and KO from billet and start drilling AL2 -01 lateral. 00:00 02:00 2.00 1,900 7,690 PROD4 STK TRIP P Continue to RIH with open hole anchor and aluminium billet for AL2 -01 lateral. Pump through open EDC @ 0.20 bpm 650 psi. 02:00 02:20 0.34 7,690 7,983 PROD4 STK DLOG P Tie in to RA marker with 0' correction. Continue to RIH. 02:20 02:45 0.42 7,983 7,971 PROD4 STK WPST P Tag liner at 7983', sit 2K# down. Pick up wt and PUH 1'. Close EDC and press up to 4100 psi and broke back. Wt on bit 1.5K#. Pull out of billet. Bottom of anchor at 7982' top of aluminium billet at 7971'. 02:45 04:30 1.75 7,971 71 PROD4 STK TRIP P POOH at 45 fpm pumping 0.8 bpm 2250 psi. Page 24 of 27 it • • Time Logs Date from To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 71 0 PROD4 STK PULD P Tagged up at surface. Monitor well, PJSM. RD anchor and billet BHA. MU milling /drilling BHA #23. 06:30 07:30 1.00 72 72 PROD4 DRILL SVRG P Injector maintenance and safety meeting 07:30 11:00 3.50 72 7,650 PROD4 DRILL TRIP P Start RIH, slowly pumping through EDC. P/U weight 21 k, 7565' tie in ( +2) Circulate out KWM. 11:00 11:42 0.70 7,650 7,969 PROD4 STK KOST P RIH & dry tag top of billet @ 7969.4'. P/U weight 23k, to 7962'. Bring pumps online @ 1.45 bpm. Trough up hole slowly 80 ft on low -side @ 5 fpm. RIH troughing, tag @ 7969.3' P/U 10 ft and start time drilling. 11:42 17:54 6.20 7,969 7,995 PROD4 STK KOST P Start time drilling @ 7967.3' CT weight 8.5K, circ 3700, BHP 4125, ECD 13.1, WHP 100, WOB 0, moving a tenth every 5 min. Actual motor work detected 7968.5' - B/U samples have light Alum. over shakers. 17:54 18:29 0.59 7,995 7,995 PROD4 STK KOST P Back ream billet. PUH 5 fpm to 7900'. PU wt 23K #. RIH 18:29 19:29 1.00 7,995 8,033 PROD4 DRILL DRLG P Drilling AL2 -01 later. Pumping 1.4 bpm, 13.2 ECD, ann press 4193, 100 psi motor work, 1.1K WOB, ROP 85 fph. 19:29 20:29 1.00 8,033 8,048 PROD4 DRILL DRLG P ROP slowed down to 6 fph, 1.8K WOB, 91 psi motor work. 20:29 21:29 1.00 8,048 8,145 PROD4 DRILL DRLG P ROP increased to 90 fph. 1.8K WOB, 225 psi motor work. 21:29 22:29 1.00 8,145 8,145 PROD4 DRILL WPRT P Wiper trip #1. PU wt 26K. PUH to 7682', RIH. 22:29 23:59 1.50 8,145 8,264 PROD4 DRILL DRLG P Continue drilling. 1.3K WOB, CT wt 7K, 150 psi motor work, ROP 90 fph. 10/29/2009 Drilled AL2 -01 lateral to 9203'. 00:00 00:15 0.25 8,264 8,296 PROD4 DRILL DRLG P Continue drilling AL2 -01 lateral. ROP 110 fpm, 1.6 WOB, 190 psi motor work. 00:15 01:05 0.84 8,296 8,296 PROD4 DRILL WPRT P Wiper trip #2. PU wt 26K. 35 fpm pumping 1.5 bpm 3800 psi (20 fpm 0.3 bpm through billet sections). PUH to 7685'. RIH 01:05 03:10 2.09 8,296 8,445 PROD4 DRILL DRLG P Drilling ahead. CT wt 7K, WOB 1 K, ECD 13.2, 1.4 bpm 185 psi motor work. 03:10 04:10 1.00 8,445 8,445 PROD4 DRILL WPRT P Wiper trip #3. PU wt 28K. PUH to 7680'. RIH and tie in to RA maker, +1.5' correction. 04:10 06:34 2.40 8,445 8,595 PROD4 DRILL DRLG P Drilling ahead. CT wt 6.7K, WOB 1.9, ECD 13.2, 1.35 bpm, 240 ppsi motor work. 06:34 08:04 1.50 8,595 8,595 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26,000 - Perfrom mud swap at the end of the wiper trip. 08:04 09:04 1.00 8,595 8,687 PROD4 DRILL DRLG P BOBD - new mud at bit, ROP 60 fpm, ECD 13.15 Page 25 of 27 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:04 09:34 0.50 8,687 8,687 PROD4 DRILL WPRT T New mud came around and had to change shakers screens, new mud was rolling off the end. - Pull a 200 ft wiper trip. P/U weight 26,000#. 09:34 11:04 1.50 8,687 8,745 PROD4 DRILL DRLG P BOBD - CT weight 5K, circ 4000psi, 1.4 bpm, ECD 13.1, BHP 4184, WHP 100, ROP - 70 11:04 12:28 1.40 8,745 8,745 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26,000 off bottom. 12:28 14:28 2.00 8,895 8,895 PROD4 DRILL DRLG P BOBD - circ 3800, 1.43 bpm, CT weight 5000, WOB 1.1, ROP 68, ECD 13.18, BHP 4180. 14:28 16:16 1.80 8,895 8,895 PROD4 DRILL WPRT P Wiper trip to window - tie in +1 ft. 16:16 18:19 2.06 8,895 9,045 PROD4 DRILL DRLG P BOBD - CT weight 5500, circ - 3890, 1.45 bpm, ECD 13.16, BHP 4170, WOB 1.4, ROP 91, WHP 100. 18:19 19:38 1.33 9,045 9,045 PROD4 DRILL WPRT P Wiper trip to window - CT weight 26K #. RIH to bottom. 19:38 21:27 1.83 9,045 9,195 PROD4 DRILL DRLG P BOBD - CT weight 2.4K, 1.4 bpm, circ 4000 psi, motor work 145 psi, WOB 1.2K. 21:27 23:52 2.42 9,195 9,197 PROD4 DRILL WPRT P Wiper trip - PUH into tubing. Static test for 12.9 ppg KWF. Start test with 4040 psi BHP with TVD gauge depth at 6022'. Observe BHP for 30 min, final BHP 4012 psi. RIH and tie in RA, +2' correction. RIH to TD. 23:52 23:56 0.08 9,197 9,203 PROD4 DRILL DRLG P BOBD - CT weight 2.7K, 1.4 bpm, circ 3900 psi, motor work 260 psi, WOB 1.6K. 10/30/2009 TD AL2 -01 lateral to 9275'. Run liner, and freeze protect well. 00:00 01:00 1.00 9,203 9,275 PROD4 DRILL DRLG P BOBD - CT weight 3.2K, 1.4 bpm, circ 3900 psi, motor work 255 psi, WOB 1.35K. TD lateral at 9275' MD. 01:00 03:00 2.00 9,275 9,275 PROD4 DRILL DLOG P PUH to 7685'. CT weight 30K. RIH and tie in to RA, 0 ft correction. Tag bottom @ 9275' pumping min rate. 03:00 06:30 3.50 9,275 72 PROD4 DRILL TRIP P PJSM. Start pumping 13.1 ppg fluid with alpine beads and laying in while PUH. Continue to displace well with 13.1 ppg fluid in the tubing while POOH. Flag CT EOP 7482' ( -20 above TD) and 5877' ( -20 above TOW) 06:30 07:30 1.00 72 0 PROD4 DRILL SFTY P CT @ surface - flo -test & safety meeting with the crew 07:30 08:30 1.00 0 0 PROD4 DRILL PULD P Lay down BHA and prepare rig floor for liner running assembly 08:30 09:30 1.00 0 0 COMPZ CASING SFTY P Safety / Rig meeting with crews. 09:30 12:00 2.50 0 0 COMPZ CASING PUTB P Start picking up liner 12:00 13:00 1.00 0 0 COMPZ CASING SFTY P Crew change and Rig Safety Meeting 13:00 14:00 1.00 0 1,736 COMPZ CASING PUTB P Finish P/U liner & BHA assembly Page 26 of 27 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:30 2.50 1,736 5,000 COMPZ CASING RUNL P RIH, EOP flag on depth, continue RIH. Tag TD @ 9275' ft. EOP Set down, 10K, Pump 1 bpm, Released off liner. P/U 60 ft CT weight 23K, RIH , string weight changed by 8000 #, looked good. Top of liner at 7583' MD. Stop open EDC. PUH 16:30 19:00 2.50 5,000 5,000 COMPZ CASING DISP P Circulate out KWF with 9.8# brine. Recover 13.1 K- formate KWF at surface. Close EDC. Crew change out. PJSM 19:00 21:00 2.00 5,000 44 COMPZ CASING DISP P PUH to 2500' while filling CT with diesel. With diesel at the nozzle, freeze protect well from 2500' to surface while POOH 21:00 23:45 2.75 44 0 COMPZ CASING PULD P Tag up BHA. Static wellhead pressure 1015 psi. PJSM. Press undeploy BHA. 23:45 00:00 0.25 0 0 DEMOB WHDBO NUND P PJSM. MU jetting nozzle to CT and wash across BOPE and wellhead down the master valve. 10/31/2009 Set BPV. Rigged down BOPE and test tree cap to 4000 psi. CDR2 Rig released from 3H -33 @ 13:00 on 10/31/2009 00:00 01:00 1.00 0 0 DEMOB WHDBO NUND P Completed washing across BOPE and tree down to the mastervalve. Blow down lines. 01:00 02:00 1.00 0 0 DEMOB WHDBO NUND P PJSM. PU and MU BPV lubricator, test to 2000 psi. 02:00 03:30 1.50 0 0 DEMOB WHDBO NUND T Set BVP, would not seal. Pull and inspect, found debris on popit seal. 03:30 04:30 1.00 0 DEMOB WHDBO NUND P Clean seal and re -run BPV. Bleed pressure, BPV holding. 04:30 05:00 0.50 0 0 DEMOB WHDBO NUND P Rig down and lay down lubricator. 05:00 08:00 3.00 0 0 DEMOB WHDBO NUND P Blow down surface lines and WH. 08:00 10:30 2.50 0 0 DEMOB WHDBO DISP P Rig up Foaming system on CT blow -down. Purge CT string, total volume recovered 22.5 bbl out of 29 bbl reel capacity. 10:30 13:00 2.50 0 0 DEMOB WHDBO NUND P Rig down BOP & test tree cap to 4000 psi using diesel. Rig released @ 13:00 hrs from 3H -33 Page 27 of 27 Page l of l • Schwartz, Guy L (DOA) From: Eller, J Gary [ J.Gary.Eller @conocophillips.com] Sent: Tuesday, January 05, 2010 1:18 PM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA); Gantt, Lamar L Subject: RE: 3H -33A / 3H -33AL1 Scope change followup (PTD 209 -103/ 104) Guy — Good eye! Yes, the liner in 3H -33A got stuck high enough that we were unable to sidetrack the AL1 lateral out of the 'A' borehole as originally planned. We were fortunate that we barely had enough room to set a whipstock and kick out of the original 3H -33 casing. In other words, we kicked off the AL1 lateral out of the 3H -33 original completion instead of further down in the 3H -33A lateral. We've had similar occurrences before in the Kuparuk CTD world but it never been suggested that we should notify the AOGCC of such. I'll convey to my CTD counterparts that in the future we should advise the AOGCC if our kickoff point changes substantially from the drilling permit even if the ultimate reservoir target and TD remain unchanged. I agree that renaming the laterals would be a very bad idea. Thanks much and please call if you'd like to discuss more. -Gary From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 05, 2010 10:01 AM To: Eller, J Gary Cc: Maunder, Thomas E (DOA) Subject: 3H -33A / 3H -33AL1 Scope change followup (PTD 209 -103/ 104) Gary, I was reviewing the well records and noticed the liner was set very high in 3H- 33A... to the point the ST aluminum billet ended up in the cement pilot hole. This changed the well completion somewhat for the following lateral (3H- 33AL1). The kickoff point changed less the 500 ft. but caused you to set a whipstock in the pilot hole to start the window. Can you elaborate on this so I can put this in the well file. Technically we could have changed the well names to reflect this but I don't think that would have been a good idea. I don't remember getting any notification on this change but I could be wrong. Be sure and keep me in the loop in the future for well construction changes that come up. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/5/2010 • Page l of l Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 21, 2009 2:00 PM To: Schwartz, Guy L (DOA) Subject: FW: Maximum Anticipated BHP in 3H -33 Laterals Information for the new permits. From: Eller, 3 Gary [ mailto: ).Gary.Eller ©conocophillips.com] Sent: Monday, September 21, 2009 1:58 PM To: Maunder, Thomas E (DOA) Cc: Gantt, Lamar L Subject: Maximum Anticipated BHP in 3H -33 Laterals Tom — Last week I submitted four drilling permits for well 3H -33: A, ALI , AL2, and AL2 -01. I have received some new information which causes me to have to amend some of the information that I gave you. The project summary dated September 16 for those four laterals indicated that the maximum potential formation pressure in the vicinity is 4126 psi based upon a measurement in well 3A -15 in January 2009. Over the weekend we got an updated pressure measurement of 4453 psi in well 3A -15, which represents the new maximum potential formation pressure in the vicinity. Accordingly, the calculated maximum potential surface pressure in the four 3H -33 laterals is 3855 psi assuming a gas gradient to surface. L for the annular preventer) of 4500 psi instead of 4000 psi for the drilling of these four 3H -33 laterals. I apologize for the inaccurate information in the summary document. Please contact me if you need any more information. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907 - 263 -4172 cell: 907 - 529 -1979 fax: 907 - 265 -1535 1/5/2010 • 0 ( , r if . ° J SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 7 PHONE (907) 279 -1433 1 FAX (907) 276-7542 Mr. V. Cawvey Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -33A ConocoPhillips Alaska, Inc. Permit No: 209 -103 Surface Location: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 2456' FSL, 825' FEL, Sec. 12, T12N, RO8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -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) 659 -3607 (pager). Sincerely, ?4 Cathy . Foerster rl Commissioner DATED this day of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • • _ -as -o9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 le. Type of Work: 1b. Current Well Class: Exploratory p evelopment 011 is 1c Specify If well is proposed for. Drill ❑ Re -drill 12 Stretigraphic Test ❑ Service f development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ] ` Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: 12j Blanket U Single Well 11. Weil Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59 - 180 3H 3. Address: 8. Proposed Depth: 12. Fleid/Pooi(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 10050' TVD: 6056' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1069' FNL, 281' FWL, Sec. 12, T12N, R8E, UM ADL 25531 Kuparuk River 011 Pool Top of Productive Horizon: 8. Land Use Permit: 13, Approximate Spud Date: 953' FNL, 443' FEL, Sec. 12, T12N, RO8E, UM 2657 10/5/2009 Total Depth: 9. Acres In Property: 14. Distance to 2456' FSL, 825` FEL, Sec. 12, T12N, RO8E, UM 2660 Nearest Properly: 18300' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 77 feet 16. Distance to Nearest Well Open Surface: x - 498655 y - 6000588 Zone 4 KB Elevation above GL: 36 feet to Same Pool: 3H-11 , 1500' 16. Deviated wells: Kickoff depth: 7685 ft. 17. Maximum Anticipated Pressures in pelt) (see 20 AAC 25.035) Maximum Hole Angle: 96.9° deg Downhole: 4126 pslg Surface: 3473 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom 0.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 1950' 8100' 6085' 10050' 6055' slotted / solid liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 8020' 6396' 7935' 6318' Casing Length Size Cement Volume MD TVD Conductor /Structural 113' 16" 97 sx AS 1 149' 149' Surface 4279' 9-5/8" 840 sxASLite, 178 sx LiteCRETE 4315' 3614' Intermediate Production 7984' 7" 309 sx Class G 8020' 6396' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): . 7740' -7760' 6140' -6158' 20. Attachments: Filing Fee ❑ BOP Sketch E✓' Drilling Program 0 lime v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.060 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact J. Gary Eller @ 263 - 4172 Printed Name V. Cawvey Title Wells Manager Signature N tb s......... . 0 „._ 2 Phone: 265 -6306 Date v Commission Use Only Permit to Drill API Numb Permit Appro I See cover letter NumberpP09/ 60- fQ�� Date: / 8' /) ? for other requirements for, test, or produce bed ane gas hydrates, or gas contained in shales: ,. ,/ Conditions of approval : If box is checked, web may not be used to explore or, t, prod . g Y � LJ 1 45 - 6 6 pS - i o i des f - Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No Other. / /� H2S measures: Yes V No ❑ Directional svy req'd: Yes Er No ❑ 2501) Jodi. APIK T�s AP ROVED BY THE COMMISSION COMMISSIONER DATE: 9- % P (itQ Form 10 -401 (Revised 1/2009) Submit in Duplicate OR!GrNAL j/ / °2y -pj' • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Summary of Operations: Well 311-33 is a 3'/2" tubing x 7" casing producer in the Kuparuk A -sand. Four proposed CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling, the existing A -Sand perfs in 3H -33 will be squeezed with cement to provide a means to kick out of the 7" casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 7725' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 3H -33A sidetrack will exit the 7" casing at 7685' MD and will target the A2 sand south of the existing well with a 2365' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,050' MD wrth a liner top aluminum billet at 8100' MD. The 311-33AL1 lateral will kick off from the aluminum billet at 8100' MD and will target the A3 sand south of the existing well with a 1950' lateral. The hole will be completed with a 2 slotted liner to the TD of 10,050' MD with the final liner top located just inside the 7" casing at 7680' MD. The 3H -33AL2 lateral will exit the 7" casing at 7665' MD via a second mechanical whipstock placed in the cement pilot hole. It will target the A2 sand north of the existing well with a 1610' lateral. The hole will be completed with a 2 slotted liner to the TD of 9275' MD with a liner top aluminum billet at 8050' MD. The 31-1- 33AL2 -01 lateral will kick off from the aluminum billet at 8050' MD and will target the A3 sand north of the existing well with an 1225' lateral. The hole will be completed with a 2W slotted liner to the TD of 9275' MD with the final liner top located just inside the 3'/2" tubing at 7560' MD. CTD Drill and Complete 3H -33: October/November 2009 Pre -Rig Work 1. Test packoffs — T & IC. 2. Positive pressure and drawdown tests on MV, SV, & SSSV. 3. DGLV's, load tbg & IA. MIT -IA. MIT -OA. 4. Obtain updated static BHP on A -sand 5. Shoot tubing punches in 3V2" tubing tail at 7575' MD. 6. Plug the A -Sand perfs with cement up to 7575' MD. 7. RU slickline. Tag cement top. 8. Prep site for Nabors CDR2 -AC. Rig Work �„. 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. s 3l 2. 3H -33A Lateral (A2 sand, south) 3 01 a. Drill 2.74" high -side pilot hole through cement to 7725 MD'. b. Drift pilot hole with whipstock dummy. c. Set 3'/2" monobore whipstock at 7685' MD with high -side orientation. d. Mill 2.74" window with high -side orientation at 7685' MD. e. Drill 2.70" x 3" bi- center lateral to TD of 10,050' MD. t' f. Run 2%" slotted liner with an aluminum liner -top billet from TD up to 8100' 1 3. 3H -33AL1 Lateral (A3 sand, south) 207- to 3/6 "O a. Kick off of the aluminum billet at 8100' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,050' MD. c. Run 2%" slotted liner from TD up to 7680' MD, up inside the 7" casing Page 1 of 4 9 e`' RR L. September 16, 2009, FINAL l �, • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling 4. 3H -33AL2 Lateral (A2 sand, north) a. Set 31/4" monobore whipstock in cement pilot hole at 7665' MD with high -side orientation. b. Mill 2.74" window with high -side orientation at 7665' MD. c. Drill 2.70" x 3" bi- center lateral to TD of 9275' MD. d. Run 2%" slotted liner with an aluminum liner -top billet from TD up to 8050' 5. 3H- 33AL2 -01 Lateral (A3 sand, north) a. Kick off of the aluminum billet at 8050' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9275' MD. c. Run 2 slotted liner from TD up to 7560' MD, up inside the 31/4" tubing tail 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Obtain static BHP 2. Run GLVs. 3. Return well to production. Mud Program: • Will use chloride -based Biozan brine or used drilling mud (8.6 ppg) for milling operations, and chloride - based Flo -Pro mud ( -10.0 ppg) for drilling operations. There is a SCSSV installed in 3H -33, so we should not have to kill the well to deploy 2%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU IR Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: .. • 3H -33A: 2 ", 4.7 #, L -80, ST -L slotted/solid liner from 8100' MD to 10,050' MD • 311- 33AL1: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 7680' MD to 10,050' MD • 3H- 33AL2: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 8050' MD to 9275' MD • 3H- 33AL2 -01: 2 ", 4.7 #, L -80, ST -L slotted/solid liner from 7560' MD to 9275' MD Existing Casing/Liner Information Surface: 9% ", L -80, 40 ppf Burst 5750 psi; Collapse 3090 psi Production: 7 ", L -80, 26 ppf Burst 7240 psi; Collapse 5410 psi Well Control: • Two well bore volumes ( -200 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. ciSO0 pS • Pipe rams, blind rams and the CT pack off will A be ressure tested to 250 psi and to.49f psi. Maximum potential surface pressure in 3H -33 is34- 73 ag?urfififg a gas gradient to surface and maximum potential pi p formation pressure. Maximum potential formation pressure is based on the highest recent measured b ott o hol pressur in the vicinity, which is 4126 psi at 6156 TVD (i.e. 12.9 ppg) in offset injector 3A- �' et 13 i n January 2009. Well 3A -15 had been shut -in several months when this survey was taken. 4- • The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 4 i t i\ I GI N A L September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 3H -33A, plan #1 2. 3H- 33AL1, plan #2 3. 31-1- 33AL2, plan #1 4. 3H- 33AL2 -01, plan #2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 3H -33 CTD southern laterals (A & AL1): 18,300' to property line, —1500' from well 311-11 • 311-33 CTD northern laterals (AL2 & AL2 -01): 18,300' to property line, 1200' from well 3H -14B Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 3H-33 was taken June 2009 after a 72 -hour shut -in, which measured reservoir pressure of 3175 psi at 6010' TVD, corresponding to 10.2 ppg EMW. Expect to encounter increasing pressure as the laterals are drilled away from the mother well due to anticipated interaction with injection well 3A -15. 3A -15 was recently shut in to allow the area to de- pressurize. The most recent pressure survey in 3A -15 showed 4126 psi at 6156 TVD (12.9 ppg EMW) as of January 2009. 44- -Z,- o? Hazards 4;3 41 3A -is CHAS 4"1 3 p s • Lost circulation is not expected to be particularly troublesome. Expect to encounter increasing pressure as the laterals are drilled away from the mother well. • Over- pressured zones are a potential hazard in 311-33. Even with 10.0 ppg mud, choke pressure will have to be maintained while drilling, both for maintaining well control and borehole stability. Use of the SSSV to deploy slotted liner should eliminate the need to spot heavy kill weight fluid, but if the SSSV fails then completion fluids in excess of 13.0 ppg will be needed to kill the well. • Shale stability is a potential problem, particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 60° hole angle, and by holding a constant 13.1 ppg EMW on the formation throughout drilling operations. • Well 3H-33 has 115 ppm H as measured on 5/6/06. Well 3H -17 is located 12.5' to the right side and 3H -18 is 12.5' to the left side of the 3H -33 surface location. Neither 3H -17 nor 3H -18 has any measured H since they are both injectors. The maximum H level on the pad is 390 ppm from well 311-16 (2/24/09), which is 38' to the right of 3H -33. All H monitoring equipment will be operational. Page 3 of 4 September 16, 2009, FINAL • • KRU 3H -33A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 3H-33 has a SCSSV, so the well should not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Maximum expected reservoir pressure (i.e. formation pressure encountered from originally drilled 311- 33): 4054 psi at 7685' MD (6091' TVD), or 12.8 ppg EMW. • Expected annular friction losses while circulating: 507 psi (assuming friction of 66 psi /1000 ft due to the 3'/2" tubing) • Planned mud density of 10.0 ppg equates to 3167 psi hydrostatic bottom hole pressure at 6091' TVD • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3674 psi or 11.6 ppg EMW without holding any additional surface pressure. This alone is insufficient to overbalance expected formation pressure in 311-33, so as much as 380 psi choke pressure will be required while drilling to maintain overbalance. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, —900 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Page 4 of 4 fl R t G I N t September 16, 2009, FINAL • • v , "" C onochilhips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3H Pad 3H -33 3H -33A Plan: Plan 1, 3H -33A Standard Planning Report 11 September, 2009 MAI EIAKER HUGHES ORIGINAL • • p S iftki ConocoPht ips P a n Planning R I p l ort BA IER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference:. Well 31 Company: _ ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 3H -33 Rig © 76.85ft (D15 (4025 +36.1)) Site: Kuparuk 3H Pad North Reference: True Well 3H -33 Survey Calculation Method: t Minimum Curvature Wellborn: 3H -33A Design: Plan 1, 3H -33A i 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 Site Kuparuk 3H Pad Site Position: Northing: 6,000,110.73ft Latitude: 70° 24' 41.531 N From: Map Easting: 498,655.44ft Longitude: 150° 0' 39.416 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Welt 3H -33 Well Position +N /-S 0.00 ft Northing: 6,000,588.21 ft Latitude: 70° 24' 46.228 N +E/ -W 0.00 ft Easting: 498,655.30 ft Longitude: 150° 0' 39.423 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 36.10ft Wellbore 3H - 33A Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nTI BGGM2009 11/4/2009 17.26 79.81 57,352 Design Plan 1, 3H -33A Audit Notes: I Version: Phase: PLAN Tie On Depth: 7,675.00 Vertical Sectiorc Depth From (TVD) +NI-S +E/-W Direction (ft) (ft) (ft) r) i - 36.10 0.00 0.00 183.00 Plan Sections Measured TVD Below Dogleg Build Turn . Depth Inclination Azimuth System +NI-S +E/ -W Rate Rate Rate TFO (ft) (°) ( °) (ft) (ft) (ft) (° /100ft) (° /100ft); (°MOOft) (°) Target 7,675.00 26.91 91.46 6,005.26 324.30 4,294.90 0.00 0.00 0.00 0.00 7,685.00 26.76 91.42 6,014.18 324.18 4,299.42 1.51 -1.50 -0.40 - 173.15 7,705.00 28.56 91.42 6,031.90 323.95 4,308.70 9.00 9.00 0.00 0.00 7,805.00 73.56 91.42 6,093.15 322.07 4,384.47 45.00 45.00 0.00 0.00 7,865.92 93.50 110.46 6,100.04 310.50 4,443.29 45.00 32.73 31.25 45.00 7,960.92 93.59 153.29 6,093.88 248.69 4,512.25 45.00 0.09 45.09 88.50 8,185.92 93.88 180.35 6,078.96 32.12 4,562.96 12.00 0.13 12.03 88.50 ■ 8,285.92 96.88 192.02 6,069.55 -66.68 4,552.28 12.00 3.01 11.67 75.00 8,420.92 90.14 206.79 6,061.25 - 193.32 4,507.60 12.00 -5.00 10.94 114.00 8,620.92 87.69 182.91 6,065.09 - 385.19 4,456.72 12.00 -1.22 -11.94 264.00 8,720.92 87.74 170.90 6,069.10 - 484.79 4,462.11 12.00 0.05 -12.01 270.00 9,070.92 90.33 212.83 6,075.28 - 819.63 4,391.73 12.00 0.74 11.98 87.00 9,420.92 91.58 170.84 6,069.19 - 1,154.51 4,321.55 12.00 0.36 -12.00 272.00 9,770.92 91.17 212.85 6,060.38 - 1,489.33 4,251.32 12.00 -0.12 12.00 90.00 10,050.00 90.98 179.35 6,054.98 - 1,753.61 4,175.03 12.00 -0.07 -12.00 270.00 9/11/2009 6 :49 :10AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips rsav Con©coPhillips Planning Report BAKER Alaska H UGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H Company: L, ConocoPhillips(Alaska) Inc. TVD Reference: - Mean Sea Level Project Kuparuk River Unit MD Reference: - 3H -33 Rig @ 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: True Well: 3H -33 Survey Calculation Method: _ Minimum Curvature Wellborn: : 3H - 33A Design: Plan 1, 3H - 33A P lanned Survey Measured TVD Below Vertical Dogleg To olface 4 Map Map Depth_ Inclination Azimuth Sys +NJ-s +E/ w ' Section Rate Azlmutis . Northing - ng (fib ( °) (°) (ft) 0t) (ft) (ft) (°Hoof:) r) (ft) (ft) _ - 7,675.00 26.91 91.46 6,005.26 324.30 4,294.90 - 548.63 0.00 0.00 6,000,911.70 502,949.83 TIP 3H - 33 1 7,685.00 26.76 91.42 6,014.18 324.18 4,299.42 - 548.75 1.51 - 173.15 6,000,911.59 502,954.34 KOP I 7,700.00 28.11 91.42 6,027.50 324.01 4,306.32 - 548.94 9.00 0.00 6,000,911.41 502,961.25 7,705.00 28.56 91.42 6,031.90 323.95 4,308.70 - 549.01 9.00 0.00 6,000,911.36 502,963.621 End of DLS 9 7,800.00 71.31 91.42 6,091.64 322.19 4,379.70 - 550.97 45.00 0.00 6,000,909.58 503,034.62 7,805.00 73.56 91.42 6,093.15 322.07 4,384.47 - 551.10 45.00 0.00 6,000,909.46 503,039.39 4 ; 7,865.92 93.50 110.46 6,100.04 310.50 4,443.29 - 542.62 45.00 45.00 6,000,897.88 503,098.20 5 7,900.00 93.77 125.82 6,097.87 294.51 4,473.19 - 528.22 45.00 88.50 6,000,881.89 503,128.09 7,960.92 93.59 153.29 6,093.88 248.69 4,512.25 - 484.50 45.00 89.48 6,000,836.06 503,167.14 End of DLS 45 8,000.00 93.70 157.99 6,091.40 213.17 4,528.33 - 449.87 12.00 88.50 6,000,800.54 503,183.21 8,100.00 93.87 170.02 6,084.77 117.43 4,555.77 - 355.70 12.00 88.80 6,000,704.81 503,210.64 8,185.92 93.88 180.35 6,078.96 32.12 4,562.96 - 270.88 12.00 89.59 6,000,619.51 503,217.81 7 8,200.00 94.31 181.99 6,077.95 18.08 4,562.68 - 256.85 12.00 75.00 6,000,605.47 503,217.52 8,285.92 96.88 192.02 6,069.55 -66.67 4,552.28 - 171.67 12.00 75.12 6,000,520.73 503,207.11 8 8,300.00 96.19 193.57 6,067.95 -80.31 4,549.18 - 157.88 12.00 113.99 6,000,507.09 503,204.01 8,400.00 91.19 204.51 6,061.49 - 174.46 4,516.66 -62.16 12.00 114.18 6,000,412.95 503,171.47 I I 8,420.92 90.14 206.79 6,061.25 - 193.32 4,507.60 -42.85 12.00 114.88 6,000,394.10 503,162.41 9 8,500.00 89.15 197.35 6,061.74 - 266.52 4,477.93 31.80 12.00 -96.00 6,000,320.91 503,132.73 8,600.00 87.93 185.41 6,064.30 - 364.34 4,458.24 130.52 12.00 -95.94 6,000,223.10 503,113.02 8,620.92 87.69 182.91 6,065.09 - 385.19 4,456.72 151.42 12.00 -95.64 6,000,202.25 503,111.50 10 8,700.00 87.72 173.41 6,068.27 - 464.07 4,459.26 230.06 12.00 -90.00 6,000,123.38 503,114.03 8,720.92 87.74 170.90 6,069.10 - 484.79 4,462.11 250.59 12.00 -89.62 6,000,102.67 503,116.88 11 8,800.00 88.26 180.38 6,071.86 - 563.49 4,468.12 328.88 12.00 87.00 6,000,023.97 503,122.87 8,900.00 88.99 192.36 6,074.26 - 662.67 4,457.05 428.49 12.00 86.67 5,999,924.81 503,111.78' 9,000.00 89.77 204.33 6,075.34 - 757.40 4,425.63 524.75 12.00 86.38 5,999,830.09 503,080.351 9,070.92 90.33 212.83 6,075.28 - 819.63 4,391.73 588.66 12.00 86.25 5,999,767.87 503,046.44 !; ■ 12 9,100.00 90.45 209.34 6,075.09 - 844.53 4,376.73 614.31 12.00 -88.00 5,999,742.98 503,031.43 9,200.00 90.85 197.35 6,073.96 - 936.17 4,337.18 707.89 12.00 -88.02 5,999,651.36 502,991.87 9,300.00 91.21 185.35 6,072.15 - 1,034.02 4,317.54 806.64 12.00 -88.16 5,999,553.52 502,972.22 9,400.00 91.52 173.35 6,069.76 - 1,133.80 4,318.67 906.22 12.00 -88.38 5,999,453.75 502,973.33 9,420.92 91.58 170.84 6,069.19 - 1,154.51 4,321.55 926.76 12.00 -88.66 5,999,433.03 502,976.20 13 9,500.00 91.56 180.33 6,067.02 - 1,233.24 4,327.63 1,005.06 12.00 90.00 5,999,354.32 502,982.27 9,600.00 91.47 192.34 6,064.37 - 1,332.41 4,316.62 1,104.67 12.00 90.26 5,999,255.16 502,971.24 9,700.00 91.32 204.34 6,061.92 - 1,427.13 4,285.22 1,200.90 12.00 90.58 5,999,160.45 502,939.84 9,770.92 91.17 212.85 6,060.38 - 1,489.33 4,251.32 1,264.79 12.00 90.87 5,999,098.26 502,905.92 14 9,800.00 91.17 209.36 6,059.78 - 1,514.22 4,236.30 1,290.43 12.00 -90.00 5,999,073.38 502,890.90 9,900.00 91.13 197.36 6,057.77 - 1,605.84 4,196.74 1,383.99 12.00 -90.07 5,998,981.78 502,851.32 10,000.00 91.04 185.36 6,055.86 - 1,703.68 4,177.09 1,482.73 12.00 -90.31 5,998,883.95 502,831.661 9/11/2009 6 :49 :10AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL • ConocoPhillips Conoco Phillips Planning Report BAKER Alaska t l�GHES H Database: , EDM Alaska Prod v16 Local Co- ordinate Reference: Well 3H - 33 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference 3H -33 Rig ,@ 76.85ft (D15 (40.75 +36.1)) Site: Kuparuk 3H Pad North Reference: True Weil: 3H - 33 Survey Calculation Method: = Minimum Curvature Welibore: 3H -33A Design; Plan 1, 3H -33A Planned Survey Measured TVD Below Vertical : - Dogleg ` Toolface Map Map DOP° tnciination Azimuth System +WS +E/-W : Section Rate Azimuth Northing r . Fasting (ft) (1 (1 (it) (ft) (ft) (ft) ( °MOOft) r) (ft) (ft) 10,050.00 90.98 179.35 6,054.98 - 1,753.61 4,175.03 1,532.70 12.00 -90.54 5,998,834.03 502,829.59 TD- 2318" Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +WS +E/ -W Northing Easting Shape (°) _ ( •) ( ( ( (ft) (ft) Latitude Longitude 3H -33 A2 S t5.1 (copy 0.00 0.00 6,075.15 - 812.82 4,401.42 5,999,774.68 503,056.13 70° 24' 38.221 N 149° 58' 30.413 W - plan misses target center by 4.58ft at 9060.31 ft MD (6075.34 TVD, - 810.64 N, 4397.39 E) I - Point 1 31 - 1-33 A2 S t4.1 (copy 0.00 0.00 6,065.15 - 376.77 4,470.35 6,000,210.67 503,125.14 70° 24' 42.509 N 149° 58' 28.385 W - plan misses target center by 13.1 Oft at 8611.55ft MD (6064.73 TVD, - 375.84 N, 4457.29 E) - Point 3H -33 A2 S t6.1 (copy 0.00 0.00 6,055.15 - 1,743.94 4,188.54 5,998,843.69 502,843.10 70° 24' 29.065 N 149° 58' 36.668 W - plan misses target center by 13.53ft at 10039.78ft MD (6055.16 TVD, - 1743.39 N, 4175.03 E) - Point 3H -33 A2 S t1.1 (copy 0.00 0.00 6,110.15 240.28 4,460.26 6,000,827.66 503,115.15 70° 24' 48.578 N 149° 58' 28.670 W - plan misses target center by 50.74ft at 7932.31ft MD (6095.73 TVD, 272.54 N, 4496.66 E) - Point 13H-33 A2 S t3.1 (copy 0.00 0.00 6,061.15 -83.74 4,529.31 6,000,503.66 503,184.14 70° 24' 45.391 N 149° 58' 26.651 W - plan misses target center by 19.40ft at 8310.16ft MD (6066.90 TVD, -90.12 N, 4546.71 E) - Point ■ 3H -33 A2 S t2.1 (copy 0.00 0.00 6,079.15 28.27 4,540.30 6,000,615.66 503,195.14 70° 24' 46.492 N 149° 58' 26.327 W - plan misses target center by 22.63ft at 8190.21ft MD (6078.66 TVD, 27.85 N, 4562.92 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ") ( ") : 4,315.06 3,532.90 9 5/8" 9 -5/8 12 -1/4 10,050.00 6,054.98 2 3/8" 2 -3/8 3 9/11/2009 6:49 :10AM Page 4 COMPASS 2003.16 Build 69 ? tf-^,tAiA ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Pr v16 Local Co- ordinate Reference: Well 3H - 33 Company ConocoPhiilips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3H 33 Rig @ 7685 (40.75 +36.1)) Site: Kuparuk 31-1 Pad North Referen True Well: 3H - 33 Survey Calculation Method. 1' Minimum Curvature Welibore: 3H -33A Deaigo: Plan 1, 3H -33A Plan Annotations- = Measured Vertical Local` Coordinates Depth Depth- +W3 +LJailt (ft) (f() (ft) (ft) Comment 7,675.00 6,005.26 324.30 4,294.90 TIP 3H -33 7,685.00 6,014.18 324.18 4,299.42 KOP 7,705.00 6,031.90 323.95 4,308.70 End of DLS 9 7,805.00 6,093.15 322.07 4,384.47 4 7,865.92 6,100.04 310.50 4,443.29 5 7,960.92 6,093.88 248.69 4,512.25 End of DLS 45 8,185.92 6,078.96 32.12 4,562.96 7 8,285.92 6,069.55 -66.67 4,552.28 8 8,420.92 6,061.25 - 193.32 4,507.60 9 8,620.92 6,065.09 - 385.19 4,456.72 10 8,720.92 6,069.10 - 484.79 4,462.11 11 9,070.92 6,075.28 - 819.63 4,391.73 12 9,420.92 6,069.19 - 1,154.51 4,321.55 13 -1,489.33 4,251.32 14 9,770.92 6,060.38 10,050.00 6,054.98 - 1,753.61 4,175.03 TD I 9/11/2009 6.49:10AM Page 5 COMPASS 2003.16 Build 69 r) D I q11 Ai _ A:imum.MTmeNwm WELLBORE DETAILS: 3H-33A REFERENCE INFORMATION ^ Project: Kuparuk River Unit Ma g neac Norm 21.es° Site: Kuparuk 3H Pad magnetic noId Parent Wellbore: 3H Co.ordinate (WE) Reference: Wel 31133, True North Well: 3H St rength 57642 n Vertical (TVD) Reference. Mean Sea Level B R R Ti on M D: 7675.00 Wellbore: 3H-33A Angie mar Date. Reference: Slot - (0.009.0.00E) [} D re 111420 • Measured De Reference; 3H-33 Rig u va lore (015 (40 +36.1)) HUGHES CO 1`A 1� �p Plan Plan 1, 3H (3H Do . 1V „ ■Y■ Calculation Method. Minimum Curvature 800 WELL DETAILS: 3H -33 600 TIP 3H -33 __KOP.. End of DLS 9 Ground Level: 36.10 +NI -S +E / -W Northing Easting Latittude Longitude Slot 0,00 0.00 6000588.21 498655.30 70° 24' 46.228 N 150° 0' 39.423 W 400 . . 311-33/311-33 End of DLS 45 SECTION DETAILS ANNOTATIONS 200 4 5 + Sec MD Inc Azi TVD +NI -S +E) -W OLeg TFace VSec Ta get Annotation 7 1 7675.00 26.91 91.46 6005.26 324.30 4294.90 0.00 0.00 - 548.63 TIP 3H-33 0 2 7685.00 26.76 91.42 6014.18 324.18 4299.42 1.51 - 173.15 - 548.75 KOP 3 7705.00 28.56 91.42 6031.90 323.95 4308.70 9.00 0.00 - 549.01 End of DLS 9 p _200 8 4 7805.00 73.56 91.42 6093.15 322.07 4384.47 45.00 0.00 - 551.10 4 9 5 7865.92 93.50 110.46 6100.04 310.50 4443.29 45.00 45.00 - 542.62 5 10- 6 7960.92 93.59 153.29 6093.88 248.69 4512.25 45.00 88.50 -484.50 End of DLS 45 0 - 400 . 7 8185.92 93.88 180.35 6078.96 32.12 4562.96 12.00 88.50 - 270.88 7 11 8 8285.92 96.88 192.02 6069.55 -66.68 4552.28 12.00 75.00 - 171.66 8 - 600 9 • 8420.92 90.14 206.79 6061.25 -193.32 4507.60 12.00 114.00 -42.85 9 10 8620.92 87.69 182.91 6065.09 - 385.19 4456.72 12.00 264.00 151.42 10 _Rog 12. 11 8720.92 87.74 170.90 6069.10 - 484.79 4462.11 12.00 270.00 250.59 11 o 12 9070.92 90.33 212.83 6075.28 - 819.63 4391.73 12.00 87.00 588.66 12 _Inon 13 9420.92 91.58 170.84 6069.19 - 1154.51 4321.55 12.00 272.00 926.76 13 14 9770.92 91.17 212.85 6060.38 - 1489.33 4251.32 12.00 90.00 1264.79 14 15 10050.00 90.98 179.35 6054.98 - 1753.61 4175.03 12.00 270.00 1532.70 TD 7 -1200 1 ••5 - ---- -. _._.. - - -- -- -..__.._ _._--- - - - - -- 0 rn - ...� - 1400 . 14 III •�,i d -1600 3H -33/3H -33A -1800 TD *, -2000 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 West( -) /East( +) (200 ft/in) 5760 L, 5820- 5880 TIP 3H -33 KOp....... 5940 . -... .. 0 End of DLS 9 la, 7D 6000- 6060 4 +. Q g 9 10 Il 14 cd rn 6120 + : 7 12 13 ',. 4 3H -33/3H -33A 9 c a. 6180 End of DLS 45 03 6240- 6300- ., .. 3H33/3H -33 6360 .. ,, _. 6420..... _.. _. .. _. _. __ -600 -540 -480 -420 -360 -300 -240 -180 -120 -60 0 60 120 180 240 300 360 420 480 540 600 660 720 780 840 900 960 1020 1080 1140 1200 1260 1320 1380 1440 1500 1560 1620 1680 1740 Vertical Section at 183.00° (60 ft/in) AzimangroTrue Norm WELLBORE DETAILS: 3H -33A REFERENCE INFORMATION �"` Project: Kuparuk River Unit Mesaetrc Bonn: zias° Site: Kuparuk 3H Pad McOaeeo field Parent Wellbore: 3H -33 Co-ordinale (WE) Reference: We0 3H-33, True North Well: 3H Saenrh 57842.3an7 V ertical (TVO) Reference: 3H33 Rg @ 76.850 0315 (40.75 +36.1)) BAKER ,��+t ` Wellbore: 3H-33A oip Angie 130.87° Tie on MD: 7675.00 Section(VS) Reference: Slot- (0.00N, 0.00E) G ��,Fr rd �T �� � +�S Plan: Plan 1, 3H-33A (3H- 33/3H -33A) nnoael BC0M20o9 Measured Depth Reference: 3H33 Rg @ 76.85ft (D15140.75+36.1)) HUGHE Calculation Method: Minimum Curvature 20001 1800 .. ,.... .. '., ... ;... ._. .. 1600. 1400... . • 1200 ', :, 1000 _. _ _..... _.__ _... .. _ _....... _._... _ 800 -. • 600 • /^''�j 400{. _ Yr "1"' -� 200- .. + :H- 33/3H -33. /"� 0 - , 11 11= t1 -II -200,.___ ._ _ O -400 . — -`. ', N + -600 › _... .. .... -. 0 -800 -. • 1 000_ .. 5 - 1200 _ - • - 1400.. ',, • • - 1600-' • 3 3H-33 /31-1-33A ... ....... 6132 -1800 .. ... -2000 - ,. -2200 -2400- • : : - 2600_. ..0,.-, _ ... -2800- .. 311- 04/311 -04 - , ,. - 3000 .. ',,.. - 3200-' - 3400 -. .. 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 . , . r . ■ _ — -;0 , ...- .-�, -6 6000 62 00 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 3H33 Rig @ 76.85ft (315 (40.75 +36.1)) West( -) /East( +) (200 ft/in) • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing I 1 Lubricator Riser Annular/ Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator J L above BHA rams 1 r ' Choke 1 2 -3/8" Pipe / Slip (BHA) Choke Equalize Manifold 2 -3/8" Pipe / Slip (BHA) J Lp�p�� Kill / ���� 17QDQ • • 1r Bl / Shear 2" Pipe / Slip (CT) Choke 2 i Swab Valves Wing Valves i I ® ® � ®i Tree Flow Cross Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi X Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union ORJGINAL 3H -33 Proposed CTD Sidetrack 3 -1/2" Camco TRMAXX -5E SSSV at 2110' MD (2.81 X- profile) 3 -1/2 ", 9.3 #, L -80 EUE 8rd Tubing to surface 16 ", 62 #, H-40 conductor .�_ 3.112" Camco MMG gas lift mandrels of 2735', 4444', 5710', 6789', & 7453' shoe 149' MD. 9-5/8", 40#,. L -80 casing J _— shoe at 4315' MD • cD / 3 ,11,,...-we X- nipple at 7504' MD (2.813" min ID) C ) Baker Premier packer at 7547' MD. No sealbore or seal assembly. r Camco D- nipple @ 7594 MD (2.75" min ID, No -Go) Nipple milled out to 2.80" ID C 3-1/2" tubing tail at 7606' MD (7602' ELM) � ""' ' Top of cement at tubing tail at r ‹ ^„ r --- 7606' MD ;w M KOP #2 at7665'MD KOP #1 at 7685' MD % AL2 -01 Lateral (A3 sand, north) �` �, — — TD = 9275' • Baker monobore whipstock trays on r /i — Liner top at 7560' openhole anchors at 7665' & 7685' _ 7 V AL2 Lateral (A2 sand, borth) 2.80" pilot hole in cement drilled to — — — — D TD = 9275' 7725' MD MEI Billet at 8050' AL1 Lateral (A3 sand, south) A -sand parrs (sgz'd) \ /f. TD = Liner op at top at ' 7680'. 2 i 7740' - 7760' MD . �y \ Sidetrack (A2 sand, south) c �� ) TD = 10,050' 7", 264, L -80 casing Billet at 8100' shoe at 8020' MD _....#111 � _ ■ II \ - )4 t . p J� ^Nc JC Alaska Department of Natural sources Land Administration System . Page 1 of l Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources i Alaska DNR Case Summary File Type: ADL File Number: 25531 & Printable Case File Summary See Township, Range, Section and Acreage? (f) Yes t No New Search LAS Menu i Case Abstract 1 Case Detail 1 Land Abstract File: ADL 25531 Ma: Search for Status Plat Updates As of 09/23/2009 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 01/28/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/07/2005 Case Subtype: NS NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED Meridian: U Township: 012N Range: 008E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 008E Section: 02 Section Acres: 640 Meridian: U Township: 012N Range: 008E Section: 11 Section Acres: 640 Meridian: U Township: 012N Range: 008E Section: 12 Section Acres: 640 Legal Description 11 -02 -1964 * * * SALE NOTICE LEGAL DESCRIPTION * * * U -3 -5 -1 ALL SECTION 1, T12N, R8E, UM 640 ALL SECTION 2, " " " 640 ALL SECTION 11, " " " 640 ALL SECTION 12, " " " 640 CONTAINING 2,560 ACRES, MORE OR LESS. 11 -10 -1982 * * * PARTICIPATING AREA LEGAL DESCRIPTION * * http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2553... 9/23/2009 • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:48 AM To: Ramirez, Darlene V (DOA) Subject: Re: 209 -103 Approved Sent from my iPhone On Sep 25, 2009, at 4:02 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209092513481.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209092513481.pdf > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C- 209092513481.pdf> 1 • Page 1 of 1 Schwartz, Guy L (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 21, 2009 2:00 PM To: Schwartz, Guy L (DOA) Subject: FW: Maximum Anticipated BHP in 3H -33 Laterals Information for the new permits. From: Eller, J Gary [ maitto: J.Gary.Eller @conocophillips.com] Sent: Monday, September 21, 2009 1:58 PM To: Maunder, Thomas E (DOA) Cc: Gantt, Lamar L Subject: Maximum Anticipated BHP in 3H -33 Laterals Tom — Last week I submitted four drilling permits for well 3H -33: A, AL1, AL2, and AL2 -01. I have received some new information which causes me to have to amend some of the information that I gave you. The project summary dated September 16 for those four laterals indicated that the maximum potential formation pressure in the vicinity is 4126 psi based upon a measurement in well 3A -15 in January 2009. Over the weekend we got an updated pressure measurement of 4453 psi in well 3A -15, which represents the new maximum potential formation pressure in the vicinity. Accordingly, the calculated maximum potential surface pressure in the four 3H -33 laterals is 3855 psi assuming a gas gradient to surface. I recommend a BOPE test pressure (except for the annular preventer) of 4500 psi instead of 4000 psi for the drillingarthese four 31-1-33 laterals. I apologize for the inaccurate information in the summary document. Please contact me if you need any more information. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907 -263 -4172 cell: 907- 529 -1979 fax: 907 - 265 -1535 9/21/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME x<ea i9 PTD# v P09 /03 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: i�/,®, ,eV Z POOL: /(' Z,V.4ie az AvZ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well - (If last two digits in Permit Nc — , API No. 5C 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. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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 program. Rev: 1/11/2008 WELL PERMIT CHEC LIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 - Well Name: KIJPARUK RIV UNIT 3H -33A Program DEV Well bore seg ❑ PTD #: 2091030 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary 6 Well located proper distance from other wells YeS 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate_ bond in force Yes _ Blanket Bond # 59 -52 -180. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/23/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 1 • 5 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j,1.A),(j2.A -D) NA 18 Conductor strintprovided NA Conductor set in 3H -33 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 3H -33 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented to GL in 3H -33 21 CMT vol adequate to tie-in long string to surf csg NA Production casing set in 3H -33 22 CMT will cover all knownproductive horizons No OH slotted liner cornpletion_(all new laterals) 23 Casing designs adequate for C, T, B & permafrost _ Yes .24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 309 -331 Plug perfs sundry 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Closest wellbore is P & A portion of 3H -33 & paths diverge 27 If diverter required, does it meet regulations NA wellhead in place, BOP stack . on top of tree. Appr Date 1 28 Drilling fluid program schematic & equip list adequate Yes Max formation press is 4126 psi (12.9ppg)Will drill with Managed Pressure GLS 9/24/2009 29 BOPEs, do they meet regulation Yes will us 10ppg mud combined with surface pressure and Wellbore friction to balance fm pressure. 30 BOPEpress rating appropriate; test to (put psig in comments) Yes MASP = 3855 psi ... will test BOP to 4500 psi 31 Choke_ manifold complies w /API RP -53 (May $4) Yes • 32 Work will occur without operation shutdown Yes _ 33 Is presence of H2S gas probable Yes H2S reported at 3H pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA- 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S for well 3H -16 was 390ppm (2/24/09). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/23/2009 38 Seabed condition survey _(if oft-shore) NA [ 39 Contact name /phone for weekly_progress reports_[exploratory only] No Geologic Engineering Public Commissioner: to Comissio er: L � % a te Commissioner Date /976 ro . C � /9
